UNITED STATES
SECURITIES AND EXCHANGE COMMISSION
Washington, D.C. 20549
---------------------
FORM 10-Q
[ X ] Quarterly Report Pursuant to Section 13 or 15(d) of the Securities
Exchange Act of 1934 for the quarter ended SEPTEMBER 30, 1996
[ ] Transition Report Pursuant to Section 13 or 15(d) of the Securities
Exchange Act of 1934 for the transition period from
______________________ to ______________________
Commission File Number: 033-73160
CALPINE CORPORATION
(A DELAWARE CORPORATION)
I.R.S. EMPLOYER IDENTIFICATION NO. 77-0212977
50 WEST SAN FERNANDO STREET
SAN JOSE, CALIFORNIA 95113
TELEPHONE: (408) 995-5115
Indicate by check mark whether the registrant (1) has filed all reports required
to be filed by Section 13 or 15(d) of the Securities Exchange Act of 1934 during
the preceding 12 months (or for such shorter period that the registrant was
required to file such reports), and (2) has been subject to such filing
requirements for the past 90 days.
Yes [ X ] No [ ]
Indicate the number of shares outstanding of each of the issuer's classes of
common stock as of the latest practicable date.
On September 30, 1996, there were 18,050,000 of the issuer's
Common Stock $0.001 par value outstanding.
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<PAGE>
CALPINE CORPORATION AND SUBSIDIARIES
REPORT ON FORM 10-Q
FOR THE QUARTER ENDED SEPTEMBER 30, 1996
INDEX
PART I. FINANCIAL INFORMATION PAGE NO.
ITEM 1. Financial Statements
Condensed Consolidated Balance Sheets
September 30, 1996 and December 31, 1995............................3
Condensed Consolidated Statements of Operations
Three and Nine Months Ended September 30, 1996 and 1995.............4
Condensed Consolidated Statements of Cash Flows
Nine Months Ended September 30, 1996 and 1995.......................5
Notes to Condensed Consolidated Financial Statements................6
ITEM 2. Management's Discussion and Analysis of Financial
Condition and Results of Operations................................14
PART II. OTHER INFORMATION
ITEM 1. Legal Proceedings.........................................20
ITEM 2. Change in Securities......................................20
ITEM 3. Defaults Upon Senior Securities...........................20
ITEM 4. Submission of Matters to a Vote of Security Holders.......20
ITEM 5. Other Information.........................................20
ITEM 6. Exhibits and Reports on Form 8-K..........................21
SIGNATURES....................................................................28
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<PAGE>
PART I. FINANCIAL INFORMATION
ITEM 1. FINANCIAL STATEMENTS
CALPINE CORPORATION AND SUBSIDIARIES
CONDENSED CONSOLIDATED BALANCE SHEETS
(IN THOUSANDS)
<TABLE>
<CAPTION>
SEPTEMBER 30, DECEMBER 31,
1996 1995
---------- ----------
ASSETS (UNAUDITED)
<S> <C> <C>
Current assets:
Cash and cash equivalents .............................................. $ 99,477 $ 21,810
Accounts receivable .................................................... 57,560 20,124
Acquisition project receivables ........................................ 791 8,805
Collateral securities, current portion ................................. 5,463 --
Prepaid lease expenses ................................................. 13,087 --
Notes receivable from Coperlasa, current portion ....................... 3,083 --
Other current assets ................................................... 7,317 5,491
---------- ----------
Total current assets .............................................. 186,778 56,230
Property, plant and equipment, net .......................................... 650,107 447,751
Investments in power projects and capitalized costs ......................... 14,404 8,218
Collateral securities, net of current portion ............................... 89,538 --
Notes receivable from related parties ....................................... 21,554 19,391
Notes receivable from Coperlasa, net of current portion ..................... 17,830 6,094
Restricted cash ............................................................. 13,382 9,627
Deferred charges and other assets ........................................... 13,036 7,220
---------- ----------
Total assets ...................................................... $1,006,629 $ 554,531
========== ==========
LIABILITIES AND SHAREHOLDERS' EQUITY Current liabilities:
Current non-recourse project financing ................................. $ 26,253 $ 84,708
Notes payable to bank and short-term borrowings ........................ -- 1,177
Accounts payable ....................................................... 15,835 6,876
Accrued payroll and related expenses ................................... 3,436 2,789
Accrued interest payable ............................................... 9,526 7,050
Other accrued expenses ................................................. 9,194 2,657
---------- ----------
Total current liabilities ......................................... 64,244 105,257
Long-term line of credit .................................................... -- 19,851
Non-recourse project financing, less current portion ........................ 286,466 190,642
Notes payable ............................................................... 6,729 6,348
Senior Notes ................................................................ 285,000 105,000
Deferred income taxes, net .................................................. 104,649 97,621
Deferred lease incentive .................................................... 80,603 --
Other liabilities ........................................................... 6,416 4,585
---------- ----------
Total liabilities ................................................. 834,107 529,304
---------- ----------
Shareholders' equity:
Common stock ........................................................... 18 10
Additional paid-in-capital ............................................. 138,347 6,214
Retained earnings ...................................................... 34,157 19,003
---------- ----------
Total shareholders' equity ........................................ 172,522 25,227
---------- ----------
Total liabilities and shareholders' equity ........................ $1,006,629 $ 554,531
========== ==========
The accompanying notes are an integral part of these condensed
consolidated financial statements.
</TABLE>
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<PAGE>
CALPINE CORPORATION AND SUBSIDIARIES
CONDENSED CONSOLIDATED STATEMENTS OF OPERATIONS
(IN THOUSANDS, EXCEPT PER SHARE AMOUNTS)
(UNAUDITED)
<TABLE>
<CAPTION>
THREE MONTHS ENDED NINE MONTHS ENDED
SEPTEMBER 30, SEPTEMBER 30,
--------------------- -----------------------
1996 1995 1996 1995
--------- --------- --------- ---------
<S> <C> <C> <C> <C>
Revenue:
Electricity and steam sales .............. $ 68,281 $ 40,883 $ 140,311 $ 89,897
Service contract revenue ................. 172 1,947 5,606 5,076
Income (loss) from unconsolidated
investments in power projects ....... 1,158 (654) 2,871 (2,445)
Interest income on loans to power projects 1,286 -- 4,103 --
--------- --------- --------- ---------
Total revenue ................... 70,897 42,176 152,891 92,528
--------- --------- --------- ---------
Cost of revenue:
Plant operating expenses, depreciation,
operating lease and production
royalties ........................... 34,384 20,682 81,219 48,895
Service contract expenses and other ...... 1,469 1,593 5,953 3,998
--------- --------- --------- ---------
Total cost of revenue ........... 35,853 22,275 87,172 52,893
--------- --------- --------- ---------
Gross profit .................................. 35,044 19,901 65,719 39,635
Project development expenses .................. 1,044 1,379 2,454 2,687
General and administrative expenses ........... 4,903 2,076 10,777 5,735
--------- --------- --------- ---------
Income from operations .......... 29,097 16,446 52,488 31,213
Other (income) expense:
Interest expense ......................... 12,434 8,404 31,099 23,520
Other expense and income, net ............ 1,149 (380) (1,628) (1,235)
--------- --------- --------- ---------
Income before provision for
income taxes ............... 15,514 8,422 23,017 8,928
Provision for income taxes .................... 4,782 3,457 7,862 3,665
--------- --------- --------- ---------
Net income ...................... $ 10,732 $ 4,965 $ 15,155 $ 5,263
========= ========= ========= =========
Primary earnings per share
Weighted average shares outstanding ...... 14,070 10,961 12,695 10,964
========= ========= ========= =========
Primary earnings per share ............... $ 0.76 $ 0.45 $ 1.19 $ 0.48
========= ========= ========= =========
Fully diluted earnings per share
Weighted average shares outstanding ...... 14,303 10,961 12,772 10,964
========= ========= ========= =========
Fully diluted earnings per share ......... $ 0.75 $ 0.45 $ 1.19 $ 0.48
========= ========= ========= =========
The accompanying notes are an integral part of these condensed
consolidated financial statements.
</TABLE>
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<PAGE>
CALPINE CORPORATION AND SUBSIDIARIES
CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS
(IN THOUSANDS)
(UNAUDITED)
<TABLE>
<CAPTION>
NINE MONTHS ENDED SEPTEMBER 30,
1996 1995
--------- ---------
<S> <C> <C>
Net cash provided by operating activities ................ $ 25,694 $ 18,909
--------- ---------
Cash flows from investing activities:
Acquisition of property, plant and equipment ........ (13,189) (12,962)
Investment in Gilroy, net of cash on hand ........... (138,073) --
Investment in King City, net of cash on hand ........ (5,408) --
Investment in King City collateral securities, net .. (95,001) --
Advances to Coperlasa ............................... (14,238) --
Investment in Greenleaf, net of cash on hand ........ -- (16,958)
Investment in Watsonville, net of cash on hand ...... -- 494
Investments in power projects and capitalized costs . (3,504) (875)
Increase in notes receivable from related party ..... (250) (250)
Decrease in restricted cash ......................... 245 1,482
Other, net .......................................... 98 (23)
--------- ---------
Net cash used in investing activities .......... (269,320) (29,092)
--------- ---------
Cash flows from financing activities:
Proceeds from issuance of common stock .............. 82,141 --
Proceeds from issuance of Senior Notes Due 2006 ..... 180,000 --
Proceeds from issuance of preferred stock ........... 50,000 --
Borrowings from lines of credit ..................... 59,922 26,851
Repayment of lines of credit ........................ (79,773) (15,000)
Borrowing from bank ................................. 45,000 --
Repayments to bank .................................. (46,177) --
Borrowings of non-recourse project financing ........ 116,000 76,026
Repayment of non-recourse project financing ......... (77,754) (73,988)
Borrowings from uncommitted demand loan facility .... -- 2,460
Repayment of uncommitted demand loan facility ....... -- (587)
Repayment of working capital loan ................... -- (4,500)
Financing costs ..................................... (8,066) (1,233)
--------- ---------
Net cash provided by financing activities ...... 321,293 10,029
--------- ---------
Net increase (decrease) in cash and cash equivalents ..... 77,667 (154)
Cash and cash equivalents, beginning of period ........... 21,810 22,527
--------- ---------
Cash and cash equivalents, end of period ................. $ 99,477 $ 22,373
========= =========
Supplementary information:
Cash paid during the period for:
Interest ....................................... $ 28,170 $ 26,001
Income taxes ................................... $ 955 $ 833
</TABLE>
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<PAGE>
CALPINE CORPORATION AND SUBSIDIARIES
NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS
SEPTEMBER 30, 1996
1. ORGANIZATION AND OPERATION OF THE COMPANY
Calpine Corporation (Calpine), a Delaware corporation, and subsidiaries
(collectively, the Company) are engaged in the development,
acquisition, ownership and operation of power generation facilities and
the sale of electricity and steam in the United States and selected
international countries. The Company has interests in 15 geothermal
steam fields, geothermal power generation facilities, and natural
gas-fired cogeneration facilities having an aggregate capacity of 1,057
megawatts in Northern California, Washington and Mexico. Each of the
generation facilities produces electricity for sale to utilities.
Thermal energy produced by the gas-fired cogeneration facilities is
sold to governmental and industrial users, and steam produced by the
geothermal steam fields is sold to utility-owned power plants. In 1996,
the Company began marketing power and energy services to utilities and
other end users.
In July 1996, the Company's Board of Directors authorized the
reincorporation of the Company into Delaware in connection with the
Company's initial public offering. In addition, the Board of Directors
approved a stock split of approximately 5.194-for-1. On September 13,
1996, the reincorporation of the Company and the stock split became
effective. The accompanying financial statements reflect the
reincorporation and the stock split as if such transactions had been
effective for all periods. (See Note 12 for further information).
2. SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES
Basis of Interim Presentation
The accompanying interim condensed consolidated financial statements of
the Company have been prepared by the Company, without audit by
independent public accountants, pursuant to the rules and regulations
of the Securities and Exchange Commission. In the opinion of
management, the condensed consolidated financial statements include all
and only normal recurring adjustments necessary to present fairly the
information required to be set forth therein. Certain information and
note disclosures normally included in financial statements prepared in
accordance with generally accepted accounting principles have been
condensed or omitted from these statements pursuant to such rules and
regulations and, accordingly, should be read in conjunction with the
audited consolidated financial statements of the Company included in
the Company's annual report on Form 10-K for the year ended December
31, 1995. The results for interim periods are not necessarily
indicative of the results for the entire year.
Earnings Per Share
Earnings per share has been computed using the weighted average number
of shares of common stock, common equivalent shares from convertible
preferred and common equivalent shares from stock options outstanding
(when dilutive, using the treasury stock method).
On September 20, 1996 in connection with the Company's initial public
offering of common stock (see Note 12), all outstanding preferred stock
was converted into common stock (see Note 11).
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<PAGE>
CALPINE CORPORATION AND SUBSIDIARIES
NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (CONTINUED)
SEPTEMBER 30, 1996
Accordingly, all share and per share amounts presented in the
accompanying consolidated condensed financial statements reflect this
conversion.
Power Marketing
The Company, through its wholly owned subsidiary Calpine Power Services
Company (CPSC), markets power and energy services to utilities and
other end users. CPSC provides these services by entering into
contracts to purchase or supply electricity at a specified delivery
point and specified future date. In some cases, CPSC utilizes option
agreements to manage its exposure to market fluctuations. At September
30, 1996, CPSC held forward contracts with net notional quantities of
approximately 415,000 megawatt hours.
Net open positions may exist due to the origination of new transactions
and the Company's evaluation of changing market conditions. The open
position exposes the Company to the risk that fluctuating market prices
may adversely impact its financial position or results of operations.
However, The net open position is actively managed. The impact of such
fluctuations on the Company's financial position is not necessarily
indicative of the impact of price fluctuations throughout the year.
CPSC values its portfolio using the aggregate lower of cost or market
method. Losses are recorded to reflect the market changes on the net
open position of the entire portfolio. Net gains are recognized when
realized.
With respect to open power contracts, CPSC has established certain
reserves and allowances, principally for adverse changes in market
conditions prior to termination of the commitments. At September 30,
1996, the Company had recorded allowances of approximately $1.6
million, which is included in service contract revenue in the
accompanying income statement.
The Company's credit risk associated with power contracts results from
the risk of loss as a result of non-performance by counterparties. The
Company reviews and assesses counterparty risk to limit any material
impact to its financial position and results of operations. The Company
does not anticipate non-performance by the counterparties. The Company
sets credit limits prior to entering into transactions and has not
obtained collateral or other security.
Impact of Recent Accounting Pronouncements
In March 1995, the Financial Accounting Standards Board issued
Statement of Financial Accounting Standards (SFAS) No. 121, Accounting
for the Impairment of Long-Lived Assets and for Long-Lived Assets to be
Disposed Of. This pronouncement requires that long-lived assets and
certain identifiable intangible assets be reviewed for impairment
whenever events or changes in circumstances indicate that the carrying
amount of an asset may not be recoverable. An impairment loss is to be
recognized when the sum of undiscounted cash flows is less than the
carrying amount of the asset. Measurement of the loss for assets that
the entity expects to hold and use are to be based on the fair market
value of the asset. SFAS No. 121 must be adopted for fiscal years
beginning in 1996. The Company adopted SFAS No. 121 effective January
1, 1996, and determined that adoption of this pronouncement had no
material impact on the results of operations or financial condition as
of January 1, 1996.
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<PAGE>
CALPINE CORPORATION AND SUBSIDIARIES
NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (CONTINUED)
SEPTEMBER 30, 1996
In October 1995, the Financial Accounting Standards Board issued SFAS
No. 123, Accounting for Stock Based Compensation. The disclosure
requirements of SFAS No. 123 are effective for the Company's 1996
fiscal year. The new pronouncement did not have an impact on results of
operations since the intrinsic value-based method prescribed by
Accounting Principles Board Opinion No. 25 and also allowed by SFAS No.
123 will continue to be used by the Company to account for its stock-
based compensation plans.
Reclassifications
Prior year amounts in the consolidated financial statements have been
reclassified where necessary to conform to the 1996 presentation.
3. ACCOUNTS RECEIVABLE
The Company has both billed and unbilled receivables. The components of
accounts receivable as of September 30, 1996 and December 31, 1995 are
as follows (in thousands):
SEPTEMBER 30, DECEMBER 31,
1996 1995
---------- ---------
Projects: ..... (unaudited)
Billed . $56,175 $18,341
Unbilled 1,002 525
Other .. 383 1,258
------- -------
$57,560 $20,124
======= =======
Other accounts receivable as of December 31, 1995 consisted primarily
of amounts related to the Greenleaf facilities purchase price. In May
1996, the Company reclassified such accounts receivable to property,
plant and equipment as an adjustment to the purchase price of the
Greenleaf facilities (see Note 6).
Accounts receivable from related parties as of September 30, 1996 and
December 31, 1995 are comprised of the following (in thousands):
SEPTEMBER 30, DECEMBER 31,
1996 1995
------ ------
(unaudited)
O.L.S. Energy-Agnews, Inc. ..... $ 686 $ 806
Geothermal Energy Partners, Ltd. 255 462
Sumas Cogeneration Company, L.P. 763 908
Electrowatt and subsidiaries ... -- 1
------ ------
$1,704 $2,177
====== ======
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<PAGE>
CALPINE CORPORATION AND SUBSIDIARIES
NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (CONTINUED)
SEPTEMBER 30, 1996
4. INVESTMENTS IN POWER PROJECTS
The Company has unconsolidated investments in power projects which are
accounted for under the equity method. Unaudited financial information
for the nine months ended September 30, 1996 and 1995 related to these
investments is as follows (in thousands):
<TABLE>
<CAPTION>
1996 1995
------------------------------------------- -------------------------------------------
Sumas O.L.S. Geothermal Sumas O.L.S. Geothermal
Cogeneration Energy- Energy Cogeneration Energy- Energy
Company, Agnews, Partners, Company, Agnews, Partners,
L.P. Inc. Ltd. L.P. Inc. Ltd.
--------------- ----------- -------------- -------------- ------------ -------------
<S> <C> <C> <C> <C> <C> <C>
Revenue $ 31,740 $ 8,182 $ 16,312 $ 22,875 $ 8,285 $ 15,705
Operating expenses 19,404 5,942 8,787 20,187 6,179 7,734
--------------- ----------- -------------- -------------- ------------ -------------
Income from
operations 12,336 2,240 7,525 2,688 2,106 7,971
Other expenses, net 7,635 2,284 3,582 7,962 2,319 4,100
--------------- ----------- -------------- -------------- ------------ -------------
Net income (loss) $ 4,701 $ (44) $ 3,943 $ (5,274) $ (213) $ 3,871
=============== =========== ============== ============== ============ =============
Company's share of
net income (loss) $ 2,687 $ (13) $ 197 $ (2,637) $ (1) $ 193
=============== =========== ============== ============== ============ =============
</TABLE>
5. NOTES RECEIVABLE FROM COPERLASA
During 1996, the Company continued to loan funds to Constructora y
Perforadora Latina, S.A. de V.V. (Coperlasa). The Company loaned $14.4
million to Coperlasa during 1996 in connection with a 160 megawatt
geothermal steam production contract at the Cerro Prieto geothermal
resource in Baja California, Mexico.
6. GREENLEAF TRANSACTION
In April 1995, the Company purchased the capital stock of the companies
which owned 100% of the assets of two 49.5 megawatt natural gas-fired
cogeneration facilities (collectively, the Greenleaf facilities)
located in Yuba City, California. The purchase price included a cash
payment of $20.3 million and the assumption of project debt totaling
$60.2 million. In April 1996, the Company finalized the purchase price
in accordance with the Share Purchase Agreement dated March 30, 1995.
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<PAGE>
CALPINE CORPORATION AND SUBSIDIARIES
NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (CONTINUED)
SEPTEMBER 30, 1996
The acquisition was accounted for as a purchase and the purchase price
has been allocated to the acquired assets and liabilities based on
their estimated fair values. The adjusted allocation of the purchase
price is as follows (in thousands):
Current assets .............. $ 6,572
Property, plant and equipment 122,545
---------
Total assets ....... 129,117
---------
Current liabilities ......... (1,079)
Deferred income taxes, net .. (46,580)
---------
Total liabilities .. (47,659)
---------
Net purchase price .......... $ 81,458
=========
7. KING CITY TRANSACTION
In April 1996, the Company entered into a long-term operating lease
with BAF Energy, A California Limited Partnership (BAF), for a 120
megawatt natural gas-fired combined cycle facility located in King
City, California. The facility generates electricity for sale to
Pacific Gas and Electric Company (PG&E) pursuant to a long-term power
sales agreement through 2019. Natural gas for the facility is supplied
by Chevron USA Inc. pursuant to a contract which expires June 30, 1997.
Under the terms of the operating lease, the Company makes semi-annual
lease payments to BAF on each February 15 and August 15, a portion of
which is supported by a $95.0 million collateral fund owned by the
Company. Included in the accompanying September 30, 1996 balance sheet
is approximately $13.1 million of unamortized prepaid lease costs
related to the August 15, 1996 payment. The collateral fund consists of
a portfolio of investment grade and U.S. Treasury Securities that will
mature serially and coincident in amounts equal to a portion of the
lease. The collateral fund securities are accounted for as
held-to-maturity investments under SFAS No. 115, Accounting for Certain
Investments in Debt and Equity Securities. As of September 30, 1996,
future rent payments are $24.4 million for 1997, $23.8 million for
1998, $19.4 million for 1999, $20.1 million for 2000 and $204.1 million
thereafter.
The Company has recorded the value of the above-market pricing provided
in the power sales agreement (PSA) as an asset which is included in
property, plant and equipment, since the Company has, in substance,
acquired the PSA. The Company has also recorded a deferred lease
incentive of $80.6 million at September 30, 1996 equal to the value of
the above-market payments to be received. The asset and liability are
being amortized over the appropriate life of the power sales agreement
and lease, respectively.
The Company financed the collateral fund and other transaction costs
with $50.0 million of proceeds from the issuance of preferred stock to
Electrowatt by Calpine (see Note 11) and other short-term borrowings,
which included $13.3 million of borrowings under the Credit Suisse
Credit Facility (see Note 9) and a $45.0 million loan from The Bank of
Nova Scotia. The Company repaid the short-term borrowings from a
portion of the net proceeds of the Senior Notes Due 2006 issued in May
1996 (see Note 10).
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<PAGE>
CALPINE CORPORATION AND SUBSIDIARIES
NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (CONTINUED)
SEPTEMBER 30, 1996
8. GILROY TRANSACTION
On August 29, 1996, the Company acquired a 120 megawatt natural
gas-fired cogeneration power facility located in Gilroy, California,
from McCormick & Company, Inc. The Company purchased the Gilroy
facility for a purchase price of $125.0 million plus certain contingent
consideration, which the Company currently estimates will amount to
approximately $24.1 million.
The acquisition of the Gilroy facility was financed utilizing a
non-recourse project loan in the aggregate amount of $116.0 million.
Such loan, which was provided by Banque Nationale de Paris, consists of
a 15-year tranche in the amount of $81.0 million and an 18-year tranche
in the amount of $35.0 million and bears interest at fixed and floating
rates.
Electricity generated by the Gilroy facility is sold to PG&E pursuant
to a long-term power sales agreement terminating in 2018. The power
sales agreement contains payment provisions for capacity and energy. In
addition to the sale of electricity to PG&E, the Gilroy facility
produces and sells thermal energy to ConAgra, Inc. Natural gas for the
Gilroy facility is supplied pursuant to a contract with Amoco Energy
Trading Corporation expiring July 31, 1997.
The following unaudited pro forma consolidated results for the Company
gives effect to (i) the King City Transaction; (ii) the Gilroy
Transaction, and (iii) interest income from the Coperlasa note
receivable, as if such transactions had occurred on January 1, 1996.
Unaudited pro forma consolidated results are also provided for the
effects of the above transactions and (iv) the Watsonville operating
lease acquired on June 28, 1995; and (v) the Greenleaf Transaction, as
if such transactions had occurred on January 1, 1995. (in thousands
except per share amounts):
Nine Months Ended September 30,
-------------------------------
1996 1995
--------- ---------
Revenue .................. $176,261 $164,728
Net income ............... $ 15,417 $ 13,599
Primary earnings per share $ 1.21 $ 1.24
9. LINES OF CREDIT
Prior to September 25, 1996, the Company had a $50.0 million Credit
Facility with Credit Suisse and had letters of credit outstanding for
$3.0 million. Credit Suisse owns 44.9% of Electrowatt Ltd.
(Electrowatt), the former indirect sole owner of the Company prior to
the initial public offering (see Note 12). On September 25, 1996, the
Company terminated its Credit Suisse Credit Facility and entered into a
$50.0 million three-year revolving credit facility with a consortium of
commercial lending institutions which include The Bank of Nova Scotia,
International Nederlanden U.S. Capital Corporation, Sumitomo Bank of
California and Canadian Imperial Bank of Commerce. At September 30,
1996, the Company had no borrowings and $3.0 million of letters of
credit outstanding. Borrowings bear interest at The Bank of Nova
Scotia's base rate or at the London Interbank Offered Rate (LIBOR) plus
an applicable margin. Interest is paid on the last day of each interest
period for such loans, but not less often than quarterly, based on the
principal amount outstanding during the period for base rate loans, and
on the last day of each applicable interest period, but not less often
than 90 days for LIBOR loans. The credit agreement expires in September
1999.
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<PAGE>
CALPINE CORPORATION AND SUBSIDIARIES
NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (CONTINUED)
SEPTEMBER 30, 1996
10. SENIOR NOTES DUE 2006
On May 16, 1996, the Company issued $180.0 million aggregate principal
amount of 10 1/2% Senior Notes Due 2006. The net proceeds of $174.9
million were used to repay $53.7 million of borrowings under the Credit
Suisse Credit Facility, $57.0 million of non-recourse project financing
and $45.0 million of borrowings from The Bank of Nova Scotia. The
remaining $19.2 million was available for general corporate purposes.
Transaction costs of $5.1 million incurred in connection with the
public debt offering were recorded as a deferred charge and are
amortized over the ten-year life of the Senior Notes Due 2006.
The Senior Notes Due 2006 will mature on May 15, 2006. The Company has
no sinking fund or mandatory redemption obligations with respect to the
Senior Notes Due 2006. Interest is payable semi-annually on May 15 and
November 15.
11. PREFERRED STOCK
The Company had 5,000,000 authorized shares of Series A Preferred
Stock, all of which were issued on March 21, 1996 to Electrowatt. The
shares of Series A Preferred Stock were not publicly traded. No
dividends were payable on the Series A Preferred Stock. The Series A
Preferred Stock contained provisions regarding liquidation and
conversion rights. Upon the consummation of the Company's initial
public offering, all of the Series A Preferred Stock was converted into
approximately 2.2 million shares of common stock and sold to the public
in the offering by Electrowatt (see Note 12).
12. COMMON STOCK
On September 25, 1996, Calpine completed the initial public offering of
18,045,000 shares of its common stock with $0.001 par value per share
(the Common Stock Offering). In the Common Stock Offering, the Company
issued and sold 5,477,820 shares of common stock and Electrowatt sold
12,567,180 shares of common stock, representing its entire ownership
interest in Calpine. As a result of the Common Stock Offering,
Electrowatt no longer owns any interest in Calpine. The Company
received approximately $82.1 million of net proceeds from the Common
Stock Offering. Approximately $13.0 million of such net proceeds was
used to repay short-term bank borrowings. The remaining net proceeds
are expected to be used for working capital and general corporate
purposes, and for the development and acquisition of power generation
facilities. In connection with the Common Stock Offering, the Company
reincorporated in the State of Delaware, converted the outstanding
Class B Common Stock into $0.001 par value Common Stock, eliminated the
authorized Class A Common Stock and Class B Common Stock, completed a
5.194-for-1 stock split of the Company's Common Stock and converted the
Company's outstanding Preferred Stock into shares of Common Stock.
On October 17, 1996, the Company issued an additional 1,793,400 shares
of Common Stock to cover over-allotments of shares in connection with
the Common Stock Offering and received approximately $27.1 million of
net proceeds. The net proceeds are expected to be used for working
capital and general corporate purposes, and for the development and
acquisition of power generation facilities.
-12-
<PAGE>
13. CONTINGENCIES
The Company, together with over 100 other parties, was named as a
defendant in the second amended complaint in an action brought in
August 1993 by the bankruptcy trustee for Bonneville Pacific
Corporation (Bonneville), captioned Roger G. Segal, as the Chapter 11
Trustee for Bonneville Pacific Corporation v. Portland General
Corporation, et al., in the United States District Court for the
District of Utah. This complaint alleges that, in conjunction with top
executives of Bonneville and with the alleged assistance of the other
100 defendants, the Company engaged in a broad conspiracy and fraud.
The complaint has been amended a number of times. The Company has
answered each version of the complaint by denying all claims. In August
1994, the Company successfully moved for an order severing the
trustee's claim against the Company from the claims against the other
defendants. Although the case involves over 25 separate financial
transactions entered into by Bonneville, the severed case concerns the
Company in respect of only one of these transactions. In 1988, the
Company invested $2.0 million in a partnership formed with Bonneville
to develop four hydroelectric projects in the State of Hawaii. The
projects were not successfully developed by the partnership, and,
subsequent to Bonneville's Chapter 11 filing, the Company filed a claim
as a creditor against Bonneville's bankruptcy estate. The trustee
initially alleged that the Company was one of many defendants in this
case responsible for Bonneville's deepening insolvency and sought
damages in excess of $500.0 million. However, based upon the motion for
summary judgement filed by the trustee in September 1996, the maximum
compensatory damages which the trustee is seeking will not exceed $2.0
million. There can be no assurance, however, of the actual amount of
damages to be sought by the trustee if the case is set for trial. The
Company believes the claims against it are without merit and will
continue to defend the action vigorously. The Company further believes
that the resolution of this matter will not have a material effect on
its financial position or results of operation.
In connection with the Company's unsuccessful attempt to acquire
O'Brien Environmental Energy, Inc. (O'Brien) in 1995 through U.S.
Bankruptcy Court proceedings, the Company had capitalized approximately
$3.7 million of third-party costs. Pursuant to the terms of a contract
with O'Brien, the Company sought the reimbursement of such costs and a
$2.0 million break-up fee, each of which was subject to the approval of
the Bankruptcy Court. On November 8, 1996, the court denied Calpine's
application for approval of such costs and fees. As a result, the
Company provided a $3.6 million allowance in the third quarter of 1996,
which is included in Other expense and income , net, in the
accompanying income statement. The Company will begin the appeal
process in the near future.
The Company is involved in various other claims and legal actions
arising out of the normal course of business. Management does not
expect that the outcome of these cases will have a material effect on
the Company's financial position or results of operations.
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<PAGE>
ITEM 2. MANAGEMENT'S DISCUSSION AND ANALYSIS OF FINANCIAL
CONDITION AND RESULTS OF OPERATIONS
Except for historical financial information contained herein, the matters
discussed in this quarterly report on Form 10-Q may be considered
"forward-looking" statements within the meaning of Section 27A of the Securities
Act of 1933, as amended, and Section 21E of the Securities Exchange Act of 1934,
as amended. Such statements include declarations regarding the intent, belief or
current expectations of the Company and its management. Prospective investors
are cautioned that any such forward-looking statements are not guarantees of
future performance and involve a number of risks and uncertainties; actual
results could differ materially from those indicated by such forward-looking
statements. Among the important factors that could cause actual results to
differ materially from those indicated by such forward-looking statements are:
(i) that the information is of a preliminary nature and may be subject to
further adjustment, (ii) the possible unavailability of financing, (iii) risks
related to the development and operation of geothermal energy resources, (iv)
the impact of avoided cost pricing and energy price fluctuations, (v) the impact
of curtailment, (vi) risks associated with power project development and
acquisitions, (vii) start-up risks, (viii) general operating risks, (ix) the
dependence on third parties, (x) risks associated with international
investments, (xi) risks associated with the power marketing business, (xii)
changes in government regulation, (xiii) the effects of seismic disturbances,
(xiv) the availability of natural gas, (xv) the effects of competition, (xvi)
the dependence on senior management, (xvii) volatility in the Company's stock
price, (xviii) fluctuations in quarterly results and seasonality, and (xix)
other risks identified from time to time in the Company's reports and
registration statements filed with the Securities and Exchange Commission,
including the registration statement on Form S-1 related to the Company's recent
initial public offering.
OVERVIEW
Calpine is engaged in the acquisition, development, ownership and operation of
power generation facilities and the sale of electricity and steam in the United
States and selected international countries. The Company has interests in 15
power generation facilities and steam fields having an aggregate capacity of
1,057 megawatts. Calpine's net interest in these facilities is 983 megawatts, of
which 467 megawatts or 48% are natural gas-fired facilities and 517 megawatts or
52% are geothermal facilities. Since its inception in 1984, Calpine has
developed substantial expertise in all aspects of electric power generation. The
Company's vertical integration has resulted in significant growth over the last
five years as Calpine has applied its extensive engineering, construction
management, operations, fuel management and financing capabilities to
successfully implement its acquisition and development program. During the last
five years, Calpine has expanded from $41.2 million of total assets as of
December 31, 1991 to $1.0 billion of total assets as of September 30, 1996.
Financial results reached record levels for the nine months ended September 30,
1996. Revenue of $152.9 million in 1996 was 65% or $60.4 million higher than the
comparable period in 1995. Revenue earned on the payment of fixed capacity
payments pursuant to the long-term power sales agreements increased by 105% to
$50.1 million compared to $24.4 million for the same period in 1995. Gross
profit of $65.7 million in 1996 was 66% or $26.1 million higher than the
comparable period in 1995, and net income of $15.2 million in 1996 was 187% or
$9.9 million higher than the same period in 1995.
Operating results also increased for the nine months ended September 30, 1996.
Production from the Company's power generation facilities increased by 91% in
1996 with 1.3 million megawatt hours produced compared to 682,300 megawatt hours
for the same period in 1995. Megawatt hours produced from the Company's steam
fields also reached record levels with over 1.8 million megawatt hours compared
to 1.7 million megawatt hours for the same period in 1995.
The increase in the Company's results of operations is directly attributable to:
(i) the acquisition of the 120 megawatt Gilroy gas-fired power facility on
August 29, 1996, (ii) the long-term lease of the 120 megawatt
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King City gas-fired power facility effective May 2, 1996, (iii) the $20.0
million investment in the Cerro Prieto Steam Fields commencing in November 1995,
(iv) the lease of the 28.5 megawatt Watsonville gas-fired power facility on June
29, 1995 and (v) the acquisition of the two 49.5 megawatt Greenleaf 1 & 2
gas-fired power facilities on April 21, 1995.
In addition, the Company completed an initial public offering of its common
stock on September 25, 1996, which provided approximately $82.1 million of net
proceeds. Subsequently, the Company sold additional shares on October 17, 1996
for $27.1 million of net proceeds. On May 16, 1996, the Company raised $174.9
million of net proceeds through the sale of its 10 1/2% Senior Notes Due 2006.
Electricity and steam sales accounted for approximately 92% of total revenue for
the nine months ended September 30, 1996. Service contract revenue, income from
unconsolidated investments in power projects recognized under the equity method,
and interest income on loans to power projects accounted for 3%, 2% and 3%,
respectively, of total revenue.
Each of the power generation facilities produces electricity for sale to a
utility pursuant to a long-term power sales agreement generally having original
terms of 20 to 30 years. For each of the Company's consolidated power generation
facilities, revenue is earned in the form of energy and capacity payments.
Energy is typically paid based upon the utility's avoided cost of energy. In
some cases, a fixed rate is received for all or a portion of the energy
delivered. In all cases, the Company receives a fixed capacity payment. The
majority of these capacity payments are paid during the months of May through
October. Steam produced from the Company's geothermal steam fields, as well as
thermal energy produced from the gas-fired facilities, are also sold pursuant to
long-term steam sales agreements.
SELECTED OPERATING DATA
Set forth below is certain selected operating information for the power
generation facilities and steam fields, for which results are consolidated in
the Company's statement of operations. The information set forth under power
plants consists of the results for the West Ford Flat and Bear Canyon
facilities, the Greenleaf 1 & 2 facilities since April 21, 1995, the Watsonville
facility since June 29, 1995, the King City facility since May 2, 1996 and the
Gilroy facility since August 29, 1996. The information set forth under steam
fields consists of the results for the PG&E Unit 13 and Unit 16 Steam Fields,
the SMUDGEO#1 Steam Fields and the Thermal Power Company Steam Fields.
<TABLE>
<CAPTION>
THREE MONTHS ENDED NINE MONTHS ENDED
------------------------------ ----------------------------
Sept. 30,1996 Sept. 30,1995 Sept. 30,1996 Sept. 30,1995
------------- ------------- ------------- -------------
<S> <C> <C> <C> <C>
POWER PLANTS (dollars in thousands)
Electricity revenue
Energy ....................... $ 26,199 $ 15,497 $ 60,561 $ 37,795
Capacity ..................... $ 30,321 $ 15,294 $ 50,095 $ 24,370
Megawatt hours produced ........ 593,172 358,241 1,332,594 682,300
Average energy rate per kilowatt
hour produced (in cents) ..... 4.417 4.326 4.545 5.539
STEAM FIELDS
Steam revenue .................. $ 11,761 $ 10,092 $ 27,627 $ 27,731
Megawatt hours produced ........ 770,021 643,370 1,811,449 1,670,687
Average energy rate per kilowatt
hour produced (in cents)...... 1.527 1.569 1.525 1.660
</TABLE>
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<PAGE>
RESULTS OF OPERATIONS
THREE AND NINE MONTHS ENDED SEPTEMBER 30, 1996 COMPARED TO THREE AND NINE MONTHS
ENDED SEPTEMBER 30, 1995
REVENUE. The Company's total revenue of $70.9 million and $152.9 million for the
three and nine months ended September 30, 1996 represented a 68% and 65%
increase, respectively, when compared to $42.2 million and $92.5 million for the
comparable periods in 1995. Electricity and steam sales revenue increased 67%
and 56% to $68.2 million and $140.3 million for the three and nine months ended
September 30, 1996, compared to $40.9 million and $89.9 million for the
comparable periods in 1995. The increase for the three months ended September
30, 1996 compared to the same period for 1995 was primarily due to revenue of
$18.8 million from the King City facility and $5.2 million from the Gilroy
facility. The increase for the nine months ended September 30, 1996 compared to
the same period in 1995 was primarily due to revenue of $29.8 million from the
King City facility, $5.2 million from the Gilroy facility, and $6.6 million and
$4.1 million of higher revenue from the Greenleaf 1 & 2 and Watsonville
facilities, respectively, due to a full nine-months of operations in 1996. The
remaining increases for the three and nine month periods were primarily due to
higher generation and higher prices at other Company power generation facilities
and steam fields. Service contract revenue decreased to $172,000 for the three
months ended September 30, 1996 compared to $1.9 million for the same period in
1995. The decrease was primarily due to a $1.6 million reserve related to the
Company's electricity trading operations. Service contract revenue increased 10%
to $5.6 million for the nine months ended September 30, 1996 compared to $5.1
million for the same period in 1995. The increase was primarily related to
billings for services at the Aidlin and Agnews facilities, partially offset by
the trading loss discussed above. Income from unconsolidated investments in
power projects increased to $1.2 million and $2.9 million for the three and nine
months ended September 30, 1996 compared to losses of $654,000 and $2.4 million
for the comparable periods in 1995. The increases are primarily attributable to
$832,000 and $2.7 million of equity income for the three and nine months ended
September 30, 1996 from the Company's investment in Sumas Cogeneration Company,
L.P. (Sumas) (see Note 4). The increase in Sumas' profitability during 1996 is
primarily attributable to a contractual increase in the energy price in
accordance with the power sales agreement with Puget Sound Power & Light
Company. Interest income on loans to power projects contributed $1.3 million and
$4.1 million to the revenue increase for the three and nine months ended
September 30, 1996. The revenue was due to $495,000 and $2.4 million
attributable to the recognition of interest income on loans to the sole
shareholder of the general partner of the Sumas facility, and $791,000 and $1.7
million of interest income on loans to Coperlasa related to the Cerro Prieto
Steam Fields.
COST OF REVENUE increased to $35.9 million and $87.2 million for the three and
nine months ended September 30, 1996 compared to $22.3 million and $52.9 million
for the same periods in 1995. The increases were primarily due to plant
operating, depreciation, operating lease and production royalty expenses
attributable to (i) operations of the King City facility subsequent to May 2,
1996, (ii) operations of the Gilroy facility subsequent to August 29, 1996 and
(iii) a full nine month period of operations at the Greenleaf 1 & 2 and
Watsonville facilities since their transaction dates of April 21, 1995 and June
29, 1995, respectively. The increases in cost of revenue were also due to the
increase in service contract expenses as a result of expenses related to the
Aidlin and Agnews overhauls, and due to expenses related to the Cerro Prieto
Steam Fields, partially offset by lower operating and depreciation expenses at
the Company's other existing power generation facilities and steam fields.
GENERAL AND ADMINISTRATIVE EXPENSES increased to $4.9 million and $10.8 million
for the three and nine months ended September 30, 1996 compared to $2.1 million
and $5.7 million for the same periods in 1995. The Company incurred an employee
bonus expense of $1.4 million in September 1996 related to the Common Stock
Offering. The remaining increases in 1996 were primarily due to additional
personnel and related expenses necessary to support the Company's expanding
operations.
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<PAGE>
INTEREST EXPENSE increased to $12.4 million and $31.1 million for the three and
nine months ended September 30, 1996 compared to $8.4 million and $23.5 million
for the same periods in 1995. The increase for the three months ended September
30, 1996 compared to the same period in 1995 was primarily due to $4.8 million
of interest expense on the Company's 10 1/2% Senior Notes issued in May 1996.
The increase for the nine months ended September 30, 1996 compared to the same
period in 1995 was primarily attributable to $7.2 million of interest expense on
the 10 1/2% Senior Notes, $790,000 of interest expense related to the Gilroy
facilities acquired on August 29, 1996 and $1.7 million of higher interest
expense related to the Greenleaf 1 & 2 facilities acquired on April 21, 1995,
offset by a $3.0 million decrease in interest expense primarily as a result of
repayments of principal on certain non-recourse project financings.
OTHER EXPENSE AND INCOME, NET was $1.1 million of expense and $1.6 million of
income for the three months and nine months ended September 30, 1996 compared to
$380,000 and $1.2 million of income for the comparable periods in 1995. In
September 1996, the Company provided a $3.7 million allowance related to the
O'Brien proceedings (see Note 13). This expense was offset by$1.6 million and
$3.1 million of interest income for the three and six months ended September
1996 periods on the collateral securities purchased in connection with the King
City Transaction. Interest income for the periods also increased due to the
investment of the net proceeds of the Preferred Stock, from the sale of the 10
1/2% Senior Notes, and from the Common Stock Offering.
PROVISION FOR INCOME TAXES. The effective rate for the income tax provision was
approximately 31% and 34% for the three and nine months ended September 30,
1996. In September 1996, in accordance with SFAS No. 109, Accounting for Income
Taxes, the Company decreased its deferred income tax liability by $769,000 to
reflect the change in California's state income tax rate from 9.3% to 8.84%
effective January 1, 1997. In addition, depletion in excess of tax basis
benefits at the Company's geothermal facilities reduced the Company's effective
tax rate for 1996. The effective rate for the 1995 income tax provision was
approximately 41%.
LIQUIDITY AND CAPITAL RESOURCES
To date, the Company has obtained cash from its operations, borrowings under its
credit facilities and other working capital lines, sales of debt and equity and
proceeds from non-recourse project financings. The Company utilized this cash to
fund its operations, service debt obligations, fund the acquisition, development
and construction of power generation facilities, finance capital expenditures
and meet its other cash and liquidity needs.
Operating activities for the nine months ended September 30, 1996 consisted of
approximately $15.2 million of net income, $26.1 million of depreciation and
amortization, $6.3 million in deferred income taxes, offset by $2.9 million of
income from unconsolidated investments in power projects and $19.0 million net
decrease in operating assets and liabilities.
Investing activities used $269.3 million during the nine months ended September
30, 1996, primarily due to $16.7 million of capital expenditures and capitalized
project costs, $95.0 million for the purchase of collateral securities, $14.2
million investment in Coperlasa, $5.4 million for deferred transaction costs in
connection with King City, and $138.1 million investment in Gilroy.
Financing activities provided $321.3 million of cash during the nine months
ended September 30, 1996. The Company issued $50.0 million of preferred stock to
Electrowatt, borrowed $161.0 million of bank debt and an additional $59.9
million under the credit facilities, received net proceeds of $174.9 million
from the Senior Notes Due 2006, and received $82.1 million upon the issuance of
common stock. The Company subsequently repaid $46.2 million of bank debt, all
borrowings outstanding under the credit facilities of $79.8 million, and $77.7
million of non-recourse project financing.
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As of September 30, 1996, cash and cash equivalents were $99.5 million and
working capital was $122.5 million. For the nine months ended September 30,
1996, working capital increased $171.6 million and cash and cash equivalents
increased $77.7 million as compared to the twelve months ended December 31,
1995. The increase in working capital is due to $69.1 million of remaining net
proceeds from the Common Stock Offering after repayment of certain short-term
borrowings, and reflects the inclusion of $57.0 million of non-recourse project
financing in current liabilities as of December 31, 1995. A portion of the funds
from the issuance of the Senior Notes Due 2006 was used to refinance current
bank debt and borrowings under the Credit Suisse Credit Facility, and to repay
the $57.0 million non-recourse indebtedness. Working capital at September 30,
1996 also includes the net remaining proceeds from the issuance of the Senior
Notes Due 2006 and the Company's net proceeds from its initial public offering.
On October 17, 1996, the Company issued additional shares of Common Stock and
received $27.1 million of net proceeds.
As a developer, owner and operator of power generation projects, the Company may
be required to make long-term commitments and investments of substantial capital
for its projects. The Company historically has financed these capital
requirements with available cash resources and borrowings under its credit
facility, other lines of credit, non-recourse project financing, or long-term
debt.
The Company currently has outstanding $105.0 million of its 9 1/4% Senior Notes
Due 2004 which mature on February 1, 2004 and bear interest payable
semi-annually on February 1 and August 1 of each year. In addition, the Company
has $180.0 million of its 10 1/2% Senior Notes Due 2006 which mature on May 15,
2006 and bear interest semi-annually on May 15 and November 15 of each year.
Under the provisions of the applicable indentures, the Company may, under
certain circumstances, be limited in its ability to make restricted payments, as
defined, which include dividends and certain purchases and investments, incur
additional indebtedness and engage in certain transactions.
At September 30, 1996, the Company had $312.7 million of non-recourse project
financing associated with power generating facilities and steam fields at the
West Ford Flat facility, the Bear Canyon facility, the PG&E Unit 13 and Unit 16
Steam Fields, the SMUDGEO#1 Steam Fields, the Greenleaf 1 & 2 facilities and the
Gilroy facility. As of September 30, 1996, the annual maturities for all
non-recourse project financing were $6.9 million for the remainder of 1996,
$30.6 million for 1997, $32.6 million for 1998, $24.2 million for 1999,$24.3
million for 2000 and $192.0 million thereafter.
The Company currently has a $50.0 million revolving credit agreement with a
consortium of commercial lending institutions led by The Bank of Nova Scotia,
with borrowings bearing interest at either LIBOR or at The Bank of Nova Scotia
base rate plus a mutually agreed margin. At September 30, 1996, the Company had
no borrowings outstanding under the revolving credit facility. (See Note 9 for
further information).
The Company has a $1.2 million working capital line with a commercial lender
that may be used to fund short-term working capital commitments and letters of
credit. At September 30, 1996, the Company had no borrowings under this working
capital line and $900,000 of letters of credit outstanding. Borrowings are at
prime plus 1%.
The Company also has outstanding a non-interest bearing promissory note to
Natomas Energy Company in the amount of $6.5 million representing a portion of
the September 1994 purchase price of Thermal Power Company. This note has been
discounted to yield 8% per annum and is due September 9, 1997.
The Company intends to continue to seek the use of non-recourse project
financing for new projects, where appropriate. The debt agreements of the
Company's subsidiaries and other affiliates governing the non-recourse project
financing generally restrict their ability to pay dividends, make distributions
or otherwise transfer funds to the Company. The dividend restrictions in such
agreements generally require that, prior to the payment of dividends,
distributions or other transfers, the subsidiary or other affiliate must provide
for the
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payment of other obligations, including operating expenses, debt service and
reserves. However, the Company does not believe that such restrictions will
adversely affect its ability to meet its debt obligations.
At September 30, 1996, the Company had planned commitments for remaining capital
expenditures in 1996 totaling $3.8 million related to various projects at its
geothermal facilities. The Company intends to fund capital expenditures for the
ongoing operation and development of the Company's power generation facilities
primarily through the operating cash flow of such facilities. For the nine
months ended September 30, 1996, capital expenditures included $4.0 million for
the purchase of geothermal leases for the Glass Mountain project, $3.1 million
for the new rotor at the PG&E Unit 13 facility and $2.8 million for well
drilling and a reinjection pipeline at the Company's geothermal steam fields.
The Company continues to pursue the development of geothermal resources and the
acquisition and development of new power generation projects. The Company
expects to commit significant capital in future years for the acquisition and
development of these projects. The Company's actual capital expenditures may
vary significantly during any year.
The Company believes that it will have sufficient liquidity from cash flow from
operations and borrowings available under the lines of credit and working
capital to satisfy all obligations under outstanding indebtedness, to finance
anticipated capital expenditures and to fund working capital requirements.
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PART II. OTHER INFORMATION
ITEM 1. LEGAL PROCEEDINGS
In connection with the Company's unsuccessful attempt to acquire O'Brien
Environmental Energy, Inc. (O'Brien) in 1995 through U.S. Bankruptcy Court
proceedings, the Company had capitalized approximately $3.7 million of
third-party costs. Pursuant to the terms of a contract with O'Brien, the Company
sought the reimbursement of such costs and a $2.0 million break-up fee, each of
which was subject to the approval of the Bankruptcy Court. On November 8, 1996,
the court denied Calpine's application for approval of such costs and fees. As a
result, the Company provided a $3.6 million allowance in the third quarter of
1996 and will begin the appeal process in the near future.
ITEM 2. CHANGE IN SECURITIES
None.
ITEM 3. DEFAULTS UPON SENIOR SECURITIES
None.
ITEM 4. SUBMISSION OF MATTERS TO A VOTE OF SECURITY HOLDERS
The Company held an annual meeting of the Company's sole shareholder on July 17,
1996 at which time the sole shareholder voted to approve: (1) the initial public
offering of the Company's common stock; (2) the reincorporation merger between
Calpine Corporation (California) and Electrowatt Services, Inc., a Delaware
corporation; (3) the amendment and restatement of the Company's Certificate of
Incorporation and Bylaws in connection with the reincorporation merger, and the
resulting stock split, including the conversion of the Class B Common Stock and
Series A Preferred Stock of Calpine Corporation (California) into Common Stock
of the Company; (4) the 1996 Stock Incentive Plan and the 1996 Employee Stock
Purchase Plan; and (5) the appointment of the following new directors of the
Company, all to become effective immediately prior to the consummation of the
initial public offering: Ann B. Curtis and George Stathakis; and (6) the
appointment of the following director for an additional year-long term: Peter
Cartwright.
Holders of record of the Company's Class B Common Stock were entitled to vote at
the special meeting. As of July 17, 1996, there were 12,567,180 (post split)
shares of Class B Common Stock outstanding and entitled to vote at the meeting.
There were no shares of Class A Common Stock outstanding and entitled to vote at
the meeting. All matters were voted for by 100% of the outstanding shares of
Class B Common Stock.
ITEM 5. OTHER INFORMATION
None.
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ITEM 6. EXHIBITS AND REPORTS ON FORM 8-K
(A) EXHIBITS
EXHIBIT
NUMBER DESCRIPTION
3.1 Amended and Restated Certificate of Incorporation of Calpine
Corporation, a Delaware corporation. (l)
3.2 Amended and Restated Bylaws of Calpine Corporation, a Delaware
corporation. (l)
4.1 Indenture dated as of February 17, 1994 between the Company and
Shawmut Bank of Connecticut, National Association, as Trustee,
including form of Notes. (a)
4.2 Indenture dated as of May 16, 1996 between the Company and Fleet
National Bank, as Trustee, including form of Notes. (m)
10.1 Financing Agreements
10.1.1 Term and Working Capital Loan Agreement, dated as of June 1, 1990,
between Calpine Geysers Company, L.P. (formerly Santa Rosa Geothermal
Company, L.P.), and Deutsche Bank AG, New York Branch. (a)
10.1.2 First Amendment to Term and Working Capital Loan Agreement, dated as
of June 29, 1990, between Calpine Geysers Company, L.P. (formerly
Santa Rosa Geothermal Company, L.P.), and Deutsche Bank AG, New York
Branch. (a)
10.1.3 Second Amendment to Term and Working Capital Loan Agreement, dated as
of December 1, 1990, between Calpine Geysers Company, L.P. (formerly
Santa Rosa Geothermal Company, L.P.), and Deutsche Bank AG, New York
Branch. (a)
10.1.4 Third Amendment to Term and Working Capital Loan Agreement, dated as
of June 26, 1992, between Calpine Geysers Company, L.P. (formerly
Santa Rosa Geothermal Company, L.P.), Deutsche Bank AG, New York
Branch, National Westminster Bank PLC, Union Bank of Switzerland, New
York Branch, and The Prudential Insurance Company of America. (a)
10.1.5 Fourth Amendment to Term and Working Capital Loan Agreement, dated as
of April l, 1993, between Calpine Geysers Company, L.P. (formerly
Santa Rosa Geothermal Company, L.P.), Deutsche Bank AG, New York
Branch, National Westminster Bank PLC, Union Bank of Switzerland, New
York Branch, and The Prudential Insurance Company of America. (a)
10.1.6 Construction and Term Loan Agreement, dated as of January 30, 1992,
between Sumas Cogeneration Company, L.P., The Prudential Insurance
Company of America, and Credit Suisse, New York Branch. (a)
10.1.7 Amendment No. 1 to Construction and Term Loan Agreement, dated as of
May 24, 1993, between Sumas Cogeneration Company, L.P., The Prudential
Insurance Company of America, and Credit Suisse, New York Branch. (a)
10.1.8 Credit Agreement-Construction Loan and Term Loan Facility, dated as of
January 10, 1990, between Credit Suisse and O.L.S. Energy-Agnews. (a)
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10.1.9 Amendment No. 1 to Credit Agreement-Construction Loan and Term Loan
Facility, dated as of December 5, 1990, between Credit Suisse and
O.L.S. Energy-Agnews. (a)
10.1.10 Participation Agreement, dated as of December 1, 1990, between O.L.S.
Energy-Agnews, Nynex Credit Company, Credit Suisse, Meridian Trust
Company of California, and GATX Capital Corporation. (a)
10.1.11 Facility Lease Agreement, dated as of December 1, 1990, between
Meridian Trust Company of California and O.L.S. Energy-Agnews. (a)
10.1.12 Project Revenues Agreement, dated as of December 1, 1990, between
O.L.S. Energy-Agnews, Meridian Trust Company of California and Credit
Suisse. (a)
10.1.13 Project Credit Agreement, dated as of June 30, 1995, between Calpine
Greenleaf Corporation, Greenleaf Unit One Associates, Greenleaf Unit
Two Associates, Inc. and The Sumitomo Bank, Limited. (g)
10.1.14 Lease dated as of April 24, 1996 between BAF Energy A California
Limited Partnership, Lessor, and Calpine King City Cogen, LLC, Lessee.
(j)
10.1.15 Credit Agreement, dated as of August 28, 1996, among Calpine Gilroy
Cogen, L.P. and Banque Nationale de Paris. (l)
10.1.16 Credit Agreement, dated as of September 25, 1996, among Calpine
Corporation and The Bank of Nova Scotia. (m)
10.2 Purchase Agreements
10.2.1 Purchase Agreement, dated as of April 1, 1993, between Sonoma
Geothermal Partners, L.P., Healdsburg Energy Company, L.P., and
Freeport-McMoRan Resource Partners, Limited Partnership. (a)
10.2.2 Stock Purchase Agreement, dated as of June 27, 1994, between Maxus
International Energy Company, Natomas Energy Company, Calpine
Corporation and Calpine Thermal Power, Inc. and amendment thereto
dated July 28, 1994. (b)
10.2.3 Share Purchase Agreement dated March 30, 1995 between Calpine
Corporation, Calpine Greenleaf Corporation, Radnor Power Corp. and LFC
Financial Corp. (e)
10.2.4 Asset Purchase Agreement, dated as of August 28, 1996, among Gilroy
Energy Company, McCormick & Company, Incorporated and Calpine Gilroy
Cogen, L.P. (m)
10.2.5 Noncompetition / Earnings Contingency Agreement, dated as of August
28, 1996, among Gilroy Energy Company, McCormick & Company,
Incorporated and Calpine Gilroy Cogen, L.P. (m)
10.3 Power Sales Agreements
10.3.1 Long-Term Energy and Capacity Power Purchase Agreement relating to the
Bear Canyon Facility, dated November 30, 1984, between Pacific Gas &
Electric and Calpine Geysers Company, L.P. (formerly Santa Rosa
Geothermal Company, L.P.), Amendment dated October 17, 1985, Second
Amendment dated October 19, 1988, and related documents. (a)
-22-
<PAGE>
10.3.2 Long-Term Energy and Capacity Power Purchase Agreement relating to the
Bear Canyon Facility, dated November 29, 1984, between Pacific Gas &
Electric and Calpine Geysers Company, L.P. (formerly Santa Rosa
Geothermal Company, L.P.), and Modification dated November 29, 1984,
Amendment dated October 17, 1985, Second Amendment dated October 19,
1988, and related documents. (a)
10.3.3 Long-Term Energy and Capacity Power Purchase Agreement relating to the
West Ford Flat Facility, dated November 13, 1984, between Pacific Gas
& Electric and Calpine Geysers Company, L.P. (formerly Santa Rosa
Geothermal Company, L.P.), and amendments dated May 18, 1987, June 22,
1987, July 3, 1987 and January 21, 1988, and related documents. (a)
10.3.4 Agreement for Firm Power Purchase, dated as of February 24, 1989,
between Puget Sound Power & Light Company and Sumas Energy, Inc. and
amendment thereto dated September 30, 1991. (a)
10.3.5 Long-Term Energy and Capacity Power Purchase Agreement, dated April
16, 1985, between O.L.S. Energy-Agnews and Pacific Gas & Electric
Company and amendment thereto dated February 24, 1989. (a)
10.3.6 Long-Term Energy and Capacity Power Purchase Agreement, dated November
15, 1984, between Geothermal Energy Partners, Ltd., and Pacific Gas &
Electric Company and related documents. (a)
10.3.7 Long-Term Energy and Capacity Power Purchase Agreement, dated November
15, 1984, between Geothermal Energy Partners, Ltd., and Pacific Gas &
Electric Company (see Exhibit 10.3.6 for related documents). (a)
10.3.8 Long-Term Energy and Capacity Power Purchase Agreement, dated December
12, 1984, between Greenleaf Unit One Associates, Inc. and Pacific Gas
and Electric Company. (f)
10.3.9 Long-Term Energy and Capacity Power Purchase Agreement, dated December
12, 1984, between Greenleaf Unit Two Associates, Inc. and Pacific Gas
and Electric Company. (f)
10.3.10 Long-Term Energy and Capacity Power Purchase Agreement, dated December
5, 1985, between Calpine Gilroy Cogen, L.P. and Pacific Gas and
Electric Company, and amendments thereto dated December 19, 1993, July
18, 1985, June 9, 1986, August 18, 1988 and June 9, 1991. (l)
10.4 Steam Sales Agreements
10.4.1 Geothermal Steam Sales Agreement, dated July 19, 1979, between Calpine
Geysers Company, L.P. (formerly Santa Rosa Geothermal Company, L.P.),
and Sacramento Municipal Utility District and related documents. (a)
10.4.2 Agreement for the Sale and Purchase of Geothermal Steam, dated March
23, 1973, between Calpine Geysers Company, L.P. (formerly Santa Rosa
Geothermal Company, L.P.), and Pacific Gas & Electric Company and
related letter dated May 18, 1987. (a)
10.4.3 Thermal Energy and Kiln Lease Agreement, dated as of January 16, 1992,
between Sumas Cogeneration Company, L.P., and Socco, Inc. and
amendment thereto dated May 24, 1993. (a)
10.4.4 Amended and Restated Energy Service Agreement, dated as of December l,
1990, between the State of California and O.L.S. Energy-Agnews. (a)
-23-
<PAGE>
10.4.5 Agreement for the Sale of Geothermal Steam, dated as of July 28, 1992,
between Thermal Power Company and Pacific Gas & Electric Company. (c)
10.4.6 Amendment to the Agreement for the Sale of Geothermal Steam, dated as
of August 9, 1995, between Union Oil Company of California, NEC
Acquisition Company, Thermal Power Company, and Pacific Gas and
Electric Company. (h)
10.5 Service Agreements
10.5.1 Operation and Maintenance Agreement, dated as of April 5, 1990,
between Calpine Operating Plant Services, Inc. (formerly
Calpine-Geysers Plant Services, Inc.), and Calpine Geysers Company,
L.P. (formerly Santa Rosa Geothermal Company, L.P.). (a)
10.5.2 Amended and Restated Operating and Maintenance Agreement, dated as of
January 24, 1992, between Calpine Operating Plant Services, Inc. and
Sumas Cogeneration Company, L.P. (a)
10.5.3 Amended and Restated Operation and Maintenance Agreement, dated as of
December 31, 1990, between O.L.S. Energy-Agnews and Calpine Operating
Plant Services, Inc. (formerly Calpine Cogen-Agnews, Inc.). (a)
10.5.4 Operating and Maintenance Agreement, dated as of January 1, 1995,
between Calpine Corporation and Geothermal Energy Partners, Ltd. (h)
10.5.5 Amended and Restated Operating Agreement for the Geysers, dated as of
December 31, 1993, by and between Magma-Thermal Power Project, a joint
venture composed of NEC Acquisition Company and Thermal Power Company,
and Union Oil Company of California. (c)
10.6 Gas Supply Agreements
10.6.1 Gas Sale and Purchase Agreement, dated as of December 23, 1991,
between ENCO Gas, Ltd, and Sumas Cogeneration Company, L.P. (a)
10.6.2 Gas Management Agreement, dated as of December 23, 1991, between
Canadian Hydrocarbons Marketing Inc., ENCO Gas, Ltd. and Sumas
Cogeneration Company, L.P. (a)
10.6.4 Natural Gas Sales Agreement, dated as of November 1, 1993, between
O.L.S. Energy-Agnews, Inc. and Amoco Energy Trading Corporation. (a)
10.6.5 Natural Gas Service Agreement, dated November 1, 1993, between Pacific
Gas & Electric Company and O.L.S. Energy-Agnews, Inc. (a)
10.7 Agreements Regarding Real Property
10.7.1 Office Lease, dated March 15, 1991, between 50 West San Fernando
Associates, L.P., and Calpine Corporation. (a)
10.7.2 First Amendment to Office Lease, dated April 30, 1992, between 50 West
San Fernando Associates, L.P. and Calpine Corporation. (a)
10.7.3 Geothermal Resources Lease CA 1862, dated July 25, 1974, between the
United States Bureau of Land Management and Calpine Geysers Company,
L.P. (formerly Santa Rosa Geothermal Company, L.P.). (a)
-24-
<PAGE>
10.7.4 Geothermal Resources Lease PRC 5206.2, dated December 14, 1976,
between the State of California and Calpine Geysers Company, L.P.
(formerly Santa Rosa Geothermal Company, L.P.). (a)
10.7.5 First Amendment to Geothermal Resources Lease PRC 5206.2, dated April
20,1994, between the State of California and Calpine Geysers Company,
L.P. (formerly Santa Rosa Geothermal Company, L.P.). (a)
10.7.6 Industrial Park Lease Agreement, dated December 18, 1990, between Port
of Bellingham and Sumas Energy, Inc. (a)
10.7.7 First Amendment to Industrial Park Lease Agreement, dated as of July
16, 1991, between Port of Bellingham, Sumas Energy, Inc., and Sumas
Cogeneration Company, L.P. (a)
10.7.8 Second Amendment to Industrial Park Lease Agreement, dated as of
December 17, 1991 between Port of Bellingham and Sumas Cogeneration
Company, L.P. (a)
10.7.9 Amended and Restated Cogeneration Lease, dated as of December 1, 1990,
between the State of California and O.L.S. Energy-Agnews. (a)
10.8 General
10.8.1 Limited Partnership Agreement of Sumas Cogeneration Company, L.P.,
dated as of August 28, 1991, between Sumas Energy, Inc. and Whatcom
Cogeneration Partners, L.P. (a)
10.8.2 First Amendment to Limited Partnership Agreement of Sumas Cogeneration
Company, L.P., dated as of January 30, 1992, between Whatcom
Cogeneration Partners, L.P., and Sumas Energy, Inc. (a)
10.8.3 Second Amendment to Limited Partnership Agreement of Sumas
Cogeneration Company, L.P., dated as of May 24, 1993, between Whatcom
Cogeneration Partners, L.P., and Sumas Energy, Inc. (a)
10.8.4 Second Amended and Restated Shareholders' Agreement, dated as of
October 22, 1993, among GATX Capital Corporation, Calpine Agnews,
Inc., JGS-Agnews, Inc., and GATX/Calpine-Agnews, Inc. (a)
10.8.5 Amended and Restated Reimbursement Agreement, dated October 22, 1993,
between GATX Capital Corporation, Calpine Agnews, Inc., JGS-Agnews,
Inc., GATX/Calpine-Agnews, Inc., and O.L.S. Energy-Agnews, Inc. (a)
10.8.6 Amended and Restated Limited Partnership Agreement of Geothermal
Energy Partners Ltd., L.P., dated as of May 19, 1989, between Western
Geothermal Company, L.P., Sonoma Geothermal Company, L.P., and
Cloverdale Geothermal Partners, L.P. (a)
10.8.7 Assignment and Security Agreement, dated as of January 10, 1990,
between O.L.S. Energy-Agnews and Credit Suisse. (a)
10.8.8 Pledge Agreement, dated as of January 10, 1990, between
GATX/Calpine-Agnews, Inc., and Credit Suisse. (a)
-25-
<PAGE>
10.8.9 Equity Support Agreement, dated as of January 10, 1990, between
Calpine Corporation and Credit Suisse. (a)
10.8.10 Assignment and Security Agreement, dated as of December 1, 1990,
between O.L.S. Energy- Agnews and Meridian Trust Company of
California. (a)
10.8.11 First Amended and Restated Limited Partner Pledge and Security
Agreement, dated as of April 1, 1993, between Sonoma Geothermal
Partners, L.P., Healdsburg Energy Company, L.P., Calpine Geysers
Company, L.P. (formerly Santa Rosa Geothermal Company, L.P.),
Freeport-McMoRan Resource Partners, L.P., and Meridian Trust Company
of California. (a)
10.8.12 Management Services Agreement, dated January 1, 1995, between Calpine
Corporation and Electrowatt Ltd. (k)
10.8.13 Guarantee Fee Agreement, dated January 1, 1995, between Calpine
Corporation and Electrowatt Ltd. (g)
10.9.1 Calpine Corporation Stock Option Program and forms of agreements
thereunder. (a)
10.9.2 Calpine Corporation 1996 Stock Incentive Plan and forms of agreements
thereunder. (l)
10.9.3 Calpine Corporation Employee Stock Purchase Plan and forms of
agreements thereunder. (l)
10.10.1 Amended and Restated Employment Agreement between Calpine Corporation
and Mr. Peter Cartwright. (l)
10.10.2 Senior Vice President Employment Agreement between Calpine Corporation
and Ms. Ann B. Curtis. (l)
10.10.3 Senior Vice President Employment Agreement between Calpine Corporation
and Mr. Lynn A. Kerby. (l)
10.10.4 Vice President Employment Agreement between Calpine Corporation and
Mr. Ron A. Walter. (l)
10.10.5 Vice President Employment Agreement between Calpine Corporation and
Mr. Robert D. Kelly. (l)
10.10.6 First Amended and Restated Consulting Contract between Calpine
Corporation and Mr. George J. Stathakis. (l)
10.11 Form of Indemnification Agreement for directors and officers. (l)
21.1 Subsidiaries of the Company. (m)
------------------------------------
(a) Incorporated by reference to Registrant's Registration Statement on
Form S-1 (Registration Statement No. 33-73160).
(b) Incorporated by reference to Registrant's Current Report on Form 8-K
dated September 9, 1994 and filed on September 26, 1994.
-26-
<PAGE>
(c) Incorporated by reference to Registrant's Quarterly Report on Form
10-Q dated September 30, 1994 and filed on November 14, 1994.
(d) Incorporated by reference to Registrant's Annual Report on Form 10-K
dated December 31, 1994 and filed on March 29, 1995.
(e) Incorporated by reference to Registrant's Current Report on Form 8-K
dated April 21, 1995 and filed on May 5, 1995.
(f) Incorporated by reference to Registrant's Quarterly Report on Form
10-Q dated March 31, 1995 and filed on May 12, 1995.
(g) Incorporated by reference to Registrant's Quarterly Report on Form
10-Q dated June 30, 1995 and filed on August 14, 1995.
(h) Incorporated by reference to Registrant's Quarterly Report on Form
10-Q dated September 30, 1995 and filed on November 14, 1995.
(I) Incorporated by reference to Registrant's Annual Report on Form 10-K
dated December 31, 1994 and filed on March 29, 1996.
(j) Incorporated by reference to Registrant's Current Report on Form 8-K
dated May 1, 1996 and filed on May 14, 1996.
(k) Incorporated by reference to Registrant's Quarterly Report on Form
10-Q dated March 31, 1996 and filed on May 15, 1996.
(l) Incorporated by reference to Registrant's Registration Statement on
Form S-1 (Registration Statement No. 333-07497).
(m) Incorporated by reference to Registrant's Current Report on Form 8-K
dated August 29, 1996 and filed on September 13, 1996.
(B) REPORTS ON FORM 8-K
A report on Form 8-K dated August 29, 1996 was filed on September 13, 1996.
-27-
<PAGE>
SIGNATURES
Pursuant to the requirements of the Securities and Exchange Act of 1934, the
registrant has duly caused this report to be signed on its behalf by the
undersigned thereunto duly authorized.
CALPINE CORPORATION
By: \s\ Ann B. Curtis Date: November 14, 1996
-----------------------------------
Ann B. Curtis
Senior Vice President
(Chief Financial Officer)
By: \s\ Gloria S. Gee Date: November 14, 1996
-----------------------------------
Gloria S. Gee
Corporate Controller
(Chief Accounting Officer)
-28-
EXHIBIT 11
CALPINE CORPORATION AND SUBSIDIARIES
CALCULATION OF EARNINGS PER SHARE
(UNAUDITED)
<TABLE>
<CAPTION>
THREE MONTHS ENDED NINE MONTHS ENDED
SEPTEMBER 30, SEPTEMBER 30,
------------------ ------------------
1996 1995 1996 1995
------- ------- ------- -------
(in thousands, except per share amounts)
<S> <C> <C> <C> <C>
NET INCOME ................................... $10,732 $ 4,965 $15,155 $ 5,263
======= ======= ======= =======
PRIMARY EARNINGS PER SHARE
Average number of common shares outstanding .. 11,044 10,388 10,606 10,388
Conversion of preferred stock ................ 2,179 -- 1,541 --
Common shares issuable upon exercise of stock
options using the treasury method ....... 847 573 548 576
------- ------- ------- -------
14,070 10,961 12,695 10,964
------- ------- ------- -------
Primary earnings per share ..... $ 0.76 $ 0.45 $ 1.19 $ 0.48
======= ======= ======= =======
FULLY DILUTED EARNINGS PER SHARE
Average number of common shares outstanding .. 11,043 10,388 10,606 10,388
Conversion of preferred stock ................ 2,179 -- 1,541 --
Common shares issuable upon exercise of stock
options using the treasury method ....... 1,081 573 625 576
------- ------- ------- -------
14,303 10,961 12,772 10,964
------- ------- ------- -------
Fully diluted earnings per share $ 0.75 $ 0.45 $ 1.19 $ 0.48
======= ======= ======= =======
</TABLE>
-29-
<TABLE> <S> <C>
<ARTICLE> 5
<LEGEND>
THE SCHEDULE CONTAINS SUMMARY FINANCIAL INFORMATION
EXTRACTED FROM CALPINE CORPORATION'S CONDENSED CONSOLIDATED BALANCE
SHEET AS OF JUNE 30, 1996 AND FROM THE CONDENSED CONSOLIDATED
STATEMENT OF OPERATIONS FOR THE THREE MONTHS ENDED JUNE 30, 1996 AND
IS QUALIFIED IN ITS ENTIRETY BY REFERENCE TO SUCH FINANCIAL STATEMENTS.
</LEGEND>
<CIK> 0000916457
<NAME> Calpine Corporation
<MULTIPLIER> 1,000
<CURRENCY> U.S. Dollars
<S> <C>
<PERIOD-TYPE> 9-MOS
<FISCAL-YEAR-END> DEC-31-1996
<PERIOD-START> JAN-01-1996
<PERIOD-END> SEP-30-1996
<EXCHANGE-RATE> 1
<CASH> 99,477
<SECURITIES> 5,463
<RECEIVABLES> 60,643
<ALLOWANCES> 0
<INVENTORY> 3,308
<CURRENT-ASSETS> 186,778
<PP&E> 738,229
<DEPRECIATION> 88,122
<TOTAL-ASSETS> 1,006,629
<CURRENT-LIABILITIES> 64,244
<BONDS> 578,195
0
0
<COMMON> 18
<OTHER-SE> 172,504
<TOTAL-LIABILITY-AND-EQUITY> 1,006,629
<SALES> 140,311
<TOTAL-REVENUES> 152,891
<CGS> 81,219
<TOTAL-COSTS> 87,172
<OTHER-EXPENSES> 0
<LOSS-PROVISION> 3,662
<INTEREST-EXPENSE> 31,099
<INCOME-PRETAX> 23,017
<INCOME-TAX> 7,862
<INCOME-CONTINUING> 15,155
<DISCONTINUED> 0
<EXTRAORDINARY> 0
<CHANGES> 0
<NET-INCOME> 15,155
<EPS-PRIMARY> 1.19
<EPS-DILUTED> 1.19
</TABLE>
