<PAGE>
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 quarterly period ended June 30, 1999
-----------------------
or
[_] TRANSITION REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES
EXCHANGE ACT OF 1934
For the transition period from __________ to __________
Commission File Number 1-13434
Edison Mission Energy
(Exact name of registrant as specified in its charter)
California 95-4031807
(State or other jurisdiction of (I.R.S. Employer Identification No.)
incorporation or organization)
18101 Von Karman Avenue
Irvine, California 92612
(Address of principal executive offices) (Zip Code)
Registrant's telephone number, including area code: (949) 752-5588
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 [_]
Number of shares outstanding of the registrant's Common Stock as of August
13, 1999: 100 shares (all shares held by an affiliate of the registrant).
<PAGE>
TABLE OF CONTENTS
Item Page
- ---- ----
PART I - Financial Information
1. Financial Statements................................................. 1
2. Management's Discussion and Analysis of Financial Condition and
Results of Operations................................................ 14
PART II - Other Information
5. Other Information.................................................... 25
6. Exhibits and Reports on Form 8-K..................................... 25
PART III
Signatures........................................................... 26
<PAGE>
PART I - FINANCIAL INFORMATION
ITEM 1. FINANCIAL STATEMENTS
EDISON MISSION ENERGY AND SUBSIDIARIES
CONSOLIDATED STATEMENTS OF INCOME
(In thousands)
<TABLE>
<CAPTION>
(Unaudited) (Unaudited)
Three Months Ended Six Months Ended
June 30, June 30,
--------------------- -----------------------
1999 1998 1999 1998
---------- -------- ---------- ----------
<S> <C> <C> <C> <C>
Operating Revenues
Electric revenues $218,672 $144,402 $ 415,525 $343,199
Equity in income from energy projects 35,254 48,225 95,999 65,792
Equity in income from oil and gas 6,118 4,962 9,760 10,427
Operation and maintenance services 9,328 9,725 17,844 19,802
-------- -------- --------- --------
Total operating revenues 269,372 207,314 539,128 439,220
-------- -------- --------- --------
Operating Expenses
Fuel 73,572 41,075 127,647 89,712
Plant operations 47,018 32,871 81,389 62,469
Operation and maintenance services 7,543 6,888 14,013 14,279
Depreciation and amortization 35,597 22,378 59,743 45,160
Administrative and general 32,567 32,990 69,064 57,162
-------- -------- --------- --------
Total operating expenses 196,297 136,202 351,856 268,782
-------- -------- --------- --------
Income from operations 73,075 71,112 187,272 170,438
-------- -------- --------- --------
Other Income (Expense)
Interest and other income 12,792 8,995 20,584 22,771
Interest expense (78,873) (45,160) (123,392) (90,885)
Dividends on preferred securities (4,145) (3,304) (7,378) (6,601)
-------- -------- --------- --------
Total other income (expense) (70,226) (39,469) (110,186) (74,715)
-------- -------- --------- --------
Income before income taxes 2,849 31,643 77,086 95,723
Provision (benefit) for income taxes (2,626) 13,055 13,675 39,435
-------- -------- --------- --------
Income before change in accounting principle $ 5,475 $ 18,588 $ 63,411 $ 56,288
Cumulative effect on prior years of change in
accounting for start-up costs -- -- (13,840) --
-------- -------- --------- --------
Net Income $ 5,475 $ 18,588 $ 49,571 $ 56,288
======== ======== ========= ========
</TABLE>
The accompanying notes are an integral part
of these consolidated financial statements.
1
<PAGE>
EDISON MISSION ENERGY AND SUBSIDIARIES
CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME
(In thousands)
<TABLE>
<CAPTION>
(Unaudited) (Unaudited)
Three Months Ended Six Months Ended
June 30, June 30,
---------------------- --------------------
1999 1998 1999 1998
---------- --------- --------- --------
<S> <C> <C> <C> <C>
Net Income $ 5,475 $18,588 $ 49,571 $56,288
Other comprehensive income (expense), net
of tax:
Foreign currency translation
adjustments, net of income tax
benefit (expense) of $1,416 and $199
for the three months and $2,794 and
$(900) for the six months ended
June 30, 1999 and 1998, respectively (29,032) (7,577) (41,657) 738
-------- ------- -------- -------
Comprehensive Income (Loss) $(23,557) $11,011 $ 7,914 $57,026
======== ======= ======== =======
</TABLE>
The accompanying notes are an integral part
of these consolidated financial statements.
2
<PAGE>
EDISON MISSION ENERGY AND SUBSIDIARIES
CONSOLIDATED BALANCE SHEETS
(In thousands)
<TABLE>
<CAPTION>
(Unaudited)
June 30, December 31,
1999 1998
----------- ------------
<S> <C> <C>
Assets
Current Assets
Cash and cash equivalents $ 808,280 $ 459,178
Accounts receivable - trade 98,770 74,403
Accounts receivable - affiliates 29,193 13,871
Inventory 61,395 13,000
Prepaid expenses and other 41,656 46,864
---------- ----------
Total current assets 1,039,294 607,316
---------- ----------
Investments
Energy projects 1,887,859 1,163,597
Oil and gas 68,987 62,949
---------- ----------
Total investments 1,956,846 1,226,546
---------- ----------
Property, Plant and Equipment 5,016,679 3,125,747
Less accumulated depreciation and amortization 300,609 250,934
---------- ----------
Net property, plant and equipment 4,716,070 2,874,813
---------- ----------
Other Assets
Goodwill 288,090 308,051
Restricted cash and other 157,891 141,390
---------- ----------
Total other assets 445,981 449,441
---------- ----------
Total Assets $8,158,191 $5,158,116
========== ==========
</TABLE>
The accompanying notes are an integral part
of these consolidated financial statements.
3
<PAGE>
EDISON MISSION ENERGY AND SUBSIDIARIES
CONSOLIDATED BALANCE SHEETS
(In thousands)
<TABLE>
<CAPTION>
(Unaudited)
June 30, December 31,
1999 1998
----------- ------------
<S> <C> <C>
Liabilities and Shareholder's Equity
Current Liabilities
Accounts payable - affiliates $ 8,489 $ 8,339
Accounts payable and accrued liabilities 140,994 99,062
Accrued incentive compensation 135,852 112,652
Interest payable 62,995 56,708
Short-term obligations 701,899 --
Current maturities of long-term obligations 101,552 194,586
---------- ----------
Total current liabilities 1,151,781 471,347
---------- ----------
Long-Term Obligations Net of Current Maturities 4,161,114 2,396,360
---------- ----------
Long-Term Deferred Liabilities
Deferred taxes and tax credits 612,630 613,009
Deferred revenue 525,418 490,471
Other 89,717 79,369
---------- ----------
Total long-term deferred liabilities 1,227,765 1,182,849
---------- ----------
Total Liabilities 6,540,660 4,050,556
---------- ----------
Preferred Securities of Subsidiaries:
Company-obligated mandatorily redeemable security
of partnership holding solely parent debentures 150,000 150,000
---------- ----------
Subject to mandatory redemption 84,032 --
---------- ----------
Not subject to mandatory redemption 118,103 --
---------- ----------
Commitments and Contingencies (Note 5)
Shareholder's Equity
Common stock, no par value; 10,000 shares
authorized; 100 shares issued and outstanding 64,130 64,130
Additional paid-in capital 929,406 629,406
Retained earnings 283,838 234,345
Accumulated other comprehensive income (loss) (11,978) 29,679
---------- ----------
Total Shareholder's Equity 1,265,396 957,560
---------- ----------
Total Liabilities and Shareholder's Equity $8,158,191 $5,158,116
========== ==========
</TABLE>
The accompanying notes are an integral part
of these consolidated financial statements.
4
<PAGE>
EDISON MISSION ENERGY AND SUBSIDIARIES
CONSOLIDATED STATEMENTS OF CASH FLOWS
(In thousands)
<TABLE>
<CAPTION>
(Unaudited)
Six Months Ended
June 30,
-------------------------
1999 1998
----------- ----------
<S> <C> <C>
Cash Flows From Operating Activities
Net income $ 49,571 $ 56,288
Adjustments to reconcile net income to net cash
provided by operating activities
Equity in income from energy projects (95,999) (65,792)
Equity in income from oil and gas (9,760) (10,427)
Distributions from energy projects 55,861 51,222
Distributions from oil and gas 400 19,112
Depreciation and amortization 59,743 45,160
Deferred taxes and tax credits 16,937 37,194
Cumulative effect on prior years of change
in accounting for start-up costs 13,840 --
(Increase) decrease in accounts receivable (40,189) 5,895
Decrease in prepaid expenses and other 393 4,236
Increase (decrease) in accounts payable and
accrued liabilities 6,287 (17,076)
Increase in interest payable 51,961 9,739
Other, net (10,760) (11,915)
----------- --------
Net cash provided by operating activities 98,285 123,636
----------- --------
Cash Flows From Financing Activities
Borrowings on long-term obligations 1,810,518 57,541
Payments on long-term obligations (154,658) (45,424)
Short-term financing, net 703,499 --
Capital contribution from parent 300,000 --
Issuance of preferred securities 202,212 --
----------- --------
Net cash provided by financing activities 2,861,571 12,117
----------- --------
Cash Flows From Investing Activities
Investments in energy projects (20,153) (5,381)
Loans to energy projects (26,101) (22,937)
Purchase of generating station (1,800,355) --
Purchase of common stock of acquired companies (648,246) (4,109)
Capital expenditures (70,113) (53,342)
(Increase) decrease in restricted cash (6,163) 32,093
Other, net (30,254) 133
----------- --------
Net cash used in investing activities (2,601,385) (53,543)
----------- --------
Effect of exchange rate changes on cash (9,369) (1,498)
----------- --------
Net increase in cash and cash equivalents 349,102 80,712
Cash and cash equivalents at beginning of period 459,178 585,883
----------- --------
Cash and cash equivalents at end of period $ 808,280 $666,595
=========== ========
</TABLE>
The accompanying notes are an integral part
of these consolidated financial statements.
5
<PAGE>
EDISON MISSION ENERGY AND SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
JUNE 30, 1999
NOTE 1. GENERAL
All adjustments, including recurring accruals, have been made that are
necessary to present fairly the consolidated financial position and results of
operations for the periods covered by this report. The results of operations for
the six months ended June 30, 1999, are not necessarily indicative of the
operating results for the full year.
Edison Mission Energy's (EME) significant accounting policies are described
in Note 2 to EME's Consolidated Financial Statements as of December 31, 1998 and
1997, included in its 1998 Annual Report on Form 10-K filed with the Securities
and Exchange Commission on March 31, 1999. EME follows the same accounting
policies for interim reporting purposes, with the exception of the American
Institute of Certified Public Accountants Statement of Position (SOP) 98-5,
"Reporting on the Costs of Start-Up Activities", which became effective in
January 1999. SOP 98-5 requires that certain costs related to start-up
activities be expensed as incurred and that certain previously capitalized costs
be expensed and reported as a cumulative change in accounting principle. This
quarterly report should be read in connection with such financial statements.
Certain prior period amounts have been reclassified to conform to the
current period financial statement presentation.
NOTE 2. INVESTMENTS
The following table presents summarized financial information of the
investments in energy projects and oil and gas accounted for by the equity
method:
<TABLE>
<CAPTION>
(In thousands)
(Unaudited) (Unaudited)
Three Months Ended Six Months Ended
June 30, June 30,
------------------- -------------------
1999 1998 1999 1998
-------- -------- -------- --------
<S> <C> <C> <C> <C>
Energy Projects
Operating Revenues $319,747 $379,045 $762,591 $722,102
Income from Operations 69,855 94,844 242,101 154,775
Net Income 57,552 66,693 198,503 103,014
Oil and Gas
Operating Revenues $ 50,370 $ 48,483 $ 93,537 $105,948
Income from Operations 15,115 12,994 23,287 28,682
Net Income 11,970 8,626 19,244 21,106
</TABLE>
6
<PAGE>
NOTE 3. ACQUISITIONS
In March 1999, EME Homer City Generation L.P. (EME Homer City), an
indirect, wholly owned affiliate of EME, completed a transaction with GPU, Inc.,
New York State Electric & Gas Corporation and their respective affiliates to
acquire the 1,884-megawatt (MW) Homer City Electric Generating Station and
certain facilities and other assets associated therewith (collectively, Homer
City).
Consideration for Homer City consisted of a cash payment of approximately
$1.8 billion, which was partially financed by $1.5 billion of new loans (see
Note 4).
In May 1999, Edison Mission Energy Taupo Ltd. (EME Taupo), an indirect,
wholly owned affiliate of EME, completed a transaction with the New Zealand
government to acquire 40% of the shares of Contact Energy Ltd. (Contact).
Contact owns and operates hydroelectric, geothermal and natural gas-fired power
generating plants in New Zealand with a total generating capacity of 2,371 MW.
Contact also supplies gas and electricity to customers in New Zealand and has
minority interests in two power projects in Australia.
Consideration for Contact consisted of a cash payment of approximately $648
million (1.2 billion New Zealand dollars). Financing of the acquisition is
discussed in Note 4.
Both acquisitions were accounted for utilizing the purchase method. EME's
consolidated statement of income for the three and six months ended June 30,
1999 reflects the operations of Homer City beginning on March 18, 1999 and
Contact beginning May 1, 1999.
NOTE 4. FINANCIAL INSTRUMENTS
In March 1999, Edison Mission Holdings Co. (EM Holdings), parent company of
EME Homer City, closed a $1.1 billion financing and EME closed a $700 million
financing. The EM Holdings financing consists of (1) an $800 million, 364-day
interest only term loan, (2) a $250 million, five-year interest only
construction term loan and (3) a $50 million, five-year interest only revolving
loan. These loans are structured on a limited-recourse basis, in which the
lenders look primarily to the cash generated by EM Holdings and its subsidiaries
to repay the debt and have taken a security interest in the assets of EM
Holdings and its subsidiaries. The EME financing consists of a $700 million,
364-day interest only revolving credit facility, structured on a recourse,
unsecured basis. The proceeds of EM Holdings' $800 million loan and EME's $700
million loan, combined with cash and corporate revolver borrowings totaling
approximately $300 million were used to finance the acquisition of Homer City.
In May 1999, EM Holdings completed an $830 million bond financing. The
financing consists of (1) $300 million, 8.137% Senior Secured Bonds due 2019 and
(2) $530 million, 8.734% Senior Secured Bonds due 2026. These bonds are non-
recourse to
7
<PAGE>
EME. The proceeds of the $830 million bonds were used primarily to repay EM
Holdings' $800 million, 364-day interest only term loan.
In May 1999, Edison Mission Energy Global Management, Inc. issued $120 million
of Flexible Money Market Cumulative Preferred Stock. The stock issuance
consists of (1) 600 Series A Shares and (2) 600 Series B Shares, both with
liquidation preference of $100,000 per share and a dividend rate of 5.74% until
May 2004. In May 1999 EME Taupo issued a $214 million (400 million New Zealand
dollars) credit facility. The proceeds from the $120 million stock and $214
million credit facility, combined with an equity contribution from Edison
International of $300 million and cash were used to finance the acquisition of
Contact. In June 1999, EME Taupo issued $84 million (160 million New Zealand
dollars) of Retail Redeemable Preference Shares, the proceeds of which were used
to repay a portion of the EME Taupo $214 million credit facility.
In June 1999, EME issued $600 million, 7.73% Senior Notes due 2009. The Notes
are senior unsecured obligations of EME, which will be used for general
corporate purposes.
NOTE 5. COMMITMENTS AND CONTINGENCIES
Firm Commitments for Asset Purchases
<TABLE>
<CAPTION>
Projects U.S. ($ in millions)
- -------- --------------------
<S> <C>
Commonwealth Edison Co. (i) $ 5,000
</TABLE>
(i) A wholly owned subsidiary of EME executed an Asset Sale Agreement to
purchase the fossil-fuel generating assets of Commonwealth Edison Co.,
totaling 9,621 MW located in the midwestern United States. The closing of
the transaction is subject to receipt of various state and federal
regulatory approvals and is expected to be completed by year end 1999.
Firm Commitments to Contribute Project Equity
<TABLE>
<CAPTION>
Projects Local Currency U.S. ($ in millions)
- -------- -------------- --------------------
<S> <C> <C>
ISAB (i) 244 billion Italian Lira $130
EcoElectrica (ii) 34
Tri Energy (iii) 25
Paiton (iv) 17
</TABLE>
(i) ISAB is a 512-MW integrated gasification combined cycle power plant under
construction near Siracusa in Sicily, Italy. A wholly owned subsidiary of
EME owns a 49% interest. Equity will be contributed at commercial
operation, which is currently scheduled for late 1999.
8
<PAGE>
(ii) EcoElectrica is a 540-MW liquefied natural gas combined-cycle cogeneration
facility under construction in Penuelas, Puerto Rico. A wholly owned
subsidiary of EME owns a 50% interest. Equity will be contributed at
commercial operation, which is currently scheduled for late 1999.
(iii) Tri Energy is a 700-MW gas-fired power plant under construction in the
Ratchaburi Province, Thailand. A wholly owned subsidiary of EME owns a 25%
interest. Equity will be contributed at commercial operation, which is
currently scheduled for mid-2000.
(iv) Paiton is a 1,230-MW coal-fired power plant in operation in East Java,
Indonesia. A wholly owned subsidiary of EME owns a 40% interest. Equity
contributions continue to be made.
Firm commitments to contribute project equity could be accelerated due to
certain events of default as defined in the non-recourse project financing
facilities. Management has no reason to believe that these events of default
will occur to require acceleration of the firm commitments.
Contingent Obligations to Contribute Project Equity
<TABLE>
<CAPTION>
Projects U.S. ($ in millions)
- -------- --------------------
<S> <C>
Paiton (i) $141
Tri Energy (ii) 20
Doga (ii) 14
All Other 19
</TABLE>
(i) Contingent obligations to contribute additional project equity (Contingent
Equity) would be based on events principally related to capital cost
overruns during the plant construction, certain partner obligations or
events of default. These contingent obligations are to be cancelled (if
unused) as of the date of term financing by the Export-Import Bank of the
United States. Term financing by the Export-Import Bank of the United
States is the subject of a comprehensive set of conditions. Based on
present projections, the Project does not expect to complete these
conditions at the time contemplated in the loan documentation (October 15,
1999), and is seeking an extension of the time to achieve term completion.
The Project is also negotiating an understanding with its Lenders with
regard to the amounts and uses of the Contingent Equity during the time of
this extension. As of the date hereof, the Project does not have any
commitment from the Lenders as to the extension. In addition, a dispute
involving a slope adjacent to the Paiton site will require Contingent
Equity to be contributed for amounts not otherwise covered by insurance.
The Contractor has initiated a Phase II arbitration on the amount of
compensation due as a result of the slope failure, and Paiton Energy is in
discussions with its insurance companies on payment under its policies.
EME's share of the total costs related to the slope failure are currently
estimated to be between $16 and $44 million. Further, because of some
delays in the completion of the construction, the Project expects certain
other cost
9
<PAGE>
overruns. The EME share of these overruns is estimated to be between $10-
15 million.
(ii) Contingent obligations to contribute additional equity to the project
would be based on events principally related to capital cost overruns
during plant construction, certain EME or partner obligations or events of
default.
Other than as noted above, management is not aware, at this time, of any other
contingent obligations or obligations to contribute project equity.
Other Commitments and Contingencies
Certain of EME's subsidiaries entered into indemnification agreements whereby
the subsidiaries agreed to repay capacity payments to the projects' power
purchasers, in the event the projects unilaterally terminate their performance
or reduce their electric power producing capability during the term of the power
contract. Obligations under these indemnification agreements as of June 30,
1999, if payment were required, would be $243 million. Management has no reason
to believe that the projects will either terminate their performance or reduce
their electric power producing capability during the term of the power
contracts.
Paiton is a 1,230-MW coal-fired power plant in operation in East Java,
Indonesia. A wholly owned subsidiary of EME owns a 40% interest and has a $370
million investment at June 30, 1999. The tariff is higher in the early years and
steps down over time. The tariff for the Paiton project includes infrastructure
to be used in common by other units at the Paiton complex. The plant's output is
fully contracted with the state-owned electricity company, PT Perusahaan Listrik
Negara (PLN). Payments are in Indonesian Rupiah, with the portion of such
payments intended to cover non-Rupiah project costs (including returns to
investors) indexed to the Indonesian Rupiah/U.S. dollar exchange rate
established at the time of the Power Purchase Agreement (PPA) in February 1994.
PLN's payment obligations are supported by the Government of Indonesia. The
projected rate of growth of the Indonesian economy and the exchange rate of
Indonesian Rupiah into U.S. dollars have deteriorated significantly since the
Paiton project was contracted, approved and financed. The project received
substantial finance and insurance support from the Export-Import Bank of the
United States, The Export-Import Bank of Japan, the U.S. Overseas Private
Investment Corporation and the Ministry of International Trade and Industry of
Japan. The Paiton project's senior debt ratings have been reduced from
investment grade to speculative grade based on the rating agencies' perceived
increased risk that PLN might not be able to honor the electricity sales
contract with Paiton. The Government of Indonesia has arranged to reschedule
sovereign debt owed to foreign governments and has entered into discussions
about rescheduling sovereign debt owed to private lenders. PLN has announced
its intentions to commence discussions with independent power producers to
renegotiate the power supply contracts, which discussions have commenced on an
initial basis, however it is not yet known what form the renegotiation may take.
Any material modifications of the contract could also require a renegotiation of
the Paiton project's debt agreement. Certain events (including
10
<PAGE>
the shortfall in payment discussed in the paragraph below) which, with the
passage of time or upon notice, may mature into defaults of the Project's debt
agreement have occurred and may require the grant of waivers or renegotiation of
the relevant agreements. Waivers of potential defaults have been received
previously from the Project's creditors. The impact of any such renegotiations
with PLN, the Government of Indonesia or the project's creditors on EME's
expected return on its investment in Paiton is uncertain at this time, however,
management believes that it will ultimately recover its investment in the
project.
Paiton notified PLN that Unit 7 of Paiton achieved Commercial Operation under
terms of the PPA on May 1999 and that Unit 8 of Paiton achieved Commercial
Operation under the terms of the PPA on July 1999. Because of the economic
downturn, PLN is experiencing low electricity demand and PLN has therefore
dispatched the Paiton plant to zero; however, under the terms of the PPA, PLN
is required to continue to pay for capacity and fixed operating costs once each
unit and the Plant achieve Commercial Operation. An invoice for these charges
for May in the amount of $7.8 million was submitted to PLN. The project and PLN
met to review the invoice and a partial payment of $2.5 million was subsequently
received. The primary reason for the payment shortage was the use of an
arbitrary Indonesian Rupiah/U.S. dollar exchange rate of 2,450 Indonesian Rupiah
to one U.S. dollar by PLN. The use of this exchange rate is not in agreement
with the Power Purchase Agreement, but is the exchange rate on which PLN
payments to other independent power producers in Indonesia have been based.
Brooklyn Navy Yard is a 286-MW gas-fired cogeneration power plant in Brooklyn,
New York. A wholly owned subsidiary of EME owns 50% of the project. In
February 1997, the construction contractor asserted general monetary claims
under the turnkey agreement against Brooklyn Navy Yard Cogeneration Partners,
L.P. (BNY) for damages in the amount of $136.8 million. BNY has asserted
general monetary claims against the contractor. In connection with a $407
million non-recourse project refinancing in 1997, EME agreed to indemnify BNY
and its partner from all claims and costs arising from or in connection with the
contractor litigation, which indemnity has been assigned to the lenders. EME
believes that the outcome of this litigation will not have a material adverse
effect on its financial position or results of operations.
Litigation
EME is routinely involved in litigation arising in the normal course of
business. While the results of such litigation cannot be predicted with
certainty, management, based on advice of counsel, does not believe that the
final outcome of any pending litigation will have a material adverse effect on
EME's financial position or results of operations.
11
<PAGE>
Environmental Matters
EME is subject to environmental regulation by federal, state and local
authorities in the U.S. and foreign regulatory authorities with jurisdiction
over projects located outside the U.S. EME believes that it is in substantial
compliance with environmental regulatory requirements and that maintaining
compliance with current requirements will not materially affect its financial
position or results of operations.
EME completed a partial review of its sites in 1995 and does not believe
that a material liability exists as of June 30, 1999. The implementation of
Clean Air Act Amendments is expected to result in increased operating expenses;
however, these expenses are not expected to have a material impact on EME's
financial position or results of operations.
NOTE 6. BUSINESS SEGMENTS
EME operates predominately in one line of business, electric power
generation, with reportable segments organized by geographic region: Americas,
Asia Pacific and Europe, Central Asia, Middle East and Africa. EME's plants are
located in different geographic areas, which mitigates the effects of regional
markets, economic downturns or unusual weather conditions. These regions take
advantage of the increasing globalization of the independent power market.
Intercompany transactions have been eliminated in the following segment
information.
<TABLE>
<CAPTION>
Europe,
(In millions) Central Asia,
Three Months Ended Asia Middle East Corporate/
June 30, 1999 Americas Pacific and Africa Other(/i/) Total
------------- -------- ------- ------------- ---------- --------
<S> <C> <C> <C> <C> <C>
Operating revenues $ 122.6 $ 56.1 $ 90.7 $ -- $ 269.4
Net income (loss) 21.0 (4.4) 1.7 (12.8) 5.5
Total assets 3,504.6 2,486.8 2,166.8 -- 8,158.2
June 30, 1998
-------------
Operating revenues $ 58.9 $ 53.2 $ 95.2 $ -- $ 207.3
Net income (loss) 22.1 (3.4) 6.0 (6.1) 18.6
Total assets 913.8 1,686.6 2,428.9 -- 5,029.3
</TABLE>
12
<PAGE>
<TABLE>
<CAPTION>
Europe,
(In millions) Central Asia,
Six Months Ended Asia Middle East Corporate/
June 30, 1999 Americas Pacific and Africa Other(/i/) Total
------------- -------- ------- ------------- ---------- --------
<S> <C> <C> <C> <C> <C>
Operating revenues $ 207.2 $ 106.3 $ 225.6 $ -- $ 539.1
Net income (loss) 51.0 (14.4) 28.9 (15.9) 49.6
Total assets 3,504.6 2,486.8 2,166.8 -- 8,158.2
June 30, 1998
-------------
Operating revenues $ 88.3 $ 107.3 $ 243.6 $ -- $ 439.2
Net income (loss) 32.3 (3.6) 39.0 (11.4) 56.3
Total assets 913.8 1,686.6 2,428.9 -- 5,029.3
</TABLE>
(i) Includes corporate net interest expense
NOTE 7. SUBSEQUENT EVENTS
In July 1999, Edison First Power Limited, a wholly owned subsidiary of EME, a
wholly owned, non-utility subsidiary of Edison International, completed a
transaction with PowerGen UK plc, to acquire the Ferrybridge and Fiddler's Ferry
coal-fired electric generating plants located in the United Kingdom.
Ferrybridge, located in West Yorkshire, and Fiddler's Ferry, located in
Warrington, each have a generating capacity of approximately 2,000 megawatts.
Consideration for Ferrybridge and Fiddler's Ferry consisted of a cash payment
of approximately $2.0 billion (1.3 billion pounds Sterling) for the two plants.
The acquisition was funded primarily with a combination of net proceeds from the
Edison First Power Limited Guaranteed Secured Variable Rate Bonds issued on July
19, 1999 and due 2019, and equity from Edison International.
13
<PAGE>
ITEM 2. MANAGEMENT'S DISCUSSION AND ANALYSIS OF
FINANCIAL CONDITION AND RESULTS OF OPERATIONS
This Quarterly Report on Form 10-Q includes certain forward-looking
statements, the realization of which may be affected by certain important
factors discussed in "Management's Discussion and Analysis of Financial
Condition and Results of Operations" thereunder and elsewhere herein.
GENERAL
- -------
Edison Mission Energy (EME) is a leading global power producer. Through its
subsidiaries, EME is engaged in the business of developing, acquiring, owning
and operating electric power generation facilities worldwide. EME's current
investments include 65 projects totaling 19,397 megawatts (MW) of generation
capacity, of which 16,922 are in operation and 2,475 are under construction. In
addition, 12 operating projects totaling 9,621 MW of generating capacity are
pending acquisition.
EME's operating revenues are derived primarily from electric revenues and
equity in income from energy projects. Operating revenues also include equity
in income from oil and gas investments and revenue attributable to operation and
maintenance services.
Electric revenues are derived from consolidated results of operations of one
domestic and several international entities. Equity in income from energy
projects relates to EME's ownership interest of 50% or less voting stock in
projects. The equity method of accounting is generally used to account for the
operating results of entities over which EME has a significant influence but in
which it does not have a controlling interest. With respect to entities
accounted for under the equity method, EME recognizes its proportional share of
the income or loss of such entities.
ACQUISITIONS
- ------------
In March 1999, EME Homer City Generation L.P. (EME Homer City), an indirect,
wholly owned affiliate of EME, completed a transaction with GPU, Inc., New York
State Electric & Gas Corporation and their respective affiliates to acquire the
1,884-MW Homer City Electric Generating Station and certain facilities and other
assets associated therewith (collectively, Homer City).
Consideration for Homer City consisted of a cash payment of approximately $1.8
billion, which was partially financed by $1.5 billion of new loans, combined
with corporate revolver borrowings and cash.
In May 1999, Edison Mission Energy Taupo Ltd. (EME Taupo), an indirect, wholly
owned affiliate of EME, completed a transaction with the New Zealand government
to acquire 40% of the shares of Contact Energy Ltd. (Contact). Contact owns and
operates hydroelectric, geothermal and natural gas-fired power generating plants
in New Zealand with a total generating capacity of 2,371 MW. Contact also
supplies gas and electricity
14
<PAGE>
to customers in New Zealand and has minority interests in two power projects in
Australia.
Consideration for Contact consisted of a cash payment of approximately $648
million (1.2 billion New Zealand dollars), which was financed by $120 million of
preferred stock issued by Edison Mission Energy Global Management, Inc., a $214
million (400 million New Zealand dollars) credit facility issued by EME Taupo, a
$300 million equity contribution from Edison International and cash.
In July 1999, Edison First Power Limited, a wholly owned subsidiary of EME, a
wholly owned, non-utility subsidiary of Edison International, completed a
transaction with PowerGen UK plc, to acquire the Ferrybridge and Fiddler's Ferry
coal-fired electric generating plants located in the United Kingdom.
Ferrybridge, located in West Yorkshire, and Fiddler's Ferry, located in
Warrington, each have a generating capacity of approximately 2,000 megawatts.
Consideration for Ferrybridge and Fiddler's Ferry consisted of a cash payment
of approximately $2.0 billion (1.3 billion pounds Sterling) for the two plants.
The acquisition was funded primarily with a combination of net proceeds from the
Edison First Power Limited Guaranteed Secured Variable Rate Bonds issued on July
19, 1999 and due 2019, and equity from Edison International.
These acquisitions were accounted for utilizing the purchase method. EME's
consolidated statement of income for the three and six months ended June 30,
1999 reflects the operations of Homer City beginning on March 18, 1999 and
Contact beginning May 1, 1999. The consolidated statements of income, balance
sheets and cash flows do not reflect the Ferrybridge and Fiddler's Ferry
generating plants acquired in July 1999.
RESULTS OF OPERATIONS
- ---------------------
OPERATING REVENUES Operating revenues increased $62.1 million and $99.9 million
for the second quarter and six months ended June 30, 1999, respectively,
compared with the corresponding periods of 1998, resulting primarily from
increases in electric revenues and equity in income from energy projects.
Electric revenues increased $74.3 million and $72.3 million for the second
quarter and six months ended June 30, 1999, respectively, compared with the
corresponding periods of 1998, primarily due to revenues from Homer City
acquired in March 1999. Equity in income from energy projects decreased $13
million and increased $30.2 million during the second quarter and six months
ended June 30, 1999, respectively, compared with the corresponding periods of
1998. The second quarter decrease was principally due to a geothermal project
that was sold in 1998 which recorded earnings in 1998 that had been deferred in
previous years. The increase for the six month period was primarily the result
of higher revenues from several cogeneration projects due to a final settlement
on energy pricing for prior years.
15
<PAGE>
OPERATING EXPENSES Operating expenses increased $60.1 million and $83.1 million
for the second quarter and six months ended June 30, 1999, respectively,
compared with the same prior year periods. These increases are due to higher
fuel, plant operations, depreciation and amortization and administrative and
general expenses. The increases in fuel expense, plant operations and
depreciation and amortization are primarily the result of expenses at Homer City
acquired in March 1999. The administrative and general expense increase is
primarily related to increased project development/acquisition costs.
OTHER INCOME (EXPENSE) Interest expense increased $33.7 million and $32.5
million for the second quarter and six months ended June 30, 1999, respectively,
compared with the same prior year periods. The increase was primarily the
result of additional debt financing of the Homer City acquisition.
CUMULATIVE EFFECT OF CHANGE IN ACCOUNTING PRINCIPLE In April 1998, the American
Institute of Certified Public Accountants issued Statement of Position (SOP) 98-
5, "Reporting on the Costs of Start-Up Activities", which became effective in
January 1999. The Statement requires that certain costs related to start-up
activities be expensed as incurred and that certain previously capitalized costs
be expensed and reported as a cumulative change in accounting principle. The
impact of adopting SOP 98-5 on EME's net income was $13.8 million, after-tax.
PROVISION FOR INCOME TAXES EME recorded an effective tax provision rate of 18%
for the six months ended June 30, 1999, compared with a 41% rate for the same
prior year period. The decrease in the 1999 effective tax rate was primarily
due to lower foreign income taxes that result from the permanent reinvestment of
earnings from foreign affiliates located in different foreign tax jurisdictions.
LIQUIDITY AND CAPITAL RESOURCES For the six months ended June 30, 1999, net
cash provided by operating activities decreased to $98.3 million from $123.6
million for the same period in 1998. The 1999 decrease primarily reflects lower
distributions from oil and gas projects and increased working capital
requirements associated with the acquisition of Homer City.
Net cash provided by financing activities totaled $2,861.6 million during the
first six months of 1999, compared to $12.1 million in 1998 for the same prior
year period. The 1999 increase is primarily due to the Edison Mission Holding
Co., parent company of EME Homer City, $830 million senior secured bonds, EME
financing of $700 million, EME Senior Notes of $600 million, Edison Mission
Energy Taupo Limited (EME Taupo) $214 million credit facility, Edison Mission
Energy Global Management, Inc. $120 million Flexible Money Market Cumulative
Preferred Stock, EME Taupo $84 million Retail Redeemable Preference Shares and
borrowing on the corporate revolver of $335 million, the proceeds of which were
used to purchase Homer City and Contact.
16
<PAGE>
Net cash used in investing activities increased to $2,601.4 million for the
six months ended June 30, 1999 from $53.5 million for the six months ended June
30, 1998. The increase is primarily due to the purchase of Homer City and
Contact.
At June 30, 1999, EME had cash and cash equivalents of $808.3 million and had
available $107 million of borrowing capacity under a $500 million revolving
credit facility that expires in 2001 and $125 million of borrowing capacity
under a $700 million commercial paper facility that expires in 2000. This
borrowing capacity under the revolving credit facility may be reduced by
borrowings for firm commitments to contribute project equity and to fund capital
expenditures and construction costs of its project facilities.
In July 1999, Edison First Power Limited, completed a transaction with
PowerGen UK plc, to acquire the Ferrybridge and Fiddler's Ferry coal-fired
electric generating plants located in the United Kingdom. Consideration for
Ferrybridge and Fiddler's Ferry consisted of a cash payment of approximately
$2.0 billion (1.3 billion pounds Sterling) for the two plants. The acquisition
was funded primarily with a combination of net proceeds from the Edison First
Power Limited Guaranteed Secured Variable Rate Bonds issued on July 19, 1999 and
due 2019, and equity from Edison International.
Firm Commitments for Asset Purchases
<TABLE>
<CAPTION>
Projects U.S. ($ in millions)
- -------- --------------------
<S> <C>
Commonwealth Edison Co. (i) $ 5,000
</TABLE>
(i) A wholly owned subsidiary of EME executed an Asset Sale Agreement to
purchase the fossil-fuel generating assets of Commonwealth Edison Co.,
totaling 9,621 MW located in the midwestern United States. The closing of
the transaction is subject to receipt of various state and federal
regulatory approvals and is expected to be completed by year end 1999.
Firm Commitments to Contribute Project Equity
<TABLE>
<CAPTION>
Projects Local Currency U.S. ($ in millions)
- -------- -------------- --------------------
<S> <C> <C>
ISAB (i) 244 billion Italian Lira $130
EcoElectrica (ii) 34
Tri Energy (iii) 25
Paiton (iv) 17
</TABLE>
(i) ISAB is a 512-MW integrated gasification combined cycle power plant under
construction near Siracusa in Sicily, Italy. A wholly owned subsidiary of
EME owns a 49% interest. Equity will be contributed at commercial
operation, which is currently scheduled for late 1999.
(ii) EcoElectrica is a 540-MW liquefied natural gas combined-cycle cogeneration
facility under construction in Penuelas, Puerto Rico. A wholly owned
subsidiary of
17
<PAGE>
EME owns a 50% interest. Equity will be contributed at
commercial operation, which is currently scheduled for late 1999.
(iii) Tri Energy is a 700-MW gas-fired power plant under construction in the
Ratchaburi Province, Thailand. A wholly owned subsidiary of EME owns a 25%
interest. Equity will be contributed at commercial operation, which is
currently scheduled for mid-2000.
(iv) Paiton is a 1,230-MW coal-fired power plant in operation in East Java,
Indonesia. A wholly owned subsidiary of EME owns a 40% interest. Equity
contributions continue to be made.
Firm commitments to contribute project equity could be accelerated due to
certain events of default as defined in the non-recourse project financing
facilities. Management has no reason to believe that these events of default
will occur to require acceleration of the firm commitments.
Contingent Obligations to Contribute Project Equity
<TABLE>
<CAPTION>
Projects U.S. ($ in millions)
- -------- --------------------
<S> <C>
Paiton (i) $141
Tri Energy (ii) 20
Doga (ii) 14
All Other 19
</TABLE>
(i) Contingent obligations to contribute additional project equity (Contingent
Equity) would be based on events principally related to capital cost
overruns during the plant construction, certain partner obligations or
events of default. These contingent obligations are to be cancelled (if
unused) as of the date of term financing by the Export-Import Bank of the
United States. Term financing by the Export-Import Bank of the United
States is the subject of a comprehensive set of conditions. Based on present
projections, the Project does not expect to complete these conditions at the
time contemplated in the loan documentation (October 15, 1999), and is
seeking an extension of the time to achieve term completion. The Project is
also negotiating an understanding with its Lenders with regard to the
amounts and uses of the Contingent Equity during the time of this extension.
As of the date hereof, the Project does not have any commitment from the
Lenders as to the extension. In addition, a dispute involving a slope
adjacent to the Paiton site will require Contingent Equity to be contributed
for amounts not otherwise covered by insurance. The Contractor has initiated
a Phase II arbitration on the amount of compensation due as a result of the
slope failure, and Paiton Energy is in discussions with its insurance
companies on payment under its policies. EME's share of the total costs
related to the slope failure are currently estimated to be between $16 and
$44 million. Further, because of some delays in the completion of the
construction, the Project expects certain other cost overruns. The EME
share of these overruns is estimated to be between $10-15 million.
18
<PAGE>
(ii) Contingent obligations to contribute additional equity to the project would
be based on events principally related to capital cost overruns during
plant construction, certain EME or partner obligations or events of
default.
Other than as noted above, management is not aware, at this time, of any other
contingent obligations or obligations to contribute project equity.
Other Commitments and Contingencies
Certain of EME's subsidiaries entered into indemnification agreements whereby
the subsidiaries agreed to repay capacity payments to the projects' power
purchasers, in the event the projects unilaterally terminate their performance
or reduce their electric power producing capability during the term of the power
contract. Obligations under these indemnification agreements as of June 30,
1999, if payment were required, would be $243 million. Management has no reason
to believe that the projects will either terminate their performance or reduce
their electric power producing capability during the term of the power
contracts.
Paiton is a 1,230-MW coal-fired power plant in operation in East Java,
Indonesia. A wholly owned subsidiary of EME owns a 40% interest and has a $370
million investment at June 30, 1999. The tariff is higher in the early years and
steps down over time. The tariff for the Paiton project includes infrastructure
to be used in common by other units at the Paiton complex. The plant's output is
fully contracted with the state-owned electricity company, PT Perusahaan Listrik
Negara (PLN). Payments are in Indonesian Rupiah, with the portion of such
payments intended to cover non-Rupiah project costs (including returns to
investors) indexed to the Indonesian Rupiah/U.S. dollar exchange rate
established at the time of the Power Purchase Agreement (PPA) in February 1994.
PLN's payment obligations are supported by the Government of Indonesia. The
projected rate of growth of the Indonesian economy and the exchange rate of
Indonesian Rupiah into U.S. dollars have deteriorated significantly since the
Paiton project was contracted, approved and financed. The project received
substantial finance and insurance support from the Export-Import Bank of the
United States, The Export-Import Bank of Japan, the U.S. Overseas Private
Investment Corporation and the Ministry of International Trade and Industry of
Japan. The Paiton project's senior debt ratings have been reduced from
investment grade to speculative grade based on the rating agencies' perceived
increased risk that PLN might not be able to honor the electricity sales
contract with Paiton. The Government of Indonesia has arranged to reschedule
sovereign debt owed to foreign governments and has entered into discussions
about rescheduling sovereign debt owed to private lenders. PLN has announced
its intentions to commence discussions with independent power producers to
renegotiate the power supply contracts, which discussions have commenced on an
initial basis, however it is not yet known what form the renegotiation may take.
Any material modifications of the contract could also require a renegotiation of
the Paiton project's debt agreement. Certain events (including the shortfall in
payment discussed in the paragraph below) which, with the passage of time or
upon notice, may mature into defaults of the Project's debt agreement have
19
<PAGE>
occurred and may require the grant of waivers or renegotiation of the relevant
agreements. Waivers of potential defaults have been received previously from
the Project's creditors. The impact of any such renegotiations with PLN, the
Government of Indonesia or the project's creditors on EME's expected return on
its investment in Paiton is uncertain at this time, however, management believes
that it will ultimately recover its investment in the project.
Paiton notified PLN that Unit 7 of Paiton achieved Commercial Operation under
terms of the PPA on May 1999 and that Unit 8 of Paiton achieved Commercial
Operation under the terms of the PPA on July 1999. Because of the economic
downturn, PLN is experiencing low electricity demand and PLN has therefore
dispatched the Paiton plant to zero; however, under the terms of the PPA, PLN
is required to continue to pay for capacity and fixed operating costs once each
unit and the Plant achieve Commercial Operation. An invoice for these charges
for May in the amount of $7.8 million was submitted to PLN. The project and PLN
met to review the invoice and a partial payment of $2.5 million was subsequently
received. The primary reason for the payment shortage was the use of an
arbitrary Indonesian Rupiah/U.S. dollar exchange rate of 2,450 Indonesian Rupiah
to one U.S. dollar by PLN. The use of this exchange rate is not in agreement
with the Power Purchase Agreement, but is the exchange rate on which PLN
payments to other independent power producers in Indonesia have been based.
Brooklyn Navy Yard is a 286-MW gas-fired cogeneration power plant in Brooklyn,
New York. A wholly owned subsidiary of EME owns 50% of the project. In
February 1997, the construction contractor asserted general monetary claims
under the turnkey agreement against Brooklyn Navy Yard Cogeneration Partners,
L.P. (BNY) for damages in the amount of $136.8 million. BNY has asserted
general monetary claims against the contractor. In connection with a $407
million non-recourse project refinancing in 1997, EME agreed to indemnify BNY
and its partner from all claims and costs arising from or in connection with the
contractor litigation, which indemnity has been assigned to the lenders. EME
believes that the outcome of this litigation will not have a material adverse
effect on its financial position or results of operations.
EME and its subsidiaries may incur additional obligations to make equity and
other contributions to projects in the future. EME believes that it will have
sufficient liquidity on both a short- and long-term basis to fund pre-financing
project development costs, make equity contributions to partnerships, pay
corporate debt obligations and pay other administrative and general expenses as
they are incurred from (1) distributions from energy projects and dividends from
investments in oil and gas, (2) proceeds from the repayment of loans to energy
projects and (3) funds available from EME's revolving credit facility.
CHANGES IN INTEREST RATES, CHANGES IN ELECTRICITY POOL PRICING, FOREIGN CURRENCY
FLUCTUATIONS AND OTHER CONTRACTUAL OBLIGATIONS Changes in interest rates,
changes in electricity pool pricing and fluctuations in foreign currency
exchange rates can have a significant impact on EME's
20
<PAGE>
results of operations. Interest rate changes affect the cost of capital needed
to construct and finance projects. EME has mitigated a portion of the risk of
interest rate fluctuations by arranging for fixed rate financing or variable
rate financing with interest rate swaps or other hedging mechanisms for the
majority of its project financing. Interest expense included $12.5 million and
$11.9 million for the six months ended June 30, 1999, and 1998, respectively, as
a result of interest rate swap and collar agreements. EME has entered into
several interest rate swap and collar agreements whereby the maturity date of
the swaps and collars occurs prior to the final maturity of the underlying debt.
EME does not believe that interest rate fluctuations will have a material
adverse effect on its financial position or results of operations.
Projects in the U.K. sell their electric energy and capacity through a
centralized electricity pool, which establishes a half-hourly clearing price
(also referred to as the "pool price") for electric energy. The pool price is
extremely volatile and can vary by as much as a factor of ten or more over the
course of a few hours, due to the large differentials in demand according to the
time of day. First Hydro mitigates a portion of the market risk of the pool by
entering into contracts for differences (electricity rate swap agreements),
related to either the selling or purchasing price of power, whereby a contract
specifies a price at which the electricity will be traded, and the parties to
the agreement make payments, calculated based on the difference between the
price in the contract and the pool price for the element of power under
contract. These contracts are sold in various structures. These contracts act
as a means of stabilizing production revenues or purchasing costs by removing an
element of First Hydro's net exposure to pool price volatility. On July 29,
1998, the Director General of Electricity Supply proposed to the Minister for
Science, Energy and Industry that the current structure of contracts-for-
differences and compulsory trading via the pool at half-hourly clearing prices
bid a day ahead be abolished. He proposed in its place, among other things, the
establishment of voluntary forwards and futures markets, organized by
independent market operators and evolving in response to demand; a short-term
bilateral market operating from 24 to 4-hours before a trading period; a
balancing market to enable the system operator to balance generation and demand
and resolve any transmission constraints; a settlement process for recovering
imbalances between contracted and metered volumes with stronger incentives for
being in balance; and a Balancing and Settlement Code Panel to oversee
governance of the short-term bilateral and balancing markets. The Minister for
Science, Energy and Industry has recommended that the proposal be implemented by
April 2000. Further definition of the proposal will be required before the
effects of the changes can be evaluated. Implementation of the proposal may
also require legislation.
Loy Yang B sells its electric energy through a centralized electricity
pool (the National Electricity Market) which provides for a system of generator
bidding, central dispatch and a settlements system based on a clearing market
for each half-hour of every day. The Victorian Power Exchange, operator and
administrator of the pool, determines a system marginal price each half-hour.
To mitigate exposure to price volatility of the electricity traded into the
pool, Loy Yang B has entered into a number of financial hedges. From May 8,
1997 to December 31, 2000, approximately 53% to 64% of the plant output sold is
hedged under "Vesting Contracts" with the remainder of the plant
21
<PAGE>
capacity hedged under the "State Hedge" described below. Vesting Contracts were
put into place by the State Government of Victoria, Australia (State), between
each generator and each distributor, prior to the privatization of electric
power distributors in order to provide more predictable pricing for those
electricity customers that were unable to choose their electricity retailer.
Vesting Contracts set base strike prices at which the electricity will be
traded, and the parties to the agreement make payments, calculated based on the
difference between the price in the contract and the half-hourly pool clearing
price for the element of power under contract. These contracts are sold in
various structures. These contracts are accounted for as electricity rate swap
agreements. The State Hedge is a long-term contractual arrangement based upon a
fixed price commencing May 8, 1997, and terminating October 31, 2016. The State
guarantees SECV's obligations under the State Hedge.
Electric power generated at Homer City is sold under bilateral arrangements
with domestic utilities and power marketers under short-term contracts (two
years or less) or to the Pennsylvania-New Jersey-Maryland Power Interconnection
(PJM) or the New York Power Pool (NYPP). The PJM pool has a market which
establishes an hourly clearing price. Homer City is situated in the PJM Control
Area and is physically connected to high-voltage transmission lines serving both
the PJM and NYPP markets. Power can also be transmitted to the midwestern
United States. EME has developed risk management policies and procedures which,
among other matters, address credit risk. It is EME's policy to sell to
investment grade counterparties or counterparties that have an investment grade
guarantor. EME intends on hedging a portion of the electric output of the plant
in order to lock in desirable outcomes. It plans to manage the "spark spread"
or margin, that is the spread between electric prices and fuel prices when
deemed appropriate. It plans to use forward contracts, swaps, futures, or
options contracts to achieve those objectives.
EME's electric revenues were increased by $20.1 million and $70.1 million
for the six-month periods ended June 30, 1999, and 1998, respectively, as a
result of electricity rate swap agreements and other hedging activities.
The electric power generated by EME's domestic operating projects,
excluding Homer City, is generally sold to electric utilities pursuant to long-
term (typically, 15 to 30-year) power sales contracts and is expected to result
in consistent cash flow under a wide range of economic and operating
circumstances. To accomplish this, EME structured its power sales contracts so
that fluctuations in fuel costs would produce similar fluctuations in electric
and/or steam revenues and entered into long-term fuel supply and transportation
agreements.
Fluctuations in foreign currency exchange rates can affect, on a U.S.
dollar equivalent basis, the amount of EME's equity contributions to, and
distributions from, its foreign projects. As EME continues to expand into
foreign markets, fluctuations in foreign currency exchange rates can be expected
to have a greater impact on EME's results of operations in the future. At times,
EME has hedged a portion of its current exposure to fluctuations in foreign
exchange rates where it deems appropriate through financial
22
<PAGE>
derivatives, offsetting obligations denominated in foreign currencies and
indexing underlying project agreements to U.S. dollars or other indices
reasonably expected to correlate with foreign exchange movements. In addition,
EME has used statistical forecasting techniques to help assess foreign exchange
risk and the probabilities of various outcomes. There can be no assurance,
however, that fluctuations in exchange rates will be fully offset by hedges or
that currency movements and the relationship between certain macro economic
variables will behave in a manner consistent with historical or forecasted
relationships.
ENVIRONMENTAL MATTERS EME is subject to environmental regulation by federal,
state and local authorities in the U.S. and foreign regulatory authorities with
jurisdiction over projects located outside the U.S. EME believes that it is in
substantial compliance with environmental regulatory requirements and that
maintaining compliance with current requirements will not materially affect its
financial position or results of operations.
EME completed a partial review of its sites in 1995 and does not believe
that a material liability exists as of June 30, 1999. The implementation of
Clean Air Act Amendments is expected to result in increased operating expenses;
however, these expenses are not expected to have a material impact on EME's
financial position or results of operations.
YEAR 2000 ISSUE EME has a comprehensive program in place to remediate potential
Year 2000 impacts from critical systems. EME divided its Year 2000 Issue
activities into five phases: inventory, impact assessment, remediation,
documentation and certification. A critical system was defined as those
applications and systems, including embedded processor technology, which if not
appropriately remediated might have had a significant impact on customers, the
revenue stream, regulatory compliance, or the health and safety of personnel.
With respect to critical systems, EME has achieved Year 2000 readiness as of
July 1999.
Assurances from third party operated plants have been received indicating
aggressive Year 2000 remediation programs. Monitoring of these efforts is
ongoing. Plants under construction have obtained assurances from new
construction and development contractors, who have been requested to ensure this
is part of their goals. General warranty of plants would likely include any
equipment issues that may arise regarding Year 2000 in the current year.
The other essential component of the EME Year 2000 readiness program was to
identify and assess vendor products and business partners for Year 2000
readiness. EME put a process in place to identify and contact vendors and
business partners to determine their Year 2000 status, and has evaluated the
responses. EME's general policy requires that all newly purchased products be
Year 2000 ready or otherwise designed to allow EME to determine whether such
products present Year 2000 issues.
23
<PAGE>
Plant contingency plans have been developed and reviewed for any
significant issues and to schedule appropriate testing and/or training. Such
contingency plans include developing strategies for dealing with Year 2000-
related processing failures or malfunctions due to EME's internal systems or
from external parties. EME's contingency plans evaluate reasonably likely worst
case scenarios or conditions. EME does not expect the Year 2000 issue to have a
material adverse effect on its results of operations or financial position.
However, if not effectively remediated, negative effects from Year 2000 issues,
including those related to external systems, vendors, business partners, the
independent system operator, the power exchange or customers, could cause
results to differ.
STATEMENT OF FINANCIAL ACCOUNTING STANDARDS NO. 133 In June 1998, the Financial
Accounting Standards Board issued Statement of Financial Accounting Standards
No. 133, "Accounting for Derivative Instruments and Hedging Activities", which,
as amended, will be effective in January 2001. The Statement establishes
accounting and reporting standards requiring that every derivative instrument be
recorded in the balance sheet as either an asset or liability measured at its
fair value. The Statement requires that changes in the derivative's fair value
be recognized currently in earnings unless specific hedge accounting criteria
are met. A derivative's gains and losses for qualifying hedges offset related
results on the hedged item in the income statement and a company must formally
document, designate and assess the effectiveness of transactions that receive
hedge accounting. The impact of adopting Statement 133 on EME's financial
statements has not been quantified at this time.
ACQUISITIONS PENDING In March 1999, EME entered into agreements to acquire the
fossil-fuel generating assets of Commonwealth Edison Co. (ComEd), totaling 9,621
MW. EME will operate the plants, which are located in the midwestern United
States. The closing of the transaction is subject to various state and federal
regulatory approvals and is expected to be completed by year end 1999. EME
plans to finance the approximately $5 billion acquisition with a combination of
debt secured by the project, corporate debt, cash and funding from Edison
International. The acquisition is expected to have an immaterial effect on
earnings in 1999, 2000 and 2001 as a result of transition contracts whereby
ComEd will retain power purchase agreements with EME, enabling ComEd access to
certain amounts of plant output for the next five years to serve its customers.
24
<PAGE>
PART II - OTHER INFORMATION
ITEM 6. EXHIBITS AND REPORTS ON FORM 8-K
(a) Exhibits
Exhibit No. Description
----------- -----------
10.63 Indenture and the First Supplemental Indenture dated as of June
28, 1999, between EME and The Bank of New York, as Trustee,
7.73% Senior Notes Due June 15, 2009.
27 Financial Data Schedule
(b) Reports on Form 8-K
The registrant filed the following reports on Form 8-K during the quarter
ended June 30, 1999.
<TABLE>
<CAPTION>
Date of Report Date Filed Item Reported
-------------- ---------- -------------
<S> <C> <C>
March 18, 1999 April 2, 1999 2
July 19, 1999 August 2, 1999 2
</TABLE>
25
<PAGE>
SIGNATURES
Pursuant to the requirements of the Securities Exchange Act of 1934, the
registrant has duly caused this report to be signed on its behalf by the
undersigned thereunto duly authorized.
Edison Mission Energy
---------------------
(Registrant)
Date: August 12, 1999 /s/ THOMAS E. LEGRO
- --------------------- -------------------
THOMAS E. LEGRO
Vice President and
Controller
26
<PAGE>
EXHIBIT 10.63
CONFIDENTIAL OFFERING CIRCULAR
$600,000,000
[LOGO OF EDISON MISSION ENERGY APPEARS HERE]
7.73% Senior Notes due June 15, 2009
------------
This is an offering by Edison Mission Energy of $600,000,000 of its 7.73%
Senior Notes due June 15, 2009. Interest is payable on June 15 and December 15
of each year, beginning on December 15, 1999. We may redeem all or part of the
Notes at any time at a redemption price equal to 100% of the principal of the
Notes being redeemed plus accrued and unpaid interest and, under certain
circumstances, a redemption premium.
We have agreed to file an Exchange Offer Registration Statement or, under
certain circumstances, a Shelf Registration Statement, pursuant to a
Registration Rights Agreement. If we fail to comply with certain of our
obligations under the Registration Rights Agreement, we will pay additional
interest to holders of the Notes.
Investing in the Notes involves risk. See "Risk Factors" beginning on page
6.
<TABLE>
<CAPTION>
Proceeds to
Discount to Edison
Price to Initial Mission
Investors (1) Purchasers Energy (1)
------------- ----------- ------------
<S> <C> <C> <C>
Per Note................................. 99.977% 0.650% 99.327%
Total.................................... $599,862,000 $3,900,000 $595,962,000
</TABLE>
(1) Plus accrued interest, if any, from June 28, 1999.
Delivery of the Notes will be made on or about June 28, 1999.
The Notes have not been registered under the Securities Act. The Notes may
not be offered or sold within the United States or to U.S. persons, except to
qualified institutional buyers in reliance on the exemption from registration
provided by Rule 144A, to a limited number of institutional "accredited
investors" and to certain persons in offshore transactions in reliance on
Regulation S. You are hereby notified that sellers of the Notes may be relying
on the exemption from the provisions of Section 5 of the Securities Act
provided by Rule 144A.
Credit Suisse First Boston
---------------
Lehman Brothers SG Cowen
The date of this Confidential Offering Circular is June 23, 1999.
<PAGE>
TABLE OF CONTENTS
<TABLE>
<CAPTION>
Page
----
<S> <C>
COMMISSION REVIEW..................................................... ii
FORWARD-LOOKING STATEMENTS............................................ ii
NOTICE TO NEW HAMPSHIRE RESIDENTS..................................... iii
OFFERING CIRCULAR SUMMARY............................................. 1
RISK FACTORS.......................................................... 6
USE OF PROCEEDS....................................................... 9
CAPITALIZATION........................................................ 9
PRO FORMA CONDENSED CONSOLIDATED BALANCE SHEET........................ 10
SELECTED CONSOLIDATED FINANCIAL DATA.................................. 11
MANAGEMENT'S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND
RESULTS OF OPERATIONS................................................ 12
BUSINESS.............................................................. 22
MANAGEMENT............................................................ 40
DESCRIPTION OF THE NOTES.............................................. 42
REGISTRATION RIGHTS AGREEMENT......................................... 50
CERTAIN UNITED STATES FEDERAL INCOME TAX CONSIDERATIONS............... 51
TRANSFER RESTRICTIONS................................................. 54
PLAN OF DISTRIBUTION.................................................. 57
NOTICE TO CANADIAN RESIDENTS.......................................... 59
LEGAL MATTERS......................................................... 60
AVAILABLE INFORMATION................................................. 60
INCORPORATION OF CERTAIN DOCUMENTS BY REFERENCE....................... 60
ANNEX A -- FORM OF LETTER TO BE DELIVERED BY ACCREDITED INVESTORS..... A-1
</TABLE>
------------
You should rely only on the information contained in this document or to
which we have referred you. We have not authorized anyone to provide you with
information that is different. This document may only be used where it is legal
to sell these securities. The information in this document may only be accurate
on the date of this document.
We are relying on an exemption from registration under the Securities Act
of 1933, as amended (the "Securities Act"), for offers and sales of securities
that do not involve a public offering. The notes offered by this offering
circular (the "Notes") are subject to restrictions on transferability and resale
and may not be transferred or resold, except as permitted under the Securities
Act and applicable state securities laws. By purchasing the Notes, you will be
deemed to have made the acknowledgments, representations, warranties and
agreements set forth in "Transfer Restrictions." You should understand that you
may be required to bear the financial risks of your investment for an indefinite
period of time.
We have furnished this offering circular confidentially to a limited number
of institutional investors and certain other investors so that they can
consider a purchase of the Notes. We have not authorized its use for any other
purpose. This offering circular may not be copied or reproduced in whole or in
part. It may be distributed and its contents disclosed only to the prospective
investors to whom it is provided. By accepting delivery of this offering
circular, you agree to these restrictions. See "Transfer Restrictions."
This offering circular is based on information provided by us and by other
sources that we believe are reliable. We cannot assure you that this
information is accurate or complete. This offering circular summarizes certain
documents and other information, and we refer you to them for a more complete
understanding of what we discuss in this offering circular. In making an
investment decision, you must rely on your own examination of our company and
the terms of the offering and the Notes, including the merits and risks
involved.
We are not making any representation to any purchaser of the Notes
regarding the legality of an investment in the Notes by such purchaser under any
legal investment or similar laws or regulations. You should not consider any
information in this offering circular to be legal, business or tax advice. You
should consult your own attorney, business advisor and tax advisor for legal,
business and tax advice regarding an investment in the Notes.
You should contact the initial purchasers with any questions about this
offering or if you require additional information to verify the information
contained in this offering circular.
i
<PAGE>
We may withdraw the offering of the Notes at any time, and the initial
purchasers may reject part or all of any offer to purchase the Notes. We are
offering the Notes subject to the terms described in this offering circular.
You must comply with all laws applicable to the purchase, sale or offer of
the Notes and to the distribution of this offering circular. You must also
obtain any approvals required for the purchase, sale or offer of the Notes, and
neither we nor the initial purchasers will assume any responsibility for
obtaining any approvals.
Commission Review
In the course of the Securities and Exchange Commission's review of the
registration statement for the exchange offer which we have agreed to make
relating to the Notes, we expect to make changes to the description of our
business and other information and financial data.
Forward-Looking Statements
This offering circular includes forward-looking statements. We have based
these forward-looking statements on our current expectations and projections
about future events based upon our knowledge of facts as of the date of this
offering circular and our assumptions about future events. These forward-
looking statements are subject to various risks and uncertainties that may be
outside our control, including, among other things:
. general political, economic and business conditions in the countries in
which we do business;
. governmental, statutory, regulatory or administrative changes or
initiatives affecting us or the electricity industry generally;
. political and business risks of international projects, including
uncertainties associated with currency exchange rates, currency
repatriation, expropriation, political instability, privatization
efforts and other issues;
. supply, demand and price for the electric capacity and energy in the
markets served by our generating units;
. competition from other power plants, including new plants that may be
developed in the future;
. operating risks, including equipment failure, dispatch levels,
availability, heat rate and output;
. the cost, availability and pricing of fuel and fuel transportation
services for our generating units;
. our ability to become year 2000 ready and the ability of our customers
and suppliers to become year 2000 ready; and
. our ability to complete the development or acquisition of current and
future projects.
We use words like "anticipate," "estimate," "project," "plan," "expect,"
"will," "believe" and similar expressions to help identify forward-looking
statements in this offering circular.
For additional factors that could affect the validity of our forward-looking
statements, you should read "Risk Factors" beginning on page 6. In light of
these and other risks, uncertainties and assumptions, actual events or results
may be very different from those expressed or implied in the forward-looking
statements in this offering circular, or may not occur. We have no obligation
to publicly update or revise any forward-looking statement, whether as a result
of new information, future events or otherwise.
------------
ii
<PAGE>
NOTICE TO NEW HAMPSHIRE RESIDENTS
NEITHER THE FACT THAT A REGISTRATION STATEMENT OR AN APPLICATION FOR A
LICENSE HAS BEEN FILED UNDER CHAPTER 421-B OF THE NEW HAMPSHIRE REVISED
STATUTES WITH THE STATE OF NEW HAMPSHIRE NOR THE FACT THAT A SECURITY IS
EFFECTIVELY REGISTERED OR A PERSON IS LICENSED IN THE STATE OF NEW HAMPSHIRE
CONSTITUTES A FINDING BY THE SECRETARY OF STATE THAT ANY DOCUMENT FILED UNDER
RSA 421-B IS TRUE, COMPLETE AND NOT MISLEADING. NEITHER ANY SUCH FACT NOR THE
FACT THAT AN EXEMPTION OR EXCEPTION IS AVAILABLE FOR A SECURITY OR A
TRANSACTION MEANS THAT THE SECRETARY OF STATE HAS PASSED IN ANY WAY UPON THE
MERITS OR QUALIFICATIONS OF, OR RECOMMENDED OR GIVEN APPROVAL TO, ANY PERSON,
SECURITY OR TRANSACTION. IT IS UNLAWFUL TO MAKE, OR CAUSE TO BE MADE, TO ANY
PROSPECTIVE PURCHASER, CUSTOMER OR CLIENT ANY REPRESENTATION INCONSISTENT WITH
THE PROVISIONS OF THIS PARAGRAPH.
iii
<PAGE>
OFFERING CIRCULAR SUMMARY
The following summary is qualified in its entirety by, and should be read in
conjunction with, the more detailed information appearing elsewhere in this
offering circular. Reference is made to "Risk Factors" for a discussion of
certain issues that should be considered in evaluating an investment in the
Notes. In this offering circular, the terms "the Company," "we," "our," "ours"
and "us" refer to Edison Mission Energy and its direct and indirect
subsidiaries unless the context otherwise requires. "EME" refers to Edison
Mission Energy.
Edison Mission Energy
We are a leading independent power producer engaged in the business of
developing, acquiring, owning and operating electric power generation
facilities worldwide. Edison International ("EIX") owns us and also owns
Southern California Edison Company ("SCE"), one of the largest electric
utilities in the United States. At March 31, 1999, we had consolidated assets
of approximately $7 billion and total shareholder's equity of approximately $1
billion.
EME was formed in 1986 with two domestic operating projects. Our business
has evolved from the development of contract-based domestic power projects to
the development of contract-based international power projects and the
acquisition of operating generating assets within developed and deregulating
power markets. Currently, we own interests in 58 domestic and international
operating power stations with an aggregate generating capacity of 11,826
megawatts ("MW"), of which our share is 8,002 MW. One domestic acquisition of
twelve operating projects and one international acquisition of two operating
projects, totaling 13,507 MW of generating capacity (of which our share is
100%), are currently pending. In addition, we own interests in one domestic and
six international projects that are under construction. The capacity of these
projects is expected to total 3,705 MW, of which our anticipated share will be
approximately 1,383 MW.
Strategic Overview
Our business goal is to be one of the leading owners and operators of
electric generating assets in the world. We play an active role, as a long-term
owner, in all phases of power generation, from planning and development through
construction and commercial operation. We believe that such involvement allows
us to better ensure, with our experienced personnel, that our projects are
well-planned, structured and managed, thereby maximizing value creation. We
have separate strategies for developed and developing countries.
In developed countries, we expect that new long-term contracts are likely to
be the exception rather than the rule. Our strategy focuses primarily on three
areas with respect to plants whose output is not committed to be sold pursuant
to long-term contracts (which are known as "merchant plants"): valuation, power
marketing and trading, and regulation. First, we continuously improve our
valuation tools, enabling us to bid more effectively and competitively on
assets that will be sold over the next five years in the United States, the
United Kingdom, Spain, Italy, Australia, New Zealand and other developed
countries. Second, we draw on our power marketing and trading skills to
mitigate price risks and to enhance the returns of our merchant plants. Third,
since our principal customers continue to be regulated utilities, we strive to
understand the regulatory and economic environment in which these utilities
operate so we may better anticipate and prepare for what they will do.
In developing countries, our strategy focuses on investing with good
partners, securing non-recourse financing based upon long-term contracts with
state-owned utilities, and securing government support from organizations such
as the Export-Import Bank of the United States, the U.S. Overseas Private
Investment Corporation and The Export-Import Bank of Japan.
In making investment decisions, we evaluate potential project returns
against rate of return guidelines. We establish these guidelines by identifying
a base rate of return and adjusting the base rate by potential risk
1
<PAGE>
factors, such as risks associated with project location and stage of project
development. We endeavor to mitigate such risks by:
. evaluating all projects and the markets in which they operate;
. selecting partners with complementary skills and local experience;
. structuring investments through subsidiaries;
. managing up-front development costs;
. utilizing limited recourse financing; and
. linking revenue and expense components where appropriate.
Many of our projects are operated by our subsidiaries, which helps us to
preserve and enhance the value of our investments.
In response to increasing globalization of the independent power market, we
have organized our operation and development activities into three geographic
regions: (1) Americas, (2) Asia Pacific and (3) Europe, Central Asia, Middle
East and Africa. Each region is served by one or more teams consisting of
business development, operations, finance and legal personnel, and each team is
responsible for all of our activities within a particular geographic region.
Also, we will mobilize personnel from outside a particular region when needed
in order to assist in the development of certain projects.
Recent Developments
Completed Acquisitions
In May 1999, we acquired 40% of Contact Energy Limited ("Contact Energy")
from the government of New Zealand for $674 million. Contact Energy owns and
operates eight hydroelectric, geothermal and natural gas-fired power generating
plants in New Zealand and owns an interest in one operating hydroelectric plant
in Australia, with a total aggregate capacity of 2,409 MW, of which our share
is 825 MW. Contact Energy also owns interests in three projects under
construction with an expected total generating capacity of 723 MW, of which our
share is 195 MW; two of these projects are in New Zealand and one is in
Australia. Contact Energy also distributes gas and electricity to customers in
New Zealand.
In March 1999, we acquired 100% of the 1,884 MW Homer City Generating
Station for approximately $1.8 billion. This facility is one of the largest
coal-fired plants in the mid-Atlantic region of the United States and has
direct, high voltage interconnections to both the New York Power Pool ("NYPP")
and the Pennsylvania-New Jersey-Maryland Power Pool ("PJM").
In December 1998, we acquired 50% of the 540 MW EcoElectrica liquefied
natural gas ("LNG")-fired combined-cycle cogeneration facility under
construction in Penuelas, Puerto Rico for approximately $243 million. The
project also includes a desalination plant and LNG storage and vaporization
facilities, and is expected to commence commercial operation by late 1999.
Pending Acquisitions
In April 1999, we entered into definitive acquisition documentation to
acquire 100% of the Ferrybridge and Fiddler's Ferry coal-fired power plants in
the United Kingdom with a total generating capacity of 3,886 MW from PowerGen
plc ("PowerGen") for approximately $2.3 billion. These mid-merit plants will
complement the pumped-storage hydroelectric power plants we already own in the
United Kingdom and will sell power into the electricity trading market there.
The closing of this acquisition requires the approval of British trade
regulators and is expected to occur in the summer of 1999.
2
<PAGE>
In March 1999, we entered into definitive acquisition documentation to
acquire the fossil-fuel generating assets of Commonwealth Edison Co. ("ComEd"),
totaling 9,621 MW of generating capacity, for approximately $5.0 billion. We
will operate the plants, which will provide us access to the Mid-America
Interconnected Network ("MAIN") and the East Central Area Reliability Council
("ECAR"). The closing of this acquisition is subject to various state and
federal regulatory approvals and is expected to be completed by year-end 1999.
Upon closing of the PowerGen and ComEd acquisitions, we will have an
interest in a total of 30,076 MW of generating capacity, of which our share
will be 23,300 MW.
----------------
EME is incorporated under the laws of the State of California. Its
headquarters and principal executive offices are located at 18101 Von Karman
Avenue, Suite 1700, Irvine, California 92612, and its telephone number is (949)
752-5588.
3
<PAGE>
The Offering
The following summary contains basic information about this offering. It
likely does not contain all the information that is important to you. For a
more complete understanding of this offering, we encourage you to read this
entire document and the documents to which we have referred you.
Securities Offered.................. $600,000,000 principal amount of 7.73%
Senior Notes due June 15, 2009.
Interest Payment Dates.............. June 15 and December 15, beginning on
December 15, 1999.
Ranking............................. The Notes will be senior unsecured
obligations of EME, will rank pari passu
with all of EME's senior unsecured
indebtedness and will rank senior to
EME's subordinated indebtedness. All
existing and future liabilities of EME's
subsidiaries will be effectively senior
to the Notes.
Ratings............................. The Notes have been assigned ratings of
"A-" by Standard & Poor's Ratings Group
and "A3" by Moody's Investors Service,
Inc.
Optional Redemption................. We may redeem any or all of the Notes at
a redemption price equal to the greater
of:
. 100% of the principal amount of the
Notes being redeemed, and
. the sum of the present values of the
remaining scheduled payments on the
Notes being redeemed discounted at a
rate based on the rates of Treasury
securities with average lives
comparable to the remaining average
lives of the Notes plus 37.5 basis
points;
plus accrued and unpaid interest on the
Notes being redeemed.
Exchange Offer; Registration
Rights.............................. EME will use its reasonable best efforts
to commence a registered exchange offer
within 270 days after the issuance of the
Notes. If the exchange offer is not
commenced (or a shelf registration
statement in respect of the Notes is not
declared effective) by the 271st day
after the issuance of the Notes, then the
interest rate on the Notes will increase
by 50 basis points, which increase will
remain in effect until the exchange offer
is commenced or the shelf registration
statement has become effective.
Use of Proceeds..................... We will use the net proceeds from the
sale of the Notes for general corporate
purposes, which may include financing the
development and construction of new
facilities, additions to working capital,
reductions of indebtedness and financing
of capital expenditures and pending or
potential acquisitions.
4
<PAGE>
Summary Consolidated Financial Data
The following table sets forth a summary of our consolidated financial data
for the periods indicated. The summary consolidated financial data for the
three months ended March 31, 1999 and 1998 was derived from the unaudited
consolidated financial statements of EME and its consolidated subsidiaries. The
summary consolidated financial data for the years ended December 31, 1998,
1997, 1996, 1995 and 1994 was derived from the audited consolidated financial
statements of EME and its consolidated subsidiaries. This summary is qualified
in its entirety by the more detailed information and financial statements,
including the notes thereto, included in the documents incorporated by
reference herein. See "Incorporation of Certain Documents by Reference."
<TABLE>
<CAPTION>
Three Months
Ended March 31, Years Ended December 31,
---------------- --------------------------------------
1999 1998 1998 1997 1996 1995 1994
------- ------- ------ ------ ------ ------ ------
(in millions)
<S> <C> <C> <C> <C> <C> <C> <C>
Income Statement Data
Operating revenues...... $ 269.8 $ 231.9 $893.8 $975.0 $843.6 $467.3 $380.6
Operating expenses...... 155.6 132.6 543.3 581.1 476.5 264.0 199.9
------- ------- ------ ------ ------ ------ ------
Income from operations.. 114.2 99.3 350.5 393.9 367.1 203.3 180.7
Interest expense........ (47.8) (49.0) (196.1) (223.5) (164.2) (93.1) (89.0)
Interest and other
income................. 8.8 14.6 50.9 53.9 40.7 33.1 38.8
Minority interest....... (1.0) (0.8) (2.8) (38.8) (69.5) (48.3) (46.1)
------- ------- ------ ------ ------ ------ ------
Income before income
taxes.................. 74.2 64.1 202.5 185.5 174.1 95.0 84.4
Provision for income
taxes.................. 16.3 26.4 70.4 57.4 82.0 31.0 29.4
------- ------- ------ ------ ------ ------ ------
Income before change in
accounting principle
and extraordinary
loss................... 57.9 37.7 132.1 128.1 92.1 64.0 55.0
Extraordinary loss on
early extinguishment of
debt, net of income tax
benefit................ -- -- -- (13.1) -- -- --
Cumulative effect on
prior years of change
in accounting for
start-up costs......... (13.8) -- -- -- -- -- --
------- ------- ------ ------ ------ ------ ------
Net income.............. $ 44.1 $ 37.7 $132.1 $115.0 $ 92.1 $ 64.0 $ 55.0
======= ======= ====== ====== ====== ====== ======
</TABLE>
<TABLE>
<CAPTION>
December 31,
March 31, --------------------------------------------
1999 1998 1997 1996 1995 1994
--------- -------- -------- -------- -------- --------
(in millions)
<S> <C> <C> <C> <C> <C> <C>
Balance Sheet Data
Assets................... $6,931.2 $5,158.1 $4,985.1 $5,152.5 $4,374.0 $2,842.9
Current liabilities...... 2,013.9 501.3 339.8 270.9 199.8 170.9
Long-term obligations.... 2,575.7 2,366.4 2,532.1 2,419.9 1,839.0 1,159.0
Shareholder's equity..... 989.0 957.6 826.6 1,019.9 1,028.5 622.2
</TABLE>
5
<PAGE>
RISK FACTORS
In addition to the information contained elsewhere in this offering
circular, the following risk factors should be carefully considered by each
prospective investor in evaluating an investment in the Notes.
EME's ability to repay its debt depends upon the performance of its
subsidiaries.
The Notes will be exclusively EME's obligations and will not be the
obligations of any of EME's subsidiaries or affiliates. Because substantially
all of EME's operations are conducted by its project subsidiaries, EME's cash
flow and ability to service its indebtedness, including EME's ability to pay
the interest on and principal of the Notes when due, are dependent upon the
ability of EME's subsidiaries to pay dividends and make distributions to EME.
Financing agreements for EME's subsidiaries generally place limitations on the
ability of those subsidiaries to pay dividends, make distributions or otherwise
transfer funds to EME. In addition, financing agreements for EME's
subsidiaries, although generally non-recourse to EME, contain certain
representations, warranties, covenants and other agreements that, if not met,
could lead to a default under such financings. After a default under a project
financing for any reason, project lenders may exercise certain rights and
remedies typically granted to secured parties, including the ability to take
control of the project's collateral assets or EME's ownership interest in the
project subsidiary. In addition, EME owns a minority interest in some of its
projects, and therefore is unable unilaterally to cause dividends or
distributions to be made to it from those operations. Accordingly, EME cannot
assure you that it will receive sufficient distributions from its subsidiaries
to pay debt service on the Notes when due.
Any right of EME to receive any assets of any of its subsidiaries upon any
liquidation or reorganization of such subsidiary (and the consequent right of
holders of the Notes to participate in the distribution of, or to realize
proceeds from, those assets) will be effectively subordinated to the claims of
any such subsidiary's creditors (including trade creditors and holders of debt
issued by such subsidiary).
The Indenture governing the Notes will impose no limitations on the ability
of EME's subsidiaries to permit contractual restrictions on their ability to
make dividends or distributions.
We have a substantial amount of indebtedness.
As of March 31, 1999, EME had total recourse debt of $1,116 million, with an
additional $3,184 million of non-recourse debt appearing on EME's consolidated
balance sheet. The percentage of EME's total recourse debt to capitalization
was 53% as of March 31, 1999. The Indenture governing the Notes will impose no
limitations on our ability to incur additional indebtedness either at the EME
level or at the subsidiary level. EME's substantial amount of total recourse
debt and the debt of its subsidiaries present the risk that EME might not have
sufficient cash to service its indebtedness, including the Notes, and that
EME's leveraged capital structure could limit EME's ability to finance the
acquisition and development of additional projects, to compete effectively or
to operate successfully under adverse economic conditions. See "Capitalization"
and "Selected Consolidated Financial Data."
Our project acquisitions and developments may not be successful.
The development projects and acquisitions in which we have invested or in
which we may invest in the future, including those described herein, may be
large and complex, and we may not be able to complete the development or
acquisition of any such project. The development of a power project may require
us to expend significant sums for preliminary engineering, permitting, legal
and other expenses before we can determine whether we will win a competitive
bid, or whether a project is feasible, economically attractive or financeable.
Moreover, access to capital for future projects is uncertain. We cannot assure
you that we will be successful in structuring the financing for our projects on
a substantially non-recourse basis or that we will obtain sufficient additional
equity capital, project cash flow or additional borrowings to enable us to fund
the equity commitments required for future projects.
Power purchase agreements often enable the utility to terminate such
agreements, or to retain security posted by the developer as liquidated
damages, in the event that a project fails to achieve commercial operation or
certain operating levels by specified dates or fails to meet other significant
contractual requirements.
6
<PAGE>
In addition, most of our acquisition agreements permit the seller to terminate
the agreement or impose penalties if the acquisition of the project is not
achieved by a specified date. If such events were to occur, the default
provisions in a financing agreement could be triggered (rendering the project
debt immediately due and payable) and, as a result, we could lose our interest
in the project.
A significant portion of our projects operate without long-term power purchase
agreements.
A significant portion of the projects in which we have acquired, or are
acquiring, an interest do not have long-term power purchase agreements. As
merchant plants, these projects are subject to market forces to determine the
amount and price of power that they sell. We cannot assure you that our
merchant plants will be successful in selling power into their respective
markets. If they are unsuccessful, they may not be able to generate enough cash
to service their own debt or to make distributions to EME.
In addition, some utilities have brought litigation aimed at forcing the
renegotiation or termination of long-term power purchase agreements based upon,
among other things, revised estimates of avoided cost or power demands. We
cannot assure you that in the future, utilities that purchase power from our
contract-based power plants or other power purchasers that purchase power under
long-term agreements from us will not seek to abrogate their existing
agreements with us.
Competition could adversely affect our business.
The global independent power industry is characterized by numerous strong
and capable competitors, some of which may have more extensive operating
experience, more extensive experience in the acquisition and development of
power projects, larger staffs and greater financial resources than we do.
Further, in recent years certain power markets have been characterized by
strong and increasing competition as a result of regulatory changes and other
factors which have contributed to a reduction in market prices for power. Such
regulatory and other changes may continue to increase competitive pressures in
the markets where we operate. Increased competition for our new project
investment opportunities may adversely affect our ability to develop or acquire
projects on economically favorable terms.
We are subject to extensive government regulation.
Our operations are subject to extensive regulation by governmental agencies
in each of the countries in which we conduct operations. See "Business--Certain
Regulatory Matters." Our domestic projects are subject to energy, environmental
and other governmental laws and regulations at the federal, state and local
levels in connection with the development, ownership and operation of the
projects. Our projects are also subject to federal, state and local laws and
regulations that govern the geographical location, zoning, land use and
operation of a project. Our international projects are subject to the energy,
environmental and other laws and regulations of the foreign jurisdictions in
which such projects are located. The degree of regulation varies according to
each country and may be materially different from the regulatory regimes in the
United States.
We cannot assure you that the introduction of new laws or other future
regulatory developments in countries in which we conduct our business will not
have a material adverse effect on our business, results of operations or
financial condition, nor can we assure you that we will be able to obtain and
comply with all necessary licenses, permits and approvals for our proposed
energy projects. If we cannot comply with all applicable regulations, our
business, results of operations and financial condition could be adversely
affected.
In addition, if any of our projects loses its status as a qualifying
facility ("QF"), eligible facility or foreign utility company under U.S.
federal regulations, EME could become subject to regulation as a "holding
company" under the Public Utility Holding Company Act. See "Business--Certain
Regulatory Matters."
General operating risks and catastrophic events can adversely affect our
projects.
The operation of power generating plants involves many risks, including
start-up problems, the breakdown or failure of equipment or processes,
performance below expected levels of output, the inability to meet
7
<PAGE>
expected efficiency standards, operator error and catastrophic events such as
earthquakes, landslides, fires, floods, explosions or similar calamities. The
occurrence of any of these events could significantly reduce revenues generated
by our projects or increase their generating expenses, thereby diminishing
distributions by the projects to EME and, as a result, EME's ability to make
payments on the Notes. Equipment and plant warranties and insurance obtained by
us may not be adequate to cover lost revenues or increased expenses and, as a
result, a project may be unable to fund principal and interest payments under
its financing obligations and may operate at a loss. A default under such a
financing obligation could cause EME to lose its interest in such project.
Our international projects are subject to risks of doing business in foreign
countries.
Our international projects are subject to political and business risks,
including uncertainties associated with currency exchange rates, currency
repatriation, expropriation, political instability, privatization efforts and
other issues that have the potential to impair such projects from making
dividends or other distributions to EME and against which we may not be fully
capable of insuring. In particular, fluctuations in currency exchange rates can
affect, on a U.S. dollar equivalent basis, the amount of our equity
contributions to, and distributions from, our international projects. At times,
we have hedged a portion of our exposure to fluctuations in currency exchange
rates. However, hedge contracts may involve risks, including counterparty
default, and we cannot assure you that fluctuations in currency exchange rates
will be fully offset by such hedges or that such hedges will be available
throughout the term of the Notes.
The economic crisis in Indonesia has raised concerns over the ability of the
state-owned utility to meet its obligations under its power sales contract with
our Paiton project and may therefore decrease that project's dividends to EME.
See "Business--Asia Pacific." Generally, the uncertainty of the legal structure
in certain foreign countries in which we may develop or acquire projects could
make it more difficult to enforce our rights under agreements relating to such
projects. In addition, the laws and regulations of certain countries may limit
our ability to hold a majority interest in some of the projects that we may
develop or acquire.
Risks associated with the year 2000 problem could have an adverse effect on our
business.
We expect to implement successfully systems to address year 2000 issues. We
cannot assure you, however, that our year 2000 compliance will not be delayed
or require significant expenditures. Our inability to implement the appropriate
software on a timely basis could have an adverse effect on our business. We may
also suffer an adverse impact on our business if our suppliers, customers,
financial institutions, technical advisors and others with which we conduct
business are not year 2000 compliant.
There is no existing market for the Notes, and we cannot assure you that an
active trading market will develop.
Prior to this offering, there has been no market for the Notes. EME has been
informed by the initial purchasers that they intend to make a market in the
Notes after the completion of this offering. However, the initial purchasers
are not required to make a market in the Notes, and they may cease market-
making at any time without notice. EME cannot assure you that an active market
for the Notes will develop. Moreover, even if a market for the Notes does
develop, the Notes could trade at a discount from their face amount. If a
market for the Notes does not develop, you may be unable to resell the Notes
for an extended period of time, if at all. Consequently, you may not be able to
liquidate your investment readily, and lenders may not readily accept the Notes
as collateral for loans.
EME intends to file a registration statement under the Securities Act with
respect to the Notes and to use its best efforts to have such registration
statement declared effective by the Securities and Exchange Commission ("SEC").
The SEC, however, has broad discretion to determine whether any registration
statement will be declared effective and may delay the effectiveness of such
registration statement filed by EME for a variety of reasons. Failure to have
such registration statement declared effective could adversely affect the
liquidity and price of the Notes.
8
<PAGE>
USE OF PROCEEDS
The net proceeds from the sale of the Notes will be used for general
corporate purposes, which may include financing the development and
construction of new facilities, additions to working capital, reductions of
indebtedness and financing of capital expenditures and pending or potential
acquisitions. Proceeds not immediately used for such purposes may be invested
in short-term investment grade securities.
CAPITALIZATION
The following table sets forth the unaudited capitalization of EME as of
March 31, 1999, as adjusted to reflect (1) the issuance of the Notes and the
application of the net proceeds therefrom as described in "Use of Proceeds" and
(2) the equity contributions to EME and other financings associated with the
Contact Energy, ComEd and PowerGen acquisitions. The table is qualified in its
entirety by the more detailed information included in the documents
incorporated by reference herein. See "Incorporation of Certain Documents by
Reference." The adjusted capitalization is based on EIX making capital
contributions to EME in an approximate aggregate amount of up to $2 billion, on
available information and on assumptions that management believes are
reasonable under the circumstances. The amount of capital contributions from
EIX could change depending on EIX's cash flow, ability to obtain financing,
project economics and other factors.
Capitalization as of March 31, 1999
<TABLE>
<CAPTION>
Actual As Adjusted
-------- -----------
(in millions)
<S> <C> <C>
Short-Term Indebtedness.................................... $ 796.5 $1,446.5
Long-Term Indebtedness..................................... 319.5 1,319.5
-------- --------
Total Indebtedness(1).................................... $1,116.0 $2,766.0
Shareholder's Equity....................................... $ 989.0 $2,989.0
-------- --------
Total Capitalization..................................... $2,105.0 $5,755.0
======== ========
</TABLE>
- --------
(1) Excludes EME subsidiary indebtedness of $3.2 billion as of March 31, 1999
and $7.2 billion (on an as adjusted basis) as of March 31, 1999.
9
<PAGE>
PRO FORMA CONDENSED CONSOLIDATED BALANCE SHEET
The following table sets forth the unaudited condensed consolidated balance
sheet of EME as of March 31, 1999 and as adjusted to reflect the issuance of
the Notes, the acquisition of a 40% interest in Contact Energy in May 1999 and
the pending acquisitions of power plants and related assets from ComEd and
PowerGen. The pro forma adjustments are based on EIX making capital
contributions to EME in an approximate aggregate amount of up to $2 billion on
available information and on assumptions that management believes are
reasonable under the circumstances. The amount of capital contributions from
EIX could change depending on EIX's cash flow, ability to obtain financing,
project economics and other factors.
<TABLE>
<CAPTION>
As Adjusted
March 31, March 31,
1999 1999
--------- -----------
(in millions)
<S> <C> <C>
Assets
Current assets......................................... $ 580.0 $ 669.3
Investments............................................ 1,275.4 1,949.1
Property, plant and equipment, net..................... 4,651.8 12,167.0
Other assets........................................... 424.0 498.4
-------- ---------
Total Assets............................................. $6,931.2 $15,283.8
======== =========
Current Liabilities
Accounts payable and accrued liabilities............... $ 289.8 $ 294.7
Short-term obligations of EME.......................... 796.5 1,446.5
Short-term obligations of subsidiaries................. 829.1 829.1
Current maturities of long-term obligations of
subsidiaries.......................................... 98.5 98.5
-------- ---------
Total current liabilities................................ 2,013.9 2,668.8
Long-Term Obligations
Long-term obligations of EME........................... 319.5 1,319.5
Long-term obligations of subsidiaries.................. 2,256.2 6,311.5
-------- ---------
Total long-term obligations.......................... 2,575.7 7,631.0
Long-Term Deferred Liabilities........................... 1,202.6 1,725.0
-------- ---------
Total Liabilities........................................ 5,792.2 12,024.8
-------- ---------
Preferred Securities of Subsidiaries..................... 150.0 270.0
-------- ---------
Shareholder's Equity..................................... 989.0 2,989.0
-------- ---------
Total Liabilities and Shareholder's Equity............... $6,931.2 $15,283.8
======== =========
</TABLE>
10
<PAGE>
SELECTED CONSOLIDATED FINANCIAL DATA
The following table sets forth a summary of our consolidated financial data
for the periods indicated. The summary consolidated financial data for the
three months ended March 31, 1999 and 1998 was derived from the unaudited
consolidated financial statements of EME and its consolidated subsidiaries. The
summary consolidated financial data for the years ended December 31, 1998,
1997, 1996, 1995 and 1994 was derived from the audited consolidated financial
statements of EME and its consolidated subsidiaries. This summary is qualified
in its entirety by the more detailed information and financial statements,
including the notes thereto, included in the documents incorporated by
reference herein. See "Incorporation of Certain Documents by Reference."
<TABLE>
<CAPTION>
Three Months
Ended March 31, Years Ended December 31,
------------------- ----------------------------------------------
1999 1998 1998 1997 1996 1995 1994
--------- -------- -------- -------- -------- -------- ------
(in millions)
<S> <C> <C> <C> <C> <C> <C> <C>
Income Statement Data
Operating revenues................ $ 269.8 $ 231.9 $ 893.8 $ 975.0 $ 843.6 $ 467.3 $380.6
Operating expenses................ 155.6 132.6 543.3 581.1 476.5 264.0 199.9
-------- -------- -------- -------- -------- -------- ------
Income from operations............ 114.2 99.3 350.5 393.9 367.1 203.3 180.7
Interest expense.................. (47.8) (49.0) (196.1) (223.5) (164.2) (93.1) (89.0)
Interest and other income......... 8.8 14.6 50.9 53.9 40.7 33.1 38.8
Minority interest................. (1.0) (0.8) (2.8) (38.8) (69.5) (48.3) (46.1)
-------- -------- -------- -------- -------- -------- ------
Income before income taxes........ 74.2 64.1 202.5 185.5 174.1 95.0 84.4
Provision for income taxes........ 16.3 26.4 70.4 57.4 82.0 31.0 29.4
-------- -------- -------- -------- -------- -------- ------
Income before change in accounting
principle and extraordinary loss.. 57.9 37.7 132.1 128.1 92.1 64.0 $ 55.0
Extraordinary loss on early
extinguishment of debt, net of
income tax benefit............... -- -- -- (13.1) -- -- --
Cumulative effect on prior years
of change in accounting for
start-up costs................... (13.8) -- -- -- -- -- --
-------- -------- -------- -------- -------- -------- ------
Net income........................ $ 44.1 $ 37.7 $ 132.1 $ 115.0 $ 92.1 $ 64.0 $ 55.0
======== ======== ======== ======== ======== ======== ======
<CAPTION>
December 31,
March 31, ------------------------------------------------
1999 1998 1997 1996 1995 1994
--------- -------- -------- -------- -------- --------
(in millions)
<S> <C> <C> <C> <C> <C> <C>
Balance Sheet Data
Assets............................ $6,931.2 $5,158.1 $4,985.1 $5,152.5 $4,374.0 $2,842.9
Current liabilities............... 2,013.9 501.3 339.8 270.9 199.8 170.9
Long-term obligations............. 2,575.7 2,366.4 2,532.1 2,419.9 1,839.0 1,159.0
Shareholder's equity.............. 989.0 957.6 826.6 1,019.9 1,028.5 622.2
<CAPTION>
Three Months
Ended March 31, Years Ended December 31,
------------------- ----------------------------------------------
1999 1998 1998 1997 1996 1995 1994
--------- -------- -------- -------- -------- -------- ------
<S> <C> <C> <C> <C> <C> <C> <C>
Other Data
Ratio of earnings to fixed
charges(1)....................... 1.7 1.9 1.7 1.6 1.4 1.3 1.2
</TABLE>
- --------
(1) For purposes of computing the ratio of earnings to fixed charges, earnings
are divided by fixed charges. "Earnings" represent the aggregate of income
(loss) before income taxes of EME (adjusted for the excess or shortfall of
dividends or other distributions over equity in earnings of less than 50%-
owned entities), amortization of previously capitalized interest and fixed
charges (net of capitalized interest). "Fixed charges" represent interest
(whether expensed or capitalized), the amortization of debt discount and
the interest portion of rentals.
11
<PAGE>
MANAGEMENT'S DISCUSSION AND ANALYSIS OF
FINANCIAL CONDITION AND RESULTS OF OPERATIONS
The following discussion contains forward-looking statements regarding our
company. These statements are based on our current plans and expectations that
involve risks and uncertainties which could cause actual future activities and
results of operations to be materially different from those set forth in the
forward-looking statements. Important factors that could cause actual results
to differ include risks set forth in "Risk Factors." Unless otherwise
indicated, the information presented in this section is with respect to EME and
its consolidated subsidiaries.
General
The Company is a leading independent power producer engaged in the business
of developing, acquiring, owning and operating electric power generation
facilities worldwide. The Company's current investments include interests in 58
domestic and international operating power stations with an aggregate
generating capacity of 11,826 MW, of which its share is approximately 8,002 MW.
One domestic acquisition of twelve operating projects and one international
acquisition of two operating projects, totaling 13,507 MW of generating
capacity (of which the Company's share is 100%) are currently pending. In
addition, the Company owns interests in one domestic and six international
projects that are under construction. The capacity of these projects is
expected to total 3,705 MW, of which the Company's anticipated share will be
approximately 1,383 MW.
The Company's consolidated operating revenues are derived primarily from
electric revenues and equity in income from energy projects. Consolidated
operating revenues also include equity in income from oil and gas investments
and revenue attributable to operation and maintenance services.
The Company's acquisitions of its interests in the Loy Yang B, Iberian Hy-
Power, EcoElectrica, Homer City and Contact Energy projects, which are
described in "Business," each have been accounted for utilizing the purchase
method. The purchase prices were allocated to the assets acquired and
liabilities assumed based on their respective fair market values. The Company's
consolidated statement of income for the three months ended March 31, 1999
reflects the operations of the Homer City project beginning on March 18, 1999.
Quarterly Results of Operations
Operating Revenues
Operating revenues increased $37.9 million for the first quarter of 1999,
compared with the first quarter of 1998, resulting primarily from an increase
in equity in income from energy projects. Equity in income from energy projects
increased $43.2 million during the first quarter of 1999, compared with the
first quarter of 1998. This increase was primarily the result of higher
revenues from several cogeneration projects due to a final settlement on energy
pricing for prior years and from one cogeneration project as the result of a
gain on termination of a power sales agreement.
Operating Expenses
Operating expenses increased $23 million for the first quarter of 1999,
compared with the first quarter of 1998. This increase was due to higher fuel,
plant operations and administrative and general expenses. The increases in fuel
expenses and plant operation expenses were primarily the result of the
acquisition of the Homer City project in March 1999. The increase in
administrative and general expenses was primarily related to increased project
development and acquisition costs.
Other Income (Expense)
Interest and other income decreased $6 million for the first quarter of
1999, compared with the first quarter of 1998. The decrease was primarily due
to less interest earned on lower cash balances.
12
<PAGE>
Cumulative Effect of Change in Accounting Principle
In April 1998, the American Institute of Certified Public Accountants issued
Statement of Position ("SOP") 98-5, "Reporting on the Costs of Start-Up
Activities," which became effective in January 1999. The Statement requires
that certain costs related to start-up activities be expensed as incurred and
that certain previously capitalized costs be expensed and reported as a
cumulative change in accounting principle. The impact of adopting SOP 98-5 on
EME's net income recorded in the first quarter of 1999 was $13.8 million, after
tax.
Provision for Income Taxes
EME recorded an effective tax provision rate of 22% for the three months
ended March 31, 1999, compared with a 41% rate for the same prior year period.
The decrease in the 1999 effective tax rate was primarily due to lower foreign
income taxes that result from the permanent reinvestment of earnings from
foreign affiliates located in different foreign tax jurisdictions.
Annual Results of Operations
Operating Revenues
Operating revenues decreased approximately 8% in 1998 compared to 1997, and
increased approximately 16% in 1997 compared to 1996. The 1998 decrease was
primarily due to the Loy Yang B project's new series of power purchase
agreements associated with our acquisition of the remainder of that project in
May 1997 and lower Australian currency exchange rates, partially offset by
higher energy revenues from the First Hydro project as a result of higher
energy prices. The 1997 increase resulted primarily from increases in electric
revenues attributable to the start of commercial operations of Loy Yang B Unit
2 in October 1996 and the Kwinana project in December 1996, and higher energy
revenues from the First Hydro projects as a result of increased utilization and
higher pool prices, partially offset by lower capacity prices in 1997. There
were no comparable electric revenues for Loy Yang B Unit 2 for the first nine
months of 1996 and for the Kwinana project for the first 11 months of 1996.
Equity in income from energy projects rose 14% in 1998 compared to 1997, and
17% in 1997 compared to 1996. The 1998 increase was primarily due to earnings
from a geothermal project that were previously deferred and lower fuel gas
prices at various cogeneration projects, partially offset by lower electric and
steam revenues, which are based, in part, on fuel prices. The 1997 increase was
mainly attributable to higher electric and steam revenues for several
cogeneration projects due to higher fuel gas prices. Equity in income from oil
and gas investments decreased approximately 54% in 1998 compared to 1997, and
increased approximately 52% in 1997 compared to 1996. The 1998 decrease was
primarily due to lower oil and gas prices, while the 1997 increase was due to
higher gas prices.
Operating Expenses
Total operating expenses decreased $37.8 million in 1998 compared to 1997,
and increased $104.6 million in 1997 compared to 1996. The 1998 decrease was
primarily due to lower fuel and depreciation and amortization expense. Fuel
expense decreased $15.4 million and depreciation and amortization decreased
$15.5 million in 1998. The increase in 1997 was principally due to higher fuel,
plant operations, depreciation and amortization and administrative and general
expenses. Fuel and plant operations expense increased $62.8 million,
depreciation and amortization expense increased $12.9 million and
administrative and general expenses increased $27.6 million in 1997.
The 1998 decrease in fuel expense was primarily due to the new fuel supply
agreement entered into for the Loy Yang B project in connection with our
acquisition of the remainder of that project in May 1997, partially offset by
higher fuel expense at the First Hydro projects as a result of higher prices
and increased generation in 1998. The 1997 increase in fuel expense and plant
operations was primarily due to commencement of commercial operations of the
Kwinana project in the fourth quarter of 1996 and increased generation and
higher prices at the First Hydro projects.
13
<PAGE>
The 1998 decrease in depreciation and amortization is the result of a full
year's impact of the extension in the useful life of the Loy Yang B project's
plant and equipment from approximately 30 years, the term of the previous power
purchase agreement, to 50 years, the projected economic life of the plant, as a
result of the May 1997 acquisition, combined with lower Australian currency
exchange rates. The 1997 increase in depreciation and amortization resulted
from the commencement of commercial operations of Loy Yang B Unit 2 and the
Kwinana project in the fourth quarter of 1996. The Loy Yang B project's
depreciation expense in 1997 was partially reduced due to the extension in the
useful life of its plant and equipment.
Administrative and general expenses decreased slightly in 1998 as a result
of lower compensation expense for charges related to EME's phantom stock plan,
which is part of the Edison International Equity Compensation Plan, partially
offset by higher project development costs. The 1997 increase in administrative
and general expenses was attributable to an increase of approximately $54
million in compensation expense as a result of charges related to EME's phantom
stock plan. The 1997 increase in compensation expense was partially offset by
lower project development costs.
Other Income (Expense)
Interest and other income increased $22.5 million in 1998 compared to 1997,
and $6.5 million in 1997 compared to 1996. The 1998 and 1997 increases resulted
primarily from interest earned on higher cash balances.
During the second quarter of 1997, EME completed a sale of its ownership
interest in B.C. Star Partners for total cash proceeds of $71.2 million. EME
recorded an after-tax gain of approximately $14 million on the sale in April
1997.
During the second quarter of 1996, CalEnergy Company, Inc., EME's partner in
four operating geothermal projects in California, purchased all of the stock of
four wholly-owned subsidiaries of EME, which held interests in these projects.
The purchase price of $70 million resulted in an after-tax gain of $15.5
million. There was no impact on EME's future revenues, as EME discontinued
recognizing earnings from these projects during 1993.
Interest expense decreased $27.4 million in 1998 compared to 1997, and
increased $59.2 million in 1997 compared to 1996. The decrease in 1998 was due
to lower Australian currency exchange rates and higher capitalized interest as
a result of higher accumulated construction expenditures. Capitalized interest
decreased $51.9 million in 1997 compared to 1996, due to the completion of
construction and resultant commercial operations of Loy Yang B Unit 2 and the
Kwinana project in the fourth quarter of 1996, at which time EME discontinued
recording capitalized interest related to these projects.
Minority interest expense decreased $36.1 million in 1998 compared to 1997,
and $30.7 million in 1997 compared to 1996. The decreases resulted from the
acquisition of the remaining 49% ownership interest in the Loy Yang B project
in May 1997.
Provision for Income Taxes
EME had effective tax provision rates of 34.8%, 30.9% and 47.1% in 1998,
1997 and 1996, respectively. The 1998 and 1997 tax provisions reflect a benefit
from reductions in the United Kingdom corporate tax rate from 33% to 31%
effective in April 1997, and from 31% to 30% effective in April 1999. In
accordance with Statement of Financial Accounting Standards No. 109,
"Accounting for Income Taxes," this reduction in the United Kingdom income tax
rate resulted in reductions in income tax expense of approximately $11 million
and $20 million in 1998 and 1997, respectively, to adjust the United Kingdom
deferred income tax liability (primarily related to the First Hydro projects)
to the new lower tax rate.
14
<PAGE>
Extraordinary Loss
The early repayment of the Loy Yang B project's existing debt facilities of
$713 million in connection with the Company's acquisition of the remaining 49%
interest in May 1997 resulted in an extraordinary loss of $13.1 million (net of
income tax benefit of $8.6 million) attributable to the write-off of
unamortized debt issue costs.
Liquidity and Capital Resources
Cash provided by operating activities is derived primarily from
distributions from energy projects and dividends from investments in oil and
gas.
For the three months ended March 31, 1999, net cash provided by operating
activities decreased to $59.1 million from $103.4 million for the same period
in 1998. The 1999 decrease primarily reflected higher income taxes, lower
distributions from energy projects and higher working capital requirements.
For the three months ended March 31, 1999, net cash provided by financing
activities increased to $1,708.8 million from net cash used of $2.7 million for
the same period in 1998. The 1999 increase was primarily due to the borrowing
of $800 million by Edison Mission Holdings Co., the parent company of EME Homer
City Generation L.P., the financing of $700 million by EME, and the borrowing
by EME on the EME revolving credit facility of $220 million, the proceeds of
which were all used to purchase the Homer City project. In May 1999, Edison
Mission Holdings Co. refinanced the $800 million borrowing with $300 million of
senior secured bonds due 2019 and $530 million of senior secured bonds due
2026. Also in May 1999, the Company financed the acquisition of the 40%
interest in Contact Energy with the proceeds from $224 million of EME
subsidiary debt, $120 million of EME subsidiary preferred stock, a capital
contribution from EIX of $300 million and from available cash.
For the three months ended March 31, 1999, net cash used in investing
activities increased to $1,834.1 million from $16.5 million for same period in
1998. The increase was primarily due to the purchase of the Homer City
projects.
At March 31, 1999, EME had cash and cash equivalents of $387.1 million and
had available $224 million of borrowing capacity under a $500 million revolving
credit facility that expires in 2001. This borrowing capacity under the
revolving credit facility may be reduced by borrowings to finance EME's firm
commitments to contribute equity to its subsidiaries so that they can fund
capital expenditures and construction costs of their projects.
Cash provided by operating activities is derived primarily from
distributions from energy projects and dividends from investments in oil and
gas. Net cash provided by operating activities increased $7.1 million in 1998
compared to 1997, and decreased $35 million in 1997 compared to 1996. The 1998
increase was primarily due to lower income taxes paid and higher distributions
from energy projects, partially offset by lower dividends from investments in
oil and gas and an increase in working capital requirements. The 1997 decrease
primarily reflected an increase in working capital requirements, principally
due to lower accounts receivable collections from the First Hydro projects.
Net cash provided by financing activities decreased $43.2 million in 1998
compared to 1997, and $123.7 million in 1997 compared to 1996. The decreases
were principally due to a reduction in financing activities. In 1997, the Loy
Yang B project's financing proceeds received in connection with the Company's
acquisition of the remaining 49% of that project were primarily used to repay
the project's existing debt facilities. In 1996, EME issued 400 million pounds
sterling of 9% Guaranteed Secured Bonds (U.S. $603.8 million), the proceeds of
which were used to repay the 400 million pounds sterling credit facility
entered into in December 1995. In addition, Edison Mission Energy Funding Corp.
("EME Funding Corp."), 99% owned by Broad Street Contract Services, Inc. and 1%
owned by EME, completed in December 1996 a sale of $450 million of senior notes
and bonds to institutional investors pursuant to the Rule 144A exemption under
the Securities Act for non-public sales.
15
<PAGE>
The Loy Yang B financing in 1997 consisted of (1) borrowings under a $373
million (490 million Australian dollars) 15-year interest only term facility,
(2) borrowings under a $583 million (765 million Australian dollars) 20-year
amortizing term facility with principal and interest payments scheduled
quarterly commencing September 30, 1998 and (3) borrowings under an $8 million
(10 million Australian dollars) working capital facility with a term equal to
that of the 20-year amortizing term facility. The financing was structured on a
non-recourse basis to EME. Lenders look solely to the operating cash proceeds
of the Loy Yang B project to repay the debt and have taken a security interest
in the Loy Yang B project assets.
The $450 million of securities issued by EME Funding Corp. in 1996 consist
of $260 million of Series A Notes and $190 million of Series B Bonds which
mature in September 2003 and September 2008, respectively. The Series A Notes
and Series B Bonds bear interest rates of 6.77% and 7.33%, respectively, and
were rated "BBB" by Standard & Poor's Ratings Group and "Baa1" by Moody's
Investors Service, Inc. The principal and interest payments under the notes
issued by the four EME subsidiaries are identical in terms to the Series A
Notes and Series B Bonds. The net proceeds from the sale of these securities
were loaned by EME Funding Corp. to EME and used by EME to repay borrowings
under its $500 million revolving credit facility, to retire EME's 200 million
Australian dollar credit facility, to defease other project debt and for other
general corporate purposes. The senior notes and bonds are secured by the
pledge of (1) notes issued by four EME subsidiaries that own interests in four
California cogeneration projects, (2) 99% of the capital stock of EME Funding
Corp. and (3) a guarantee issued by the four EME subsidiaries. The financing
structure was designed to pool and cross-collateralize available cash flow to
the four EME subsidiaries from the four projects, thus providing for repayment
of the senior notes and bonds with available cash flow from the four projects.
The obligations of the four EME subsidiaries are non-recourse to EME.
Net cash used in investing activities increased $311.1 million in 1998
compared to 1997, and decreased $149.2 million in 1997 compared to 1996. The
1998 increase is principally due to the investments and loans totaling $242.8
million for the purchase of EME's ownership interest in the EcoElectrica
project and lower proceeds from loan repayments. The 1997 decrease is primarily
due to an increase in proceeds received from loan repayments related to the
Brooklyn Navy Yard and Carbon II projects and fewer loans made to energy
projects. Proceeds of $71.2 million were received from the sale of EME's
ownership interest in B.C. Star Partners in 1997. The Company invested $73.4
million, $87.7 million and $119.4 million in 1998, 1997 and 1996, respectively,
in new plant and equipment principally related to the Doga project in 1998 and
1997 and Loy Yang B Unit 2 and the Kwinana project in 1996.
Firm Commitments for Pending Asset Purchases as of May 31, 1999
<TABLE>
<CAPTION>
Projects U.S. ($ in millions)
-------- --------------------
<S> <C>
ComEd(1).............................................. $5,000
PowerGen(2)........................................... $2,300
</TABLE>
- --------
(1) A wholly-owned subsidiary of EME executed an Asset Sale Agreement to
purchase the fossil-fuel generating assets of ComEd, totaling 9,621 MW,
located in the midwestern United States for approximately $5.0 billion. The
closing of the acquisition is subject to receipt of various state and
federal regulatory approvals and is expected to be completed by year-end
1999. EME plans to finance the acquisition with debt secured by the
project, EME debt, cash and capital contributions from EIX to EME.
(2) A wholly-owned subsidiary of EME entered into definitive acquisition
documentation to acquire 100% of the Ferrybridge and Fiddler's Ferry
coal-fired power plants in the United Kingdom with a total generating
capacity of 3,886 MW from PowerGen for approximately $2.3 billion. The
closing of the acquisition requires the approval of British trade
regulators and is expected to occur in the summer of 1999. EME plans to
finance the acquisition with debt secured by the project, EME debt, cash
and capital contributions from EIX to EME.
16
<PAGE>
Firm Commitments to Contribute Project Equity as of May 31, 1999
<TABLE>
<CAPTION>
Projects Local Currency U.S. ($ in millions)
-------- ------------------------ --------------------
<S> <C> <C>
ISAB(1)...................... 244 billion Italian Lira $136
Paiton(2).................... 24
EcoElectrica(3).............. 34
Tri Energy(4)................ 25
</TABLE>
- --------
(1) ISAB is a 512 MW integrated gasification combined cycle power plant under
construction near Siracusa in Sicily, Italy. A wholly-owned subsidiary of
EME owns a 49% interest. Equity will be contributed at commercial
operation, which is currently scheduled for late 1999.
(2) Paiton is a 1,230 MW two-unit coal-fired power plant under construction in
East Java, Indonesia. A wholly-owned subsidiary of EME owns a 40% interest.
An equity contribution of $7 million was made on June 2, 1999. Accordingly,
as of the date of this offering circular, the Company's firm commitment to
contribute equity to the Paiton project is $17 million. Equity
contributions will continue until commercial operation, which is currently
scheduled for the third quarter of 1999.
(3) EcoElectrica is a 540 MW liquefied natural gas combined-cycle cogeneration
facility under construction in Penuelas, Puerto Rico. A wholly-owned
subsidiary of EME owns a 50% interest. Equity will be contributed at
commercial operation, which is currently scheduled for late 1999.
(4) Tri Energy is a 700 MW gas-fired power plant under construction in the
Ratchaburi Province, Thailand. A wholly-owned subsidiary of EME owns a 25%
interest. Equity will be contributed at commercial operation, which is
currently scheduled for mid-2000.
Firm commitments to contribute project equity could be accelerated due to
certain events of default as defined in the non-recourse project financing
facilities. Management has no reason to believe that these events of default
will occur requiring acceleration of the firm commitments.
Contingent Obligations to Contribute Project Equity as of May 31, 1999
<TABLE>
<CAPTION>
Projects U.S. ($ in millions)
-------- --------------------
<S> <C>
Paiton(1)............................................. $141
Tri Energy(2)......................................... 20
Doga(2)............................................... 14
All Other............................................. 18
</TABLE>
- --------
(1) Contingent obligations to contribute additional equity ("Contingent
Equity") would be based on events principally related to capital cost
overruns during the plant's construction, certain partner obligations or
events of default. These contingent obligations are to be cancelled (if
unused) as of the date of term financing by the Export-Import Bank of the
United States. Term financing by the Export-Import Bank of the United
States is the subject of a comprehensive set of conditions and is currently
scheduled to be achieved by October 1999. A dispute involving a slope
adjacent to the Paiton site will require Contingent Equity to be
contributed for amounts not otherwise covered by insurance. EME's share of
the total costs related to the slope failure are currently estimated to be
between $16 and $44 million.
(2) Contingent obligations to contribute additional equity to the project would
be based on events principally related to capital cost overruns during the
plant's construction, certain partner obligations or events of default.
Other Commitments and Contingencies
Subsidiary Indemnification Agreements
Certain of EME's subsidiaries have entered into indemnification agreements
whereby the subsidiaries agreed to repay capacity payments to the projects'
power purchasers in the event the projects unilaterally
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terminate their performance or reduce their electric power producing capability
during the term of the power contracts. Obligations under these indemnification
agreements as of March 31, 1999, if payment were required, would be $252
million. Management has no reason to believe that the projects will either
terminate their performance or reduce their electric power producing capability
during the term of the power contracts.
Contact Energy
In May 1999, a wholly-owned subsidiary of EME issued $120 million of
preferred stock in connection with the acquisition of a 40% interest in Contact
Energy. EME entered into a support agreement with its subsidiary that requires
EME to make capital contributions to the subsidiary in order for it to maintain
a positive net worth and to provide sufficient funds for payment of declared
dividends on preferred stock and any redemption price in respect of the
preferred stock. EME's maximum obligation under the support agreement is
limited to either (A) an amount equal to twice the sum of (1) the liquidation
preference of the preferred stock (currently approximately $240 million) and
(2) the liquidation preference of all outstanding shares of stock of the
subsidiary ranking on a parity with the preferred stock (currently zero) or (B)
the amount that EME could lawfully distribute to its shareholder under the
Corporation Code of the State of California (approximately $278 million as of
March 31, 1999).
Brooklyn Navy Yard
Brooklyn Navy Yard is a 286 MW gas-fired cogeneration power plant in
Brooklyn, New York. A wholly-owned subsidiary of EME owns 50% of the project.
In February 1997, the construction contractor asserted general monetary claims
under the turnkey agreement against Brooklyn Navy Yard Cogeneration Partners,
L.P. ("BNY") for damages in the amount of $136.8 million. BNY has asserted
general monetary claims against the contractor. In connection with a $407
million non-recourse project refinancing in 1997, EME agreed to indemnify BNY
and its partner from all claims and costs arising from or in connection with
the contractor litigation, which indemnity has been assigned to BNY's lenders.
EME believes that the outcome of this litigation will not have a material
adverse effect on its consolidated financial position or results of operations.
Homer City
EME has guaranteed to the bondholders, banks and other secured parties which
financed the Company's acquisition of the Homer City project the performance
and payment when due by Edison Mission Holdings Co. of its obligations in
respect of specified senior debt, up to approximately $40 million. This
guarantee will be available until December 31, 2001.
Other
In support of the businesses of its subsidiaries, EME, from time to time,
has made guarantees and has entered into indemnity agreements with respect to
its subsidiaries' obligations (such as those for debt service, fuel supply or
the delivery of power) and has entered into reimbursement agreements with
respect to letters of credit issued to third parties to support its
subsidiaries' obligations.
EME may incur additional guaranty, indemnification and reimbursement
obligations as well as obligations to make equity and other contributions to
projects in the future. EME believes that it will have sufficient liquidity on
both a short and long-term basis to fund pre-financing project development
costs, make equity contributions to project subsidiaries, pay debt obligations
of EME and pay other administrative and general expenses as they are incurred
from (1) distributions from energy projects and dividends from investments in
oil and gas, (2) proceeds from the repayment of loans made by EME to its
project subsidiaries and (3) funds available from EME's revolving credit
facility.
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Managing Interest Rates, Electricity Market Pricing, Foreign Currency
Fluctuations and Other Contractual Obligations
Changes in interest rates, changes in electricity pool pricing and
fluctuations in foreign currency exchange rates can have a significant impact
on the Company's results of operations. Interest rate changes affect the cost
of capital needed to finance the construction and operation of the Company's
projects. The Company has mitigated the risk of interest rate fluctuations by
arranging for fixed rate financing or variable rate financing with interest
rate swaps or other hedging mechanisms for the majority of its project
financings. Interest expense included $6.2 million and $6.1 million for the
three months ended March 31, 1999 and 1998, respectively, as a result of
interest rate swap and collar agreements. The Company has entered into several
interest rate swap agreements whereby the maturity date of the swaps occurs
prior to the final maturity of the underlying debt. EME does not believe that
interest rate fluctuations will have a materially adverse effect on its
financial position or results of operations.
The Company's electric revenues increased by $22.1 million and $50.7 million
for the three-month periods ended March 31, 1999, and 1998, respectively, as a
result of electricity rate swap agreements. An electricity rate swap agreement
is an exchange of a fixed price of electricity for a floating price. As a
seller of power, the Company receives the fixed price in exchange for a
floating price, such as the index price associated with electricity pools. In
the United Kingdom, these forward sales are also called electricity forward
agreements or contracts for differences.
Electric power generated at the Company's uncontracted plants is generally
sold under bilateral arrangements with utilities and power marketers under
short-term contracts (two years or less) or, in the case of the Homer City
project, to the PJM or the NYPP. The Company has developed risk management
policies and procedures which, among other matters, address credit risk. When
making sales under negotiated bilateral contracts, it is the Company's policy
to deal with investment grade counterparties. The Company hedges a portion of
the electric output of its merchant plants in order to lock-in desirable
outcomes. It manages the "spark spread" or margin, which is the spread between
electric prices and fuel prices, when deemed appropriate, and uses forward
contracts, swaps, futures, or options contracts to achieve those objectives.
For a detailed description of market risk in connection with the Homer City
project, the United Kingdom projects and the Loy Yang B project and how such
risk is mitigated, see "Business--Project Development--Sales of Power from
Merchant Plants."
Fluctuations in foreign currency exchange rates can affect, on a U.S. dollar
equivalent basis, the amount of the Company's equity contributions to, and
distributions from, its international projects. As the Company continues to
expand into foreign markets, fluctuations in foreign currency exchange rates
can be expected to have a greater impact on the Company's results of operations
in the future. At times, the Company has hedged a portion of its current
exposure to fluctuations in foreign exchange rates through financial
derivatives, offsetting obligations denominated in foreign currencies, and
indexing underlying project agreements to U.S. dollars or other indices
reasonably expected to correlate with foreign exchange movements. In addition,
the Company has used statistical forecasting techniques to help assess foreign
exchange risk and the probabilities of various outcomes. Foreign exchange
considerations for two major international projects are discussed below.
The First Hydro projects in the United Kingdom and the Loy Yang B project in
Australia have been financed in their local currency (pounds sterling and
Australian dollars, respectively), thereby hedging the majority of their
acquisition costs against foreign exchange fluctuations. Furthermore, the
Company has evaluated the return on the remaining equity portion of these
investments with regard to the likelihood of various foreign exchange
scenarios. These analyses use market derived volatilities, statistical
correlations between certain variables, and long-term forecasts to predict
ranges of expected returns. Based upon these analyses, management believes that
the investment returns for the First Hydro and Loy Yang B projects are
adequately insulated from a broad range of foreign exchange scenarios at this
time. In 1996, the Company repaid a 200 million Australian dollar loan that was
originally structured to hedge a portion of the foreign
19
<PAGE>
exchange risk associated with the Company's equity investment in the Loy Yang B
project. The decision to repay the loan was based on management's view that the
cost of the hedge was high relative to the current and expected volatility of
the Australian dollar.
The Company will continue to monitor its foreign exchange exposure and
analyze the effectiveness and efficiency of hedging strategies in the future.
The electric power generated by certain of the Company's operating projects
is sold to electric utilities pursuant to long-term power purchase agreements
and is expected to result in consistent cash flow under a wide range of
economic and operating circumstances. To accomplish this, the Company
structures its long-term contracts so that fluctuations in fuel costs will
produce similar fluctuations in electric and/or steam revenues and enters into
long-term fuel supply and transportation agreements.
Environmental Matters and Regulations
The Company is subject to environmental regulation by federal, state and
local authorities in the United States and foreign regulatory authorities with
jurisdiction over projects located outside the United States. The Company
believes that, as of the date of this offering circular, it is in substantial
compliance with environmental regulatory requirements and that maintaining
compliance with current requirements will not materially affect its financial
position or results of operations.
Management expects that the implementation of Clean Air Act Amendments will
result in increased capital expenditures and operating expenses. For example,
the Company plans to spend approximately $246 million to install upgrades to
the environmental controls at the Homer City project in 2000 and 2001 to
control sulfur dioxide and nitrogen oxide emissions. Similarly, the Company
plans to upgrade the environmental controls at the former ComEd plants to
control nitrogen oxide emissions. The Company does not expect these increased
capital expenditures and operating expenses to have a material effect of the
Company's financial position or results of operations.
Year 2000 Issues
The Company has a comprehensive program in place to remediate potential year
2000 impacts from critical systems. The Company divides its year 2000 issue
activities into five phases: inventory, impact assessment, remediation,
documentation and certification. The Company plans to complete critical systems
by July 1999. A critical system is defined as those applications and systems,
including embedded processor technology, which, if not appropriately
remediated, may have a significant impact on customers, the revenue stream,
regulatory compliance, or the health and safety of personnel. The Company has
essentially completed all phases of its year 2000 project and is going through
the final review and approval process.
The Company's costs of remediation through March 31, 1999 have been
approximately $2 million, and it estimates that the remaining costs of
remediation will be approximately $2 million. Most of these expenses have
related to, and are expected to continue to relate to, the operating costs
associated with time spent by the Company's employees and a systems testing
facility for year 2000 compliance. These estimates do not include the costs of
systems, software and equipment that the Company is obtaining, replacing or
upgrading in the normal course of business.
Assurances from third party operated plants have been received indicating
aggressive year 2000 remediation programs. Monitoring of these efforts is
ongoing. Plants under construction have obtained assurances from new
construction and development contractors, who have been requested to ensure
this is part of their goals. General warranty of plants would likely include
any equipment issues that may arise regarding the year 2000 issue in the
current year.
The other essential component of the Company's year 2000 readiness program
is to identify and assess vendor products and business partners for year 2000
readiness. The Company has a process in place to identify and contact vendors
and business partners to determine their year 2000 status, and is evaluating
the responses.
20
<PAGE>
The Company's general policy requires that all newly purchased products be year
2000 ready or otherwise designed to allow the Company to determine whether such
products present year 2000 issues.
Plant contingency plans have been developed and reviewed for any significant
issues and to schedule appropriate testing and/or training. Such contingency
plans include developing strategies for dealing with year 2000-related
processing failures or malfunctions due to the Company's internal systems or
those of third parties. The Company's contingency plans evaluate reasonably
likely worst case scenarios or conditions. The Company does not expect the year
2000 issue to have a material adverse effect on its results of operations or
financial position. However, if not effectively remediated, negative effects
from year 2000 issues, including those related to external systems, vendors,
business partners, independent system operators, power exchanges or customers,
could cause the Company's results of operations to differ from those expected.
Statement of Financial Accounting Standards No. 133
In June 1998, the Financial Accounting Standards Board issued Statement of
Financial Accounting Standards No. 133, "Accounting for Derivative Instruments
and Hedging Activities", which will be effective in January 2001. The Statement
establishes accounting and reporting standards requiring that every derivative
instrument be recorded in the balance sheet as either an asset or liability
measured at its fair value. The Statement requires that changes in the
derivative's fair value be recognized currently in earnings unless specific
hedge accounting criteria are met. A derivative's gains and losses for
qualifying hedges offset related results on the hedged item in the income
statement and a company must formally document, designate and assess the
effectiveness of transactions that receive hedge accounting. The impact of
adopting Statement 133 on the Company's financial statements has not been
quantified at this time.
21
<PAGE>
BUSINESS
Overview
The Company is a leading independent power producer engaged in the business
of developing, acquiring, owning and operating electric power generation
facilities worldwide. EIX owns the Company and also owns SCE, one of the
largest electric utilities in the United States. At March 31, 1999, the Company
had consolidated assets of approximately $7 billion and total shareholder's
equity of approximately $1 billion.
EME was formed in 1986 with two domestic operating projects. The Company's
business has evolved from the development of contract-based domestic power
projects to the development of contract-based international power projects and
the acquisition of operating generating assets within developed and
deregulating power markets. Currently, the Company owns interests in 58
domestic and international operating power stations with an aggregate
generating capacity of 11,826 MW, of which the Company's share is 8,002 MW. One
domestic acquisition of twelve operating projects and one international
acquisition of two operating projects, totaling 13,507 MW of generating
capacity (of which the Company's share is 100%), are currently pending. In
addition, the Company owns interests in one domestic and six international
projects that are under construction. The capacity of these projects is
expected to total 3,705 MW, of which the Company's anticipated share will be
approximately 1,383 MW.
Strategic Overview
The Company's business goal is to be one of the leading owners and operators
of electric generating assets in the world. The Company plays an active role,
as a long-term owner, in all phases of power generation, from planning and
development through construction and commercial operation. The Company believes
that such involvement allows it to better ensure, with its experienced
personnel, that its projects are well-planned, structured and managed, thereby
maximizing value creation. The Company has separate strategies for developed
and developing countries.
In developed countries, we expect that new long-term contracts are likely to
be the exception rather than the rule. The Company's strategy focuses primarily
on three areas with respect to plants whose output is not committed to be sold
pursuant to long term contracts (which are known as "merchant plants"):
valuation, power marketing and trading, and regulation. First, the Company
continuously improves its valuation tools, enabling it to bid more effectively
and competitively on assets that will be sold over the next five years in the
United States, the United Kingdom, Spain, Italy, Australia, New Zealand and
other developed countries. Second, the Company draws on its power marketing and
trading skills to mitigate price risks and to enhance the returns of its
merchant plants. Third, since the Company's principal customers continue to be
regulated utilities, the Company strives to understand the regulatory and
economic environment in which these utilities operate so it may better
anticipate and prepare for what they will do.
In developing countries, the Company's strategy focuses on investing with
good partners, securing non-recourse financing based upon long-term contracts
with state-owned utilities, and securing government support from organizations
such as such as the Export-Import Bank of the United States, the U.S. Overseas
Private Investment Corporation and The Export-Import Bank of Japan.
In making investment decisions, the Company evaluates potential project
returns against rate of return guidelines. It establishes these guidelines by
identifying a base rate of return and adjusting the base rate by potential risk
factors, such as risks associated with project location and stage of project
development. The Company endeavors to mitigate such risks by:
. evaluating all projects and the markets in which they operate;
. selecting partners with complementary skills and local experience;
. structuring investments through subsidiaries;
. managing up-front development costs;
. utilizing limited recourse financing; and
. linking revenue and expense components where appropriate.
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Many of the Company's projects are operated by its subsidiaries, which helps
the Company to preserve and enhance the value of its investments.
In response to the increasing globalization of the independent power market,
the Company has organized its operation and development activities into three
geographic regions: (1) Americas, (2) Asia Pacific and (3) Europe, Central
Asia, Middle East and Africa. Each region is served by one or more teams
consisting of business development, operations, finance and legal personnel,
and each team is responsible for all the Company's activities within a
particular geographic region. Also, the Company will mobilize personnel from
outside a particular region when needed in order to assist in the development
of certain projects.
Set forth below is a brief discussion of the current strategy for each of
the three regions and a summary of certain of the Company's projects that are
currently in the construction, advanced development or early operations stage
and other significant operating projects in each of the regions.
Americas
The Company's Americas region is headquartered in Irvine, California, with
additional offices located in Fairfax, Virginia and Washington, D.C. The
strategy for the Americas region is (1) to manage the Company's interest in
operating and construction-phase projects located throughout the United States,
(2) to pursue the acquisition and development of existing generating assets
from utilities, industrial companies and other independent power producers
("IPPs") throughout the region and (3) to pursue the development of new power
projects throughout the region. The Company currently has 24 operating projects
in this region, all of which are located in the United States.
In December 1998, the Company acquired 50% of the 540 MW EcoElectrica LNG-
fired combined-cycle cogeneration facility under construction in Penuelas,
Puerto Rico for approximately $243 million. The project also includes a
desalination plant and LNG storage and vaporization facilities, and is expected
to commence commercial operation by late 1999.
In March 1999, the Company acquired 100% of the 1,884 MW Homer City
Generating Station for approximately $1.8 billion. EME financed the acquisition
with a combination of debt secured by the project, EME debt, cash and
borrowings under EME's revolving credit facility. The Homer City project is one
of the largest coal-fired plants in the mid-Atlantic region of the United
States and has direct, high voltage interconnections to both the NYPP and the
PJM.
In March 1999, the Company entered into definitive acquisition documentation
to acquire the fossil-fuel generating assets of ComEd, totaling 9,621 MW of
generating capacity, for approximately $5.0 billion. The Company will operate
the plants, which will provide it access to MAIN and ECAR. The closing of this
acquisition is subject to various state and federal regulatory approvals and is
expected to be completed by year-end 1999.
For additional information regarding the Company's 24 domestic operating
projects, see "--The Company's Operating Power Generation Facilities--
Domestic."
Asia Pacific
The Company's Asia Pacific region is headquartered in Singapore with
additional offices located in Australia, Indonesia and the Philippines. The
strategy for this region is (1) to pursue projects in countries where there
exist strong political commitment and the structural framework necessary for
private power, (2) to seek opportunities to employ indigenous fuels and (3) to
seek strategic, complementary alliances with partners who bring value to a
project by providing fuel, equipment and construction services.
Beginning in mid-1997, several of the developing economies in Asia
experienced an economic downturn that is continuing, and has resulted in an
overall decline in the growth of demand for electric power, and, in
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some countries, a decline in electric power usage. Many governments in the
region have committed to privatization of the electric power industry, and are
looking to the private sector to develop a significant portion of new
generating capacity and to purchase existing generating assets.
The Company's activity in the Asia Pacific region commenced in December 1992
with the acquisition of a 51% interest of Loy Yang B from the State Government
of Victoria, Australia's first electric privatization effort. In May 1997, the
Company acquired the State's remaining 49% interest in the Loy Yang B project.
The first of two 500 MW units at the Loy Yang B project began commercial
operations in October 1993. Loy Yang B Unit 2 commenced commercial operation in
October 1996. An EME affiliate provides operation and maintenance services for
both units.
In April 1995, the Company and its partners, Mitsui & Co. Ltd., General
Electric Corporation and P.T. Batu Hitam Perkasa, an Indonesian limited
liability company, commenced construction of the $2.5 billion Paiton project, a
1,230 MW coal-fired power plant in East Java, Indonesia. The project will
consist of two units, each of which is expected to have a capacity of 615 MW.
In January 1996, the Company purchased an additional 7.5% interest in the
Paiton project from a subsidiary of General Electric Corporation, thereby
increasing its ownership interest to 40%.
Construction on the two-unit Paiton project is nearing completion, with
commercial operation expected to begin in 1999. The project's output is fully
contracted with the state-owned electricity company, PLN. Payments are in
Indonesian Rupiah, with the portion of such payments intended to cover non-
Rupiah project costs (including returns to investors) indexed to the Indonesian
Rupiah/U.S. dollar exchange rate established at the time the power purchase
agreement was executed in February 1994. PLN's payment obligations are
supported by the Government of Indonesia. The exchange rate of Indonesian
Rupiah into U.S. dollars and the projected rate of growth of the Indonesian
economy have deteriorated significantly since the Paiton project was
contracted, approved and financed, thereby significantly increasing the cost of
power in Rupiah terms to PLN. The project received substantial finance and
insurance support from the Export-Import Bank of the United States, The Export-
Import Bank of Japan, the U.S. Overseas Private Investment Corporation and the
Ministry of International Trade and Industry of Japan. The Paiton project's
senior debt ratings have been reduced from investment grade to speculative
grade based on the rating agencies' perceived increased risk that PLN might not
be able to honor its power purchase agreement with Paiton. PLN has announced
its intentions to commence discussions with IPPs to renegotiate its power
purchase agreement; however, it is not yet known what form the negotiation may
take. Any material modifications of the Paiton project's power purchase
agreement with PLN could also require a renegotiation of the Paiton project's
debt agreements. The impact of any such renegotiation with PLN, the Government
of Indonesia or the project's creditors on the Company's dividends from the
project is uncertain at this time; however, the Company believes that it will
ultimately recover its investment in the project.
In September 1997, the San Pascual project, a consortium including the
Company (37.5% ownership), Texaco Inc. (37.5% ownership) and Caltex (25%
ownership), signed a twenty-five year power purchase agreement with the
National Power Corporation ("NPC"), the Philippines' state-owned electric
utility company, pursuant to which NPC will purchase 304 MW of output from the
San Pascual project. The low-sulfur residual fuel oil cogeneration project is
located in the Philippines. Financial closing and commencement of construction
are anticipated in the second quarter of 2000, with commercial operation
expected to begin in 2003.
In December 1997, the Bo Nok project, of which the Company owns 40%, signed
a twenty-five year power purchase contract with the Electricity Generating
Authority of Thailand ("EGAT"), pursuant to which EGAT will purchase 734 MW of
output from the coal-fired power generation project at Bo Nok in Thailand.
Financial closing and commencement of construction are anticipated in late
1999, with commercial operation expected to begin in 2002.
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In July 1998, the Company purchased a 25% interest in the Tri Energy
project, a 700 MW gas-fired power plant under construction in the Ratchaburi
Province, Thailand. The project will sell its capacity and energy to EGAT
pursuant to a 20-year power purchase agreement. Commercial operation is
expected to begin in mid-2000.
In May 1999, the Company acquired 40% of Contact Energy from the government
of New Zealand for $674 million. Contact Energy owns and operates eight
hydroelectric, geothermal and natural gas-fired power generating plants in New
Zealand and owns an interest in one operating hydroelectric plant in Australia,
with a total aggregate capacity of 2,409 MW, of which the Company's share is
825 MW. Contact Energy also owns interests in three projects under construction
with an expected total generating capacity of 723 MW, of which the Company's
share is 195 MW; two of these projects are in New Zealand and one is in
Australia. Contact Energy also distributes gas and electricity to customers in
New Zealand.
Europe, Central Asia, Middle East and Africa
The Company's Europe, Central Asia, Middle East and Africa region is
headquartered in London, England with additional offices located in Italy,
Spain and Turkey. The London office was established in 1989. The territorial
scope of the region includes Europe, Africa, the Middle East, India and
Pakistan. The region is characterized by both mature and developing markets.
The Company's strategy for the region is to pursue the development and
acquisition of medium to large scale power and cogeneration facilities with
diversified fuel sources and generation technology.
The Company's operating projects in the region are the First Hydro projects
located in North Wales, the Roosecote project located in northwest England, the
Derwent project located in Derby, England and the Iberian Hy-Power projects
(which consist of 18 small, hydroelectric facilities) located in Spain.
In December 1995, the Company purchased all of the outstanding shares of
First Hydro Company ("First Hydro") for approximately $1 billion (653 million
pounds sterling). First Hydro's principal assets are two pumped-storage
electric power stations located in North Wales at Dinorwig and Ffestiniog,
which have a combined capacity of 2,088 MW. The Dinorwig station, which was
commissioned in 1983, is comprised of six units totaling 1,728 MW. The
Ffestiniog station was commissioned in 1963 and is comprised of four units
totaling 360 MW. First Hydro is an independent generating company with three
main sources of revenues: (1) selling power into the electricity trading market
or "pool" in England and Wales; (2) providing system support services to The
National Grid Company plc; and (3) selling its installed capacity on a forward
basis by entering into "contracts for differences" (electricity rate swap
agreements) with large electricity suppliers.
In June 1995, the ISAB project, of which the Company owns 49%, signed a
twenty-year power purchase contract with ENEL S.p.A., Italy's state electricity
corporation, pursuant to which ENEL S.p.A. will purchase 507 MW of output from
the 512 MW ISAB power project, which is located near Siracusa in Sicily, Italy.
The project will employ gasification technology to convert heavy oil residues
from the ISAB refinery in Priolo Gargallo into clean-burning syngas that will
be used to generate electricity in a combustion turbine. The approximately 2
trillion lira ($1.3 billion) project financing was completed in April 1996,
with construction commencing in July 1996. The project is near completion, with
commercial operation expected to begin in late 1999.
In February 1995, the Company signed a shareholders' agreement to develop
the $180 million Doga Enerji A.S. project in Esenyurt, near Istanbul, Turkey.
In April 1997, the Company completed financing and commenced construction of
the Doga project. The 180 MW combined cycle gas-fired cogeneration facility
commenced commercial operation in May 1999.
In April 1999, the Company entered into definitive acquisition documentation
to acquire 100% of the Ferrybridge and Fiddler's Ferry coal-fired power plants
in the United Kingdom with a total generating capacity of 3,886 MW from
PowerGen for approximately $2.3 billion. These mid-merit plants will complement
the pumped-storage hydroelectric power plants the Company already owns in the
United Kingdom and will sell power into the electricity trading market there.
The closing of this acquisition requires the approval of British trade
regulators and is expected to occur in the summer of 1999.
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Project Development
The development of power generation projects, whether through new
construction or the acquisition of existing assets, involves numerous elements,
including evaluating and selecting development opportunities, evaluating
regulatory and market risks, designing and engineering the project, acquiring
necessary land rights, permits and fuel resources, obtaining financing,
managing construction and, in some cases, obtaining power and steam sales
agreements.
The Company initially evaluates and selects potential development projects
based on a variety of factors, including the reliability of technology, the
strength of the potential partners, the feasibility of the project, the
likelihood of obtaining a long-term power purchase agreement or profitably
selling power without such an agreement, the probability of obtaining required
licenses and permits and the projected economic return. During the development
process, the Company monitors the viability of its projects and makes business
judgments concerning expenditures for both internal and external development
costs. Completion of the financing arrangements for a project is generally an
indication that business development activities are substantially complete.
Project Type
The selection of power generation technology for a particular project is
influenced by various factors, including regulatory requirements, availability
of fuel and anticipated economic advantages of a particular application.
The Company has interests in operating projects that employ gas-fired
combustion turbine technology, predominantly through an application known as
"cogeneration". Cogeneration facilities sequentially produce two or more useful
forms of energy (e.g., electricity and steam) from a single primary source of
fuel (e.g., natural gas or coal). Many of the Company's cogeneration projects
are located near large, industrial steam users or in oil fields that inject
steam underground to enhance recovery of heavy oil. The regulatory advantages
for cogeneration facilities under the Public Utility Regulatory Policies Act of
1978, as amended ("PURPA"), have become somewhat less significant because of
other federal regulatory exemptions made available to IPPs under the Energy
Policy Act. Accordingly, the Company expects that the majority of its future
projects will generate power without selling steam to industrial users.
The Company also has interests in projects that use renewable resources such
as hydroelectric energy. The Company's hydroelectric projects, excluding First
Hydro's projects, use "run-of-the-river" technology to generate electricity.
The First Hydro project utilizes pumped-storage stations that consume
electricity when it is comparatively less expensive in order to pump water for
storage in an upper reservoir. Water is then allowed to flow back through
turbines in order to generate electricity when its market value is higher. This
type of generation is characterized by its speed of response, its ability to
work efficiently at wide variations of load and the basic reliance of revenue
on the difference between the peak and trough prices of electricity during the
day.
The Company also has domestic and international interests in operating
projects and projects under construction and advanced development, which are
large-scale, coal-fired projects using pulverized coal and coal-fired
generation technology. In the United States, the Company has developed and
acquired coal and waste coal-fired projects that employ traditional pulverized
coal and circulating fluidized bed technology.
Long-Term Power and Steam Sales Contracts
Many of the Company's operating projects in the United States sell power and
steam to domestic electric utilities and industrial steam users pursuant to
long-term contracts. Electric power generated by several of the Company's
international projects is sold under long-term contracts to electric utilities
located in the country where the power project is located. These projects'
revenues from power purchase agreements usually consist of two components:
energy payments and capacity payments. Energy payments are made based on actual
deliveries of electric energy (e.g., kilowatt-hours) to the purchaser. Energy
payments are usually indexed to certain variable costs that the purchaser
avoids by purchasing such electric energy from the Company's projects as
opposed to operating its own power plants to produce the same amount of
electric energy. The variable
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<PAGE>
components typically include fuel costs and certain operation and maintenance
expenses. These costs may be indexed to the utility's cost of fuel and/or
certain inflation indices. Capacity payments are based on a project's proven
capability reliably to make electric capacity available, whether or not the
project is called on to deliver electric energy. Capacity payments compensate a
project for certain fixed costs that are incurred independent of the amount of
energy sold by the project. Such fixed costs include taxes, debt service and
distributions to the project's owners. To receive capacity payments, there are
typically minimum performance standards that must be met, and often there is a
performance range that further influences the amount of capacity payments.
Steam produced from the Company's cogeneration facilities is sold to
industrial steam users, such as petroleum refineries or companies involved in
the enhanced recovery of oil through steam flooding of oil fields, under long-
term steam sales contracts. Steam payments are generally based on formulas that
reflect the cost of water, fuel and capital to the Company. In some cases, the
Company has provided steam purchasers with discounts from their previous costs
for producing such steam and/or has partially indexed steam payments to other
indices, including certain oil prices.
Sales of Power from Merchant Plants
Over the past two years, EME has shifted its primary focus to the
acquisition and operation of competitive generation, both domestically and
internationally. EME identifies high-quality generating assets that are
strategic to deregulated power markets. EME has recently acquired, or has under
contract for acquisition, a number of merchant plants, which sell capacity,
energy and, in some cases, other services on a competitive basis under
bilateral arrangements or through centralized power pools that provide an
institutional framework for price setting, dispatch and settlement procedures.
Electric power generated at the Homer City project is sold under bilateral
arrangements with domestic utilities and power marketers under short-term
contracts (two years or less), or to the PJM or the NYPP. These pools have
short-term markets, which establish an hourly clearing price. The Homer City
project is situated in the PJM Control Area and is physically connected to
high-voltage transmission lines serving both the PJM and NYPP markets. The
Homer City project can also transmit power to the midwestern United States.
The Company's projects in the United Kingdom sell their electrical energy
and capacity through a centralized electricity pool, which establishes a half-
hourly clearing price (also referred to as the "pool price") for electrical
energy. The pool price is extremely volatile and can vary by as much as a
factor of ten or more over the course of a few hours, due to the large
differentials in demand according to the time of day. First Hydro mitigates a
significant portion of the market risk of the pool by entering into "contracts
for differences" (electricity rate swap agreements), related to either the
selling or purchasing price of power, whereby a contract specifies a price at
which the electricity will be traded, and the parties to the agreement make
payments calculated based on the difference between the price in the contract
and the pool price for the element of power under contract. These contracts are
sold in various structures and act to stabilize revenues or purchasing costs by
removing an element of the First Hydro projects' net exposure to pool price
volatility.
The Loy Yang B project sells its electrical energy through a centralized
electricity pool, which provides for a system of generator bidding, central
dispatch and a settlements system based on a clearing market for each half-hour
of every day. The Victorian Power Exchange, operator and administrator of the
pool, determines a system marginal price each half-hour. To mitigate exposure
to price volatility of the electricity traded into the pool, the Loy Yang B
project has entered into a number of financial hedges. From May 8, 1997 to
December 31, 2000, approximately 53% to 64% of the plant output sold is hedged
under "Vesting Contracts" with the remainder of the plant capacity hedged under
the "State Hedge" described below. Vesting Contracts were put into place by the
State of Victoria, between each generator and each distributor, prior to the
privatization of electric power distributors, in order to provide more
predictable pricing for those electricity customers that were unable to choose
their electricity retailer. Vesting Contracts set base strike prices at which
the electricity will be traded, and the parties to the Vesting Contracts make
payments, calculated based on the difference between the price in the contract
and the half-hourly pool clearing price for the element of power under
contract. Vesting
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<PAGE>
Contracts are sold in various structures and are accounted for as electricity
rate swap agreements. The State Hedge is a long-term contractual arrangement
based upon a fixed price commencing May 8, 1997 and terminating October 31,
2016. The State of Victoria guarantees the State Electricity Commission of
Victoria's obligations under the State Hedge.
Power Marketing and Trading Activities
When making sales under negotiated bilateral contracts, it is the Company's
policy to deal with investment grade counterparties. The Company hedges a
portion of the electric output of its merchant plants in order to stabilize and
enhance the operating revenues from merchant plants. It manages the "spark
spread" or margin, which is the spread between electric prices and fuel prices,
when deemed appropriate, and uses forward contracts, swaps, futures, or options
contracts to achieve those objectives.
The Company's power marketing and trading organization is divided into
front-, middle- and back-office segments, with certain duties segregated for
control purposes. The risk management personnel have a high level of knowledge
of utility operations, fuel procurement, energy marketing and futures and
options trading. The Company has systems in place which monitor real-time spot
and forward pricing and perform option valuations. It also has a wholesale
power scheduling group that operates on a 24-hour basis.
Fuel Supply Contracts
The Company seeks to enter into long-term contracts to mitigate the risks of
fluctuations in prices for coal, oil, gas and fuel transportation. The Company
believes, however, that its financial condition will not be substantially
adversely affected by such fluctuations because its long-term contracts to sell
power and steam typically are structured so that fluctuations in fuel costs
will produce similar fluctuations in electric energy and/or steam revenues. The
degree of linkage between such revenues and expenses varies from project to
project, but generally permits the projects to operate profitably under a wide
array of potential price fluctuation scenarios.
Project Financing
Each project developed by the Company requires a substantial capital
investment. The permanent project financing is often arranged immediately prior
to the construction of the project. With limited exceptions, such debt
financing is for approximately 50 to 80% of each project's costs and is
structured on a basis that is non-recourse to EME and its other projects. In
addition, the collateral security for each project's financing generally has
been limited to the physical assets, contracts and cash flow of that project
and the Company's ownership interests in that project.
In general, each of EME's direct or indirect subsidiaries is organized as a
legal entity separate and apart from EME and its other subsidiaries. Any asset
of any such subsidiary may not be available to satisfy the obligations of EME
or any of its other subsidiaries. However, unrestricted cash or other assets
that are available for distribution by an EME subsidiary may, subject to
applicable law and the terms of financing arrangements of such subsidiaries, be
advanced, loaned, paid as dividends or otherwise distributed or contributed to
EME.
The ability to arrange project financing and the cost of such financing are
dependent upon numerous factors, including general economic and capital market
conditions, the credit attributes of a project, conditions in energy markets,
regulatory developments, credit availability from banks or other lenders,
investor confidence in the industry, the Company and other project
participants, the continued success of the Company's other projects, and
provisions of tax and securities laws that are conducive to raising capital.
The Company has developed extensive project and corporate financing expertise
in the relevant markets of execution and seeks to mitigate financing risks by
developing flexible financing plans that allow for access to a number of
alternate markets.
The Company's financial exposure in any project is generally limited by
contractual arrangement to its equity commitment, which is usually about 20 to
50% of the Company's share of the aggregate project cost. In certain cases, the
Company provides additional credit support to projects in the form of debt
service reserves,
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<PAGE>
contingent equity commitments, revenue shortfall support or other arrangements
designed to provide limited support.
Permits and Approvals
Because the process for obtaining initial environmental, siting and other
governmental permits and approvals is complicated and lengthy (often taking a
year or longer), the Company seeks to obtain all permits, licenses and other
approvals required for the construction and operation of a project, including
siting, construction and environmental permits, rights-of-way and planning
approvals, early in the development process for a project. See "--Certain
Regulatory Matters--General."
Construction, Operations & Maintenance and Management
In the project implementation stage, the Company often provides construction
management, start-up and testing services. The detailed engineering and
construction of the projects typically are performed by outside contractors
under fixed-price, "turnkey" contracts. Under such contracts, the contractor
generally is required to pay liquidated damages to the Company in the event of
cost overruns, schedule delays or the project's failure to meet certain
capacity, efficiency and emission standards.
As a project goes into operation, operation and maintenance services are
provided to the project by one of the Company's operation and maintenance
subsidiaries or another operation and maintenance contractor. The projects that
the Company operated in 1998 achieved an average 97% availability. Availability
is a measure of the weighted average number of hours each generator is
available for generation as a percentage of the total number of hours in a
year.
An executive director generally manages the day-to-day administration of
each project. Management committees comprised of a project's partners generally
meet monthly or quarterly to review and manage the operating performance of the
project.
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<PAGE>
The Company's Operating Power Generation Facilities
Domestic
As set forth in the table below, the Company currently owns interests in 24
domestic operating projects in nine states. These operating projects consist of
13 natural gas-fired cogeneration projects, one coal-fired cogeneration
project, one coal-fired "eligible facility" project, one waste coal project,
two geothermal projects and six gas-fired "eligible facility" projects. All of
the Company's domestic cogeneration and geothermal projects, as well as the
waste coal project, are QFs under PURPA. The Company's domestic operating
projects have a total generating capacity of 5,513 MW, of which the Company's
net ownership share is 3,499 MW.
<TABLE>
<CAPTION>
Electric Operation/
Capacity Primary Electric Type of Ownership Acquisition
Project Location (in MW) Purchaser(3) Facility(4) Interest Date
------- ------------------------- -------- ---------------- ---------------- --------- -----------
<S> <C> <C> <C> <C> <C> <C>
Aidlin(1) Cloverdale, California 20 PG&E Geothermal 5% 1990
American Bituminous(2) Grant Town, West Virginia 80 MPC Waste Coal 50% 1993
Auburndale(2) Polk County, Florida 150 FPC Cogeneration/EWG 50% 1994
Bayonne Bayonne, New Jersey 165 JCP&L/PSE&G Cogeneration 0.38% 1989
Brooklyn Navy Yard Brooklyn, New York 286 CE Cogeneration/EWG 50% 1996
Coalinga(2) Coalinga, California 38 PG&E Cogeneration 50% 1991
Commonwealth Atlantic Chesapeake, Virginia 340 VEPCO EWG 50% 1992
Gordonsville(2) Gordonsville, Virginia 240 VEPCO Cogeneration/EWG 50% 1994
Harbor(2) Wilmington, California 80 Pool EWG 30% 1989
Homer City(2) Homer City, Pennsylvania 1,884 Pool EWG 100% 1999
Hopewell Hopewell, Virginia 356 VEPCO Cogeneration 25% 1990
James River Hopewell, Virginia 110 VEPCO Cogeneration 50% 1987
Kern River(2) Oildale, California 300 SCE Cogeneration 50% 1985
March Point 1 Anacortes, Washington 80 PSE Cogeneration 50% 1991
March Point 2 Anacortes, Washington 60 PSE Cogeneration 50% 1993
Mid-Set(2) Fellows, California 38 PG&E Cogeneration 50% 1989
Midway-Sunset(2) Fellows, California 225 SCE Cogeneration 50% 1989
Nevada Sun-Peak Las Vegas, Nevada 210 NVP EWG 50% 1991
Saguaro(2) Henderson, Nevada 90 NVP Cogeneration 50% 1991
Salinas River(2) San Ardo, California 38 PG&E Cogeneration 50% 1991
Sargent Canyon(2) San Ardo, California 38 PG&E Cogeneration 50% 1991
Sycamore(2) Oildale, California 300 SCE Cogeneration 50% 1988
Watson Carson, California 385 SCE Cogeneration 49% 1988
</TABLE>
- --------
(1) Consists of two projects on the same site.
(2) Operated by the Company.
(3) Electric purchaser abbreviations are as follows:
<TABLE>
<S> <C>
CE Consolidated Edison Company of New York, Inc.
FPC Florida Power Corporation
JCP&L Jersey Central Power & Light Company
MPC Monongahela Power Company
NVP Nevada Power Company
Pool Regional electricity trading market
</TABLE>
<TABLE>
<S> <C>
PG&E Pacific Gas & Electric Company
PSE Puget Sound Energy, Inc.
PSE&G Public Service Electric & Gas Company
SCE Southern California Edison Company
VEPCO Virginia Electric & Power Company
</TABLE>
(4) All of the cogeneration projects are gas-fired facilities, except for the
James River project, which uses coal.
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<PAGE>
International
As set forth in the table below, the Company owns interests in 34 operating
projects outside the United States. The total generating capacity of such
facilities is 6,313 MW, of which the Company's net ownership share is 4,503 MW.
<TABLE>
<CAPTION>
Electric Operation/
Capacity Primary Electric Ownership Acquisition
Project Location (in MW) Purchaser(/2/) Interest Date
- ------- ----------- -------- ---------------- --------- ----------------
<S> <C> <C> <C> <C> <C>
Alos(1) Spain 5 FECSA 100% 1993
Bocos(1) Spain 2 FECSA 100% 1993
Castellas(1) Spain 2 FECSA 100% 1993
Clyde New Zealand 432 Pool 40% 1999
Derwent(1) England 214 SE(3) 33% 1995
Dinorwig(1) Wales 1,728 Pool 100% 1995
Doga(1) Turkey 180 TEAS 80% 1999
Ffestiniog(1) Wales 360 Pool 100% 1995
Gelsa(1) Spain 7 FECSA 100% 1993
Kwinana(1) Australia 116 WP 100% 1996
La Flecha(1) Spain 3 FECSA 100% 1993
La Ribera(1) Spain 4 FECSA 100% 1993
Logrono(1) Spain 4 FECSA 100% 1993
Loy Yang B (1) Australia 1,000 Pool(4) 100% 1993, 1996, 1997
Mendavia(1) Spain 6 FECSA 100% 1993
Menuza(1) Spain 17 FECSA 91.3% 1992
Monasterio(1) Spain 2 FECSA 100% 1993
New Plymouth New Zealand 464 Pool 40% 1999
Ohaaki New Zealand 104 Pool 40% 1999
Olvera(1) Spain 2 FECSA 100% 1992
Otahuhu A New Zealand 85 Pool 40% 1999
Quintana(1) Spain 1 FECSA 100% 1993
Roosecote England 220 NORWEB(5) 80% 1992
Roxburgh New Zealand 320 Pool 40% 1999
Sardon Bajo(1) Spain 2 FECSA 100% 1993
Sastago I(1) Spain 3 FECSA 91.3% 1992
Sastago II(1) Spain 17 FECSA 91.3% 1992
Sossis(1) Spain 4 FECSA 100% 1992
Southern Hydro Australia 479 Pool 11% 1999
Stratford New Zealand 198 Pool 40% 1999
Toro(1) Spain 4 FECSA 100% 1993
Tudela(1) Spain 1 FECSA 100% 1993
Wairakei New Zealand 165 Pool 40% 1999
Whirinaki New Zealand 162 Pool 40% 1999
</TABLE>
- --------
(1) Operated by the Company.
(2) Electric purchaser abbreviations are as follows:
<TABLE>
<S> <C>
FECSA Fuerzas Electricas de Cataluma, S.A.
NORWEB North Western Electricity Board
WP Western Power
TEAS Turkiye Elektrik, A.S.
</TABLE>
<TABLE>
<S> <C>
Pool Electricity trading market for England and
Wales, Australia or New Zealand, as applicable
SE Southern Electric plc
</TABLE>
(3) Sells to the Pool with a long-term contract with SE.
(4) Sells to the Pool with a long-term contract with the State Electricity
Commission of Victoria.
(5) Sells to the Pool with a long-term contract with NORWEB.
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<PAGE>
Oil and Gas Investments
In 1988, the Company formed a wholly-owned subsidiary, Mission Energy Fuel
Company, to develop and invest in fuel interests. Since that time, Mission
Energy Fuel Company has invested in a number of oil and gas properties and a
production company. Oil and gas produced from the properties are generally sold
at spot or short-term market prices.
Four Star
The Company and Texaco Inc. each own approximately 50% of the stock of Four
Star Oil & Gas Company ("Four Star"). The underlying value of Four Star is
attributable to production of oil and gas from nine producing properties. The
Company's proportionate interest in net quantities of proved reserves at
December 31, 1998 totaled 190.5 billion cubic feet of natural gas and 21.2
million barrels of oil.
Competition
The Company competes with many other companies, including multinational
development groups, equipment suppliers and other IPPs (including affiliates of
utilities), in selling electric power and steam, and with electric utilities in
obtaining the right to install new generating capacity. Over the past decade,
obtaining a power sales contract with a utility has generally become a
progressively more difficult, expensive and competitive process. Many power
sales contracts are now awarded by competitive bidding, which both increases
the costs of obtaining such contracts and decreases the chances of obtaining
such contracts. The Company evaluates each potential project in an effort to
determine when the probability of success is high enough to justify
expenditures in developing a proposal or bid for the project.
Amendments to the Public Utility Holding Company Act of 1935, as amended
("PUHCA"), made by the Energy Policy Act have increased the number of
competitors in the domestic independent power industry by reducing certain
restrictions applicable to projects that are not QFs under PURPA. "Retail
wheeling" of power could also lead to increased competition in the independent
power market. See "--Certain Regulatory Matters--Retail Competition."
Tax Sharing Agreements
EME is included in the consolidated federal income tax and combined state
franchise tax returns of Edison International. EME calculates its income tax
provision on a separate company basis under a tax sharing arrangement with The
Mission Group, which in turn has an agreement with EIX. Tax benefits generated
by EME and used in the Edison International consolidated tax return are
recognized by EME without regard to separate company limitations.
Employees and Offices
At April 30, 1999, the Company employed 1,434 people, all of whom were full-
time employees and approximately 172, 140 and 167 of whom were covered by
collective bargaining agreements in Wales,
Australia and the United States, respectively. The Company has never
experienced a work stoppage, strike or labor dispute. The Company believes it
has good relations with its employees.
The Company leases its corporate headquarters in Irvine, California and its
principal regional offices in London, Melbourne and Singapore. The Company also
leases other smaller offices in the United States and certain foreign
countries.
Certain Regulatory Matters
General
The Company's operations are subject to extensive regulation by governmental
agencies in each of the countries in which it conducts operations. The
Company's domestic projects are subject to energy,
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<PAGE>
environmental and other governmental laws and regulations at the federal, state
and local levels in connection with the development, ownership and operation
of, and use of electric energy, capacity and related products, including
ancillary services from, its projects. Federal laws and regulations govern,
among other things, transactions by and with purchasers of power, including
utility companies, the operations of a project and the ownership of a project.
Under certain circumstances where exclusive federal jurisdiction is not
applicable or specific exemptions or waivers from certain state or federal laws
or regulations are otherwise unavailable, federal and/or state utility
regulatory commissions may have broad jurisdiction over non-utility owned
electric power plants. Energy-producing projects are also subject to federal,
state and local laws and regulations that govern the geographical location,
zoning, land use and operation of a project. Federal, state and local
environmental requirements generally require that a wide variety of permits and
other approvals be obtained before the commencement of construction or
operation of an energy-producing facility and that the facility then operate in
compliance with such permits and approvals. While the Company believes the
requisite approvals for its existing projects have been obtained and that its
business is operated in substantial compliance with applicable laws, the
Company remains subject to a varied and complex body of laws and regulations
that both public officials and private parties may seek to enforce. Regulatory
compliance for the construction of new facilities is a costly and time
consuming process. Intricate and changing environmental and other regulatory
requirements may necessitate substantial expenditures and may create a
significant risk of expensive delays or significant loss of value in a project
if the project is unable to function as planned due to changing requirements or
local opposition.
Each of the Company's international projects is subject to the energy and
environmental laws and regulations of the foreign country in which such project
is located. The degree of regulation varies according to each country and may
be materially different from the regulatory regime in the United States.
U.S. Federal Energy Regulation
Overview. The enactment of PURPA in 1978 and the adoption of regulations
thereunder by the Federal Energy Regulatory Commission ("FERC") provided
incentives for the development of cogeneration facilities and small power
production facilities (those utilizing alternative or renewable fuels). The
passage of the Energy Policy Act in 1992 further encouraged independent power
production by providing certain exemptions from PUHCA (but not from the Federal
Power Act ("FPA") or state regulation) for exempt wholesale generators ("EWGs")
and foreign utility companies ("FUCOs").
A domestic electricity generating project must be a QF under FERC
regulations in order to take advantage of certain rate and regulatory
incentives provided by PURPA. Subject to certain exceptions, PURPA exempts
owners of QFs from PUHCA, exempts QFs from most provisions of the FPA and,
except under certain limited circumstances, exempts QFs from most provisions of
state laws concerning rate, financial or organizational regulation. In order to
be a QF, a cogeneration facility must (i) sequentially produce both useful
thermal (e.g., steam) and electric energy, (ii) meet certain operating
standards and energy efficiency standards when oil or natural gas is used as a
fuel source and (iii) not be controlled, or more than 50% owned, by an electric
utility, an electric utility holding company or an affiliate thereof. Certain
non-cogeneration facilities may also be QFs if they produce power from
renewable energy (e.g., geothermal energy) or a waste source of fuel (e.g.,
waste coal) and meet the ownership restrictions discussed above. Before 1990,
non-cogeneration QFs were subject to 30 MW or 80 MW size limits, depending upon
their fuel source. In 1990, these limits were lifted for solar, wind, waste,
and geothermal QFs, provided that applications for or notices of QF status were
filed with FERC for such facilities on or before December 31, 1994, and
provided, in the case of new facilities, the construction of such facilities
commences on or before December 31, 1999.
Amendments made to PUHCA by the Energy Policy Act provide that owners or
operators of EWGs and FUCOs will not be considered "electric utility
companies," and upstream owners will not be considered "holding companies"
under PUHCA. An EWG is an entity determined by the FERC to be exclusively
engaged, directly or indirectly, in the business of owning and/or operating
certain eligible facilities and selling electric energy at wholesale (or, if
located in a foreign country, at wholesale or retail). A FUCO is, in general,
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<PAGE>
an entity located outside the United States that owns or operates facilities
used for the generation, distribution or transmission of electric energy for
sale or the distribution at retail of natural or manufactured gas, but derives
none of its income, directly or indirectly, from such activities within the
United States.
Under present federal law, EME is not and will not be subject to regulation
as a holding company under PUHCA as long as the projects in which it has an
interest are QFs, EWGs or FUCOs (or are subject to another exemption from
regulation). See "PUHCA."
PURPA. PURPA provides two primary benefits to QFs. First, QFs are relieved
of compliance with extensive federal and state regulations that control the
development, financial structure and operation of an energy-producing project
and the prices and terms on which wholesale energy may be sold by the project.
Second, FERC regulations promulgated under PURPA require that electric
utilities purchase electricity generated by QFs at a price based on the
purchasing utility's "avoided cost," and that the utilities sell back-up power
to the QF on a non-discriminatory basis. The term "avoided cost" is defined by
FERC regulations as the "incremental cost to an electric utility of electric
energy or capacity or both which, but for the purchase from the qualifying
facility or qualifying facilities, such utility would generate itself or
purchase from another source." FERC regulations also permit QFs and utilities
to negotiate agreements for utility purchases of power at prices different than
the utility's avoided costs. While public utilities are not explicitly required
by PURPA to enter into long-term contracts, it has been common for long-term
contracts to be negotiated in order, among other things, to facilitate the
project financing of independent power facilities and to reflect the deferral
by the utility of capital costs for new plant additions. However, increasing
competition and the development of new power markets have resulted in a trend
toward shorter term power contracts that would place greater risk on the
project owner.
The Company endeavors to develop its QF projects, monitor regulatory
compliance by such projects and choose its customers in a manner that minimizes
the risks of losing such projects' QF status. However, certain factors
necessary to maintain QF status are subject to risks of events outside the
Company's control. For example, loss of a thermal energy customer or failure of
a thermal energy customer to take required amounts of thermal energy from a
cogeneration facility that is a QF could cause the facility to fail
requirements regarding the level of useful thermal energy output. Upon the
occurrence of such an event, the Company would seek to replace the thermal
energy customer or find another use for the thermal energy that meets PURPA's
requirements.
If one of the projects in which the Company has an interest were to lose its
status as a QF, the project would no longer be entitled to the QF-related
exemptions from regulation under PUHCA and the FPA. This could subject the
project to rate regulation as a public utility under the FPA and could result
in EME inadvertently becoming a public utility holding company by owning more
than 10% of the voting securities of, or controlling, a facility that would no
longer be exempt from PUHCA. Loss of QF status may also trigger defaults under
covenants to maintain QF status in the project's power sales agreements, steam
sales agreements and financing agreements and result in termination, penalties
or acceleration of indebtedness under such agreements. Such loss of QF status
may be on a retroactive or a prospective basis. If a power purchaser ceased
taking and paying for electricity or sought to obtain refunds of past amounts
paid due to the loss of QF status, the Company cannot assure you that the costs
incurred in connection with the project could be recovered through sales to
other purchasers. Moreover, the Company's business and financial condition
could be adversely affected if regulations or legislation were modified or
enacted that changed the standards for maintaining QF status or that eliminated
or reduced the benefits and exemptions currently enjoyed by QFs. If a project
were to lose its QF status, EME could attempt to avoid holding company status
on a prospective basis by qualifying the project as an EWG. However, assuming
this changed status would be permissible under the terms of the applicable
power sales agreement, rate approval from the FERC would be required. In
addition, the project would be required to cease selling electricity to any
retail customers (in order to qualify for EWG status) and could become subject
to additional state regulation. Loss of QF status on a retroactive basis could
lead to, among other things, fines and penalties being levied against the
Company, or claims by the utility customer for refund of payments previously
made. Loss of QF status by one project could also, because of
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<PAGE>
PURPA ownership restrictions, adversely affect the QF status of other projects
having one or more of the same partners. In addition, pursuant to Section 26(b)
of PUHCA, any project contracts that are entered into in violation of PUHCA may
be determined by the courts or the SEC to be void.
The Energy Policy Act. The passage of the Energy Policy Act in 1992
significantly expanded the options available to IPPs with respect to their
regulatory status. The Energy Policy Act created a new class of power producer,
the EWG, that (like a QF) is not considered an electric utility company under
PUHCA. EWGs may own facilities of any size, use any fuel source and be owned by
utilities or non-utilities. Thus, in addition to QF status, an IPP now can also
apply to the FERC to be granted status as an EWG. EWGs, however, are not exempt
from regulation by the FERC or state public utility commissions. The effect of
such amendments is to enhance the development of non-QFs that do not have to
meet the fuel, production and ownership requirements of PURPA. The Company
believes that the amendments benefit it by expanding its ability to own and
operate facilities that do not qualify for QF status, but also result in
increased competition because utilities and other companies (e.g., equipment
suppliers) may now develop facilities that are not subject to the constraints
of PUHCA. The Energy Policy Act also expanded FERC authority to order utilities
to grant transmission access to QFs and EWGs and lifted restrictions on
ownership of foreign utilities by U.S. companies. Pursuant to the Energy Policy
Act, FUCOs are also not electric utility companies under PUHCA.
PUHCA. Under PUHCA, any corporation, partnership or other entity or
organized group that owns, controls or holds with power to vote 10% or more of
the outstanding voting securities of a "public-utility company" or a company
that is a "holding company" of a public utility company is subject to
registration with the SEC and regulation under PUHCA, unless eligible for an
exemption or unless an appropriate application is filed with, and an order is
granted by, the SEC declaring it not to be a holding company. A registered
public utility holding company regulated under PUHCA is required to limit its
utility operations to a single integrated utility system and to divest any
other operations not functionally related to the operation of that utility
system. Approval by the SEC is required for major financial commitments and
other business dealings of the regulated holding company or its subsidiaries.
As noted above, however, regulations have been adopted under PURPA and the
Energy Policy Act providing that QFs, EWGs and FUCOs are not public utility
companies under PUHCA. Accordingly, EME is not regulated as a "holding company"
under PUHCA because the power generation facilities it owns or in which it has
investments are either QFs, EWGs or FUCOs. All international projects and
certain U.S. projects that the Company is currently developing or proposing to
acquire will be non-QF independent power projects. The Company intends for each
such project to qualify as an EWG or as a FUCO. Loss of EWG or FUCO status
(like loss of QF status, as discussed above) could also result in EME becoming
subject to registration and regulation as a public utility holding company
under PUHCA and could trigger defaults under covenants in project agreements.
Loss of EWG or FUCO status on a retroactive basis could lead to, among other
things, fines and penalties and could cause certain project and other contracts
to be void.
Natural Gas Act. Nineteen of the domestic operating facilities that the
Company owns, operates or has investments in are fueled by natural gas.
Pursuant to the Natural Gas Act, the FERC has jurisdiction over the sale,
transportation and storage of natural gas in interstate commerce. With respect
to most transactions that do not involve the construction of pipeline
facilities, regulatory authorization can be obtained on a self-implementing
basis. However, pipeline rates for such services are subject to continuing FERC
oversight. Order No. 636, issued by the FERC in April 1992 (and affirmed in
Orders 636A and 636B issued, respectively, in August and November 1992),
mandated the restructuring of interstate natural gas pipeline sales and
transportation services and changed the terms and conditions under which
interstate pipelines provide transportation services, as well as the rates
pipelines may charge for such services. The restructuring required by the rule
included (i) the separation (unbundling) of a pipeline's sales, transportation
and storage services, (ii) the prohibition against pipelines engaging in sales
of gas, (iii) the implementation of a straight fixed-variable rate design
methodology under which all of a pipeline's fixed costs are recovered through
its reservation charge, (iv) the implementation of a capacity releasing
mechanism under which holders of firm transportation
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capacity on pipelines can release that capacity for resale by the pipeline, and
(v) the opportunity for pipelines to recover 100% of their prudently incurred
costs (transition costs) associated with implementing the restructuring
mandated by the rule.
FPA. The FPA grants the FERC exclusive ratemaking jurisdiction over
wholesale sales of electricity in interstate commerce, including ongoing as
well as initial rate jurisdiction, which enables the FERC to revoke or modify
previously approved rates. Such rates may be based on a cost-of-service
approach or may, in competitive markets, be market-based. While qualifying
facilities under PURPA generally are exempt from the ratemaking and certain
other provisions of the FPA, EWGs and other non-QF independent power projects
are subject to the FPA and to FERC ratemaking jurisdiction, which may limit
their flexibility in negotiations with power purchasers. However, since such
projects would not be bound by PURPA's thermal energy use requirement, they
have greater latitude in site selection and facility size. In addition, as
noted above, EWGs may be 100% owned by the Company. In addition, the FPA grants
FERC jurisdiction over the sale or transfer of jurisdictional facilities,
including wholesale power sales contracts, and in some cases, jurisdiction over
the issuance of securities or the assumption of certain liabilities.
Currently, five of the Company's operating projects, the Homer City, Nevada
Sun-Peak, Brooklyn Navy Yard, Commonwealth Atlantic and Harbor projects, are
subject to FERC rate-making regulation under the FPA. The Company's future
domestic non-QF independent power projects will also be subject to FERC
jurisdiction on rates.
State Energy Regulation
State public utility commissions ("PUCs") have broad jurisdiction over non-
QF independent power projects (including EWGs), which are considered public
utilities in many states. Such jurisdiction often includes the issuance of
certificates of public convenience and necessity ("CPCNs") and/or other
certifications to construct, own and operate a facility, as well as regulation
of organizational, accounting, financial and other corporate matters on an
ongoing basis. QFs may also be required to obtain CPCNs in some states. Certain
states that have restructured their electric industries require generators to
register to provide electric service to customers. Many states are currently
undergoing significant changes in their electric statutory and regulatory
frameworks that result from restructuring the electric industries that may
affect generators in those states. Although the FERC generally has exclusive
jurisdiction over the rates charged by a non-QF independent power project to
its wholesale customers, PUCs have the ability, in practice, to influence the
establishment of such rates by asserting jurisdiction over the purchasing
utility's ability to pass through the resulting cost of purchased power to its
retail customers. PUCs also have the authority to determine avoided costs for
QFs and regulate the retail rates charged by QFs. In addition, states may
assert jurisdiction over the siting and construction of independent power
projects and, among other things, the issuance of securities, related party
transactions and the sale or other transfer of assets by these facilities. The
actual scope of jurisdiction over independent power projects by state PUCs
varies from state to state.
In addition, state PUCs may seek to modify, suspend or terminate a QF's
power sales contract under certain circumstances. This could occur if the state
PUC determined that the pricing mechanism of the power sales contract is
unfairly high in light of the current prevailing market cost of power for the
utility purchasing the power. In such instance, the state PUC may attempt to
alter the terms of the power sales contract to reflect more accurately market
conditions for the prevailing cost of power. While the Company believes that
such attempts are not common and that the state PUCs may not have any
jurisdiction to modify the terms of wholesale power sales, it cannot assure you
that the power sales contracts of its projects will not be subject to adverse
regulatory actions.
The California Public Utility Commission ("CPUC") has authorized the
electric utilities in California to "monitor" compliance by QFs with PURPA
rules and regulations. However, the United States Court of Appeals for the
Ninth Circuit found in 1994 that a CPUC program was preempted by PURPA insofar
as it authorized utilities to determine that a QF was not in compliance with
PURPA rules and regulations, to then
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pay a reduced avoided cost rate and to take other action contrary to a
facility's status as a QF. The court did, however, uphold reasonable monitoring
of QF operating data. Other states, such as New York and Virginia, have also
instituted QF monitoring programs.
The Company buys and transports the natural gas used at its domestic
facilities through local distribution companies ("LDCs"). State PUCs have
jurisdiction over the transportation of natural gas by LDCs. Each state's
regulatory laws are somewhat different; however, all generally require the LDC
to obtain approval from the relevant PUC for the construction of facilities and
transportation services if the LDC's generally applicable tariffs do not cover
the proposed transaction. LDC rates are usually subject to continuing PUC
oversight.
Certain Recent Foreign Regulatory Matters
On July 29, 1998, the British Director General of Electricity Supply
proposed to the Minister for Science, Energy and Industry that the current
structure of "contracts for differences" and compulsory trading via the pool at
half-hourly clearing prices bid a day ahead be abolished. He proposed in their
place, among other things: the establishment of voluntary forwards and futures
markets, organized by independent market operators and evolving in response to
demand; a short-term bilateral market operating from 24 to 4-hours before a
trading period; a balancing market to enable the system operator to balance
generation and demand and resolve any transmission constraints; a settlement
process for recovering imbalances between contracted and metered volumes with
stronger incentives for being in balance; and a Balancing and Settlement Code
Panel to oversee governance of the short- term bilateral and balancing markets.
The Minister for Science, Energy and Industry has recommended that the proposal
be implemented by April 2000. Further definition of the proposal will be
required before the effects of the changes on EME's U.K. projects can be
evaluated. Implementation of the proposal may also require legislation.
The New Zealand Government has been undergoing a steady process of electric
industry deregulation since 1987. Reform in the distribution and retail supply
sector began in 1992 with legislation that deregulated electricity distribution
and provided for competition in the retail electric supply function. The New
Zealand Energy Market, established in 1996, is a voluntary competitive
wholesale market which allows for the trading of physical electricity on a
half-hourly basis. The Electricity Industry Reform ("EIR") Act, which was
passed in July 1998, was designed to increase competition at the wholesale
generation level by splitting up Electricity Company of New Zealand Limited,
the large state-owned generator, into three separate generation companies. The
EIR Act also prohibits the ownership of both generation and distribution assets
by the same entity.
Transmission of Wholesale Power
Generally, projects that sell power to wholesale purchasers other than the
local utility to which the project is interconnected require the transmission
of electricity over power lines owned by others (wheeling). The prices and
other terms and conditions of transmission contracts are regulated by FERC,
when the entity providing the wheeling service is a jurisdictional public
utility under the FPA. Until 1992, FERC's ability to compel wheeling was very
limited, and the availability of voluntary wheeling service could be a
significant factor in determining whether a site was viable for project
development.
FERC's authority under the FPA to require electric utilities to provide
transmission service on a case by case basis to QFs, EWGs, and other power
generators was expanded substantially by the Energy Policy Act. Furthermore, in
1996 FERC issued a rulemaking order, Order 888, in which FERC asserted the
power, under its authority to eliminate undue discrimination in transmission,
to compel all jurisdictional public utilities under the FPA to file open access
transmission tariffs consistent with a pro forma tariff drafted by FERC. The
FERC subsequently issued Orders 888-A, 888-B and 888-C to clarify the terms
that jurisdictional transmitting utilities are required to include in their
open access transmission tariffs. The FERC also issued Order 889, which
required those transmitting utilities to abide by certain standards of conduct
when using their own transmission systems to make wholesale sales of power, and
to post certain transmission information, including information about
transmission requests and availability, on a publicly available computer
bulletin board. Although the pro
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forma tariff does not cover the pricing of transmission service, Order 888 is
expected to improve transmission access for independent power producers such as
the Company. A recent decision by the United States Court of Appeals for the
Eighth Circuit has cast doubt on the extent of FERC's authority to require
certain curtailment policies in the pro forma tariff.
Retail Competition
In response to pressure from retail electric customers, particularly large
industrial users, the state commissions or state legislatures of most states
are considering, or have considered, whether to open the retail electric power
market to competition. Retail competition is possible when a customer's local
utility agrees, or is required, to "unbundle" its distribution service (e.g.,
the delivery of electric power through its local distribution lines) from its
transmission and generation service (e.g., the provision of electric power from
the utility's generating facilities or wholesale power purchases). Several
state commissions and legislatures have issued orders or passed legislation
requiring utilities to offer unbundled retail distribution service ("retail
wheeling") beginning as early as 1998 and phasing in retail wheeling over the
next several years. Other states are expected to move toward retail competition
by 2000.
The competitive pricing environment that will result from retail competition
may cause utilities to experience revenue shortfalls and deteriorating
creditworthiness. However, the Company expects that most, if not all, state
plans will insure that utilities receive sufficient revenues, through a
distribution surcharge if necessary, to pay their obligations under existing
long-term power purchase contracts with QFs and EWGs. On the other hand, QFs
and EWGs may be subject to pressure to lower their contract prices in an effort
to reduce the "stranded investment" costs of their utility customers.
The Company believes that, as a predominantly low cost producer of
electricity, it will ultimately benefit from any increased competition that may
arise from the opening of the retail market. Although the Company's EWGs are
forbidden under PUHCA from selling electric power in the retail market, its
EWGs could sell at wholesale to a power marketer which could resell at retail.
Furthermore, QFs are permitted to market power directly to large industrial
users that could not previously be served, because of local franchise laws or
the inability to obtain retail wheeling. The Company also believes it will be
an attractive wholesale supplier to power marketers serving the newly-open
retail markets.
Environmental Regulation
The construction and operation of power projects are subject to
environmental regulation by federal, state and local authorities in the United
States and regulatory authorities with jurisdiction over the projects located
outside the United States. The Company believes that, as of the date of this
offering circular, it is in substantial compliance with environmental
regulatory requirements and that maintaining compliance with current
requirements will not materially affect its financial condition or results of
operations. However, possible future developments, such as more stringent
environmental laws and regulations, could affect the costs and the manner in
which the Company conducts its business. The Company cannot assure you that in
such event it would be able to recover such increased costs from its customers
or that its financial position and results of operations would not be
materially adversely affected.
Typically, environmental laws require a lengthy and complex process for
obtaining licenses, permits and approvals prior to construction and operation
of a project. Meeting all of the necessary requirements can delay or sometimes
prevent the completion of a proposed project as well as require extensive
modifications to existing projects, which may involve significant capital
expenditures.
In 1990, Congress passed amendments (the "1990 Amendments") to the Clean Air
Act that greatly expand the scope of federal regulations in several significant
respects. A Company project is anticipated to make capital expenditures of
approximately $5.7 million (of which the Company's share is $2.9 million)
during 1999 in order to comply with the 1990 Amendments. In addition, the
Company plans to spend approximately $246 million to install upgrades to the
environmental controls at the Homer City project during 2000 and 2001
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to control sulfur dioxide and nitrogen oxide emissions. Similarly, the Company
plans to upgrade the environmental controls at the former ComEd plants to
control nitrogen oxide emissions. Provisions related to nonattainment, air
toxins, permitting, enforcement and "acid rain" may affect the Company's
projects; however, final details of all these programs have not been issued by
the United States Environmental Protection Agency and state agencies.
The Comprehensive Environmental Response, Compensation, and Liability Act
("CERCLA") requires the cleanup of sites from which there has been a release or
threatened release of hazardous substances. As of the date of this offering
circular, the Company is not aware of any CERCLA liability; however, it cannot
assure you that it will not incur such liability in the future.
Legal Proceedings
In February 1997, a civil action was commenced in the Superior Court of the
State of California, Orange County, entitled The Parsons Corporation and PMNC
v. Brooklyn Navy Yard Cogeneration Partners, L.P., Mission Energy New York,
Inc. and B-41 Associates, L.P., Case No. 774980, in which plaintiffs assert
general monetary claims under the Construction Turnkey Agreement in the amount
of $136.8 million. Brooklyn Navy Yard has also filed an action entitled
Brooklyn Navy Yard Cogeneration Partners, L.P. v. PMNC, Parsons Main of New
York, Inc., Nab Construction Corporation, L.K. Comstock & Co., Inc. and The
Parsons Corporation, in the Supreme Court of the State of New York, Kings
County, Index No. 5966/97 asserting general monetary claims in excess of $13
million under the Construction Turnkey Agreement. On March 26, 1998, the
Superior Court in the California action granted PMNC's motion for attachment in
the amount of $43 million against Brooklyn Navy Yard and attached a Brooklyn
Navy Yard bank account in the amount of $0.5 million. Brooklyn Navy Yard is
appealing the attachment order. On the same day, the court stayed all
proceedings in the California action due to the action pending in New York.
PMNC's motion to dismiss the New York action was denied by the New York Supreme
Court and further denied on appeal in September 1998. EME agreed to indemnify
BNY and its partner from all claims and costs arising from or in connection
with the contractor litigation. EME believes that the outcome of this
litigation will not have a material adverse effect on its consolidated
financial position or results of operations.
The Company experiences other routine litigation in the normal course of its
business. None of such pending litigation is expected to have a material
adverse effect on the consolidated financial position or results of operations
of the Company. See "--Certain Regulatory Matters--Environmental Regulation."
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MANAGEMENT
Directors and Executive Officers of EME
The following table sets forth the names and ages of, the positions held
with EME by, and the terms of office of, the directors and executive officers
of EME as of June 3, 1999.
<TABLE>
<CAPTION>
Name Age Position
- ---- --- --------
<S> <C> <C>
Alan J. Fohrer................. 48 Chairman of the Board
Bryant C. Danner............... 61 Director
Robert M. Edgell............... 52 Director, Executive Vice President and
Division President of EME, Asia Pacific
Edward R. Muller............... 46 Director, President and Chief Executive
Officer
S. Linn Williams............... 52 Senior Vice President and Division President
of EME, Europe, Central Asia, Middle East
and Africa
Kevin M. Smith................. 41 Senior Vice President, Chief Financial
Officer and Treasurer
James V. Iaco, Jr.............. 54 Senior Vice President and Division President
of EME, Americas
Georgia R. Nelson.............. 49 Senior Vice President and President of
Midwest Generation EME, LLC
Ronald L. Litzinger............ 39 Senior Vice President, Worldwide Operations
Raymond W. Vickers............. 56 Senior Vice President and General Counsel
</TABLE>
Business Experience
Set forth below is a description of the principal business experience during
the past five years of each of the individuals named above and the name of each
public company in which any director named above is a director.
Mr. Fohrer has been Chairman of the Board of EME since January 1998. From
1993 to 1998, Mr. Fohrer served as Vice Chairman of the Board. Mr. Fohrer has
been Executive Vice President and Chief Financial Officer of Edison
International and SCE since June 1995. Effective February 1996 and June 1995,
Mr. Fohrer also served as Treasurer of SCE and Edison International,
respectively, until August 1996. Mr. Fohrer was Senior Vice President,
Treasurer and Chief Financial Officer of Edison International, and Senior Vice
President and Chief Financial Officer of SCE from January 1993 until May 1995.
Mr. Fohrer was interim Chief Executive Officer of EME between May 1993 and
August 1993. From 1991 until 1993, Mr. Fohrer was Vice President, Treasurer and
Chief Financial Officer of Edison International and SCE.
Mr. Danner has been Executive Vice President and General Counsel of Edison
International and SCE since June 1995. Mr. Danner was Senior Vice President and
General Counsel of Edison International and SCE from July 1992 until May 1995.
Mr. Edgell has been Executive Vice President of EME since April 1988. Mr.
Edgell was named Division President of EME's Asia Pacific region in January
1995.
Mr. Muller has been President and Chief Executive Officer of EME since
August 1993. Prior to joining EME, Mr. Muller served as vice president, chief
administrative officer, general counsel and secretary of Whittaker Corporation,
an aerospace firm, from 1988 until 1992 and as vice president, chief financial
officer, general counsel and secretary of Whittaker Corporation from 1992 until
1993. From 1991 until 1993, Mr. Muller also served as vice president, secretary
and general counsel of BioWhittaker, Inc., a biotechnology company. Mr. Muller
is a director of Whittaker Corporation and Global Marine, Inc.
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Mr. Williams has been Senior Vice President of EME since November 1994. Mr.
Williams was named Division President of EME's Europe, Central Asia, Middle
East and Africa region in November 1998. Mr. Williams served as General Counsel
of EME from November 1994 until being named as Division President. From 1985
through 1989 and from 1992 to 1993, Mr. Williams was a partner with the law
firm of Gibson, Dunn and Crutcher. From 1993 to 1994, Mr. Williams was a
partner with the law firm of Jones, Day, Reavis and Pogue.
Mr. Smith has been Senior Vice President, Chief Financial Officer and
Treasurer of EME since May 1999. Mr. Smith served as Vice President and
Treasurer of EME and Regional Vice President, Americas region, from March 1998
until April 1999. Mr. Smith has served as Treasurer since September 1992.
Mr. Iaco has been Senior Vice President of EME since January 1994 and
Division President of EME's Americas region since January 1998. Mr. Iaco served
as Chief Financial Officer from January 1994 to May 1999. From September 1993
until December 1993, Mr. Iaco was self-employed and provided consulting
services, specializing in restructuring, finance, crisis management and other
management services. From October 1992 until September 1993, Mr. Iaco served as
senior vice president and chief financial officer of Phoenix Distributors,
Inc., a distributor of industrial gas and welding supplies.
Ms. Nelson has been President of Midwest Generation EME, LLC since May 1999.
From January 1996 until June 1999, Ms. Nelson was Senior Vice President,
Worldwide Operations. Ms. Nelson was Division President of EME's Americas
region from January 1996 to January 1998. Prior to joining EME, Ms. Nelson
served as Senior Vice President of SCE from June 1995 until December 1995 and
Vice President of SCE from June 1993 until May 1995. From 1992 to 1993, Ms.
Nelson served as a Special Assistant to the Chairman of Edison International.
Mr. Litzinger has been Senior Vice President, Worldwide Operations, since
June 1999. Mr. Litzinger served as Vice President-O&M Business Development from
December 1998 to May 1999. Mr. Litzinger has been with EME since November 1995
serving as both Regional Vice President, O&M Business Development and Manager,
O&M Business Development until December 1998. Prior to joining EME, Mr.
Litzinger was a Reliability Supervisor with Texaco Refining and Marketing, Inc.
from March 1995 to October 1995 and prior to that held numerous management
positions with SCE since June 1986.
Mr. Vickers has been Senior Vice President and General Counsel of EME since
March 1999. Prior to joining EME, Mr. Vickers was a partner with the law firm
Skadden, Arps, Slate, Meagher & Flom LLP concentrating on international
business transactions, particularly cross-border capital markets and investment
transactions, project implementation and finance. Mr. Vickers originally joined
Skadden, Arps, Slate, Meagher & Flom LLP in 1989 as resident partner in the
Hong Kong office.
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DESCRIPTION OF THE NOTES
In this "Description of the Notes", references to "EME", "we", "our",
"ours" and "us" refer only to Edison Mission Energy, and not to any of our
direct or indirect subsidiaries or affiliates. The following description is a
summary of certain provisions of the Indenture and the Notes. It does not
restate the Indenture and the Notes in their entirety. We urge you to read the
Indenture and the Notes because they, and not this description, define your
rights as a holder of these Notes. You may obtain a copy of the Indenture and
the Notes from us by writing to us at 18101 Von Karman Avenue, Suite 1700,
Irvine, California 92612.
General
We will issue the Notes under the Indenture and the First Supplemental
Indenture, each to be dated as of June 28, 1999, between EME and The Bank of
New York, as Trustee. The Notes will be unsecured senior obligations of EME.
The Notes will rank equal in right of payment with all other unsubordinated
indebtedness of EME. Because we conduct substantially all our business through
numerous subsidiaries, all existing and future liabilities of our direct and
indirect subsidiaries will be effectively senior to the Notes. The Notes will
not be guaranteed by, or otherwise be obligations of, our project subsidiaries
and project affiliates, or our other direct and indirect subsidiaries and
affiliates.
We will issue the Notes in aggregate principal amount of $600,000,000. The
Notes will mature on June 15, 2009 and will bear interest at the rate of 7.73%
per annum. We will pay interest on the Notes on each June 15 and December 15,
beginning on December 15, 1999, to the holders of record on the immediately
preceding June 1 and December 1. Interest on the Notes will accrue from the
most recent date to which interest has been paid or, if no interest has been
paid, from June 28, 1999. Interest will be computed on the basis of a 360-day
year consisting of twelve 30-day months. The interest rate on the Notes may be
increased under the circumstances described in "Registration Rights
Agreement."
The Notes will be in denominations of $100,000 and any integral multiple of
$1,000 in excess thereof.
We may issue additional series of notes under the Indenture from time to
time in accordance with the conditions described therein.
Redemption
We may redeem the Notes at any time, in whole or in part, at a redemption
price equal to:
. the greater of
(1) 100% of the principal amount of the Notes being redeemed
and
(2) the sum of the present values of the Remaining Scheduled
Payments on the Notes being redeemed discounted to the date of
redemption on a semiannual basis (assuming a 360-day year consisting of
twelve 30-day months) at a rate equal to the Treasury Rate plus 37.5
basis points,
. plus accrued and unpaid interest, if any, on the principal amount of
Notes being redeemed to the redemption date.
"Remaining Scheduled Payments" means, with respect to each Note that we are
redeeming, the remaining scheduled payments of the principal and interest on
that Note that would be due after the related redemption date if we were not
redeeming that Note. However, if the redemption date is not a scheduled
interest payment date with respect to that Note, the amount of the next
succeeding scheduled interest payment on that Note will be reduced by the
amount of interest accrued on that Note to the redemption date.
"Treasury Rate" means, with respect to any redemption date, an annual rate
equal to the semiannual equivalent yield to maturity of the Comparable
Treasury Issue, assuming a price for the Comparable Treasury Issue (expressed
as a percentage of its principal amount) equal to the Comparable Treasury
Price for the redemption date. The semiannual equivalent yield to maturity
will be computed as of the third business day immediately preceding the
redemption date.
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"Comparable Treasury Issue" means the United States Treasury security
selected by Credit Suisse First Boston Corporation or an affiliate as having a
maturity comparable to the remaining term of the Notes that would be utilized,
at the time of selection and in accordance with customary financial practice,
in pricing new issues of corporate debt securities of comparable maturity to
the remaining term of the Notes.
"Comparable Treasury Price" means the average of three Reference Treasury
Dealer Quotations obtained by the Trustee in respect of the Notes to be
redeemed on the applicable redemption date.
"Reference Treasury Dealer Quotation" means, with respect to each Reference
Treasury Dealer and any redemption date, the average, as determined by the
Trustee, of the bid and asked prices for the Comparable Treasury Issue
(expressed in each case as a percentage of its principal amount) quoted in
writing to the Trustee by a Reference Treasury Dealer at 3:30 p.m., New York
City time, on the third business day preceding the redemption date.
"Reference Treasury Dealers" means Credit Suisse First Boston Corporation
(so long as it continues to be a primary U.S. Government securities dealer) and
any two other primary U.S. Government securities dealers chosen by us. If
Credit Suisse First Boston Corporation ceases to be a primary U.S. Government
securities dealer, we will appoint in its place another nationally recognized
investment banking firm that is a primary U.S. Government securities dealer.
We will give notice to The Depository Trust Company ("DTC") and holders of
definitive Notes at least 30 days (but not more than 60 days) before we redeem
the Notes. If we redeem only some of the Notes, DTC's practice is to choose by
lot the amount to be redeemed from the Notes held by each of its participating
institutions. DTC will give notice to these participants, and these
participants will give notice to any "Street Name" holders of any indirect
interests in the Notes according to arrangements among them. These notices may
be subject to statutory or regulatory requirements. We will not be responsible
for giving notice of a redemption of the Notes to anyone other than DTC and
holders of definitive Notes.
Certain Covenants
Restrictions on Liens
We will agree not to pledge, mortgage, hypothecate or permit to exist any
mortgage, pledge or other lien upon any property at any time directly owned by
us to secure any indebtedness for money borrowed which is incurred, issued,
assumed or guaranteed by us ("Indebtedness"), without providing for the Notes
to be equally and ratably secured with any and all such Indebtedness and with
any other Indebtedness similarly entitled to be equally and ratably secured;
provided, however, that this restriction will not apply to, or prevent the
creation or existence of:
(1) liens existing at the original date of issuance of the Notes;
(2) purchase money liens which do not exceed the cost or value of the
purchased property;
(3) other liens not to exceed 10% of our Consolidated Net Tangible Assets;
and
(4) liens granted in connection with extending, renewing, replacing or
refinancing in whole or in part the Indebtedness (including, without
limitation, increasing the principal amount of such Indebtedness)
secured by liens described in clauses (1) through (3) above.
"Consolidated Net Tangible Assets" means, as of any date of determination,
the total amount of all of our assets, determined on a consolidated basis in
accordance with generally accepted accounting principles as of such date, less
the sum of
(a) our consolidated current liabilities, determined in accordance with
generally accepted accounting principles and
(b) our assets that are properly classified as intangible assets in
accordance with generally accepted accounting principles, except for any
intangible assets which are distribution or related contracts with an
assignable value.
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If we propose to pledge, mortgage or hypothecate any property at any time
directly owned by us to secure any Indebtedness, other than as permitted by
clauses (1) through (4) of the second previous paragraph, we will agree to give
prior written notice thereof to the Trustee, who will give notice to the
holders of Notes, and we will further agree, prior to or simultaneously with
such pledge, mortgage or hypothecation, effectively to secure all the Notes
equally and ratably with such Indebtedness.
This covenant will not restrict the ability of our subsidiaries and
affiliates to pledge, mortgage, hypothecate or permit to exist any mortgage,
pledge or lien upon their assets, in connection with project financings or
otherwise.
Merger, Consolidation, Sale, Lease or Conveyance
We will agree not to merge or consolidate with or into any other person and
we will agree not to sell, lease or convey all or substantially all of our
assets to any person, unless (1) we are the continuing corporation, or the
successor corporation or the person that acquires all or substantially all of
our assets is a corporation organized and existing under the laws of the United
States or a State thereof or the District of Columbia and expressly assumes all
our obligations under the Notes and the Indenture, (2) immediately after such
merger, consolidation, sale, lease or conveyance, there is no default or Event
of Default (as defined below) under the Indenture, (3) if, as a result of the
merger, consolidation, sale, lease or conveyance, any or all of our property
would become the subject of a lien that would not be permitted by the
Indenture, we secure the Notes equally and ratably with the obligations secured
by that lien and (4) we deliver or cause to be delivered to the Trustee an
officers' certificate and opinion of counsel each stating that the merger,
consolidation, sale, lease or conveyance comply with the Indenture.
The meaning of the term "all or substantially all of the assets" has not
been definitely established and is likely to be interpreted by reference to
applicable state law if and at the time the issue arises and will be dependent
on the facts and circumstances existing at the time.
Except for a sale of our assets substantially as an entirety as provided
above, and other than assets we are required to sell to conform with
governmental regulations, we may not sell or otherwise dispose of any assets
(other than short-term, readily marketable investments purchased for cash
management purposes with funds not representing the proceeds of other asset
sales) if, on a pro forma basis, the aggregate net book value of all such sales
during the most recent 12-month period would exceed 10% of our Consolidated Net
Tangible Assets (as defined above) computed as of the end of the most recent
quarter preceding such sale; provided, however, that any such sales shall be
disregarded for purposes of this 10% limitation if the proceeds are invested in
assets in similar or related lines of our business; and, provided further, that
we may sell or otherwise dispose of assets in excess of this 10% limitation if
we retain the proceeds from such sales or dispositions, which are not
reinvested as provided above, as cash or cash equivalents or if we use the
proceeds from such sales to purchase and retire Notes or Indebtedness ranking
equal in right of payment to the Notes or indebtedness of our subsidiaries.
Reporting Obligations
We will agree to furnish or cause to be furnished to holders of Notes copies
of our annual reports and of the information, documents and other reports that
we are required to file with the SEC pursuant to Section 13 or 15(d) of the
Exchange Act within 15 days after we file them with the SEC.
Additional Covenants
Subject to certain exceptions and qualifications, we will agree in the
Indenture to do, among other things, the following:
(1) deliver to the Trustee copies of all reports that we file with the
SEC;
(2) deliver to the Trustee annual officers' certificates with respect to
our compliance with our obligations under the Indenture;
(3) maintain our corporate existence, subject to the provisions
described above relating to mergers and consolidations; and
(4) pay our taxes when due, except when we are contesting such taxes in
good faith.
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Modification of the Indenture
The Indenture will contain provisions permitting us and the Trustee, with
the consent of the holders of at least a majority in aggregate principal amount
of Notes then outstanding, to modify or amend the Indenture or the rights of
the holders of Notes. However, no such modification or amendment may, without
the consent of the holder of each outstanding Note affected thereby:
(a) change the stated maturity of the principal of, or extend the time
of payment of interest on, any Note;
(b) reduce the principal amount of, or interest on, any Note;
(c) change the place or currency of payment of principal of, or interest
on, any Note;
(d) reduce any amount payable upon the redemption of any Note; or
(e) impair the right to institute suit for the enforcement of any
payment on or with respect to any Note;
In addition, without the consent of the holders of all Notes then
outstanding, no such modification or amendment may:
(x) reduce the percentage in principal amount of outstanding Notes the
consent of whose holders is required for modification or amendment of the
Indenture;
(y) reduce the percentage in principal amount of outstanding Notes
necessary for waiver of compliance with certain provisions of the Indenture
or for waiver of certain defaults; or
(z) modify such provisions with respect to modification and waiver.
The holders of at least a majority in principal amount of the outstanding
Notes may waive compliance by EME with certain restrictive provisions of the
Indenture. The holders of a majority in principal amount of the outstanding
Notes may waive any past default under the Indenture, except a default in the
payment of principal or interest and certain covenants and provisions of the
Indenture which cannot be amended without the consent of the holder of each
outstanding Note affected.
We and the Trustee may, without the consent of any holder of Notes, amend
the Indenture and the Notes for the purpose of curing any ambiguity, or of
curing, correcting or supplementing any defective provision thereof, or in any
manner that we and the Trustee may determine is not inconsistent with the
Indenture and the Notes and will not adversely affect the interest of any
holder of Notes.
Events of Default
Each of the following will be an "Event of Default" under the Indenture:
(a) our failure to pay any interest on any Note when due, which failure
continues for 30 days; or
(b) our failure to pay principal or premium when due; or
(c) our failure to perform any other covenant in the Notes or the
Indenture for a period of 90 days after the Trustee or the holders of at
least 25% in aggregate principal amount of the Notes gives us written
notice of our failure to perform; or
(d) an event of default occurring under any of our instruments under
which there may be issued, or by which there may be secured or evidenced,
any Indebtedness for money borrowed that has resulted in the acceleration
of such Indebtedness, or any default occurring in payment of any such
Indebtedness at final maturity (and after the expiration of any applicable
grace periods), other than
(i) Indebtedness which is payable solely out of the property or
assets of a partnership, joint venture or similar entity of which we or
any of our subsidiaries or affiliates is a participant, or which is
secured by a lien on the property or assets owned or held by such
entity, without further recourse to or liability of us; or
(ii) Indebtedness not exceeding $20,000,000; or
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(e) one or more nonappealable final judgments, decrees or orders of any
court, tribunal, arbitrator, administrative or other governmental body or
similar entity for the payment of money aggregating more than $20,000,000
shall be rendered against us (excluding the amount thereof covered by
insurance) and shall remain undischarged, unvacated and unstayed for more
than 90 days, except while being contested in good faith by appropriate
proceedings; or
(f) certain events of bankruptcy, insolvency or reorganization in
respect of us.
If any Event of Default (other than an Event of Default due to certain
events of bankruptcy, insolvency or reorganization) has occurred and is
continuing, either the Trustee or the holders of not less than 25% in principal
amount of the Notes outstanding under the Indenture may declare the principal
of all Notes under the Indenture and interest accrued thereon to be due and
payable immediately.
The Trustee will be entitled, subject to the duty of the Trustee during a
default to act with the required standard of care, to be indemnified by the
holders of Notes before proceeding to exercise any right or power under the
Indenture at the request of such holders. Subject to such provisions in the
Indenture for the indemnification of the Trustee and certain other limitations,
the holders of a majority in principal amount of the Notes then outstanding may
direct the time, method and place of conducting any proceeding for any remedy
available to the Trustee or exercising any trust or power conferred on the
Trustee.
No holder of Notes may institute any action against us under the Indenture
(except actions for payment of overdue principal or interest) unless:
(1) such holder previously has given the Trustee written notice of the
default and continuance thereof;
(2) the holders of not less than 25% in principal amount of the Notes
then outstanding have requested the Trustee to institute such action and
offered the Trustee reasonable indemnity;
(3) the Trustee has not instituted such action within 60 days of the
request; and
(4) the Trustee has not received direction inconsistent with such
written request from the holders of a majority in principal amount of the
Notes then outstanding.
Defeasance and Covenant Defeasance
Defeasance
We will be deemed to have paid and will be discharged from any and all
obligations in respect of the Notes on the 123rd day after we have made the
deposit referred to below, and the provisions of the Indenture will cease to be
applicable with respect to the Notes (except for, among other matters, certain
obligations to register the transfer of or exchange of the Notes, to replace
stolen, lost or mutilated Notes, to maintain paying agencies and to hold funds
for payment in trust) if
(A) we have deposited with the Trustee, in trust, money and/or certain
U.S. government obligations that, through the payment of interest and
principal in respect thereof in accordance with their terms, will provide
money in an amount sufficient to pay the principal of, premium, if any, and
accrued interest on the Notes at the time such payments are due in
accordance with the terms of the Indenture,
(B) we have delivered to the Trustee
(i) an opinion of counsel to the effect that Note holders will not
recognize income, gain or loss for federal income tax purposes as a
result of the defeasance and will be subject to federal income tax on
the same amount and in the same manner and at the same times as would
have been the case if such deposit, defeasance and discharge had not
occurred, which opinion of counsel must be based upon a ruling of the
Internal Revenue Service to the same effect or a change in applicable
federal income tax law or related treasury regulations after the date
of the Indenture and
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(ii) an opinion of counsel to the effect that the defeasance trust
does not constitute an "investment company" within the meaning of the
Investment Company Act of 1940 and after the passage of 123 days
following the deposit, the trust fund will not be subject to the effect
of Section 547 of the U.S. Bankruptcy Code or Section 15 of the New
York Debtor and Creditor Law,
(C) immediately after giving effect to such deposit, no Event of
Default, or event that after the giving of notice or lapse of time or both
would become an Event of Default, will have occurred and be continuing on
the date of such deposit or during the period ending on the 123rd day after
the date of such deposit, and such deposit shall not result in a breach or
violation of, or constitute a default under, any other agreement or
instrument to which we are a party or by which we are bound and
(D) if at such time the Notes are listed on a national securities
exchange, we have delivered to the Trustee an opinion of counsel to the
effect that the Notes will not be delisted as a result of such deposit and
discharge.
Defeasance of Certain Covenants and Certain Events of Default
The provisions of the Indenture will cease to be applicable with respect to
(x) the covenants described in "--Certain Covenants" (other than those
with respect to the maintenance of our existence and those described under
the first paragraph of the caption "--Certain Covenants--Merger,
Consolidation, Sale, Lease or Conveyance"),
(y) clause (c) in "--Events of Default" with respect to such covenants
and
(z) clauses (d) and (e) in "--Events of Default" upon
(1) the deposit with the Trustee, in trust, of money and/or certain
U.S. government obligations that through the payment of interest and
principal in respect thereof in accordance with their terms will
provide money in an amount sufficient to pay the principal of, premium,
if any, and accrued interest on the Notes,
(2) the satisfaction of the conditions described in clauses (B)(ii),
(C) and (D) of the preceding paragraph and
(3) our delivery to the Trustee of an opinion of counsel to the
effect that, among other things, the holders of the Notes will not
recognize income, gain or loss for federal income tax purposes as a
result of such deposit and defeasance and will be subject to federal
income tax on the same amount and in the same manner and at the same
times as would have been the case if such deposit and defeasance had
not occurred.
Defeasance and Certain Other Events of Default
If we exercise our option to omit compliance with certain covenants and
provisions of the Indenture as described in the immediately preceding paragraph
and the Notes are declared due and payable because of the occurrence of an
Event of Default that remains applicable, the amount of money and/or U.S.
government obligations on deposit with the Trustee may not be sufficient to pay
amounts due on the Notes at the time of acceleration resulting from such Event
of Default. In such event, we will remain liable for such payments.
Book-Entry; Delivery and Form
General
The Notes, except for those sold to institutional "accredited investors" (as
defined in Rule 501(a)(1), (2), (3) or (7) under the Securities Act), will be
issued in the form of one or more fully registered Notes in global form
("Global Notes"). The Global Notes will be deposited with, or on behalf of, DTC
and registered in the name of DTC or its nominee. Notes sold to institutional
"accredited investors" will be delivered as definitive fully registered
certificates.
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Upon issuance of the Global Notes, DTC or its nominee will credit, on its
book-entry registration and transfer system, the number of Notes sold to
qualified institutional buyers pursuant to Rule 144A represented by such Global
Notes to the account of institutions that have accounts with DTC or its nominee
participants (the "DTC Participants") and Euroclear will credit on its book-
entry registration and transfer system the number of Notes sold to certain
persons in offshore transactions in reliance on Regulation S under the
Securities Act also represented by Global Notes, to the account of institutions
that have accounts with Euroclear or its nominee participants (the "Euroclear
Participants" and, collectively with the DTC Participants, the "Participants").
The accounts to be credited shall be designated by the initial purchasers.
Ownership of beneficial interests in the Global Notes will be limited to
Participants or persons that may hold interests through Participants. Ownership
of beneficial interests in such Global Notes will be shown on, and the transfer
of that ownership will be effected only through, records maintained by DTC or
its nominee (with respect to the Participants' interests) for such Global
Notes, or by Participants or persons that hold interests through Participants
(with respect to beneficial interests of persons other than Participants). The
laws of some jurisdictions may require that certain purchasers of securities
take physical delivery of such securities in definitive form. Such limits and
laws may impair the ability to transfer or pledge beneficial interests in the
Global Notes.
So long as DTC, or its nominee, is the registered holder of any Global
Notes, DTC or such nominee, as the case may be, will be considered the sole
legal owner of such Notes for all purposes under the Indenture and the Notes.
Except as set forth below, owners of beneficial interests in Global Notes will
not be entitled to have such Global Notes registered in their names, will not
receive or be entitled to receive physical delivery in exchange therefor and
will not be considered to be the owners or holders of such Global Notes for any
purpose under the Notes or the Indenture. We understand that under existing
industry practice, in the event an owner of a beneficial interest in a Global
Note desires to take any action that DTC, as the holder of such Global Note, is
entitled to take, DTC would authorize the Participants to take such action, and
that the Participants would authorize beneficial owners owning through such
Participants to take such action or would otherwise act upon the instructions
of beneficial owners owning through them.
Any payment of principal or interest due on the Notes on any interest
payment date or at maturity will be made available by us to the Trustee by such
date. As soon as possible thereafter, the Trustee will make such payments to
DTC or its nominee, as its nominee, as the case may be, as the registered owner
of the Global Notes representing such Notes in accordance with existing
arrangements between the Trustee and DTC.
We expect that DTC or its nominee, upon receipt of any payment of principal
or interest in respect of the Global Notes, will credit immediately the
accounts of the related participants with payments in amounts proportionate to
their respective beneficial interests in the principal amount of such Global
Notes as shown on the records of DTC. We also expect that payments by
Participants to owners of beneficial interests in the Global Notes held through
such Participants will be governed by standing instructions and customary
practices, as is now the case with securities held for the accounts of
customers in bearer form or registered in "street name," and will be the
responsibility of such Participants.
Neither we nor the Trustee nor any payment agent for the Global Notes will
have any responsibility or liability for any aspect of the records relating to
or payments made on account of beneficial ownership interests in any of the
Global Notes or for maintaining, supervising or reviewing any records relating
to such beneficial ownership interests or for other aspects of the relationship
between DTC and its Participants or the relationship between such Participants
and the owners of beneficial interests in the Global Notes owning through such
Participants.
Unless and until exchanged in whole or in part for Notes in definitive form
or for beneficial interests in an unrestricted Global Note, in each case in
accordance with the terms of the Indenture, the Global Notes may not be
transferred except as a whole by DTC to a nominee of DTC or by a nominee of DTC
to DTC or another nominee of DTC or by DTC or any such nominee to a successor
of DTC or a nominee of such successor.
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Although DTC has agreed to the foregoing procedures in order to facilitate
transfers of interests in the Global Notes among DTC Participants, it is under
no obligation to perform or continue to perform such procedures, and such
procedures may be discontinued at any time. Neither we nor the Trustee will
have any responsibility for the performance by DTC or its Participants or
indirect participants of their respective obligations under the rules and
procedures governing their operations. We and the Trustee may conclusively rely
on, and will be protected in relying on, instructions from DTC for all
purposes.
Certificated Notes
Notes that are originally issued to institutional "accredited investors" who
are not qualified institutional buyers will be sold in certificated form.
The Global Notes will be exchangeable for corresponding certificated Notes
registered in the name of persons other than DTC or its nominee only if (A) DTC
(1) notifies us that it is unwilling or unable to continue as depositary for
any of the Global Notes or (2) at any time ceases to be a clearing agency
registered under the Exchange Act, (B) there shall have occurred and be
continuing an Event of Default with respect to the applicable Notes or (C) we
execute and deliver to the Trustee an order that the Global Notes will be so
exchangeable. Any definitive Notes will be issued only in fully registered
form, and will be issued without coupons in denominations of $100,000 and any
integral multiple of $1,000 in excess thereof. Any definitive Notes so issued
will be registered in such names and in such denominations as DTC requests.
The Clearing System
DTC has advised us as follows: DTC is a limited-purpose trust company
organized under the laws of the State of New York, a member of the Federal
Reserve System, a "clearing corporation" within the meaning of the New York
Uniform Commercial Code, and a "clearing agency" registered pursuant to the
provisions of Section 17A of the Exchange Act. DTC was created to hold
securities of DTC Participants and to facilitate the clearance and settlement
of securities transactions among DTC Participants in such securities through
electronic book-entry changes in accounts of DTC Participants, thereby
eliminating the need for physical movement of securities certificates. DTC
Participants include securities brokers and dealers (which may include the
initial purchasers), banks, trust companies, clearing corporations and certain
other organizations. Access to DTC's book-entry system is also available to
others such as banks, brokers, dealers, and trust companies that clear through
or maintain a custodial relationship with DTC Participants, whether directly or
indirectly.
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REGISTRATION RIGHTS AGREEMENT
Pursuant to the Registration Rights Agreement, EME has agreed with the
initial purchasers, for the benefit of the holders of the Notes, that EME will
file and use its reasonable best efforts to cause to become effective, at its
cost, a registration statement with respect to a registered offer to exchange
the Notes for a series of debt securities of EME (the "Exchange Notes") which
are in all material respects substantially identical to the Notes. Upon such
registration statement being declared effective, EME will offer the Exchange
Notes in return for surrender of the Notes. Such offer will remain open for no
less than 30 days after the date notice of the exchange offer is mailed to the
Note holders. For each Note surrendered to EME under the exchange offer, the
Note holder will receive Exchange Notes in an equal principal amount. Interest
on each Exchange Note will accrue from the last date on which interest was paid
on the Note so surrendered or, if no interest has been paid, since the date set
forth on the cover of this offering circular.
In the event that EME determines in good faith that applicable
interpretations of the staff of the Securities and Exchange Commission or other
circumstances specified in the Registration Rights Agreement do not permit EME
to effect such an exchange offer, EME will, at its cost, use its reasonable
best efforts (subject to customary representations and agreements of the Note
holders) to have a shelf registration statement covering resale of the Notes
declared effective and kept effective until two years after the closing date of
the offering of the Notes (the "Closing Date"), subject to certain exceptions.
EME will, in the event of such a shelf registration, provide to each Note
holder copies of the prospectus, notify each Note holder when a registration
statement for the Notes has become effective and take certain other actions as
are appropriate to permit resale of the Notes.
In the event that such exchange offer is not commenced or such registration
statement is not declared effective within 270 days following the Closing Date,
the annual interest rates on the Notes will increase by one half of one percent
(50 basis points) effective on the 271st day following the Closing Date, which
increase will remain in effect until the date on which such exchange offer is
commenced or such registration statement will have become effective.
Each Note holder (other than certain specified holders) who wishes to
exchange its Notes for Exchange Notes in the exchange offer will be required to
represent that any Exchange Notes to be received by it will be acquired in the
ordinary course of business and that at the time of the commencement of the
exchange offer it will have no arrangement with any person to participate in
the distribution (within the meaning of the Securities Act) of the Exchange
Notes.
A Note holder that sells its Notes pursuant to a shelf registration
generally would be required to be named as a selling holder in the related
prospectus and to deliver a prospectus to purchasers, will be subject to
certain of the civil liability provisions under the Securities Act in
connection with such sale and will be required to agree in writing to be bound
by the provisions of the Registration Rights Agreement which are applicable to
such Note holder (including certain indemnification obligations).
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CERTAIN UNITED STATES FEDERAL INCOME TAX CONSIDERATIONS
The following summary describes certain material United States federal
income tax considerations of the acquisition, ownership and disposition of the
Notes. The summary is based on the Internal Revenue Code of 1986, as amended
(the "Code"), and regulations, rulings and judicial decisions as of the date
hereof, all of which may be repealed, revoked or modified with possible
retroactive effect. This discussion does not deal with holders that may be
subject to special tax rules (including, but not limited to, insurance
companies, tax-exempt organizations, financial institutions, dealers in
securities or currencies, holders whose functional currency is not the United
States dollar or holders who will hold the Notes as a hedge against currency
risks or as part of a straddle, synthetic security, conversion transaction or
other integrated investment comprised of the Notes and one or more other
investments). The summary is applicable only to purchasers that acquire the
Notes pursuant to the offering at the initial offering price and who will hold
the Notes as capital assets within the meaning of Section 1221 of the Code.
This summary is for general information only and does not address all aspects
of United States federal income taxation that may be relevant to holders of the
Notes in light of their particular circumstances, and it does not address any
tax consequences arising under the laws of any state, local or foreign taxing
jurisdiction. Prospective holders should consult their own tax advisors as to
the particular tax consequences to them of acquiring, holding or disposing of
the Notes.
As used herein, the term "United States Holder" means a beneficial owner of
a Note that is (i) a citizen or resident of the United States for United States
federal income tax purposes, (ii) a corporation created or organized under the
laws of the United States, any state thereof or the District of Columbia, (iii)
an estate the income of which is subject to United States federal income tax
without regard to its source or (iv) a trust if (x) a court within the United
States is able to exercise primary supervision over the administration of the
trust and one or more United States persons have the authority to control all
substantial decisions of the trust or (y) the trust has a valid election in
effect under applicable United States Treasury regulations to be treated as a
United States Holder. A "Non-United States Holder" is any beneficial holder of
a Note that is not a United States Holder.
United States Holders
It is anticipated that the Notes will not be issued with more than a de
minimis amount of original issue discount. In such case, interest on a Note
generally will be taxable to a United States Holder as ordinary income as it
accrues or is received in accordance with the United States Holder's method of
accounting for United States federal income tax purposes.
Failure of EME to consummate the exchange offer or to file or cause to be
declared effective the shelf registration statements as described in
"Registration Rights Agreement" will cause additional interest to accrue on the
Notes in the manner described therein. According to U.S. Treasury regulations,
the possibility of a change in the interest rate will not affect the amount of
interest income recognized by a United States Holder (or the timing of such
recognition) if the likelihood of the change, as of the date the Notes are
issued, is remote. EME believes that the likelihood of a change in the interest
rate on the Notes is remote and does not intend to treat the possibility of a
change in the interest rate as affecting the yield to maturity of any Note. In
the unlikely event that the interest rate on the Notes is increased, then such
increased interest may be treated as original issue discount, includible by a
United States Holder in income as such interest accrues, in advance of receipt
of any cash payment thereof. If, as anticipated, the issue price of the Notes
equals their stated principal amount, and based on EME's belief that the
likelihood of a change in the interest rate is remote, the Notes will not be
issued with original issue discount.
Upon the sale, exchange, redemption, retirement or other disposition of a
Note, a United States Holder generally will recognize gain or loss equal to the
difference between the amount realized upon the sale, exchange, redemption,
retirement or other disposition (not including amounts attributable to accrued
but unpaid interest, which will be taxable as such) and such United States
Holder's adjusted tax basis in the Note. A United States Holder's tax basis in
a Note will, in general, be the United States Holder's cost therefor. Such
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gain or loss will be capital gain or loss. Capital gain recognized by an
individual investor upon a disposition of a Note that has been held for more
than 12 months will generally be subject to a maximum tax rate of 20% or, in
the case of a Note that has been held for 12 months or less, will be subject to
tax at ordinary income tax rates.
A United States Holder will not recognize any taxable gain or loss on the
exchange of the Notes for Exchange Notes pursuant to the exchange offer, and a
United States Holder's tax basis and holding period in the Exchange Notes will
be the same as in the Notes.
Non-United States Holders
Under present United States federal income tax law, subject to the
discussion of backup withholding and information reporting below:
(a) payments of principal and interest on the Notes to any Non-United
States Holder will not be subject to United States federal income, branch
profits or withholding tax provided that (i) the Non-United States Holder
does not actually or constructively own 10% or more of the total combined
voting power of all classes of stock of EME entitled to vote, (ii) the Non-
United States Holder is not a bank receiving interest pursuant to a loan
agreement entered into in the ordinary course of its trade or business,
(iii) the Non-United States Holder is not a controlled foreign corporation
that is related to EME (directly or indirectly) through stock ownership,
(iv) such interest payments are not effectively connected with a United
States trade or business and (v) certain certification requirements are
met. Such certification will be satisfied if the beneficial owner of the
Note certifies on IRS Form W-8 or a substantially similar substitute form,
under penalties of perjury, that it is not a United States person and
provides its name and address, and (x) such beneficial owner files such
form with the withholding agent or (y) in the case of a Note held by a
securities clearing organization, bank or other financial institution that
holds customers' securities in the ordinary course of its trade or business
(a "financial institution") and holds the Note, such financial institution
certifies to EME or its agent under penalties of perjury that such
statement has been received from the beneficial owner by it or by a
financial institution between it and the beneficial owner and furnishes the
withholding agent with a copy thereof; and
(b) a Non-United States Holder will not be subject to United States
federal income or branch profits tax on gain realized on the sale,
exchange, redemption, retirement or other disposition of a Note, unless (i)
the gain is effectively connected with a trade or business carried on by
such holder within the United States or, if a treaty applies (and the
holder complies with applicable certification and other requirements to
claim treaty benefits), is generally attributable to a United States
permanent establishment maintained by the holder, or (ii) the holder is an
individual who is present in the United States for 183 days or more in the
taxable year of disposition and certain other requirements are met.
The Internal Revenue Service has recently amended the certification rules
described in clause (a) above. Non-United States Holders should be aware that
withholding certificates or statements that are valid on December 31, 1999 may
be treated as valid until the earlier of their expiration or December 31, 2000.
Certificates or statements received under the currently effective rules will
fail to be effective after December 31, 2000.
Backup Withholding and Information Reporting
In general, payments of interest and the proceeds of the sale, exchange,
redemption, retirement or other disposition of the Notes payable by a United
States paying agent or other United States intermediary will be subject to
information reporting. In addition, backup withholding at a rate of 31% will
apply to these payments if (i) in the case of a United States Holder, the
Holder fails to provide an accurate taxpayer information number, or fails to
certify that such Holder is not subject to backup withholding or fails to
report all interest and dividends required to be shown on its United States
federal income tax returns, or (ii) in the case of a Non-United States Holder,
the Holder fails to provide the certification on IRS Form W-8 described above
or
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otherwise does not provide evidence of exempt status. Certain United States
Holders (including, among others, corporations) and Non-United States Holders
that comply with certain certification requirements are not subject to backup
withholding. Any amount paid as backup withholding will be creditable against
the Holder's United States federal income tax liability provided that the
required information is timely furnished to the IRS. Holders of Notes should
consult their tax advisors as to their qualification for exemption from backup
withholding and the procedure for obtaining such an exemption. On October 6,
1997, new Treasury Regulations were issued that generally modify the
information reporting and backup withholding rules applicable to certain
payments made after December 31, 2000. In general, the new regulations would
not significantly alter the present rules discussed above, except in certain
special situations.
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TRANSFER RESTRICTIONS
The Notes have not been registered under the Securities Act and may not be
offered or sold within the United States or to, or for the account or benefit
of, U.S. persons (as defined in Regulation S under the Securities Act) except
to (a) qualified institutional buyers in reliance on the exemption from the
registration requirements of the Securities Act provided by Rule 144A, (b) a
limited number of institutional "accredited investors," as defined in Rule 501
(a)(1), (2), (3) or (7) under the Securities Act, and (c) certain persons in
offshore transactions in reliance on Regulation S.
Each purchaser of the Notes will be deemed to have represented and agreed as
follows (terms used below that are defined in Rule 144A or Regulation S, as
applicable, under the Securities Act are used below as defined in those rules
and regulations):
(1) it (a)(i) is a qualified institutional buyer, (ii) is aware that the
sale to it is being made in reliance on Rule 144A and (iii) is acquiring
the Notes for its own account or for the account of a qualified
institutional buyer, (b)(i) is an institutional "accredited investor" and
(ii) is concurrently with its purchase executing and delivering the
purchaser's letter described below, or (c) is not a U.S. person and is
purchasing the Notes in an offshore transaction pursuant to Regulation S;
(2) it understands that the Notes are being offered in a transaction not
involving any public offering in the United States within the meaning of
the Securities Act, that the Notes have not been and, except as described
in this offering circular, will not be registered under the Securities Act
and that (a) if in the future it decides to offer, resell, pledge or
otherwise transfer any Notes, those Notes may be offered, resold, pledged
or otherwise transferred only (i) to EME, (ii) inside the United States to
a person whom the seller reasonably believes is a qualified institutional
buyer in a transaction meeting the requirements of Rule 144A, (iii) outside
the United States in a transaction complying with the provisions of Rule
904 under the Securities Act and subject to EME's and the Trustee's right
prior to any such reoffer, resale or transfer to require the delivery of an
opinion of counsel, certification or other information reasonably
satisfactory to each of them that such reoffer, resale or transfer is in
compliance with the Securities Act and other applicable laws, (iv) pursuant
to an exemption from registration under the Securities Act provided by Rule
144 (if available), or (v) pursuant to an effective registration statement
under the Securities Act, in each of cases (ii) through (v), in accordance
with any applicable securities laws of any State of the United States, and
that (b) the purchaser will, and each subsequent holder is required to,
notify any subsequent purchaser of such Notes from it of the resale
restrictions referred to in clause (a) above;
(3) it acknowledges that none of EME, the initial purchasers or any
person representing EME or the initial purchasers has made any
representation to it with respect to EME, the initial purchasers, any
affiliates thereof or the offering of the Notes, other than the information
contained in this offering circular. The purchaser is purchasing the Notes
for its own account, or for one or more investor accounts for which it is
acting as a fiduciary or agent, in each case for investment, and not with a
view to, or for offer or sale in connection with, any distribution thereof
in violation of the Securities Act, subject to any requirements of law that
the disposition of its property or the property of such investor account at
all times remain within its or their control and subject to its or their
ability to resell the Notes pursuant to Rule 144A; and
(4) it understands that the Notes will, until the expiration of the
applicable holding period with respect to the Notes set forth in Rule
144(k) of the Securities Act, unless otherwise agreed by EME and the holder
thereof, bear a legend substantially to the following effect:
"THIS NOTE (OR ITS PREDECESSOR) WAS ORIGINALLY ISSUED IN A TRANSACTION
EXEMPT FROM REGISTRATION UNDER THE UNITED STATES SECURITIES ACT OF 1933
(THE "SECURITIES ACT"), AND THIS NOTE MAY NOT BE OFFERED, SOLD OR OTHERWISE
TRANSFERRED IN THE ABSENCE OF SUCH REGISTRATION OR AN APPLICABLE EXEMPTION
THEREFROM. EACH PURCHASER OF THIS NOTE IS HEREBY NOTIFIED THAT THE SELLER
OF THIS NOTE MAY BE RELYING ON THE EXEMPTION FROM THE PROVISIONS OF SECTION
5 OF THE SECURITIES ACT PROVIDED BY RULE 144A THEREUNDER.
54
<PAGE>
THE HOLDER OF THIS NOTE AGREES FOR THE BENEFIT OF EDISON MISSION ENERGY
THAT (A) THIS NOTE MAY BE OFFERED, RESOLD, PLEDGED OR OTHERWISE
TRANSFERRED, ONLY (I) TO EDISON MISSION ENERGY, (II) INSIDE THE UNITED
STATES TO A PERSON WHOM THE SELLER REASONABLY BELIEVES IS A QUALIFIED
INSTITUTIONAL BUYER (AS DEFINED IN RULE 144A UNDER THE SECURITIES ACT) IN A
TRANSACTION MEETING THE REQUIREMENTS OF RULE 144A, (III) OUTSIDE THE UNITED
STATES IN AN OFFSHORE TRANSACTION IN ACCORDANCE WITH RULE 904 UNDER THE
SECURITIES ACT, (IV) PURSUANT TO AN EXEMPTION FROM REGISTRATION UNDER THE
SECURITIES ACT PROVIDED BY RULE 144 THEREUNDER (IF AVAILABLE) OR (V)
PURSUANT TO AN EFFECTIVE REGISTRATION STATEMENT UNDER THE SECURITIES ACT,
IN EACH OF CASES (II) THROUGH (V) IN ACCORDANCE WITH ANY APPLICABLE
SECURITIES LAWS OF ANY STATE OF THE UNITED STATES, AND (B) THE HOLDER WILL,
AND EACH SUBSEQUENT HOLDER IS REQUIRED TO, NOTIFY ANY PURCHASER OF THIS
NOTE FROM IT OF THE RESALE RESTRICTIONS REFERRED TO IN (A) ABOVE."
Each purchaser of Notes that is an institutional "accredited investor" but
is not a qualified institutional buyer must execute and deliver a purchaser's
letter for the benefit of the initial purchasers and EME, substantially in the
form of Annex A to this offering circular, whereby such institutional
"accredited investor" (a) agrees to the restrictions on transfer set forth in
clause (2) above, (b) confirms that it is: (i) acquiring Notes with a minimum
purchase price of not less than $100,000 for its own account or for any
separate account for which it is acting; (ii) acquiring such Notes for its own
account or for certain qualified institutional accounts, as specified therein;
and (iii) not acquiring the Notes with a view to distribution thereof or with
any present intention of offering or selling any of the Notes except in
accordance with Rule 144A under the Securities Act or in accordance with Rule
904 under the Securities Act, and (c) acknowledges that the registrar and
transfer agent for the Notes will not be required to accept for registration of
transfer any Notes acquired by it, except upon presentation of evidence
satisfactory to EME and the transfer agent that the restrictions on transfer
set forth in clause (2) above have been complied with, and that any such Notes
will be in the form of definitive physical certificates bearing the legend set
forth in clause (4) above and the following additional legend:
"IN CONNECTION WITH ANY TRANSFER, THE HOLDER WILL DELIVER TO THE REGISTRAR
AND TRANSFER AGENT SUCH CERTIFICATES AND OTHER INFORMATION AS SUCH TRANSFER
AGENT MAY REASONABLY REQUIRE TO CONFIRM THAT THE TRANSFER COMPLIES WITH THE
FOREGOING RESTRICTIONS."
Consequently, such institutional "accredited investor" may not have its
Notes represented by the global certificate. See "Description of the Notes--
Book-Entry; Delivery and Form."
Registered or beneficial owners of the Notes who wish to exchange or
transfer their Notes will be required to make certain certifications and
deliver certain documents as set forth in the Indenture.
The Notes may not be sold or transferred to, and each purchaser by its
purchase of the Notes will be deemed to have represented and covenanted that it
is not acquiring the Notes for or on behalf of, and will not transfer the Notes
to, any pension or welfare plan as defined in Section 3 of the Employee
Retirement Income Security Act of 1974, as amended ("ERISA"), except that such
purchase for or on behalf of a pension or welfare plan shall be permitted:
(1) to the extent such purchase is made by or on behalf of a bank
collective investment fund maintained by the purchaser in which no plan
(together with any other plans maintained by the same employer or employee
organization) has an interest in excess of 10% of the total assets in such
collective investment fund, and the other applicable conditions of
Prohibited Transaction Class Exemption 91-38 issued by the Department of
Labor are satisfied;
(2) to the extent such purchase is made by or on behalf of an insurance
company pooled separate account maintained by the purchaser in which, at
any time while the Notes are outstanding, no plan
55
<PAGE>
(together with any other plans maintained by the same employer or employee
organization) has an interest in excess of 10% of the total of all assets
in such pooled separate account, and the other applicable conditions of
Prohibited Transaction Class Exemption 90-1 issued by the Department of
Labor are satisfied;
(3) to the extent such purchase is made on behalf of a plan by (A) an
investment adviser registered under the Investment Advisers Act of 1940, as
amended (the "1940 Act"), that had as of the last day of its most recent
fiscal year total assets under its management and control in excess of
$50.0 million and had stockholders' or partners' equity in excess of
$750,000, as shown in its most recent balance sheet prepared in accordance
with generally accepted accounting principles, or (B) a bank as defined in
Section 202(a)(2) of the 1940 Act with equity capital in excess of $1.0
million as of the last day of its most recent fiscal year, or (C) an
insurance company which is qualified under the laws of more than one state
to manage, acquire or dispose of any assets of a pension or welfare plan,
which insurance company has as of the last day of its most recent fiscal
year, net worth in excess of $1.0 million and which is subject to
supervision and examination by a State authority having supervision over
insurance companies and, in any case, such investment adviser, bank or
insurance company is otherwise a qualified professional asset manager, as
such term is used in Prohibited Transaction Class Exemption 84-14 issued by
the Department of Labor, and the assets of such plan when combined with the
assets of other plans established or maintained by the same employer (or
affiliate thereof) or employee organization and managed by such investment
adviser, bank or insurance company, do not represent more than 20% of the
total client assets managed by such investment adviser, bank or insurance
company at the time of the transaction, and the other applicable conditions
of such exemption are otherwise satisfied;
(4) to the extent such plan is a governmental plan (as defined in
Section 3 of ERISA) which is not subject to the provisions of Title I of
ERISA or Section 401 of the Code;
(5) to the extent such purchase is made by or on behalf of an insurance
company using the assets of its general account, the reserves and
liabilities for the general account contracts held by or on behalf of any
plan, together with any other plans maintained by the same employer (or its
affiliates) or employee organization, do not exceed 10% of the total
reserves and liabilities of the insurance company general account
(exclusive of separate account liabilities), plus surplus as set forth in
the National Association of Insurance Commissioners Annual Statement filed
with the state of domicile of the insurer, in accordance with Prohibited
Transaction Class Exemption 95-60, and the other applicable conditions of
such exemption and otherwise satisfied;
(6) to the extent such purchase is made by an in-house asset manager
within the meaning of Part IV(a) of Prohibited Transaction Class Exemption
96-23, such manager has made or properly authorized the decision for such
plan to purchase Notes, under circumstances such that Prohibited
Transaction Class Exemption 96-23 is applicable to the purchase and holding
of such Notes; or
(7) to the extent such purchase will not otherwise give rise to a
transaction described in Section 406 or Section 4975(c)(1) of the Code for
which a statutory or administrative exemption is unavailable.
56
<PAGE>
PLAN OF DISTRIBUTION
Subject to the terms and conditions set forth in the purchase agreement
dated June 23, 1999, we have agreed to sell to Credit Suisse First Boston
Corporation, Lehman Brothers Inc. and SG Cowen Securities Corp., who will be
the initial purchasers, the following principal amounts of Notes:
<TABLE>
<CAPTION>
Initial Purchasers Principal Amount of Notes
------------------ -------------------------
<S> <C>
Credit Suisse First Boston Corporation........... $420,000,000
Lehman Brothers Inc.............................. 120,000,000
SG Cowen Securities Corp......................... 60,000,000
------------
Total.......................................... $600,000,000
============
</TABLE>
The purchase agreement provides that the initial purchasers are obligated to
purchase all of the Notes if any are purchased. The purchase agreement also
provides that if an initial purchaser defaults, the purchase commitments of
non-defaulting initial purchasers may be increased or the offering may be
terminated.
The initial purchasers propose to offer the Notes initially at the offering
price on the cover page of this offering circular. After the initial offering,
the offering price may be changed.
The Notes have not been registered under the Securities Act and may not be
offered or sold within the United States or to, or for the account or benefit
of, U.S. persons except to qualified institutional buyers in reliance on Rule
144A, to a limited number of institutional accredited investors and to certain
persons in offshore transactions in reliance on Regulation S. The initial
purchasers have agreed that, except as permitted under the purchase agreement,
they will not offer, sell or deliver the Notes as part of their distribution at
any time within the United States or to, or for the account or benefit of, U.S.
persons, and they will have sent to each dealer to which they sell Notes in
reliance on Regulation S during such restricted period a confirmation or other
notice setting forth the restrictions on offers and sales of the Notes within
the United States or to, or for the account or benefit of, U.S. persons. Terms
used in this paragraph have the meanings given to them by Regulation S. Resales
of the Notes are restricted as described above in "Transfer Restrictions."
In addition, an offer or sale of the Notes within the United States by a
broker/dealer (whether or not it is participating in the offering) may violate
the registration requirements of the Securities Act if such offer or sale is
made otherwise than pursuant to Rule 144A.
Each of the initial purchasers severally represent and agree that:
(1) it has not offered or sold, and prior to the date six months after
the date of issuance of the Notes will not offer or sell, any Notes to
persons in the United Kingdom except to persons whose ordinary activities
involve them in acquiring, holding, managing or disposing of investments
(as principal or agent) for the purposes of their businesses or otherwise
in circumstances which have not resulted and will not result in an offer to
the public in the United Kingdom within the meaning of the Public Offers of
Securities Regulations 1995;
(2) it has complied and will comply with all applicable provisions of
the Financial Services Act 1986 with respect to anything done by it in
relation to the Notes in, from or otherwise involving the United Kingdom;
and
(3) it has only issued or passed on and will only issue or pass on in
the United Kingdom any document received by it in connection with the issue
of the Notes to a person who is of a kind described in Article 11(3) of the
Financial Services Act 1986 (Investment Advertisements) (Exemptions) Order
1996 or is a person to whom such document may otherwise lawfully be issued
or passed on.
The Notes are new securities for which there currently is no market. The
initial purchasers have advised us that they presently intend to make a market
in the Notes as permitted by applicable law. However, the initial
57
<PAGE>
purchasers are not obligated to make a market in the Notes and any such market-
making may be discontinued at any time at the sole discretion of the initial
purchasers. Accordingly, we cannot assure you that any market for the Notes
will develop or that any market that does develop will be liquid.
We have agreed to indemnify the initial purchasers against certain
liabilities or to contribute to payments which they may be required to make in
respect thereof.
The initial purchasers and certain of their affiliates have engaged in
transactions with and performed commercial banking and investment banking
services for us and our affiliates from time to time for which they receive
customary banking fees and commissions.
The initial purchasers may engage in over-allotment, stabilizing
transactions, covering transactions and penalty bids in accordance with
Regulation M under the Exchange Act, as described below:
. Over-allotment involves sales in excess of the offering size, which
creates a short position for the initial purchasers.
. Stabilizing transactions permit bids to purchase the underlying security
so long as the stabilizing bids do not exceed a specified maximum.
. Covering transactions involve purchases of the Notes in the open market
after the distribution has been completed in order to cover short
positions.
. Penalty bids permit the initial purchasers to reclaim a selling
concession from a broker/dealer when the Notes originally sold by such
broker/dealer are repurchased in a covering transaction to cover short
positions.
Such stabilizing transactions, covering transactions and penalty bids may
cause the price of the Notes to be higher than it would otherwise be in the
absence of such transactions. If the initial purchasers commence any of these
transactions, they may discontinue them at any time.
58
<PAGE>
NOTICE TO CANADIAN RESIDENTS
Resale Restrictions
The distribution of the Notes in Canada is being made only on a private
placement basis exempt from the requirement that we prepare and file a
prospectus with the securities regulatory authorities in each province where
trades of the Notes are effected. Accordingly, any resale of the Notes in
Canada must be made in accordance with applicable securities laws which will
vary depending on the relevant jurisdiction, and which may require resales to
be made in accordance with available statutory exemptions or pursuant to a
discretionary exemption granted by the applicable Canadian securities
regulatory authority. Purchasers are advised to seek legal advice prior to any
resale of the Notes.
Representations of purchasers
Each purchaser of the Notes in Canada who receives a purchase confirmation
will be deemed to represent to us and the dealer from whom such purchase
confirmation is received that (i) such purchaser is entitled under applicable
provincial securities laws to purchase such Notes without the benefit of a
prospectus qualified under such securities laws, (ii) where required by law,
such purchaser is purchasing as a principal and not as an agent, and (iii) such
purchaser has reviewed the text above in "--Resale Restrictions."
Rights of Action (Ontario Purchasers)
The securities being offered are those of a foreign issuer, and Ontario
purchasers will not receive the contractual right of action prescribed by
Ontario securities law. As a result, Ontario purchasers must rely on other
remedies that may be available, including common law rights of action for
damages or recission or rights of action under the civil liability provisions
of the U.S. federal securities laws. Following a decision of the U.S. Supreme
Court, it is possible that Ontario purchasers will not be able to rely upon the
remedies set out in Section 12(2) of the United States Securities Act of 1933
where securities are being offered under a U.S. private placement memorandum
such as this document.
Enforcement of Legal Rights
All of the issuers, directors and officers as well as the experts named in
this offering circular may be located outside Canada and, as a result, it may
not be possible for Canadian purchasers to effect service of process within
Canada upon the issuer or such persons. All or a substantial portion of the
assets of the issuer and such persons may be located outside Canada and, as a
result, it may not be possible to satisfy a judgment against the issuer or such
persons in Canada or to enforce a judgment obtained in Canadian courts against
such issuer or persons outside Canada.
Notice to British Columbia Residents
A purchaser of the Notes to whom the Securities Act (British Columbia)
applies is advised that such purchaser is required to file with the British
Columbia Securities Commission a report within ten days of the sale of any
Notes acquired by such purchaser pursuant to the offering made pursuant to this
offering circular. Such report must be in the form attached to British Columbia
Securities Commission Blanket Order BOR #95/17, a copy of which may be obtained
from us. Only one such report must be filed in respect of Notes acquired on the
same date and under the same prospectus exemption.
Taxation and Eligibility for Investment
Canadian purchasers of Notes should consult their own legal and tax advisors
with respect to the tax consequences of an investment in the Notes in their
particular circumstances and with respect to the eligibility of the Notes for
investment by the purchaser under relevant Canadian legislation.
59
<PAGE>
LEGAL MATTERS
Certain legal matters with respect to the Notes will be passed upon for EME
by Skadden, Arps, Slate, Meagher & Flom LLP, New York, New York. Skadden, Arps,
Slate, Meagher & Flom LLP also represents the initial purchasers from time to
time. Latham & Watkins, New York, New York, will pass upon certain legal
matters for the initial purchasers in connection with the issuance of the
Notes. Latham & Watkins also represents EME and its affiliates from time to
time.
AVAILABLE INFORMATION
EME is subject to the informational requirements of the Exchange Act and, in
accordance therewith, files reports and information statements and other
information with the Securities and Exchange Commission. Such reports and
information statements and other information filed by EME with the Securities
and Exchange Commission can be inspected and copied at the Public Reference
Section of the Securities and Exchange Commission at Room 1024, Judiciary
Plaza, 450 Fifth Street, N.W., Washington, D.C. 20549, and at the regional
offices of the Securities and Exchange Commission located at Seven World Trade
Center, 13th Floor, New York, New York 10048 and 500 West Madison Street, Suite
1400, Chicago, Illinois 60661. Copies of such material can be obtained from the
Public Reference Section of the Securities and Exchange Commission at Room
1024, Judiciary Plaza, 450 Fifth Street, N.W., Washington, D.C. 20549 at
prescribed rates. The Securities and Exchange Commission maintains a Web site
that contains reports, proxy and information statements and other materials
that are filed through the Securities and Exchange Commission's Electronic Data
Gathering, Analysis and Retrieval (EDGAR) system. This Web site can be accessed
at http://www.sec.gov.
INCORPORATION OF CERTAIN DOCUMENTS BY REFERENCE
The following documents filed with the Securities and Exchange Commission
are incorporated by reference into this offering circular:
(i) EME's Annual Report on Form 10-K for the year ended December 31,
1998;
(ii) EME's Current Report on Form 8-K dated March 18, 1999; and
(iii) EME's Quarterly Report on Form 10-Q for the quarter ended March
31, 1999.
Any statement contained in a document incorporated by reference herein will
be deemed to be modified or superseded for purposes of this offering circular
to the extent that a statement contained herein modifies or supersedes such
statement. Any such statement so modified or superseded will not be deemed to
constitute a part of this offering circular except as so modified or
superseded.
60
<PAGE>
ANNEX A
FORM OF LETTER TO BE DELIVERED BY ACCREDITED INVESTORS
Edison Mission Energy
18101 Von Karman Avenue, Suite 1700
Irvine, California 92612-1046
Credit Suisse First Boston Corporation
Lehman Brothers Inc.
SG Cowen Securities Corp.
c/o Credit Suisse First Boston Corporation
Eleven Madison Avenue
New York, NY 10010-3629
Attention: Transactions Advisory Group
Dear Sirs:
We are delivering this letter in connection with an offering of $600,000,000
of 7.73% Senior Notes due June 15, 2009 (the "Notes") of Edison Mission Energy,
a California corporation (the "Company"), as described in the Confidential
Offering Circular (the "Offering Circular") relating to the offering.
We hereby confirm that:
(i) we are an "accredited investor" within the meaning of Rule
501(a)(1), (2) or (3) under the Securities Act of 1933, as amended (the
"Securities Act"), or an entity in which all of the equity owners are
accredited investors within the meaning of Rule 501(a)(1), (2) or (3) under
the Securities Act (an "Institutional Accredited Investor");
(ii) (A) any purchase of the Notes by us will be for our own account or
for the account of one or more other Institutional Accredited Investors or
as fiduciary for the account of one or more trusts, each of which is an
"accredited investor" within the meaning of Rule 501(a)(7) under the
Securities Act and for each of which we exercise sole investment discretion
or (B) we are a "bank", within the meaning of Section 3(a)(2) of the
Securities Act, or a "savings and loan association" or other institution
described in Section 3(a)(5)(A) of the Securities Act that is acquiring the
Notes as fiduciary for the account of one or more institutions for which we
exercise sole investment discretion;
(iii) in the event that we purchase any of the Notes, we will acquire
Notes having a minimum purchase price of not less than $100,000 for our own
account or for any separate account for which we are acting;
(iv) we have such knowledge and experience in financial and business
matters that we are capable of evaluating the merits and risks of
purchasing the Notes;
(v) we are not acquiring the Notes with a view to distribution thereof
or with any present intention of offering or selling any of the Notes,
except inside the United States in accordance with Rule 144A under the
Securities Act or outside the United States in accordance with Regulation S
under the Securities Act, as provided below, provided that the disposition
of our property and the property of any accounts for which we are acting as
fiduciary shall remain at all times within our control; and
(vi) we have received a copy of the Offering Circular relating to the
offering of the Notes and acknowledge that we have had access to such
financial and other information, and have been afforded the opportunity to
ask such questions of representatives of the Company and receive answers
thereto, as we deem necessary in connection with our decision to purchase
the Notes.
We understand that the Notes are being offered in a transaction not
involving any public offering within the United States within the meaning of
the Securities Act and that the Notes have not been registered under the
Securities Act, and we agree, on our own behalf and on behalf of each account
for which we acquire any Notes, that if in the future we decide to resell,
pledge or otherwise transfer such Notes, such Notes may be offered, resold,
pledged or otherwise transferred only (i) to the Company, (ii) inside the
United States to a person who we reasonably believe is a "qualified
institutional buyer" (as defined in Rule 144A under the
A-1
<PAGE>
Securities Act) in a transaction meeting the requirements of Rule 144A, (iii)
outside the United States in a transaction in accordance with Rule 904 under
the Securities Act, (iv) pursuant to an exemption from registration under the
Securities Act provided by Rule 144 thereunder (if available) or (v) pursuant
to an effective registration statement under the Securities Act, in each of
cases (ii) through (v), in accordance with any applicable securities laws of
any State of the United States or any other applicable jurisdiction. We
understand that the registrar and transfer agent for the Notes will not be
required to accept for registration of transfer any Notes acquired by us,
except upon presentation of evidence satisfactory to the Company and the
transfer agent that the foregoing restrictions on transfer have been complied
with. We further understand that any Notes acquired by us will be in the form
of definitive physical certificates and will bear a legend reflecting the
substance of this paragraph.
We acknowledge that you, the Company and others will rely upon our
confirmations, acknowledgments and agreements set forth herein, and we agree to
notify you promptly in writing if any of our representations or warranties
herein ceases to be accurate and complete.
THIS LETTER SHALL BE GOVERNED BY, AND CONSTRUED IN ACCORDANCE WITH, THE LAWS
OF THE STATE OF NEW YORK, WITHOUT REGARD TO PRINCIPLES OF CONFLICTS OF LAWS.
Date: _______________________________ _____________________________________
(Name of Purchaser)
By: _________________________________
Name:
Title:
Address:
A-2
<PAGE>
[LOGO OF EDISON MISSION ENERGY APPEARS HERE]
<TABLE> <S> <C>
<PAGE>
<ARTICLE> 5
<LEGEND>
THIS SCEHDULE CONTAINS SUMMARY FINANCIAL INFORMATION EXTRACTED FROM EDISON
MISSION ENERGY AND SUBSIDIARIES FINANCIAL STATEMENTS AND IS QUALIFIED IN ITS
ENTIRETY BY REFERENCE TO SUCH FINANCIAL STATEMENTS.
</LEGEND>
<MULTIPLIER> 1,000
<S> <C>
<PERIOD-TYPE> 6-MOS
<FISCAL-YEAR-END> DEC-31-1999
<PERIOD-START> APR-01-1999
<PERIOD-END> JUN-30-1999
<CASH> 808,280
<SECURITIES> 0
<RECEIVABLES> 98,770
<ALLOWANCES> 0
<INVENTORY> 0
<CURRENT-ASSETS> 1,039,294
<PP&E> 5,016,679
<DEPRECIATION> 300,609
<TOTAL-ASSETS> 8,158,191
<CURRENT-LIABILITIES> 1,151,781
<BONDS> 4,161,114
234,032
118,103
<COMMON> 64,130
<OTHER-SE> 929,406
<TOTAL-LIABILITY-AND-EQUITY> 8,158,191
<SALES> 0
<TOTAL-REVENUES> 433,369
<CGS> 0
<TOTAL-COSTS> 223,049
<OTHER-EXPENSES> 0
<LOSS-PROVISION> 0
<INTEREST-EXPENSE> 130,770
<INCOME-PRETAX> 77,086
<INCOME-TAX> 13,675
<INCOME-CONTINUING> 0
<DISCONTINUED> 0
<EXTRAORDINARY> 0
<CHANGES> 13,840
<NET-INCOME> 49,571
<EPS-BASIC> 0
<EPS-DILUTED> 0
</TABLE>
