SECURITIES AND EXCHANGE COMMISSION
WASHINGTON, D.C. 20549
FORM 10-K
[X] ANNUAL REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE
SECURITIES EXCHANGE ACT OF 1934
For the Fiscal Year Ended December 31, 2000
Commission File Number 33-82034
INDIANTOWN COGENERATION, L.P.
(Exact name of co-registrant as specified in its charter)
Delaware 52-1722490
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(State or other jurisdiction of (I.R.S. Employer Identification Number)
incorporation or organization)
Indiantown Cogeneration Funding Corporation
(Exact name of co-registrant as specified in its charter)
Delaware 52-1889595
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(State or other jurisdiction of (I.R.S. Employer Identification Number)
incorporation or organization)
7500 Old Georgetown Road, 13th Floor
Bethesda, Maryland 20814-6161
(Registrants' Address of principal executive offices)
(301)-718-6800
(Registrants' telephone number, including area code)
Indicate by check mark whether the registrant (1) has filed all reports required
to be filed by Section 13 or 15(d) of the Securities Exchange Act of 1934 during
the preceding 12 months (or for 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. [ X ] Yes [ ] No
Indicate by check mark if disclosure of delinquent filer 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 March 29, 2001, there were 100 shares of common stock of Indiantown
Cogeneration Funding Corporation, $1 par value outstanding.
Indiantown Cogeneration, L.P.
Indiantown Cogeneration Funding Corporation
PART I Page Number
Item 1 Business............................................... 1
Item 2 Properties............................................. 7
Item 3 Legal Proceedings...................................... 7
Item 4 Submission of Matters to a Vote
of Security Holders.................................... 9
PART II
Item 5 Market for the Registrant's Common
Stock and Related Security Holder Matters.............. 10
Item 6 Selected Financial Data................................. 10
Item 7 Management's Discussion and Analysis of
Financial Condition and Results of Operations........... 11
Item 7A Qualitative and Quantitative Disclosures About
Market Risk............................................. 15
Item 8 Financial Statements and Supplementary Data............. 16
Item 9 Changes in and Disagreements with Accountants
on Accounting and Financial Disclosure.................. 39
PART III
Item 10 Directors and Executive Officers........................ 40
Item 11 Remuneration of Directors and Officers.................. 41
Item 12 Security Ownership of Certain Beneficial Owners
and Management................................... 41
Item 13 Certain Relationships and Related Transactions.......... 41
PART IV
Item 14 Exhibits, Financial Statement Schedules and
Reports on Form 8-K..................................... 42
Signatures.............................................. 45
Item 1 BUSINESS
Indiantown Cogeneration, L.P. (the "Partnership") is a special purpose
Delaware limited partnership formed on October 4, 1991. The Partnership was
formed to develop, construct, and operate an approximately 330 megawatt (net)
pulverized coal-fired cogeneration facility (the "Facility") located on an
approximately 240 acre site in southwestern Martin County, Florida. The Facility
produces electricity for sale to Florida Power & Light Company ("FPL") and
supplies steam to Caulkins Indiantown Citrus Co. ("Caulkins") for its plant
located near the Facility.
The original general partners were Toyan Enterprises ("Toyan"), a
California corporation and a wholly owned special purpose indirect subsidiary of
PG&E National Energy Group, Inc. ("NEG, Inc."), and Palm Power Corporation
("Palm"), a Delaware corporation and a special purpose indirect subsidiary of
Bechtel Enterprises, Inc. ("Bechtel Enterprises"). The sole limited partner was
TIFD III-Y, Inc. ("TIFD"), a special purpose indirect subsidiary of General
Electric Capital Corporation ("GECC"). During 1994, the Partnership formed its
sole, wholly owned subsidiary, Indiantown Cogeneration Funding Corporation ("ICL
Funding"), to act as agent for, and co-issuer with, the Partnership in
accordance with the 1994 bond offering of $505,000,000 of First Mortgage Bonds.
ICL Funding has no separate operations and has only $100 in assets.
In 1998, Toyan consummated transactions with DCC Project Finance Twelve,
Inc. ("PFT"), whereby PFT, through a new partnership (Indiantown Project
Investment, L.P. ("IPILP")) with Toyan, became a new general partner in the
Partnership. Toyan is the sole general partner of IPILP. Prior to the PFT
transaction, Toyan converted some of its general partnership interest into a
limited partnership interest such that Toyan now directly holds only a limited
partnership interest in the Partnership. In addition, Bechtel Generating
Company, Inc. ("Bechtel Generating"), sold all of the stock of Palm to a wholly
owned indirect subsidiary of Cogentrix Energy, Inc. ("Cogentrix"). Palm holds a
10% general partner interest in the Partnership.
On June 4, 1999, Thaleia, LLC ("Thaleia"), a wholly-owned subsidiary of
Palm and indirect wholly-owned subsidiary of Cogentrix, acquired from TIFD a
19.9% limited partner interest in the Partnership. On September 20, 1999,
Thaleia acquired another 20.0% limited partnership interest from TIFD and TIFD's
membership on the Board of Control. On November 24, 1999, Thaleia purchased
TIFD's remaining limited partner interest in the Partnership from TIFD.
The net profits and losses of the Partnership are allocated to Toyan,
Palm, TIFD and IPILP and Thaleia (collectively, the "Partners") based on the
following ownership percentages:
1
As of As of As of As of As of
August 21, October 20, June 4, September 20, November 24,
1998 1998 1999 1999 1999
---- ---- ---- ---- ----
Toyan 30.05% 30.05% 30.05% 30.05% 30.05%
Palm 10% 10%* 10%* 10%* 10%*
IPILP 19.95%** 19.95%** 19.95% 19.95% 19.95%
TIFD 40% 40% 20.1% 0.1% --
Thaleia -- -- 19.9%* 39.9%* 40%*
*Now beneficially owned by Cogentrix.
**PFT’s beneficial ownership in the Partnership through IPILP was equal to 10% as of
August 21, 1998, and 15% as of November 23, 1998.
The changes in ownership were the subject of notices of
self-recertification of Qualifying Facility status filed by the Partnership with
the Federal Energy Regulatory Commission on August 20, 1998, November 16, 1998,
June 4, 1999, September 21, 1999, and November 24, 1999.
All distributions other than liquidating distributions will be made
based on the Partners' percentage interest as shown above, in accordance with
the project documents and at such times and in such amounts as the Board of
Control of the Partnership determines.
The Partnership is managed by PG&E National Energy Group Company
("NEG"), formerly known as PG&E Generating Company, pursuant to a Management
Services Agreement (the "MSA"). The Facility is operated by PG&E Operating
Services Company ("PG&E OSC"), formerly known as U.S. Operating Services
Company, pursuant to an Operation and Maintenance Agreement (the "O&M
Agreement"). NEG and PG&E OSC are general partnerships wholly owned by NEG,
Inc.
NEG, Inc. is a wholly-owned indirect subsidiary of PG&E Corporation.
Because the California energy markets situation has caused financial
difficulties for Pacific Gas and Electric Company, a wholly owned subsidiary of
PG&E Corporation, PG&E Corporation's credit ratings were downgraded to
below investment grade in January 2001, which caused PG&E Corporation to
default on outstanding commercial paper and bank borrowings. In January 2001,
certain corporate actions were taken to insulate the assets of NEG and its
direct and indirect subsidiaries from an effort to substantively consolidate
those assets in any insolvency or bankruptcy proceeding of PG&E Corporation.
In March 2001, PG&E Corporation refinanced all of its outstanding commercial
paper and bank borrowings, and Standard & Poor's subsequently removed its
below investment grade credit rating since PG&E Corporation no longer had
rated securities outstanding. Management of NEG believes that NEG and its direct
and indirect subsidiaries as described above, including the Partnership, would
not be substantively consolidated with PG&E Corporation in any insolvency or
bankruptcy proceeding involving PG&E Corporation.
The Partnership began construction of the Facility in October 1992 and
was in the development phase through the commencement of commercial operation.
The Facility commenced commercial operation under its power purchase agreement
(the "Power Purchase Agreement" or "PPA") with FPL on December 22, 1995. The
Facility synchronized with the FPL system on June 30, 1995 and the Partnership
sold to FPL electricity produced by the
2
Facility during startup and testing. The Partnership’s
continued existence is dependent on the ability of the Partnership to maintain
successful commercial operation under the Power Purchase Agreement. The
Partnership has filed a complaint against FPL with respect to the interpretation
of a certain provision of the Power Purchase Agreement. Please see “Item 3
Legal Proceedings” below. Management of the Partnership is of the opinion
that the assets of the Partnership are realizable at their current carrying
value. The Partnership has no assets other than the Facility, the Facility site,
contractual arrangements relating to the Facility (the “Project
Contracts”) and the stock of ICL Funding.
Certain Project Contracts
The Facility supplies (i) electric generating capacity and energy to FPL
pursuant to the Power Purchase Agreement and (ii) steam to Caulkins Indiantown
Citrus Company ("Caulkins") pursuant to a long-term energy services agreement
(the "Energy Services Agreement").
Payments from FPL pursuant to the Power Purchase Agreement provide
approximately 99% of Partnership revenues. Under and subject to the terms of the
Power Purchase Agreement, FPL is obligated to purchase electric generating
capacity made available to it and associated energy from the Facility through
December 22, 2025.
Payments by FPL consist of capacity payments and energy payments. FPL is
required to make capacity payments to the Partnership on a monthly basis for
electric generating capacity made available to FPL during the preceding month
regardless of the amount of electric energy actually purchased. The capacity
payments have two components, an un-escalated fixed capacity payment and an
escalated fixed operation and maintenance payment, which together are expected
by the Partnership to cover all of the Partnership's fixed costs, including debt
service. Energy payments are made only for the amount of electric energy
actually delivered to FPL. The energy payments made by FPL are expected by the
Partnership to cover the Partnership's variable costs of electric energy
production but will be insufficient to cover the variable costs of steam
production for steam supplied to Caulkins. The amount of this shortfall is not
expected by the Partnership to have a material adverse effect on its ability to
service its debt.
The Partnership supplies thermal energy to Caulkins in order for the
Facility to meet the operating and efficiency standards under the Public Utility
Regulatory Policy Act of 1978, as amended, and the FERC's regulations
promulgated thereunder (collectively, "PURPA"). The Facility has been certified
as a Qualifying Facility under PURPA. Under PURPA, Qualifying Facilities are
exempt from certain provisions of the Public Utility Holding Company Act of
1935, as amended ("PUHCA"), most provisions of the Federal Power Act (the
"FPA"), and, except under certain limited circumstances, rate and financial
regulation under state law. The Energy Services Agreement with Caulkins requires
Caulkins to purchase the lesser of (i) 525 million pounds of steam per year or
(ii) the minimum quantity of steam per year necessary for the Facility to
maintain its status as a Qualifying Facility under PURPA (currently estimated by
the Partnership not to exceed 525 million pounds per year).
The Partnership has a coal purchase agreement (the "Coal Purchase
Agreement") with Lodestar Energy, Inc. ("Lodestar") pursuant to which Lodestar
supplies all of the Facility's coal needs, which are estimated to be 1 million
tons of coal per year. The Partnership has no obligation to purchase a minimum
quantity of coal under the Coal Purchase Agreement. The fuel price escalation
provisions in the Coal Purchase Agreement are substantially the same as
3
escalation of the fuel price component of the energy price
contained in the Power Purchase Agreement with FPL. This mechanism is intended
to mitigate any mismatch between the price the Partnership pays for coal and the
energy payments received from FPL. Lodestar’s parent, Lodestar
Holding’s Inc., announced in November, 2000 that it did not make a
scheduled interest payment on its outstanding debt and that its primary surety
of its performance bonds no longer meets local, state, and federal credit
requirements. As of March 19, 2001, the interest payment remained unpaid and no
alternative bonding arrangements had been made. The Partnership is currently
evaluating alternative sources of coal and options for ash disposal. Such
alternatives may result in increased fuel costs and waste handling expenses to
the Partnership.
During 1997, coal ash produced during operation of the Facility was
disposed of pursuant to the Coal Purchase Agreement and back-up disposal
arrangements with Chambers Waste Systems, Inc. of Florida ("Chambers"). In 1998,
the Partnership entered into agreements with Lodestar and VFL Technology
Corporation ("VFL") for ash disposal at alternative sites. These agreements will
reduce the cost of ash disposal. The Partnership has been informed that
Lodestar, Chambers, and VFL have obtained the permits necessary to receive such
coal ash.
The Partnership entered into a lime purchase agreement (the "Lime
Purchase Agreement") with Chemical Lime Company ("Chemlime"), an Alabama
corporation, to supply the lime requirements of the Facility's dry scrubber and
sulfur dioxide removal system. The initial term of the Lime Purchase Agreement
is 15 years from the commercial operation date. Chemlime is obligated to provide
all of the Facility's lime requirements, but the Partnership has no obligation
to purchase a minimum quantity of lime. The price of lime was renegotiated in
1999 for a three-year period beginning January 1, 2000. Chemlime notified the
Partnership of its intention to cancel the agreement effective in the first
quarter of 2002. The Partnership expects to put a replacement contract in place
during the third quarter of 2001.
Competition
Since the Partnership has a long-term contract to sell electric
generating capacity and energy from the Facility to FPL, it does not expect
competitive forces to have a significant effect on its business. As discussed
under "Energy Prices " below, the cost of power available to FPL from other
sources will affect FPL's dispatch of the Facility and, therefore, the amount of
electric energy FPL purchases from the Partnership. The Partnership expects that
the capacity payments under the Power Purchase Agreement, which are not affected
by the level of FPL's dispatch of the Facility, will cover all of the
Partnership's fixed costs, including debt service.
4
Energy Prices
In October 1999, FPL filed with the Florida Public Service Commission its
projections for its 2000-2001 "as available" energy costs (in this context, "as
available" energy costs reflect actual energy production costs avoided by FPL
resulting from the purchase of energy from the Facility and other Qualifying
Facilities). The projections filed by FPL are lower for certain periods than the
energy prices specified in the Power Purchase Agreement for energy actually
delivered by the Facility. At other times, the projections exceed the energy
prices specified in the Power Purchase Agreement. Should FPL's "as available"
energy cost projections prove to reflect actual rates, FPL may elect, pursuant
to its dispatch and control rights over the Facility set forth in the Power
Purchase Agreement, to run the Facility less frequently or at lower loads than
if the Facility's energy prices were lower than the cost of other energy sources
available to FPL. Since capacity payments under the Power Purchase Agreement are
not affected by FPL's dispatch of the Facility and because capacity payments are
expected by the Partnership to cover all of the Partnership's fixed costs,
including debt service, the Partnership currently expects that, if the filed
projections prove to reflect actual rates, such rates and the resulting dispatch
of the Facility will not have a material adverse effect on the Partnership's
ability to service its debt. To the extent the Facility is not operated by FPL
during Caulkins' processing season (November to June), the Partnership may elect
to run the Facility at a minimum load or shut down the Facility and run
auxiliary boilers to produce steam for Caulkins in amounts required under the
Partnership's steam agreement with Caulkins. Such operations may result in
decreased net operating income for such periods. The Partnership expects that
the decrease, if any, will not be material.
Employees
The Partnership has no employees and does not anticipate having any
employees in the future because, under a management services agreement, NEG acts
as the Partnership's representative in all aspects of managing the operation of
the Facility as directed by the Partnership's Board of Control. As noted above,
PG&E OSC is providing operations and maintenance services for the Partnership.
Business Strategy and Outlook
The Partnership's overall business plan is to safely produce clean,
reliable energy at competitive prices. The Facility commenced commercial
operation on December 22, 1995 and completed its fifth full calendar year of
operation on December 31, 2000.
During 2000, the Facility produced 2,343,677 MW-hr of energy for sale to
FPL compared to 1,745,760 MW-hr in 1999. This increase was due primarily to
FPL's higher dispatch of the Facility. Dispatch of the Facility by FPL averaged
approximately 87.56% over the year compared to 65.41% for 1999.
The Facility produced approximately 649 million pounds of steam for sale
to Caulkins in 2000 compared to approximately 390 million pounds in 1999 thereby
exceeding the minimum requirements to maintain Qualifying Facility status. The
259 million-pound increase in steam deliveries was due primarily to higher
production of juice by Caulkins in 2000.
The Facility ended the year with a twelve-month rolling average Capacity
Billing Factor of 98.636% in 2000 and 100.636% in 1999. The Capacity Billing
Factor measures the overall
5
availability of the Facility, but gives a heavier weighting
to on-peak availability. Cash flows during 2000 were sufficient to fund all
operating expenses and debt repayment obligations.
Dispatch of the unit by FPL during the summer months is expected to be
similar to 2000 levels. Dispatch during the winter is highly dependent on
weather and FPL's cost of running its oil and gas fired units. Caulkins expects
a strong citrus crop for processing in 2001 and steam demand from Caulkins is
expected to be similar to 2000 levels.
The Facility is planning on four weeks of scheduled outages during 2001
to perform routine inspections and maintenance. The primary outage is scheduled
for October and November 2001, which is before or at the beginning of citrus
production.
In the absence of any major equipment failures, unit availability
is expected to be comparable to 2000 levels. If this is achieved, the Capacity
Billing Factor and associated capacity bonuses would be similar.
The Partnership believes that its current financial resources will be
adequate to cover operating expenses and debt repayment obligations in 2001.
Forward Looking Statements
When used in this report, words or phrases that are predictions of or
indicate future events and trends are subject to a number of risks and
uncertainties which could cause actual results to differ materially from those
projected. Given such uncertainties, readers are cautioned not to place undue
reliance on such statements. The Partnership undertakes no obligation to
publicly update or revise any forward-looking statement to reflect current or
future events or circumstances.
Governmental Approvals
The Partnership has obtained all material environmental permits and
approvals required, as of December 31, 2000, in order to continue commercial
operation of the Facility. Certain of these permits and approvals are subject to
periodic renewal. Certain additional permits and approvals will be required in
the future for the continued operation of the Facility. The Partnership is not
aware of any technical circumstances that would prevent the issuance of such
permits and approvals or the renewal of currently issued permits. The
Partnership timely filed its application for a Title V air permit on May 24,
1996. The permit was issued on October 11, 1999.
On December 22, 1999, the Partnership submitted to the Florida
Department of Environmental Protection ("DEP") a request for amendments to the
Site Certification and an application for modifications of the Site Certificate.
The amendments to the Site Certification are being provided to inform DEP of
certain changes to the Facility's design and operation. The requests will not
require changes to the Conditions of Certification for the Facility and do not
involve significant environmental impacts that would require new environmental
permits or approvals. Also submitted was an application for modifications of the
Site Certificate, which describes other proposed changes to the Facility design
and operations. The modifications will require changes to the Conditions of
Certification. The requests include modifications to allow the addition of a
carbon dioxide plant and clarifications of the operation of the auxiliary
boilers related to operation rules. DEP approved these site certification
changes on April 20, 2000.
6
The DEP has proposed to modify the conditions of the Site Certification
to allow emergency discharge of cooling water and process water to conform to
NPDES Permit Number FL0183750, which was issued on January 19, 2000.
On November 10, 2000 the Partnership submitted to the DEP an application for
modifications to the Site Certificate. The proposed modifications include a
requested increase of the groundwater withdrawal, clarification of authority to
allow emergency water withdrawals, changes to groundwater monitoring
requirements and programs, and changing the address of the facility. On March
14, 2001 DEP approved and issued a final order modifying the Conditions of
Certification related to South Florida Management District (“SFWMD”)
authority to authorize withdrawals of ground or surface water and a modification
for storage pond elevation changes. The remaining modifications remain under
review with DEP.
Item 2 PROPERTIES
The Facility is located in a predominantly industrial area in
southwestern Martin County, Florida, on approximately 240 acres of land owned by
the Partnership (the "Site"). Other than the Facility, the Site, and the make-up
water pipeline and associated equipment, the Partnership does not own or lease
any material properties.
Item 3 LEGAL PROCEEDINGS
Dispute with FPL
On March 19, 1999, the Partnership filed a complaint against FPL in the
United States District Court for the Middle District of Florida. The lawsuit
stems from a course of action pursued by FPL since March 10, 1999, in which FPL
purported to exercise its dispatch and control rights under the Power Purchase
Agreement in a manner which the Partnership believes violated the terms of the
power sales agreement. In its complaint, the Partnership charges that such
conduct was deliberately calculated to cause the Partnership to be unable to
meet the requirements to maintain the Facility's status as a Qualifying Facility
under the Public Utility Regulatory Policies Act of 1978.
The complaint alleges that FPL took the position that if the Facility is
off-line for any reason, then FPL is under no obligation to allow the Facility
to reconnect to FPL's system. The original complaint asserted, however, that the
Partnership specifically and successfully negotiated for a contractual right to
operate the Facility up to 100 MW ("Minimum Load") in order to enable it to
cogenerate sufficient steam to maintain its Qualifying Facility status. While
FPL has not disputed that the Partnership may maintain Minimum Load operations
if the Facility is delivering power when FPL requests the Partnership to
decommit the Facility, the complaint states that FPL has claimed absolute
discretion to deny the Partnership permission to reconnect the Facility with
FPL's system.
Since the loss of Qualifying Facility status may result in an event of
default under the Power Purchase Agreement, the Partnership must take action to
address this matter. The Partnership is investigating various alternatives to
mitigate its QF risk. These are described under "QF Mitigation Options" below.
7
The complaint asserts causes of action for (i) FPL's breach of the Power
Purchase Agreement, (ii) FPL's anticipatory repudiation of the Power Purchase
Agreement, (iii) breach of the implied covenant of good faith, fair dealing and
commercial reasonableness and (iv) a declaratory judgment by the court of the
rights of the parties under the Power Purchase Agreement. The Partnership seeks
(a) a declaratory ruling that FPL's actions constitute a breach of the terms of
the Power Purchase Agreement and that the Partnership has the absolute right to
operate the Facility at Minimum Load (except for reasons of safety or system
security) at the rates provided for in the Power Purchase Agreement, (b)
injunctive relief preventing FPL from further violating the Power Purchase
Agreement, (c) compensatory damages and (d) other relief as the court may deem
appropriate.
On April 14, 1999, FPL filed a responsive pleading to the complaint
including a motion to dismiss two of the four counts raised in the complaint,
raising certain affirmative defenses and seeking declaration that FPL has
unfettered dispatch rights under the Power Purchase Agreement. On April 23,
1999, FPL filed answer to the counts, which were not challenged in the motion to
dismiss. On May 13, 1999, the Partnership filed its response to FPL's motion to
dismiss and request for declaratory judgement. On May 18, 1999, the Court denied
FPL's Motion to Dismiss in its entirety. The Partnership filed an amended
complaint, which was accepted on June 17, 1999. The amended complaint simply
consolidated the Partnership's claims for breach of contract and breach of the
implied obligation of good faith and fair dealing which was, in part, in
response to a recent federal court decision. FPL moved to dismiss the entire
amended complaint and the Partnership filed its opposition papers August 2,
1999. The Court granted FPL's motion to dismiss only with respect to the first
count of the complaint. The Partnership has amended its complaint to address
issues raised by the Court in its decision to dismiss this count. FPL was
expected to file a new motion to dismiss the amended complaint. The second
amended complaint, which was filed on March 21, 2000, is attached as an exhibit
to the Report.
This summary of the Partnership's complaint against FPL is qualified in
its entirety by the complaint, which was filed with the court in docket
99-317-CIV-ORL-19C. This summary does not, nor does it purport to, include all
of the material statements and claims made in the complaint, and has been
provided solely for the reader's convenience. This summary is not intended to be
relied upon for any purpose without reference to the complaint.
On December 19, 2000, FPL and the Partnership participated in a
mediation conference with respect to the pending litigations described herein.
As a result of this conference, FPL and the Partnership executed two Settlement
Agreements intended to resolve all pending litigation. Only the Settlement
Agreement for the pending federal court litigation requires amendment of the
power sales agreement. The amendment must be approved by the Florida Public
Service Commission, and certain conditions set forth in the Indenture for the
Bonds, including confirmation of the Bonds' investment grade rating, must be met
for it to become effective.
An outline of the business terms set forth in this Settlement Agreement
provides that if the Facility is off-line for any reason, the Partnership shall
have the right, upon up to 6 hours notice and subject only to safety and system
reliability issues, to reconnect to FPL's system and produce up to 100 MW. The
Settlement Agreement provides that if this occurs when FPL has decommitted the
Facility, the Partnership will be paid FPL's actual "as available" energy rates
for the first 360 of such hours each year (in this context, "as available"
energy costs reflect actual energy production costs avoided by FPL resulting
from the production or purchase of energy from the Facility and other sources).
If fewer than 360 hours are used in any year, FPL may carry the balance forward,
not to exceed a total of 1440 hours in any year. If the hours
8
accumulated exercising this reconnection right exceed
FPL’s balance, the Partnership will be paid for energy produced during
those hours at the energy rates set forth under the power sales agreement.
Management of the Partnership believes that this resolution provides the
Partnership with the flexibility it requires to maintain its Qualifying Facility
status without materially adversely affecting the Project.
On December 12, 2000, FPL filed a complaint against the Partnership in
the Circuit Court of the 19th Judicial District in and for Martin County,
Florida. In its complaint, FPL alleged that the Partnership breached the power
sales agreement by failing to include certain payments from its coal supplier
and its coal transporter in the Partnership's calculation of its fuel costs
which are included in the calculation of the actual energy costs under the power
sales agreement. The power sales agreement requires a sharing of actual energy
costs between FPL and the Partnership to the extent the actual costs differ
(either upward or downward) from a formula contained in the agreement. FPL
sought unspecified damages and declaratory relief including a finding that the
Partnership breached the power sales agreement. The Settlement Agreement
provides that the Partnership will include in future calculations of its fuel
costs all costs, credits, rebates, discounts, and allowances/concessions from
all past, current or future vendors of fuel, ash, lime, and fuel transportation
subject to execution of a definitive agreement embodying the terms of this
Settlement Agreement. The Partnership will make a one time payment of $800,000
to FPL as settlement for disputed amounts under fuel audits performed for
calendar years 1997 and 1998.
Property Tax Matter
The Partnership was contacted in 1998 by the local Martin County
property appraiser concerning the proper qualification of some of its pollution
control equipment, which equipment receives reduced valuation for property tax
purposes. After review by the Partnership, and discussion directly with the
appraiser's office, the Partnership provided the appraiser with all requested
information. The appraiser has not taken any further action on this matter.
Item 4 SUBMISSION OF MATTERS TO A VOTE OF SECURITY HOLDERS
No matters were submitted to a vote of the security holders of the
Partnership during 2000.
9
PART II
Item 5 MARKET FOR THE REGISTRANT'S COMMON STOCK AND
RELATED SECURITY HOLDER MATTERS
The Partnership is a Delaware limited partnership wholly owned by Palm,
Toyan, Thaleia and IPILP. Beneficial interests in the Partnership are not
available to other persons except with the consent of the Partners.
There is no established public market for ICL Funding's common stock.
The 100 shares of $1 par common stock are owned by the Partnership. ICL Funding
has not paid, and does not intend to pay, dividends on the common stock.
Item 6 SELECTED FINANCIAL DATA
The selected financial data of the Partnership presented below, which consists
primarily of certain summary consolidated balance sheet information of the
Partnership as of December 31, 2000, 1999, 1998, 1997, and 1996, should be read
in conjunction with Item 7 of this report, “Management’s Discussion an
Analysis of Financial Condition And Results of Operations”, and with the
Partnership’s consolidated financial statements appearing elsewhere in this
report. The Partnership, which was in the development stage through December 21,
1995, began construction of the Facility in October 1992 and declared commercial
operation of the Facility on December 22, 1995. The financial statements and
supplementary data required by this item are presented under Item 8.
2000 1999 1998 1997 1996
---- ---- ---- ---- ----
Total Assets $680,669,565 $694,852,029 $708,139,691 $735,468,011 $753,669,863
Long-Term Debt 572,521,507 583,994,031 595,835,699 606,119,747 616,651,805
Total Liabilities 595,689,890 606,607,479 616,339,161 629,342,447 637,472,694
Capital Distributions 25,400,000 25,970,000 35,680,000 28,080,382 36,395,054
Total Partners' Capital 84,979,675 88,244,550 91,800,530 106,125,564 116,197,169
Property, Plant & Equipment, Net
628,354,758 641,449,0555 654,188,458 668,464,373 682,214,731
Operating Revenues 177,790,391 163,270,119 159,183,399 162,517,435 158,845,947
Net Income 22,135,125 22,414,021 21,354,967 18,008,777 11,790,051
10
The following is a summary of the quarterly results of operations (unaudited) for the years ended December 31, 2000 and 1999.
Quarter Ended
March 31 June 30 September 30 December 31 Total
-------- ------- ------------ ----------- -----
(in thousands)
2000
- ----
Operating revenues $44,106 $42,589 $47,318 $43,777 $177,790
Gross profit 22,611 20,965 22,977 20,813 87,367
Net income before
cumulative change in
accounting principle 5,794 4,529 6,466 4,426 21,215
Net income 6,714 4,529 6,466 4,426 22,135
1999
- ----
Operating revenues $35,751 $40,457 $45,600 $41,462 $163,270
Gross profit 23,190 21,743 22,313 21,235 88,481
Net income 6,517 5,108 5,794 4,995 22,414
Item 7 MANAGEMENT'S DISCUSSION AND ANALYSIS OF FINANCIAL
CONDITION AND RESULTS OF OPERATIONS
Results of Operations
Year ended December 31, 2000 Compared to the Year Ended December 31, 1999
For the years ended December 31, 2000 and 1999, the Partnership had
total operating revenues of $177.8 million and $163.3 million, respectively.
This increase in 2000 was attributable primarily to increased energy revenues of
$14.2 million and by increased capacity bonus and capacity revenues of $0.3
million. For the years ending December 31, 2000 and 1999, the Facility achieved
an average Capacity Billing Factor of 98.64% and 100.64% respectively. This
decrease was primarily attributable to minor mechanical problems with turbine
control valves. This resulted in earning full monthly capacity payments
aggregating $112.8 million for the year in 2000 and $112.5 million for the year
in 1999. Bonuses aggregated $11.2 million for the year in both 2000 and 1999.
The increased revenues from capacity are due primarily to the quarterly
escalations on the fixed operating & maintenance component of the capacity
charge. The higher energy revenues are due primarily to greater dispatch levels
by FPL. During 2000 and 1999, the Facility was dispatched by FPL and generated
2,343,677 megawatt-hours and 1,745,760 megawatt-hours, respectively. The monthly
average dispatch rate requested by FPL was 87.6% and 65.4% for the twelve months
ended December 31, 2000 and 1999, respectively. Total operating costs were
$102.1 million and $85.5 million for the years ended December 31, 2000 and 1999,
respectively. This increase
11
was due primarily to an increase of $16.1 million in fuel and ash costs, both
resulting from higher dispatch by FPL, and an increase of $0.7 million in
general and administrative expenses relating to the FPL litigation costs. For
the years ended December 31, 2000 and 1999, the total net interest expense was
approximately $54.5 million and $55.4 million, respectively. The decrease was
primarily due to a $0.8 million reduction in bond interest expense due to
installment payments of the Series A-9 First Mortgage Bonds on June 15, 2000 and
on December 15, 2000, an increase in interest income of $0.3 million, and an
increase in letter of credit fees of $0.2 million. Net income was $22.1 million
and $22.4 million for the twelve months ended December 31, 2000 and 1999,
respectively. This $0.3 million decrease was primarily attributable to a $16.6
million increase in operating costs offset by the increased revenues of $14.5
million, the effect of a cumulative change in accounting principle for major
maintenance of $0.9 million, and a decrease in net interest expense of $0.9
million.
As of December 31, 2000 and 1999 the Partnership had approximately
$628.4 million and $641.4 million, respectively, of property, plant and
equipment consisting primarily of purchased equipment, construction related
labor and materials, interest during construction, financing costs, and other
costs directly associated with the construction of the Facility. This decrease
is due primarily to depreciation of $15.0 million, offset by $2.1 million of
capital improvements.
Year ended December 31, 1999 Compared to the Year Ended December 31, 1998
For the years ended December 31, 1999 and 1998, the Partnership had
total operating revenues of $163.3 million and $159.2 million, respectively.
This increase was attributable primarily to increased energy revenues of $3.9
million and by increased capacity bonus and capacity revenues of $0.2 million.
For the years ending December 31, 1999 and 1998, the Facility achieved an
average Capacity Billing Factor of 100.64% and 101.038% respectively. The
decrease was primarily attributable to minor mechanical problems. This resulted
in earning full monthly capacity payments aggregating $112.5 million for the
year in 1999 and $112.3 million for the year in 1998. Bonuses aggregated $11.2
million for the year in both 1999 and 1998. The increased revenues from capacity
are due primarily to the quarterly escalations on the Fixed O&M component. The
higher energy revenues are due primarily to greater dispatch levels by FPL.
Total operating costs were $85.5 million and $80.6 million for the years ended
December 31, 1999 and 1998, respectively. This increase was due primarily to an
increase of $3.6 million in fuel and ash costs, both resulting from higher
dispatch by FPL and an increase of $1.0 million in operations and maintenance
expenses. During 1999 and 1998, the Facility was dispatched by FPL and generated
1,745,760 megawatt-hours and 1,485,008 megawatt-hours, respectively. The monthly
average dispatch rate requested by FPL was 65.4% and 51.6% for the twelve months
ended December 31, 1999 and 1998, respectively. For the years ended December 31,
1999 and 1998, the total net interest expense was approximately $55.4 million
and $56.4 million, respectively. The decrease was primarily due to a $0.8
million reduction in bond interest expense due to the maturity of Series A-7 of
the First Mortgage Bonds on June 15, 1999 and Series A-8 of the First Mortgage
Bonds on December 15, 1999, a reduction in LOC fees of $0.4 million, and a
reduction in interest income of $0.2 million. Net income was $22.4 million and
$21.4 million for the twelve months ended December 31, 1999 and 1998,
respectively. This $1.0 million increase was primarily attributable to the
increased revenues of $4.1 million and the effect in 1998 for the write off of
$0.8 million for start-up costs, a $1.0 million decrease in net interest expense
and offset by a $4.9 million increase in operating costs.
12
As of December 31, 1999 and 1998, the Partnership had approximately
$641.4 million and $654.2 million, respectively, of property, plant and
equipment consisting primarily of purchased equipment, construction related
labor and materials, interest during construction, financing costs, and other
costs directly associated with the construction of the Facility. This decrease
is due primarily to depreciation of $15.2 million, offset by $2.1 million of
capital improvements.
Liquidity and Capital Resources
On November 22, 1994, the Partnership and ICL Funding issued first
mortgage bonds in an aggregate principal amount of $505 million (the "First
Mortgage Bonds"). Of this amount, $236.6 million of the First Mortgage Bonds
bear an average interest rate of 9.05% and $268.4 million of the First Mortgage
Bonds bear an interest rate of 9.77%. Concurrent with the Partnership's issuance
of its First Mortgage Bonds, the Martin County Industrial Development Authority
issued $113 million of Industrial Development Refunding Revenue Bonds (Series
1994A) which bear an interest rate of 7.875% (the "1994A Tax Exempt Bonds"). A
second series of tax exempt bonds (Series 1994B) in the approximate amount of
$12 million, which bear an interest rate of 8.05%, were issued by the Martin
County Industrial Development Authority on December 20, 1994 (the "1994B Tax
Exempt Bonds" and, together with the 1994A Tax Exempt Bonds, the "1994 Tax
Exempt Bonds"). The First Mortgage Bonds and the 1994 Tax Exempt Bonds are
hereinafter collectively referred to as the "Bonds."
Certain proceeds from the issuance of the First Mortgage Bonds were used
to repay $421 million of the Partnership's indebtedness, and financing fees and
expenses incurred in connection with the development and construction of the
Facility. The balance of the proceeds were deposited in various restricted funds
that are being administered by an independent disbursement agent pursuant to
trust indentures and a disbursement agreement. Funds administered by such
disbursement agent are invested in specified investments. These funds together
with other funds available to the Partnership were used: (i) to finance
completion of construction, testing, and initial operation of the Facility; (ii)
to finance construction interest and construction-related contingencies; and
(iii) to provide for initial working capital.
The proceeds of the 1994 Tax Exempt Bonds were used to refund $113
million principal amount of Industrial Development Revenue Bonds (Series 1992A
and Series 1992B) previously issued by the Martin County Industrial Development
Authority for the benefit of the Partnership, and to fund, in part, a debt
service reserve account for the benefit of the holders of its tax-exempt bonds
and to complete construction of certain portions of the Facility.
The Partnership's total borrowings from inception through December 2000
were $769 million. The equity loan of $139 million was repaid on December 26,
1995. As of December 31, 2000, the outstanding borrowings included $125 million
from the 1994 Tax Exempt Bonds and all of the available First Mortgage Bond
proceeds. The First Mortgage Bonds have matured as follows:
Series Aggregate Principal Amount Date Matured and Paid
------ -------------------------- ---------------------
A-1 $4,397,000 June 15, 1996
A-2 4,398,000 December 15, 1996
A-3 4,850,000 June 15, 1997
A-4 4,851,000 December 15, 1997
13
A-5 5,132,000 June 15, 1998
A-6 5,133,000 December 15, 1998
A-7 4,998,000 June 15, 1999
A-8 4,999,000 December 15, 1999**
**Note the A-9 Series does not fully mature until December 15, 2010.
The weighted average interest rate paid by the Partnership on its debt
for the years ended December 31, 2000 and 1999, was 9.204% and 9.182%
respectively.
The Partnership, pursuant to certain of the Project Contracts, is
required to post letters of credit which, in the aggregate, will have a face
amount of no more than $65 million. Certain of these letters of credit have been
issued pursuant to a Letter of Credit and Reimbursement Agreement with Credit
Suisse First Boston and the remaining letters of credit will be issued when
required under the Project Contracts, subject to conditions contained in such
Letter of Credit and Reimbursement Agreement. As of December 31, 2000, no
drawings have been made on any of these letters of credit. The Letter of Credit
and Reimbursement Agreement has a term of seven years subject to extension at
the discretion of the banks party thereto.
The Partnership entered into a debt service reserve letter of credit and
reimbursement agreement, dated as of November 1, 1994, with BNP Paribas
(formerly known as Banque Nationale de Paris) pursuant to which a debt service
reserve letter of credit in the amount of approximately $60 million was issued.
This agreement has a term of five years subject to extension at the discretion
of the banks party thereto. Drawings on the debt service reserve letter of
credit became available on the Commercial Operation Date of the Facility to pay
principal and interest on the First Mortgage Bonds, the 1994 Tax Exempt Bonds
and interest on any loans created by drawings on such debt service reserve
letter of credit. Cash and other investments held in the debt service reserve
account will be drawn on for the Tax Exempt Bonds prior to any drawings on the
debt service reserve letter of credit. As of December 31, 2000, no drawings have
been made on the debt service reserve letter of credit. On January 11, 1999, in
accordance with the Partnership's financing documents, the debt service reserve
letter of credit was reduced to approximately $30 million, which, together with
cash in the debt service reserve account, represents the maximum remaining
semi-annual debt service on the First Mortgage Bonds and the 1994 Tax Exempt
Bonds.
In order to provide for the Partnership's working capital needs, the
Partnership entered into a Revolving Credit Agreement with Credit Suisse First
Boston dated as of November 1, 1994. This Agreement has a term of seven years
subject to extension at the discretion of the banks party thereto. The revolving
credit agreement has a maximum available amount of $15 million and may be drawn
on by the Partnership from time to time. The interest rate is based upon various
short-term indices at the Partnership's option and is determined separately for
each draw. During 2000, working capital loans were made to the Partnership under
the working capital loan facility. All working capital loans were repaid in a
timely manner and as of December 31, 2000 no borrowings were outstanding.
For 2001, we have identified possible capital improvements that will
enhance the reliability of the facility. This list includes the purchase of
heavy mobile equipment, baghouse upgrades, additional upper aquifer wells, and
water treatment modifications.
14
Item 7A Qualitative and Quantitative Disclosures About Market Risk
The only material market risk to which the Partnership is exposed is
interest rate risk. The Partnership's exposure to market risk for changes in
interest rates relates primarily to the opportunity costs of long-term fixed
rate obligations in a falling interest rate environment.
The table below presents principal, interest and related weighted average
interest rates by year of maturity (in thousands).
- --------------------------------------------------------------------------------------------------------------------------------
DEBT (all fixed rate) 2001 2002 2003 2004 2005 Thereafter Total Fair Value
---- ---- ---- ---- ---- ---------- ----- ----------
Tax Exempt Bonds:
Principal $0.0 $0.0 $0.0 $0.0 $0.0 $125,010 $125,010 $127,510
Interest $9,865 $9,865 $9,865 $9,865 $9,865 $175,683 $225,012
Average Interest Rate 7.89% 7.89% 7.89% 7.89% 7.89% 7.89%
First Mortgage Bonds:
Principal $11,141 $11,460 $14,566 $16,785 $16,257 $384,499 $454,708 $492,484
Interest $43,217 $42,178 $41,045 $39,645 $38,102 $282,582 $486,769
Average Interest Rate 9.56% 9.57% 9.58% 9.59% 9.61% 9.71%
- --------------------------------------------------------------------------------------------------------------------------------
15
Item 8 FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA
-------------------------------------------
Index to Financial Statements Page
----------------------------- ----
Report of Independent Public Accountants 18
Consolidated Balance Sheets 19
Consolidated Statements of Operations 21
Consolidated Statements of Changes in Partners' Capital 22
Consolidated Statements of Cash Flows 23
Notes to Consolidated Financial Statements 24
16
Report of independent public accountants
To Indiantown Cogeneration, L.P.:
We have audited the accompanying consolidated balance sheets of Indiantown
Cogeneration, L.P., (a Delaware limited partnership) and subsidiaries (the
“Partnership”) as of December 31, 2000 and 1999, and the related
consolidated statements of operations, changes in partners’ capital and
cash flows for each of the three years in the period ended December 31, 2000.
These financial statements are the responsibility of the Partnership’s
management. Our responsibility is to express an opinion on these financial
statements based on our audits.
We conducted our audits in accordance with auditing standards generally accepted
in the United States. Those standards require that we plan and perform the audit
to obtain reasonable assurance about whether the financial statements are free
of material misstatement. An audit includes examining, on a test basis, evidence
supporting the amounts and disclosures in the financial statements. An audit
also includes assessing the accounting principles used and significant estimates
made by management, as well as evaluating the overall financial statement
presentation. We believe that our audits provide a reasonable basis for our
opinion.
In our opinion, the financial statements referred to above present fairly, in
all material respects, the financial position of Indiantown Cogeneration, L.P.
and subsidiaries as of December 31, 2000 and 1999, and the results of their
operations and their cash flows for each of the three years in the period ended
December 31, 2000, in conformity with accounting principles generally accepted
in the United States.
As discussed in Note 2 to the financial statements, the Partnership changed its
method of accounting for scheduled major overhauls in 2000 and costs of start-up
activities in 1998.
Vienna, Virginia
January 11, 2001 (except with respect to matters discussed in Note 1, as to
which the date is March 15, 2001)
17
Indiantown Cogeneration, L.P. and Subsidiaries
Consolidated Balance Sheets
As of December 31, 2000 and 1999
--------------------------------
ASSETS 2000 1999
- ---------------------------------------------------------------------- ------------------ ------------------
CURRENT ASSETS:
Cash and cash equivalents $ 821,955 $ 2,416,997
Accounts receivable-trade 13,853,485 13,471,985
Inventories 2,116,636 1,146,017
Prepaid expenses 800,238 807,372
Deposits 44,450 44,450
Investments held by Trustee, including restricted funds
of $2,694,068 and $2,752,669 respectively 2,980,292 3,283,909
------------------ ------------------
Total current assets 20,617,056 21,170,730
INVESTMENTS HELD BY TRUSTEE,
restricted funds 15,108,428 14,501,877
DEPOSITS 159,365 80,000
PROPERTY, PLANT & EQUIPMENT:
Land 8,582,363 8,582,363
Electric and steam generating facilities 700,310,050 698,401,089
Less - accumulated depreciation (80,537,655) (65,534,397)
------------------ ------------------
Net property, plant & equipment 628,354,758 641,449,055
FUEL RESERVE 922,254 1,318,099
DEFERRED FINANCING COSTS, net of accumulated
amortization of $44,679,212 and $43,854,648 respectively 15,507,704 16,332,268
------------------ ------------------
Total assets $ 680,669,565 $ 694,852,029
================== ==================
The accompanying notes are an integral part of these consolidated
balance sheets.
18
Indiantown Cogeneration, L.P. and Subsidiaries
Consolidated Balance Sheets
As of December 31, 2000 and 1999
--------------------------------
LIABILITIES AND PARTNERS' CAPITAL 2000 1999
- --------------------------------------------------------------- ----------------- -----------------
CURRENT LIABILITIES:
Accounts payable and accrued liabilities $ 9,325,173 $ 7,584,226
Accrued interest 2,370,686 2,267,017
Current portion - First Mortgage Bonds 11,140,896 11,533,135
Current portion of lease payable - railcars 331,628 308,534
----------------- -----------------
Total current liabilities 23,168,383 21,692,912
----------------- -----------------
LONG TERM DEBT:
First Mortgage Bonds 443,567,969 454,708,865
Tax Exempt Facility Revenue Bonds 125,010,000 125,010,000
Lease payable - railcars 3,943,538 4,275,166
----------------- -----------------
Total long term debt 572,521,507 583,994,031
Scheduled major overhaul costs -- 920,536
----------------- -----------------
Total liabilities 595,689,890 606,607,479
----------------- -----------------
COMMITMENTS AND CONTINGENCIES
PARTNERS' CAPITAL:
Toyan Enterprises 25,536,395 26,517,489
Palm Power Corporation 8,497,967 8,824,455
Indiantown Project Investment, L.P. Partnership 16,953,444 17,604,787
Thaleia, LLC 33,991,869 35,297,819
----------------- -----------------
Total partners' capital 84,979,675 88,244,550
----------------- -----------------
Total liabilities and partners' capital $ 680,669,565 $ 694,852,029
================= =================
19
The accompanying notes are an integral part of these consolidated
balance sheets.
Indiantown Cogeneration, L.P. and Subsidiaries
Consolidated Statements of Operations
For the Years Ended December 31, 2000, 1999 and 1998
----------------------------------------------------
2000 1999 1998
------------ ------------ ------------
Operating Revenues:
Electric capacity and capacity bonus $124,029,498 $123,682,957 $123,461,237
Electric energy revenue 53,652,475 39,461,349 35,549,353
Steam 108,418 125,813 172,809
-------------- ------------- ------------
Total operating revenues 177,790,391 163,270,119 159,183,399
-------------- ------------- ------------
Cost of Sales:
Fuel and ash 55,910,214 39,794,007 36,220,511
Operating and maintenance 19,353,798 19,767,743 18,807,227
Depreciation 15,003,258 15,227,631 15,091,155
Loss on disposal of assets 155,780 -- --
------------- ------------ -------------
Total cost of sales 90,423,050 74,789,381 70,118,893
------------- ------------ -------------
Gross Profit 87,367,341 88,480,738 89,064,506
------------- ------------ -------------
Other Operating Expenses:
General and administrative 5,179,313 4,501,136 3,826,290
Insurance and taxes 6,475,006 6,212,453 6,689,843
------------ ----------- ------------
Total other operating expenses 11,654,319 10,713,589 10,516,133
------------ ----------- -----------
Operating Income 75,713,022 77,767,149 78,548,373
------------ ----------- -----------
Non-Operating Income (Expense):
Interest expense (56,905,787) (57,475,271) (58,868,345)
Interest income 2,407,354 2,122,142 2,493,655
------------- ------------- --------------
Net non-operating expense (54,498,433) (55,353,129) (56,374,690)
-------------- ------------- -------------
Income before cumulative effect of change in accounting
principles 21,214,589 22,414,020 22,173,683
Cumulative effect of a change in accounting
for costs of start-up activities (Note 2) -- -- (818,716)
Cumulative effect of a change in accounting
for scheduled major overhaul costs (Note 2) 920,536 -- --
-------------- ----------- ------------
Net Income $22,135,125 $22,414,020 $21,354,967
=========== =========== ============
The accompanying notes are an integral part of these consolidated statements.
20
Indiantown Cogeneration, L. P. and Subsidiaries
Consolidated Statements of Changes in Partners' Capital
For the Years Ended December 31, 2000, 1999 and 1998
----------------------------------------------------
Toyan Palm Power TIFD III-Y,
Enterprises Corporation Inc. IPILP Thaleia, LLC Total
----------- ----------- ----------- ----- ------------ -----
Partners' capital,
December 31, 1997 $53,062,783 $10,612,556 $42,450,225 $-- $ -- $106,125,564
Net Income (1/1/98 through 8/21/98) 7,228,833 1,445,767 5,783,066 14,457,666
Capital Distributions (1/1/98 through (13,240,000) (2,648,000) (10,592,000) -- -- (26,480,000)
8/21/98)
------------ ------------ ------------ -------- ------------ -------------
Partners' capital, August 21, 1998 $47,051,616 $ 9,410,323 $37,641,291 $-- $ -- $94,103,230
=========== =========== =========== ========= ============ =============
Transfer Toyan 19.95% interest to IPILP (18,773,594) -- -- 18,773,594 -- --
Net Income (8/22/98 through 12/31/98) 2,072,639 689,730 2,758,920 1,376,011 -- 6,897,300
Capital Distributions (8/22/98 through (2,764,600) (920,000) (3,680,000) (1,835,400) -- (9,200,000)
12/31/98 ------------- -------------- -------------- ------------- ---------- --------------
Partners' capital, December 31, 1998 $27,586,061 $9,180,053 $36,720,211 $18,314,205 $-- $91,800,530
============= ============= ============= ============= ========== ==============
Net Income (1/1/99 through 6/4/99) 3,139,325 1,044,700 4,178,802 2,084,177 -- 10,447,004
Partners' capital, June 4, 1999 $30,725,386 $10,224,753 $40,899,013 $20,398,382 $-- $102,247,534
============= ============== ============ ============= ========== ==============
Transfer TIFD 19.90% interest to
Thaleia, LLC -- -- (20,347,259) -- 20,347,259 --
Net Income (6/5/99 through 9/20/99) 1,915,912 637,575 1,281,525 1,271,961 1,268,773 6,375,746
Capital distributions (6/5/99 through) --
9/20/99) (5,039,385) (1,677,000) (3,370,770) (3,345,615) (3,337,230) (16,770,000)
------------ -------------- ------------- ------------- ------------ --------------
Partners' capital, September 20, 1999 $27,601,913 $ 9,185,328 $18,462,509 $18,324,728 $18,278,802 $91,853,280
=========== ============== ============= ============= ============ ==============
Transfer TIFD 20.00% interest to
Thaleia, LLC -- -- (18,370,656) -- 18,370,656 --
Net Income (9/21/99 through 11/24/99) 1,175,664 391,236 3,912 780,517 1,561,032 3,912,361
Partners' capital, November 24, 1999 $28,777,577 $ 9,576,564 $ 95,765 $19,105,245 $38,210,490 $95,765,641
=========== ============ ========== ============ =========== =============
Transfer TIFD 0.10% interest to
Thaleia, LLC
-- -- (95,765) -- 95,76 --
Net Income (11/25/99 through 12/31/99) 504,51 167,891 -- 334,942 671,564 1,678,90
Capital distributions (11/25/99 through
12/31/99) (2,764,600) (920,000) -- (1,835,400) (3,680,000) (9,200,000)
------------ ------------- ------------ ------------- ------------ -------------
Partners' capital, December 31, 1999 $26,517,489 $8,824,455 -- $ 17,604,787 $35,297,819 $88,244,550
=========== ============ ============ ============ ============ =============
Net Income 6,651,60 2,213,512 -- 4,415,957 8,854,050 22,135,125
Capital distributions (7,632,700) (2,540,000) (5,067,300) (10,160,000) (25,400,000)
------------ ------------- ------------ ------------- ------------- --------------
Partners' capital, December 31, 2000 $25,536,395 $8,497,967 $ 16,953,444 $ 33,991,869 $84,979,675
=========== ============ ============ ============= ============ =============
The accompanying notes are an integral part of these consolidated statements.
21
Indiantown Cogeneration, L.P. and Subsidiaries
Consolidated Statements of Cash Flows
For the Years Ended December 31, 2000, 1999, and 1998
-----------------------------------------------------
2000 1999 1998
---- ---- ----
CASH FLOWS FROM OPERATING ACTIVITIES:
Net income $22,135,125 $22,414,020 $21,354,967
Adjustments to reconcile net income to net cash
provided by operating activities:
Cumulative effect of a change in accounting principles (920,536) -- 818,716
Depreciation and amortization 15,827,822 15,681,507 15,666,912
Loss on disposal of assets 155,780 -- --
Effect of changes in assets and liabilities:
(Increase) decrease in accounts receivable-trade (381,500) (1,102,391) 2,113,496
(Increase) decrease in inventories and fuel reserve (574,774) 1,904,412 (890,538)
(Increase) decrease in deposits and prepaids (72,231) (76,122) 428,029
Increase (decrease) in accounts payable,
accrued liabilities and (2,471,228)
-----------
accrued interest 1,844,616 552,186
--------- -------
Net cash provided by operating activities 38,014,302 39,373,612 37,020,354
---------- ---------- ----------
CASH FLOWS FROM INVESTING ACTIVITIES:
Purchase of property, plant & equipment, net of retirements (2,064,741) (2,108,071) (1,361,673)
(Increase) decrease in investments held by trustee (302,934) (1,013,585) 9,738,087
--------- ----------- ---------
Net cash (used in) provided by investing activities (2,367,675) (3,121,656) 8,376,414
----------- ----------- ---------
CASH FLOWS FROM FINANCING ACTIVITIES:
Decrease in lease payable--railcars (308,534) (287,048) (267,058)
Borrowings under revolving credit agreement 12,835,436 14,568,378 17,662,159
Repayments under revolving credit agreement (12,835,436) (14,568,378) (17,662,159)
Payment of bonds (11,533,135) (9,997,000) (10,265,000)
Capital distributions (25,400,000) (25,970,000) (35,680,000)
------------ ------------ ------------
Net cash used in financing activities (37,241,669) (36,254,048) (46,212,058)
------------ ------------ ------------
CHANGE IN CASH AND CASH EQUIVALENTS (1,595,042) (2,092) (815,290)
Cash and cash equivalents, beginning of year 2,416,997 2,419,089 3,234,379
--------- --------- ---------
Cash and cash equivalents, end of year $821,955 $2,416,997 $2,419,089
======== ========== ==========
SUPPLEMENTAL DISCLOSURE OF CASH FLOW
INFORMATION:
Cash paid for interest $54,141,427 $55,039,501 $55,879,716
=========== =========== ===========
The accompanying notes are an integral part of these consolidated statements.
22
Indiantown Cogeneration, L.P. and Subsidiaries
Notes to Consolidated Financial Statements
As of December 31, 2000 and 1999
1. ORGANIZATION AND BUSINESS:
Indiantown Cogeneration, L.P. (the "Partnership") is a special purpose
Delaware limited partnership formed on October 4, 1991. The Partnership was
formed to develop, construct, and operate an approximately 330 megawatt (net)
pulverized coal-fired cogeneration facility (the "Facility") located on an
approximately 240 acre site in southwestern Martin County, Florida. The Facility
produces electricity for sale to Florida Power & Light Company ("FPL") and
supplies steam to Caulkins Indiantown Citrus Co. ("Caulkins") for its plant
located near the Facility.
The original general partners were Toyan Enterprises ("Toyan"), a
California corporation and a wholly owned special purpose indirect subsidiary of
PG&E National Energy Group, Inc. ("NEG, Inc.") and Palm Power Corporation
("Palm"), a Delaware corporation and a special purpose indirect subsidiary of
Bechtel Enterprises, Inc. ("Bechtel Enterprises"). The sole limited partner was
TIFD III-Y, Inc. ("TIFD"), a special purpose indirect subsidiary of General
Electric Capital Corporation ("GECC"). During 1994, the Partnership formed its
sole, wholly owned subsidiary, Indiantown Cogeneration Funding Corporation ("ICL
Funding"), to act as agent for, and co-issuer with, the Partnership in
accordance with the 1994 bond offering discussed in Note 4. ICL Funding has no
separate operations and has only $100 in assets.
In 1998, Toyan consummated transactions with DCC Project Finance
Twelve, Inc. ("PFT"), whereby PFT, through a new partnership (Indiantown Project
Investment, L.P. ("IPILP")) with Toyan, became a new general partner in the
Partnership. Toyan is the sole general partner of IPILP. Prior to the PFT
transaction, Toyan converted some of its general partnership interest into a
limited partnership interest such that Toyan now directly holds only a limited
partnership interest in the Partnership. In addition, Bechtel Generating
Company, Inc. ("Bechtel Generating"), sold all of the stock of Palm to a wholly
owned indirect subsidiary of Cogentrix Energy, Inc. ("Cogentrix"). Palm holds a
10% general partner interest in the Partnership.
On June 4, 1999, Thaleia, LLC ("Thaleia"), a wholly owned subsidiary of
Palm and indirect wholly owned subsidiary of Cogentrix, acquired from TIFD a
19.9% limited partner interest in the Partnership. On September 20, 1999,
Thaleia acquired another 20% limited partnership interest from TIFD and TIFD's
membership on the Board of Control. On November 24, 1999, Thaleia purchased
TIFD's remaining limited partnership interest in the Partnership from TIFD.
The net profits and losses of the Partnership are allocated to Toyan, Palm, TIFD
and IPILP and Thaleia (collectively, the “Partners”) based on the
following ownership percentages:
23
As of As of As of As of As of
August 21, October 20, June 4, September 20, November 24,
1998 1998 1999 1999 1999
---- ---- ----- ---- ----
Toyan 30.05% 30.05% 30.05% 30.05% 30.05%
Palm 10% 10%* 10%* 10%* 10%*
IPILP 19.95%** 19.95%** 19.95% 19.95% 19.95%
TIFD 40% 40% 20.1% 0.1% --
Thaleia -- -- 19.9% 39.9% 40%
*Now beneficially owned by Cogentrix.
**PFT’s beneficial ownership in the Partnership through IPILP was equal to
10%
as of August 21, 1998, and 15% as of November 23, 1998.
The changes in ownership were the subject of notices of
self-recertification of Qualifying Facility status filed by the Partnership with
the Federal Energy Regulatory Commission on August 21, 1998, November 16, 1998,
June 4, 1999, September 21, 1999, and November 24, 1999.
All distributions other than liquidating distributions will be made
based on the Partners' percentage interest as shown above, in accordance with
the project documents and at such times and in such amounts as the Board of
Control of the Partnership determines.
The Partnership is managed by PG&E National Energy Group Company
("NEG"), formerly known as PG&E Generating Company pursuant to a Management
Services Agreement (the "MSA"). The Facility is operated by PG&E Operating
Services Company ("PG&E OSC"), formerly known as U.S. Operating Services
Company, pursuant to an Operation and Maintenance Agreement (the "O&M
Agreement"). NEG and PG&E OSC are general partnerships indirectly wholly owned
by NEG, Inc., an indirect wholly owned subsidiary of PG&E Corporation.
The Partnership commenced commercial operations on December 22, 1995
(the "Commercial Operation Date").
/P>
24
NEG, Inc. is a wholly-owned indirect subsidiary of PG&E Corporation.
Because the California energy markets situation has caused financial
difficulties for Pacific Gas and Electric Company, a wholly owned subsidiary of
PG&E Corporation, PG&E Corporation's credit ratings were downgraded to
below investment grade in January 2001, which caused PG&E Corporation to
default on outstanding commercial paper and bank borrowings. In January 2001,
certain corporate actions were taken to insulate the assets of NEG and its
direct and indirect subsidiaries from an effort to substantively consolidate
those assets in any insolvency or bankruptcy proceeding of PG&E Corporation.
In March 2001, PG&E Corporation refinanced all of its outstanding commercial
paper and bank borrowings, and Standard & Poor's subsequently removed its below
investment grade credit rating since PG&E Corporation no longer had rated
securities outstanding. Management of NEG believes that NEG and its direct and
indirect subsidiaries as described above, including the Partnership, would not
be substantively consolidated with PG&E Corporation in any insolvency or
bankruptcy proceeding involving PG&E Corporation.
2. SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES:
Presentation
The Partnership's consolidated financial statements are prepared on the
accrual basis of accounting in accordance with accounting principles generally
accepted in the United States. The preparation of financial statements in
conformity with accounting principles generally accepted in the United States
requires management to make estimates and assumptions that affect reported
amounts of assets and liabilities and disclosure of contingent assets and
liabilities at the date of the financial statements and the reported amounts of
revenue and expenses during the reporting period. Actual results could differ
from those estimates.
The accompanying consolidated financial statements include the accounts
of the Partnership and ICL Funding. All significant intercompany balances have
been eliminated in consolidation.
Cash and Cash Equivalents
For the purposes of reporting cash flows, cash equivalents include
short-term investments with original maturities of three months or less.
Inventories
Coal and lime inventories are stated at the lower of cost or market
using the average cost method.
25
Prepaid Expenses
Prepaid expenses of $800,238 as of December 31, 2000, include $500,000
for operation and maintenance funding, $229,230 for insurance costs related to
property damage and other general liability policies and $71,008 for prepayments
of the annual administrative fees for the letters of credit and for the trustee.
Prepaid expenses of $807,372 as of December 31, 1999, include $500,000
for operation and maintenance funding, $243,135 for insurance costs related to
property damage and other general liability policies and $64,237 for prepayments
of the annual administrative fees for the letters of credit and for the trustee.
Deposits
Deposits are stated at cost and include amounts required under certain
of the Partnership's agreements as described in Note 3.
Investments Held by Trustee
The investments held by the trustee represent bond and equity proceeds
held by a bond trustee/disbursement agent and are carried at cost, which
approximates market. All funds are invested in either Nations Treasury
Fund-Class A or other permitted investments for longer periods. The Partnership
also maintains restricted investments covering a portion of the partnership's
debt as required by the financing documents. The proceeds include $12,501,000 of
restricted tax-exempt debt service reserve required by the financing documents
and are classified as a noncurrent asset on the accompanying consolidated
balance sheets. The Partnership maintains restricted investments covering a
portion of debt principal and interest payable, as required by the financing
documents. These investments are classified as current assets in the
accompanying consolidated balance sheets. A qualifying facility ("QF") reserve
of $2,500,000 is also held as a non-current asset (see Note 4).
Property, Plant and Equipment
Property, plant and equipment, which consist primarily of the Facility,
are recorded at actual cost. The Facility is depreciated on a straight-line
basis over 35 years with a residual value on the Facility approximating 25
percent of the gross Facility costs.
Other property, plant and equipment are depreciated on a straight-line
basis over the estimated economic or service lives of the respective assets
(ranging from five to seven years). Routine maintenance and repairs are charged
to expense as incurred.
The Financial Accounting Standards Board issued Statement of Financial
Accounting Standards No. 121, "Accounting for the Impairment of Long-Lived
Assets and for Long-Lived Assets to be Disposed Of" ("SFAS No. 121"). SFAS No.
121 establishes criteria for recognizing and measuring impairment losses when
recovery of recorded long-lived asset values is uncertain. In the opinion of
Management of the Partnership, there has been no impact on the Partnership's
financial condition or results of operations in 2000, 1999, or 1998.
26
Fuel Reserve
The fuel reserve, carried at cost, represents an approximate six-day
supply of coal held for emergency purposes. Management plans to rebuild the fuel
reserve in order to maintain an approximate twenty-day supply on hand throughout
the year.
Deferred Financing Costs
Financing costs, consisting primarily of the costs incurred to obtain
project financing, are deferred and amortized using the effective interest rate
method over the term of the related permanent financing.
Scheduled major overhauls
The Securities and Exchange Commission ("SEC") has recently stated that
it objects to the accrue in advance method for scheduled significant replacement
and overhaul costs. The SEC has asked the Accounting Standards Executive
Committee ("AcSEC") to issue guidance related to accounting for these costs,
which will not include the accrue in advance method. Prior to the issuance of
guidance from the AcSEC, the SEC has stated that it will allow companies to
recognize the change from accrue in advance as a cumulative effect of a change
in accounting principle. The Partnership has, therefore, changed its method of
accounting for scheduled major overhaul to the as incurred method effective
January 1, 2000.
As such, the Partnership has recognized a cumulative effect of a change
in accounting principle of $920,536 to increase net income. The effect of
adopting this new accounting principle in 2000 was to reduce operating and
maintenance costs and increase net income by approximately $424,000.
Revenue Recognition
Revenues from the sale of electricity are recorded based on output
delivered and capacity provided at rates as specified under contract terms.
Income Taxes
Under current law, no Federal or state income taxes are paid directly by
the Partnership. All items of income and expense of the Partnership are
allocable to and reportable by the Partners in their respective income tax
returns. Accordingly, no provision is made in the accompanying consolidated
financial statements for Federal or state income taxes.
Reclassifications
Certain reclassifications have been made in the 1999 financial
statements to conform to the 2000 presentation.
Derivative Financial Instruments
27
The Partnership will adopt SFAS No. 133 "Accounting for Derivative
Instruments and Hedging Activities", as amended by SFAS Nos. 137 and 138, on
January 1, 2001. This standard requires the Partnership recognize all
derivatives, as defined in the statements listed above, on the balance sheet at
fair value. Derivatives, or any portion thereof, that are not effective hedges
must be adjusted to fair value through income. If derivatives are effective
hedges, depending on the nature of the hedges, changes in the fair value of
derivatives either will offset the change in fair value of the hedged assets,
liabilities, or firm commitments through earnings, or will be recognized in
other comprehensive income until the hedged items are recognized in earnings.
The Partnership has certain derivative commodity contracts for the physical
delivery of purchase and sale quantities transacted in the normal course of
business. These derivatives are exempt from the requirements of SFAS No. 133
under the normal purchases and sales exception, and thus will not be reflected
on the balance sheet at fair value. Due to this exception and the Partnership's
current adoption of SFAS No. 133 will not have a material impact on its
financial condition or results of operations.
Organization Costs
The Partnership adopted the American Institute of Certified Public
Accountants Statement of Position 98-5, "Reporting on the Costs of Start-up
Activities" ("SOP 98-5") during 1998 which resulted in the write-off of all
organization costs reflected on the accompanying consolidated financial
statements.
3. DEPOSITS:
In 1991, in accordance with a contract between the Partnership and Martin
County, the Partnership provided Martin County with a security deposit in the
amount of $149,357 to secure installation and maintenance of required
landscaping materials. In January 1998, the Partnership received a refund of
funds in excess of the required deposit as security for the first year
maintenance as set forth in the contract between the Partnership and Martin
County. The remaining deposit in the amount of $39,804 was included in current
assets as of December 31, 1997. These funds were returned in September 1998 when
the Partnership submitted a surety bond for the refund amount. In July 1999,
Martin County Growth Management Environmental Division authorized release of the
funds securing the landscaping.
In 1991, in accordance with the Planned Unit Development Zoning
Agreement between the Partnership and Martin County, the Partnership deposited
$1,000,000 in trust with the Board of County Commissioners of Martin County (the
"PUD Trustee"). Income from this trust will be used solely for projects
benefiting the community of Indiantown. On July 23, 2025, the PUD Trustee is
required to return the deposit to the Partnership. As of December 31, 2000 and
1999, estimated present values of this deposit of $159,365 and $80,000,
respectively, are included in deposits in the accompanying consolidated balance
sheets. The remaining balance is included in property, plant and equipment as
part of total capitalized construction expenses.
28
4. BONDS AND NOTES PAYABLE:
First Mortgage Bonds
The Partnership and ICL Funding jointly issued $505,000,000 of First
Mortgage Bonds (the "First Mortgage Bonds") in a public issuance registered with
the SEC. Proceeds from the issuance were used to repay outstanding balances of
$273,513,000 on a prior construction loan and to complete the project. The First
Mortgage Bonds are secured by a lien on and security interest in substantially
all of the assets of the Partnership. The First Mortgage Bonds were issued in 10
separate series with fixed interest rates ranging from 7.38 to 9.77 percent and
with maturities ranging from 1996 to 2020. Interest is payable semi-annually on
June 15 and December 15 of each year. Interest expense related to the First
Mortgage Bonds was $44,275,872, $45,138,915, and $46,014,161, in 2000, 1999, and
1998 respectively.
Tax Exempt Facility Revenue Bonds
The proceeds from the issuance of $113,000,000 of Series 1992A and
1992B Industrial Development Revenue Bonds (the "1992 Bonds") through the Martin
County Industrial Development Authority (the "MCIDA") were invested in an
investment portfolio with Fidelity Investments Institutional Services Company.
On November 22, 1994, the Partnership refunded the 1992 Bonds with proceeds from
the issuance of $113,000,000 Series 1994A and of $12,010,000 Series 1994B Tax
Exempt Facility Refunding Revenue Bonds which were issued on December 20, 1994
(the Series 1994A Bonds and the Series 1994B Bonds, collectively, the "1994 Tax
Exempt Bonds").
The 1994 Tax Exempt Bonds were issued by the MCIDA pursuant to an
Amended and Restated Indenture of Trust between the MCIDA and NationsBank of
Florida, N.A. (succeeded by The Bank of New York Trust Company of Florida, N.A.)
as trustee (the "Trustee"). Proceeds from the 1994 Tax Exempt Bonds were loaned
to the Partnership pursuant to the MCIDA Amended and Restated Authority Loan
Agreement dated as of November 1, 1994 (the "Authority Loan"). The Authority
Loan is secured by a lien on and a security interest in substantially all of the
assets of the Partnership. The 1994 Tax Exempt Bonds, which mature December 15,
2025, carry fixed interest rates of 7.875 percent and 8.05 percent for Series
1994A and 1994B, respectively. Total interest paid related to the 1994 Tax
Exempt Bonds was $9,865,555 for each of the years ended December 31, 2000, 1999,
and 1998. The Tax Exempt Bonds and the First Mortgage Bonds are equal in
seniority.
29
Future minimum payments related to outstanding First Mortgage Bonds and
1994 Tax Exempt Bonds at December 31, 2000 are as follows:
2001 $ 11,140,896
2002 11,460,408
2003 14,566,086
2004 16,785,152
2005 16,257,206
Thereafter 509,509,117
-------------
Total $579,718,865
=============
Equity Contribution Agreement30
FPL Termination Fee Letter of Credit
On or before the Commercial Operation Date, the Partnership was
required to provide FPL with a letter of credit equal to the total termination
fee as defined in the Power Purchase Agreement in each year not to exceed
$50,000,000. Pursuant to the terms of the Letter of Credit and Reimbursement
Agreement, the Partnership obtained a commitment for the issuance of this letter
of credit. At the Commercial Operation Date, this letter of credit replaced the
completion letter of credit. The initial amount of $13,000,000 was issued for
the first year of operations and increased to $40,000,000 in January 1999 and
then to $50,000,000 in January 2000. During 2000, 1999, and 1998 no draws were
made on this letter of credit. Commitment fees of $689,092, $704,555, and
$643,076, were paid on this letter of credit in 2000 1999, and 1998,
respectively.
FPL QF Letter of Credit
Within 60 days after the Commercial Operation Date, the Partnership was
required to provide a letter of credit for use in the event of a loss of
Qualifying Facility ("QF") status under the Public Utility Regulatory Policies
Act of 1978 ("PURPA"). The initial amount was $500,000 increasing by $500,000
per agreement year to a maximum of $5,000,000. Pursuant to the terms of the
Letter of Credit and Reimbursement Agreement, the Partnership obtained a
commitment for the issuance of this letter of credit. The amount will be used by
the Partnership as necessary to maintain or reinstate the Facility's qualifying
facility status. The Partnership may, in lieu of a letter of credit, make
regular cash deposits to a dedicated account in amounts of $500,000 per
agreement year to a maximum of $5,000,000. In February 1996, the Partnership
established a QF account with the Trustee. The balance in this account at
December 31, 2000 and 1999, was $2,500,000 and $2,000,000, respectively, and is
included in noncurrent, restricted funds held by trustee in the accompanying
consolidated balance sheets.
Steam Host Letter of Credit
At financial closing in October 1992, the Partnership provided Caulkins
a letter of credit in the amount of $10,000,000 pursuant to the Energy Services
Agreement (see Note 6). This letter of credit was terminated in 1994 and a new
one was issued with essentially the same terms. In the event of a default under
the Energy Services Agreement (see Note 6), the Partnership is required to pay
liquidated damages in the amount of $10,000,000. Failure by the Partnership to
pay the damages within 30 days allows the steam host to draw on the letter of
credit for the amount of damages suffered by Caulkins. As of December 31, 2000,
1999, and 1998, no draws had been made on this letter of credit. Commitment fees
of $137,818, $143,011 and $156,315 were paid relating to this letter of credit
in 2000, 1999 and 1998, respectively.
31
Debt Service Reserve Letter of Credit
On November 22, 1994, the Partnership also entered into a debt service
reserve letter of credit and reimbursement agreement with Banque Nationale de
Paris pursuant to which a debt service reserve letter of credit in the amount of
approximately $60,000,000 was issued. Such agreement has a rolling term of five
years subject to extension at the discretion of the banks party thereto.
Drawings on the debt service reserve letter of credit are available to pay
principal and interest on the First Mortgage Bonds, the 1994 Tax-Exempt Bonds
and interest on any loans created by drawings on such debt service reserve
letter of credit. Cash and other investments held in the debt service reserve
account will be drawn on prior to any drawings on the debt service reserve
letter of credit. As of December 31, 2000, 1999, and 1998, no draws had been
made on this letter of credit. Commitment fees of $410,733, $488,281, and
$877,901 were paid on this letter of credit in 2000, 1999, and 1998,
respectively. On January 11, 1999, pursuant to the Disbursement Agreement, the
Debt Service Reserve Letter of Credit was reduced to $29,925,906.
5. PURCHASE AGREEMENTS:
Coal Purchase and Transportation Agreement
The Partnership entered into a 30-year purchase contract with Lodestar
Energy, Inc. ("Lodestar") (formerly known as Costain Coal, Inc.), commencing
from the first day of the calendar month following the Commercial Operation
Date, for the purchase of the Facility's annual coal requirements at a price
defined in the agreement, as well as for the disposal of ash residue. The
Partnership has no obligation to purchase a minimum quantity of coal under this
agreement.
On June 8, 1998, the Partnership entered into a three-year agreement
with Lodestar, which established an arrangement for the Partnership's disposal
of ash at alternative locations. The Partnership also entered a three-year
agreement with VFL Technology Corporation for the disposal of ash with similar
terms.
32
Lime Purchase Agreement
On May 1, 1992, the Partnership entered into a lime purchase agreement
with Chemical Lime Company of Alabama, Inc. for supply of the Facility's lime
requirements for the Facility's dry scrubber sulfur dioxide removal system. The
initial term of the agreement is 15 years from the Commercial Operation Date and
may be extended for a successive 5-year period. Either party may cancel the
agreement after January 1, 2000, upon proper notice. The Partnership has no
obligation to purchase a minimum quantity of lime under the agreement. The price
of lime was renegotiated in 1999 for a three-year period beginning January 1,
2000. Chemlime notified the Partnership of its intention to cancel the agreement
effective in the first quarter of 2002. The Partnership expects to put a
replacement contract in place during the third quarter of 2001.
6. SALES AND SERVICES AGREEMENTS:
Power Purchase Agreement
On May 21, 1990, the Partnership entered into a Power Purchase Agreement
with FPL for sales of the Facility's electric output. As amended, the agreement
is effective for a 30-year period, commencing with the Commercial Operation
Date. The pricing structure provides for both capacity and energy payments.
Capacity payments remain relatively stable because the amounts do not
vary with dispatch. Price increases are contractually provided. Capacity
payments include a bonus or penalty payment if actual capacity is in excess of
or below specified levels of available capacity. Energy payments are derived
from a contractual formula defined in the agreement based on the actual cost of
domestic coal at another FPL plant, St. Johns River Power Park.
Energy Services Agreement
On September 30, 1992, the Partnership entered into an energy services
agreement with Caulkins. Commencing on the Commercial Operation Date and
continuing throughout the 15-year term of the agreement, Caulkins is required to
purchase the lesser of 525 million pounds of steam per year or the minimum
quantity of steam per year necessary for the Facility to maintain its status as
a Qualifying Facility under PURPA. The Facility declared Commercial Operation
with Caulkins on March 1, 1996.
33
7. COMMITMENTS AND CONTINGENCIES
Dispute with FPL
On March 19, 1999, the Partnership filed a complaint against FPL in the
United States District Court for the Middle District of Florida. The lawsuit
stems from a course of action pursued by FPL since March 10, 1999, in which FPL
purported to exercise its dispatch and control rights under the Power Purchase
Agreement in a manner which the Partnership believes violated the terms of the
power sales agreement. In its complaint, the Partnership charges that such
conduct was deliberately calculated to cause the Partnership to be unable to
meet the requirements to maintain the Facility's status as a Qualifying Facility
under the Public Utility Regulatory Policies Act of 1978.
The complaint alleges that FPL took the position that if the Facility is
off-line for any reason, then FPL is under no obligation to allow the Facility
to reconnect to FPL's system. The original complaint asserted, however, that the
Partnership specifically and successfully negotiated for a contractual right to
operate the Facility up to 100 MW ("Minimum Load") in order to enable it to
cogenerate sufficient steam to maintain its Qualifying Facility status. While
FPL has not disputed that the Partnership may maintain Minimum Load operations
if the Facility is delivering power when FPL requests the Partnership to
decommit the Facility, the complaint states that FPL has claimed absolute
discretion to deny the Partnership permission to reconnect the Facility with
FPL's system.
Since the loss of Qualifying Facility status may result in an event of
default under the Power Purchase Agreement, the Partnership must take action to
address this matter. The Partnership is investigating various alternatives to
mitigate its QF risk. These are described under "QF Mitigation Options" below.
The complaint asserts causes of action for (i) FPL's breach of the Power
Purchase Agreement, (ii) FPL's anticipatory repudiation of the Power Purchase
Agreement, (iii) breach of the implied covenant of good faith, fair dealing and
commercial reasonableness and (iv) a declaratory judgment by the court of the
rights of the parties under the Power Purchase Agreement. The Partnership seeks
(a) a declaratory ruling that FPL's actions constitute a breach of the terms of
the Power Purchase Agreement and that the Partnership has the absolute right to
operate the Facility at Minimum Load (except for reasons of safety or system
security) at the rates provided for in the Power Purchase Agreement, (b)
injunctive relief preventing FPL from further violating the Power Purchase
Agreement, (c) compensatory damages and (d) other relief as the court may deem
appropriate.
On April 14, 1999, FPL filed a responsive pleading to the complaint
including a motion to dismiss two of the four counts raised in the complaint,
raising certain affirmative defenses and seeking declaration that FPL has
unfettered dispatch rights under the Power Purchase Agreement. On April 23,
1999, FPL filed answer to the counts, which were not challenged in the motion to
dismiss. On May 13, 1999, the Partnership filed its response to FPL's motion to
dismiss and request for declaratory judgement. On May 18, 1999, the Court denied
FPL's Motion to Dismiss in its entirety. The Partnership filed an amended
complaint, which was accepted on June 17, 1999. The amended complaint simply
consolidated the Partnership's claims for breach of contract and breach of the
implied obligation of good faith and fair dealing which was, in part, in
response to a recent federal court decision. FPL moved to dismiss the entire
amended complaint and the Partnership filed its opposition papers August 2,
1999. The Court
34
granted FPL’s motion to dismiss only with respect to the first count of the
complaint. The Partnership has amended its complaint to address issues raised by
the Court in its decision to dismiss this count. FPL was expected to file a new
motion to dismiss the amended complaint. The second amended complaint, which was
filed on March 21, 2000, is attached as an exhibit to the Report.
This summary of the Partnership's complaint against FPL is qualified in
its entirety by the complaint, which was filed with the court in docket
99-317-CIV-ORL-19C. This summary does not, nor does it purport to, include all
of the material statements and claims made in the complaint, and has been
provided solely for the reader's convenience. This summary is not intended to be
relied upon for any purpose without reference to the complaint.
On December 19, 2000, FPL and the Partnership participated in a
mediation conference with respect to the pending litigations described herein.
As a result of this conference, FPL and the Partnership executed two Settlement
Agreements intended to resolve all pending litigation. Only the Settlement
Agreement for the pending federal court litigation requires amendment of the
power sales agreement. The amendment must be approved by the Florida Public
Service Commission, and certain conditions set forth in the Indenture for the
Bonds, including confirmation of the Bonds' investment grade rating, must be met
for it to become effective.
An outline of the business terms set forth in this Settlement Agreement
provides that if the Facility is off-line for any reason, the Partnership shall
have the right, upon up to 6 hours notice and subject only to safety and system
reliability issues, to reconnect to FPL's system and produce up to 100 MW. The
Settlement Agreement provides that if this occurs when FPL has decommitted the
Facility, the Partnership will be paid FPL's actual "as available" energy rates
for the first 360 of such hours each year (in this context, "as available"
energy costs reflect actual energy production costs avoided by FPL resulting
from the production or purchase of energy from the Facility and other sources).
If fewer than 360 hours are used in any year, FPL may carry the balance forward,
not to exceed a total of 1440 hours in any year. If the hours accumulated
exercising this reconnection right exceed FPL's balance, the Partnership will be
paid for energy produced during those hours at the energy rates set forth under
the power sales agreement.
Management of the Partnership believes that this resolution provides the
Partnership with the flexibility it requires to maintain its Qualifying Facility
status without materially adversely affecting the Project.
On December 12, 2000, FPL filed a complaint against the Partnership in
the Circuit Court of the 19th Judicial District in and for Martin County,
Florida. In its complaint, FPL alleged that the Partnership breached the power
sales agreement by failing to include certain payments from its coal supplier
and its coal transporter in the Partnership's calculation of its fuel costs
which are included in the calculation of the actual energy costs under the power
sales agreement. The power sales agreement requires a sharing of actual energy
costs between FPL and the Partnership to the extent the actual costs differ
(either upward or downward) from a formula contained in the agreement. FPL
sought unspecified damages and declaratory relief including a finding that the
Partnership breached the power sales agreement. The Settlement Agreement
provides that the Partnership will include in future calculations of its fuel
costs all costs, credits, rebates, discounts, and allowances/concessions from
all past, current or future
35
vendors of fuel, ash, lime, and fuel transportation subject to execution of a
definitive agreement embodying the terms of this Settlement Agreement. The
Partnership will make a one time payment of $800,000 to FPL as settlement for
disputed amounts under fuel audits performed for calendar years 1997 and 1998.
8. RELATED PARTY TRANSACTIONS:
Management Services Agreement
The Partnership has a Management Services Agreement with NEG, a
California general partnership and a wholly owned indirect subsidiary of NEG,
Inc., for the day-to-day management and administration of the Partnership's
business relating to the Facility. The agreement commenced on September 30, 1992
and will continue through August 31, 2026. Compensation to NEG under the
agreement includes an annual base fee of $650,000 (adjusted annually), wages and
benefits for employees performing work on behalf of the Partnership and other
costs directly related to the Partnership. Payments of $4,324,042, $4,120,468,
and $2,800,644, in 2000, 1999, and 1998 were made to NEG, respectively. At
December 31, 2000 and 1999, the Partnership owed NEG $437,925 and $432,068,
respectively, which are included in accounts payable and accrued liabilities in
the accompanying consolidated balance sheets.
Operations and Maintenance Agreement
The Partnership has an Operation and Maintenance Agreement with PG&E
OSC, a California general partnership and a wholly owned indirect subsidiary of
NEG, Inc., for the operations and maintenance of the Facility for a period of 30
years (starting September 30, 1992). Thereafter, the agreement will be
automatically renewed for periods of 5 years until terminated by either party
with 12 months notice. If targeted plant performance is not reached, PG&E
OSC will pay liquidated damages to the Partnership. Compensation to PG&E OSC
under the agreement includes an annual base fee of $1.5 million ($900,000 of
which is subordinate to debt service and certain other costs), certain earned
fees and bonuses based on the Facility's performance and reimbursement for
certain costs including payroll, supplies, spare parts, equipment, certain
taxes, licensing fees, insurance and indirect costs expressed as a percentage of
payroll and personnel costs. The fees are adjusted quarterly by a measure of
inflation as defined in the agreement. Payments of $9,921,638, $9,790,473, and
$9,605,917 were made to PG&E OSC in 2000, 1999, and 1998, respectively. At
December 31, 2000 and 1999, the Partnership owed PG&E OSC $201,840 and
$836,346 respectively, which is included in accounts payable and accrued
liabilities in the accompanying consolidated balance sheets.
Railcar Lease
The Partnership entered into a 15 year Car Leasing Agreement with GE
Capital Railcar Services Corporation, an affiliate of GECC, to furnish and lease
72 pressure differential hopper railcars to the Partnership for the
transportation of fly ash and lime. The cars were delivered starting in April
1995, at which time the lease was recorded as a capital lease. The leased asset
of $5,753,375 and accumulated depreciation of $2,168,022 and $1,784,463 is
included in property, plant and equipment as of December 31, 2000 and 1999.
Payments of $629,856, including principal and interest, were made in 2000, 1999,
and 1998 and the lease obligation of approximately $4,275,166 and $4,583,700, as
36
of December 31, 2000 and 1999 is reported as a lease payable in the accompanying
consolidated balance sheets.
Future minimum payments related to the Car Leasing Agreement as of
December 31, 2000 are as follows:
2001 $ 629,856
2002 629,856
2003 629,856
2004 629,856
2005 629,856
Thereafter 2,744,767
---------
Total minimum lease payments 5,894,047
Interest portion of lease payable (1,618,881)
-----------
Present value of future minimum lease
payments 4,275,166
Current portion (331,628)
-----------
Long-term portion $3,943,538
===========
Distribution to Partners
On June 15 and December 15, 2000, as provided in the Partnership
Agreement, Indiantown distributed approximately $15.3 million and $10.1 million,
respectively, to the Partners. An additional $0.6 million of distributable cash
was retained for capital projects and is included in cash and cash equivalents
as of December 31, 2000, on the accompanying consolidated balance sheet.
37
9. DISCLOSURE ABOUT FAIR VALUE OF FINANCIAL INSTRUMENTS
December 31, 2000
Financial Liabilities Carrying Amount Fair Value
- --------------------- --------------- ----------
Tax Exempt Bonds $125,010,000 $127,510,200
First Mortgage Bonds $454,708,865 $492,483,915
December 31, 1999
Financial Liabilities Carrying Amount Fair Value
- --------------------- --------------- ----------
Tax Exempt Bonds $125,010,000 $127,510,200
First Mortgage Bonds $466,242,000 $465,188,912
For the Tax Exempt Bonds and First Mortgage Bonds, the fair values of
the Partnership's bonds payable are based on the stated rates of the Tax Exempt
Bonds and First Mortgage Bonds and current market interest rates to estimate
market values for the Tax Exempt Bonds and the First Mortgage Bonds.
The carrying amounts of the Partnership's cash and cash equivalents,
accounts receivable, deposits, prepaid expenses, investments held by trustee,
accounts payable, accrued liabilities and accrued interest approximate fair
value.
38
CONSENT OF INDEPENDENT PUBLIC ACCOUNTANTS
As independent public accountants, we hereby consent to the incorporation of our
report dated January 11, 2001 (except with respect to matters discussed in Note
1, as to which the date is March 15, 2001) in this Form 10-K included in
Registration Statement File No. 33-82034. It should be noted that we have not
audited any financial statements of the company subsequent to December 31, 2000
or performed any audit procedures subsequent to the date of our report.
/S/ ARTHUR ANDERSEN LLP
Vienna, VA
March 28, 2001
Item 9 CHANGES IN AND DISAGREEMENTS WITH ACCOUNTANTS ON
ACCOUNTING AND FINANCIAL DISCLOSURE
None.
39
PART III
Item 10 DIRECTORS AND EXECUTIVE OFFICERS
Indiantown Cogeneration, L.P. Board of Control
The following table sets forth the names, ages and positions of the
members of the Board of Control of the Partnership. Members of the Board of
Control are selected from time to time by, and serve at the pleasure of, the
Partners of the Partnership.
Name Age Position
---- --- --------
Thomas J. Bonner................. 46 Palm Representative and
Thaleia Representative
Thomas F. Schwartz .............. 39 Palm Representative and
Thaleia Representative
P. Chrisman Iribe................ 49 IPILP Representative
Sanford L. Hartman............... 47 IPILP Representative
Thomas J. Bonner is Vice President - Asset Management for Cogentrix Energy,
Inc. and has been with Cogentrix since 1987. Prior to joining Cogentrix Energy,
Inc., Mr. Bonner spent five years as a utilities manager in an integrated fiber
and chemical production facility. Mr. Bonner holds a B.S. from the U.S. Naval
Academy, and an M.B.A. from Old Dominion University.
Thomas F. Schwartz is Group Senior Vice President and Chief Financial
Officer of Cogentrix Energy, Inc. He is responsible for the areas of corporate
finance and tax planning. Mr. Schwartz joined Cogentrix Energy, Inc. in 1991,
and has held various positions in accounting and finance. Prior to joining
Cogentrix Energy, Inc., Mr. Schwartz was Audit Manager with Arthur Andersen,
LLP. Mr. Schwartz holds a B.A. degree in accounting from the University of North
Carolina - Charlotte.
P. Chrisman Iribe is President of NEG and has been with NEG since it was
formed in 1989. Prior to joining NEG, Mr. Iribe was senior vice president for
planning, state relations and public affairs with ANR Pipeline Company, a
natural gas pipeline company and a subsidiary of the Coastal Corporation. Mr.
Iribe holds a B.A. degree in Economics from George Washington University.
Sanford L. Hartman joined NEG's legal group in 1990 and became its
General Counsel in April 1999. Prior to joining NEG, Hartman was counsel to Long
Lake Energy Corporation, an independent power producer with headquarters in New
York City and was an attorney with Bishop, Cook, Purcell & Reynolds, a
Washington, D.C., law firm. Mr. Hartman has a BA in Political Science from Drew
University and a JD from Temple University.
ICL Funding Corporation Board of Directors
The following table sets forth the names, ages and positions of the
directors and executive officers of ICL Funding. Directors are elected annually
and each elected director
40
holds office until a successor is elected. Officers are elected from time to
time by vote of the Board of Directors.
Name Age Position
---- --- --------
P. Chrisman Iribe 49 Director, President
Sanford L. Hartman 47 Director
John R. Cooper 52 Vice President, Chief
Financial Officer and
Principal Accounting
Officer
Item 11 REMUNERATION OF DIRECTORS AND OFFICERS
No cash compensation or non-cash compensation was paid in any prior year
or is currently proposed to be paid in the current calendar year by ICL Funding
or the Partnership to any of the officers and directors listed above.
Accordingly, the Summary Compensation Table and other tables required under Item
402 of the Securities and Exchange Commission's Regulation S-K have been
omitted, as presentation of such tables would not be meaningful.
Management services for the Partnership are being performed by NEG on a
cost-plus basis in addition to the payment of a base fee. Operation and
maintenance services for the Partnership will be performed by PG&E OSC on a
cost-plus basis. In addition to a base fee, PG&E OSC may earn certain additional
fees and bonuses based on specified performance criteria.
Item 12 SECURITY OWNERSHIP OF CERTAIN BENEFICIAL OWNERS
AND MANAGEMENT
Partnership interests in the Partnership, as of December 31, 2000, are
held as follows:
Toyan 30.05% L.P.
IPILP 19.95% G.P.
Palm 10.00% G.P.
Thaleia 40.00% L.P.
All of the outstanding shares of common stock of ICL Funding are owned by
the Partnership.
Item 13 CERTAIN RELATIONSHIPS AND RELATED TRANSACTIONS
The Partnership has several material contracts with affiliated entities.
These contracts, which include the Construction Contract, the Management
Services Agreement, the Operations and Maintenance Agreement and the Railcar
Lease, are described elsewhere in this report, most notably in Note 7 to the
Partnership's consolidated financial statements.
41
PART IV
Item 14 EXHIBITS, FINANCIAL STATEMENT SCHEDULES AND
REPORTS ON FORM 8-K
a) Documents filed as of this Report Page
(1) Consolidated financial statements:
Report of Independent Public Accountants............ 18
Consolidated Balance Sheets as of
December 31, 2000 and 1999 ........................ 19
Consolidated Statements of Operations for the
years ended December 31, 2000, 1999 and 1998....... 21
Consolidated Statements of Changes
in Partners' Capital for the years ended
December 31, 2000, 1999 and 1998................... 22
Consolidated Statements of Cash Flows for the
years ended December 31, 2000, 1999 and 1998....... 23
Notes to Consolidated Financial
Statements......................................... 24
(2) Consolidated Financial Statement
Schedules.......................................... None
b) Reports on Form 8-K:
None
c) Exhibits:
Exhibit
No. Description
3.1 Certificate of Incorporation of Indiantown Cogeneration
Funding Corporation.*
3.2 By-laws of Indiantown Cogeneration Funding Corporation.*
3.3 Certificate of Limited Partnership of Indiantown
Cogeneration, L.P.*
3.4 Amended and Restated Limited Partnership Agreement of
Indiantown Cogeneration, L.P., among Palm Power Corporation,
Toyan Enterprises and TIFD III-Y Inc.*
3.5 Form of First Amendment to Amended and Restated Limited
Partnership Agreement of Indiantown Cogeneration, L.P.*
42
3.6 Dana Amendment to Amended and Restated Limited Partnership
Agreement of Indiantown Cogeneration, L.P.******
3.7 Cogentrix Amendment to Amended and Restated Limited
Partnership Agreement of Indiantown Cogeneration, L.P.******
3.8 Third Amendment to Amended and Restated Limited Partnership
Agreement of Indiantown Cogeneration, L.P.******
4.1 Trust Indenture, dated as of November 1, 1994, among
Indiantown Cogeneration Funding Corporation, Indiantown
Cogeneration, L.P., and NationsBank of Florida, N.A., as
Trustee, and First Supplemental Indenture thereto.**
4.2 Amended and Restated Mortgage, Assignment of Leases, Rents,
Issues and Profits and Security Agreement and Fixture Filing
among Indiantown Cogeneration, L.P., as Mortgagor, and Bankers
Trust Company as Mortgagee, and NationsBank of Florida, N.A.,
as Disbursement Agent and, as when and to the extent set forth
therein, as Mortgagee with respect to the Accounts, dated as
of November 1, 1994.**
4.3 Assignment and Security Agreement between Indiantown
Cogeneration, L.P., as Debtor, and Bankers Trust Company as
Secured Party, and NationsBank of Florida, N.A., as
Disbursement Agent and, as when, and to the extent set forth
therein, a Secured Party with respect to the Accounts, dated
as of November 1, 1994.**
10.1.1 Amended and Restated Indenture of Trust between Martin County
Industrial Development Authority, as Issuer, and NationsBank
of Florida, N.A., as Trustee, dated as of November 1, 1994.**
10.1.2 Amended and Restated Authority Loan Agreement by and between
Martin County Industrial Development Authority and Indiantown
Cogeneration, L.P., dated as of November 1, 1994.**
10.1.3 Letter of Credit and Reimbursement Agreement among Indiantown
Cogeneration, L.P., as Borrower, and the Banks Named Therein,
and Credit Suisse, as Agent, dated as of November 1, 1994.**
10.1.4 Disbursement Agreement, dated as of November 1, 1994, among
Indiantown Cogeneration, L.P., Indiantown Cogeneration Funding
Corporation, NationsBank of Florida, N.A., as Tax-Exempt
Trustee, NationsBank of Florida, N.A., as Trustee, Credit
Suisse, as Letter of Credit Provider, Credit Suisse, as
Working Capital Provider, Banque Nationale de Paris, as Debt
Service Reserve Letter of Credit Provider, Bankers Trust
Company, as Collateral Agent, Martin County Industrial
Development Authority, and NationsBank of Florida, N.A., as
Disbursement Agent.**
10.1.5 Revolving Credit Agreement among Indiantown Cogeneration,
L.P., as Borrower, and the Banks Named Therein, and Credit
Suisse, as Agent, dated as of November 1, 1994.**
10.1.6 Collateral Agency and Intercreditor Agreement, dated as of
November 1, 1994, among NationsBank of Florida, N.A., as
Trustee under the Trust Indenture, dated as of November 1,
1994, NationsBank of Florida, N.A., as
43
Tax-Exempt Trustee under the Tax Exempt Indenture, dated as of
November 1, 1994, Credit Suisse, as letter of Credit Provider,
Credit Suisse, as Working Capital Provider, Banque Nationale
de Paris, as Debt Service Reserve Letter of Credit Provider,
Indiantown Cogeneration, L.P., Indiantown Cogeneration Funding
Corporation, Martin County Industrial Development Authority,
NationsBank of Florida, N.A., as Disbursement Agent under the
Disbursement Agreement dated as of November 1, 1994, and
Bankers Trust Company, as Collateral Agent.**
10.1.7 Amended and Restated Equity Loan Agreement dated as of
November 1, 1994, between Indiantown Cogeneration, L.P., as
the Borrower, and TIFD III-Y Inc., as the Equity Lender.**
10.1.8 Equity Contribution Agreement, dated as of November 1, 1994,
between TIFD III-Y Inc. and NationsBank of Florida, N.A., as
Disbursement Agent.**
10.1.9 GE Capital Guaranty Agreement, dated as of November 1, 1994,
between General Electric Capital Corporation, as Guarantor,
and NationsBank of Florida, N.A., as Disbursement Agent.**
10.1.11 Debt Service Reserve Letter of Credit and Reimbursement
Agreement among Indiantown Cogeneration, L.P., as Borrower,
and the Banks Named Therein, and Banque Nationale de Paris, as
Agent, dated as of November 1, 1994.**
10.2.18 Amendment No. 2 to Coal Purchase Agreement, dated as of April
19, 1995.***
10.2.19 Fourth Amendment to Energy Services Agreement, dated as of
January 30, 1996.****
21 Subsidiaries of Registrant*
99 Copy of Registrants' press release dated January 3, 1996.****
99.1 Copy of Registrant’s complaint against FPL filed March 19,
1999.*****
99.2 Copy of Registrant’s Second Amended Complaint against FPL filed
March 21, 2000.*******
- --------------------
* Incorporated by reference from the Registrant Statement on Form S-1, as
amended, file no. 33-82034 filed by the Registrants with the SEC in July 1994.
** Incorporated by reference from the quarterly report on Form 10-Q, file no.
33-82034 filed by the Registrants with the SEC in December 1994.
*** Incorporated by reference from the quarterly report on Form 10-Q, file no.
33-82034 filed by the Registrants with the SEC in May 1995. **** Incorporated by
reference from the current report on Form 8-K, file no. 33-82034 filed by the
Registrants with the SEC in January 1996.
***** Incorporated by reference from the current report on Form 8-K file no.
33-82034 filed by the Registrants with the SEC in March 1999.
****** Incorporated by reference from the quarterly report on Form 10-Q file no.
33-82034 filed by the Registrants with the SEC in August 1999
*******Incorporated by reference from annual report on Form 10-K file no.
33-82034 filed by Registrants with the SEC in March 2000.
44
SIGNATURE
Pursuant to the requirements of the Securities Exchange Act of 1934, the
co-registrant has duly caused this Form 10-K to be signed on its behalf by the
undersigned, thereunto duly authorized, in the city of Bethesda, state of
Maryland, on March 30, 2001.
INDIANTOWN COGENERATION, L.P.
Date: March 30, 2001 /s/ John R. Cooper
-----------------------------
Name: John R. Cooper
Title: Chief Financial Officer,
Principal Accounting Officer
and Senior Vice President
Pursuant to the requirements of the Securities Act of 1933, this Form
10-K has been signed by the following persons in the capacities and on the dates
indicated.
Signature Title Date
- --------- ----- ----
/s/ P. Chrisman Iribe Member of Board of Control, March 30, 2001
- ---------------------- President and Secretary
P. Chrisman Iribe
/s/ John R. Cooper Chief Financial Officer, March 30, 2001
- ---------------------- Principal Accounting
John R. Cooper Officer and Senior
Vice President
/s/ Thomas J. Bonner Member of Board of Control March 30, 2001
- --------------------
Thomas J. Bonner
/s/ Thomas F. Schwartz Member of Board of Control March 30, 2001
- ----------------------
Thomas F. Schwartz
/s/ Sanford L. Hartman Member of Board of Control March 30, 2001
- ---------------------- and Senior Vice President
Sanford L. Hartman
45
SIGNATURE
Pursuant to the requirements of the Securities Exchange Act of 1934, the
co-registrant has duly caused this Form 10-K to be signed on its behalf by the
undersigned, thereunto duly authorized, in the city of Bethesda, state of
Maryland, on March 30, 2001.
INDIANTOWN COGENERATION
FUNDING CORPORATION
Date: March 30, 2001 /s/ John R. Cooper
------------------
Name: John R. Cooper
Title: Chief Financial Officer,
Principal Accounting Officer
and Vice President
Pursuant to the requirements of the Securities Act of 1933, this Form
10-K has been signed by the following persons in the capacities and on the dates
indicated.
Signature Title Date
/s/ P. Chrisman Iribe Director and President March 30, 2001
- ---------------------
P. Chrisman Iribe
/s/ John R. Cooper Chief Financial Officer, March 30, 2001
- ---------------------- Principal Accounting
John R. Cooper Officer and Vice President
46