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SECURITIES AND EXCHANGE COMMISSION
WASHINGTON, D.C. 20549
FORM 10-K
[X] ANNUAL REPORT PURSUANT TO SECTION 13 OR 15(D) OF THE SECURITIES
EXCHANGE ACT OF 1934
FOR THE FISCAL YEAR ENDED DECEMBER 31, 1993
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COMMISSION FILE NUMBER 1-9936
SCECORP
(EXACT NAME OF REGISTRANT AS SPECIFIED IN ITS CHARTER)
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CALIFORNIA 95-4137452
(STATE OR OTHER JURISDICTION OF (I.R.S. EMPLOYER
INCORPORATION OR ORGANIZATION) IDENTIFICATION NO.)
2244 WALNUT GROVE AVENUE (818) 302-2222
ROSEMEAD, CALIFORNIA 91770 (REGISTRANT'S TELEPHONE
(ADDRESS OF PRINCIPAL (ZIP CODE) NUMBER, INCLUDING AREA CODE)
EXECUTIVE OFFICES)
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Securities registered pursuant to Section 12(b) of the Act:
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NAME OF EACH EXCHANGE
TITLE OF EACH CLASS ON WHICH REGISTERED
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Common Stock New York and Pacific
(also listed on London
Exchange)
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Securities registered pursuant to Section 12(g) of the Act: None
Indicate by check mark whether the registrant (1) has filed all
reports required to be filed by Section 13 or 15(d) of the Securities Exchange
Act of 1934 during the preceding 12 months (or for such shorter period that the
registrant was required to file such reports), and (2) has been subject to such
filing requirements for the past 90 days. Yes X No
Indicate by check mark if disclosure of delinquent filers pursuant to
Item 405 of Regulation S-K is not contained herein, and will not be contained,
to the best of registrant's knowledge, in definitive proxy or information
statements incorporated by reference in Part III of this Form 10-K or any
amendment to this Form 10-K. [ ]
The aggregate market value of registrant's voting stock held by
non-affiliates was approximately $8,118,598,988 on or about March 1, 1994,
based upon prices reported on the New York Stock Exchange. As of March 1,
1994, there were 447,799,172 shares of Common Stock outstanding.
DOCUMENTS INCORPORATED BY REFERENCE
Portions of the following documents listed below have been
incorporated by reference into the parts of this report so indicated.
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(1) Designated portions of the Annual Report to Shareholders
for the year ended December 31, 1993 . . . . . . . . . . . . . . . . . . . . Parts I, II and IV
(2) Designated portions of the Joint Proxy Statement relating
to registrant's 1994 Annual Meeting of Shareholders . . . . . . . . . . . . Part III
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TABLE OF CONTENTS
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ITEM PAGE
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PART I
1. Business . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 1
Business of SCEcorp . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 1
Regulation of SCEcorp . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 1
Environmental Matters . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 2
Business of Southern California Edison Company . . . . . . . . . . . . . . . . . . . . . 4
Regulation of Edison . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 5
Rate Matters . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 5
Fuel Supply . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 11
Business of The Mission Group and its Subsidiaries . . . . . . . . . . . . . . . . . . . 13
2. Properties . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 14
Existing Utility Generating Facilities . . . . . . . . . . . . . . . . . . . . . . 14
El Paso Electric Company ("El Paso") Bankruptcy . . . . . . . . . . . . . . . . . . 16
Construction Program and Capital Expenditures . . . . . . . . . . . . . . . . . . . 16
Nuclear Power Matters . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 18
Nuclear Waste Policy Act . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 19
Competitive Environment . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 20
3. Legal Proceedings . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 21
Antitrust Matters . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 21
Environmental Litigation . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 22
San Onofre Personal Injury Litigation . . . . . . . . . . . . . . . . . . . . . . . 23
4. Submission of Matters to a Vote of Security Holders . . . . . . . . . . . . . . . . . . 23
Executive Officers of the Registrant . . . . . . . . . . . . . . . . . . . . . . . . . . 24
PART II
5. Market for Registrant's Common Equity and Related
Stockholder Matters . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 30
6. Selected Financial Data . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 30
7. Management's Discussion and Analysis of Results of
Operations and Financial Condition . . . . . . . . . . . . . . . . . . . . . . . . 30
8. Financial Statements and Supplementary Data . . . . . . . . . . . . . . . . . . . . . . 30
9. Changes in and Disagreements with Accountants on
Accounting and Financial Disclosure . . . . . . . . . . . . . . . . . . . . . . . . 30
PART III
10. Directors and Executive Officers of the Registrant . . . . . . . . . . . . . . . . . . . 31
11. Executive Compensation . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 31
12. Security Ownership of Certain Beneficial Owners and
Management . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 31
13. Certain Relationships and Related Transactions . . . . . . . . . . . . . . . . . . . . . 31
PART IV
14. Exhibits, Financial Statement Schedules, and Reports on
Form 8-K . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 31
Report of Independent Public Accountants on Supplemental
Schedules . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 33
Signatures . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 49
Exhibit Index . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 50
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PART I
ITEM 1. BUSINESS
BUSINESS OF SCECORP
SCEcorp was incorporated on April 20, 1987, under the laws of the
State of California for the purpose of becoming the parent holding company of
Southern California Edison Company ("Edison"), a California public utility
corporation. SCEcorp owns all of the issued and outstanding common stock of
Edison and, in addition, owns all of the issued and outstanding capital stock
of The Mission Group ("Mission Group"), which in turn owns the stock of
subsidiaries engaged in nonutility businesses. These subsidiaries are
currently engaged in developing cogeneration and other energy projects
("Mission Energy"), making financial investments in electric generating
facilities and other assets ("Mission First Financial") and developing,
managing, and selling existing real estate projects ("Mission Land").
SCEcorp is engaged solely in the business of holding for investment
the stock of its subsidiaries and is not presently conducting any independent
business activities. For the year ended December 31, 1993, Edison and Mission
Group accounted for 99.3% and 0.7%, respectively, of the net income of SCEcorp.
At December 31, 1993, Edison had 16,487 full-time employees and Mission Group
and its subsidiaries had 706 full-time employees. Currently, SCEcorp has no
employees of its own.
The principal executive offices of SCEcorp are located at 2244 Walnut
Grove Avenue, Rosemead, California 91770, and its telephone number is (818)
302-2222.
REGULATION OF SCECORP
SCEcorp and its subsidiaries are exempt from all provisions, except
Section 9(a)(2), of the Public Utility Holding Company Act of 1935 ("Holding
Company Act") on the basis that SCEcorp and Edison are incorporated in the same
state and their business is predominately intrastate in character and carried
on substantially in the state of incorporation. It is necessary for SCEcorp to
file an annual exemption statement with the Securities and Exchange Commission
("SEC"), and the exemption may be revoked by the SEC upon a finding that the
exemption may be detrimental to the public interest or the interest of
investors or consumers. SCEcorp has no intention of becoming a registered
holding company under the Holding Company Act.
SCEcorp is not a public utility under the laws of the State of
California and is not subject to regulation as such by the California Public
Utilities Commission ("CPUC"). See "Business of Southern California Edison
Company--Regulation of Edison" below for a description of the regulation of
Edison by the CPUC. However, the CPUC decision authorizing Edison to
reorganize into a holding company structure contains certain conditions, which,
among other things, ensure the CPUC access to books and records of SCEcorp and
its affiliates which relate to transactions with Edison; require SCEcorp and
its subsidiaries to employ accounting and other procedures and controls to
ensure full review by the CPUC and to protect against subsidization of
nonutility activities by Edison's customers; require that all transfers of
market, technological or similar data from Edison to SCEcorp or its affiliates
be made at market value; preclude Edison from guaranteeing any obligations of
SCEcorp without prior written consent from the CPUC; provide for royalty
payments to be paid by SCEcorp or its subsidiaries in connection with the
transfer of product rights, patents, copyrights or similar legal rights
from
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Edison; and prevent SCEcorp and its subsidiaries from providing certain
facilities and equipment to Edison except through competitive bidding. In
addition, the decision provides that Edison shall maintain a balanced capital
structure in accordance with prior CPUC decisions, that Edison's dividend
policy shall continue to be established by Edison's Board of Directors as
though Edison were a comparable stand-alone utility company, and that the
capital requirements of Edison, as determined to be necessary to meet Edison's
service obligations, shall be given first priority by the Boards of Directors
of SCEcorp and Edison.
ENVIRONMENTAL MATTERS
Legislative and regulatory activities in the areas of air and water
pollution, waste management, hazardous chemical use, noise abatement, land use,
aesthetics and nuclear control continue to result in the imposition of numerous
restrictions on SCEcorp's subsidiaries with respect to the operation of
existing facilities, on the timing, cost, location, design, construction and
operation of new facilities required to meet future load requirements, and on
the cost of mitigating the effect of past operations on the environment. These
activities substantially affect future planning and will continue to require
modifications of existing facilities and operating procedures. SCEcorp is
unable to predict the extent to which additional regulations may affect the
operations and capital expenditure requirements of its subsidiaries.
The Clean Air Act provides the statutory framework to implement a
program for achieving national ambient air quality standards and provides for
maintenance of air quality in areas exceeding such standards. The Clean Air
Act was amended in 1990, giving the South Coast Air Quality Management District
("SCAQMD") 20 years to achieve all the federal air quality standards. The
SCAQMD's Air Quality Management Plan ("AQMP"), adopted in 1991, demonstrates a
commitment to attain federal air quality standards within 20 years. Consistent
with the requirements of the AQMP and the Clean Air Act Amendments of 1990
("CAAA"), the SCAQMD adopted rules to reduce emissions of oxides of nitrogen
("NOx") from combustion turbines, internal combustion engines, industrial
coolers and utility boilers. On October 15, 1993, the SCAQMD adopted the
Regional Clean Air Incentives Market ("RECLAIM") which replaces most of the
previous rule requirements with a market mechanism for NOx emission trading
(trading credits). RECLAIM will, however, still require Edison to reduce NOx
emissions through retrofit or purchase of trading credits on all basin
generation by over 86% by 2003. In Ventura County, a NOx rule was adopted
requiring more than an 88% NOx reduction by June 1996 at all utility boilers.
Edison's expected total cost to meet these requirements is approximately
$330,000,000 of capital expenditures.
The CAAA do not require any significant additional emissions control
expenditures that are identifiable at this time. The amendments call for a
five-year study of the sources and causes of regional haze in the southwestern
U.S. The extent to which this study may require sulfur dioxide emissions
reductions at Edison's Mohave Generating Station ("Mohave") is not known. The
acid rain provisions of the amended Clean Air Act also put an annual limit on
sulfur dioxide emissions allowed from power plants. Edison will receive more
sulfur dioxide allowances than it requires for its projected operations. The
CAAA also require the Environmental Protection Agency ("EPA") to carry out a
three-year study of risk to public health from emissions of toxic air
contaminants from power plants, and to regulate such emissions only if
required. As a result of a petition by Mohave County in the State of Arizona,
the Nevada Department of Environmental Protection ("NDEP") studied the impact
of the plume from Edison's Mohave plant on the Mohave area air quality. The
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regulatory outcome requires Edison to meet a new lower opacity limit in early
1994. The NDEP will review the opacity limit again in 1995 in conjunction with
an ongoing tracer study being conducted by the EPA and evaluate potential
impacts on visibility in the Grand Canyon from sulfur dioxide emissions. Until
more definitive information on tracer study results are available, Edison
expects to meet all the present regulations through improved operations at the
plant.
Regulations under the Clean Water Act require permits for the
discharge of certain pollutants into waters of the United States. Under this
act, the EPA issues effluent limitation guidelines, pretreatment standards and
new source performance standards for the control of certain pollutants.
Individual states may impose even more stringent limitations. In order to
comply with guidelines and standards applicable to steam electric power plants,
Edison incurs additional expenses and capital expenditures. Edison presently
has discharge permits for all applicable facilities.
The Safe Drinking Water and Toxic Enforcement Act prohibits the
exposure to individuals of chemicals known to the State of California to cause
cancer or reproductive harm and the discharge of such listed chemicals into
potential sources of drinking water. Additional chemicals are continuously
being put on the state's list, requiring constant monitoring by Edison.
The State of California has adopted a policy discouraging the use of
fresh water for plant cooling purposes at inland locations. Such a policy,
when taken in conjunction with existing federal and state water quality
regulations and coastal zone land use restrictions, could substantially
increase the difficulty of siting new generating plants anywhere in California.
SCEcorp has identified 46 sites for which any of its subsidiaries, are
or may be, responsible for remediation under environmental laws. SCEcorp's
subsidiaries are participating in investigations and cleanups at a number of
these sites and SCEcorp has recorded a $60,000,000 liability for the estimated
minimum costs to clean up several sites. Additional costs may be incurred as
progress is made in determining the magnitude of required remedial actions, as
the share of these costs attributable to SCEcorp's subsidiaries in proportion
to other responsible parties is determined and as additional investigations and
cleanups are performed.
The CPUC currently allows Edison rate recovery of environmental-
cleanup costs, subject to reasonableness reviews. Edison filed
for a reasonableness review of costs incurred through 1991 at two hazardous
substance sites. Hearings have been delayed due to a 1992 CPUC decision
involving another California utility, which concluded that the current
procedure may not be appropriate for these costs and requested interested
parties to recommend alternatives. In November 1993, the major California
utilities, the DRA and others filed a collaborative report recommending an
incentive mechanism, which would require shareholders to fund 10% of cleanup
costs. Shareholders would have the opportunity to recover these costs through
insurance. Accordingly, Edison has recorded a regulatory asset which
represents 90% of the estimated cleanup costs for sites covered by this
proposed mechanism. The remaining sites' cleanup costs are expected to be
immaterial and would be recovered through base rates. If approved by the CPUC,
Edison would be allowed to recover 90% of cleanup costs incurred to date under
the reasonableness review procedure ($11,000,000). A March 10, 1994 proposed
decision issued by a CPUC ALJ accepted the collaborative report's
recommendation. A final CPUC decision is expected in early 1994.
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Twenty of the 46 sites identified are Edison's former manufactured gas
plant sites. Edison's cleanup responsibility for these sites is based on
Edison's, or a predecessor company's, ownership or operation of the plants.
These gas plants were operated for the production of gas prior to the
widespread availability of natural gas. The EPA and the California Department
of Toxic Substances Control have determined that specified constituents of the
gas plant by-products are hazardous substances or hazardous wastes, and may
require removal or other remedial action.
The Resource Conservation and Recovery Act ("RCRA") provides the
statutory authority for the EPA to implement a regulatory program for the safe
treatment, recycling, storage and disposal of solid and hazardous wastes.
There is an unresolved issue regarding the degree to which coal wastes should
be regulated under RCRA. Increased regulation may result in an increase in
expenses related to the operation of Mohave.
The Toxic Substance Control Act and accompanying regulations govern
the manufacturing, processing, distribution in commerce, use and disposal of
polychlorinated biphenyls, a toxic substance used in certain electrical
equipment ("PCB waste"). Current costs for deposal of PCB waste are
immaterial.
Edison's capitalized expenditures for environmental protection for the
years 1969 through 1993 and its currently estimated capital expenditures for
such purpose for the years 1994 through 1998 are as follows:
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(IN THOUSANDS)
AIR WATER SOLID ADDITIONAL
POLLUTION POLLUTION WASTE NOISE PLANT
YEARS TOTAL CONTROL CONTROL DISPOSAL ABATEMENT AESTHETICS CAPACITY MISCELLANEOUS
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1969-1993 $3,823,749 $770,911 $285,648 $60,320 $15,323 $2,454,146 $16,531 $220,870
1994 . . . 277,198 68,104 17,531 11,108 260 176,339 -- 3,856
1995 . . . 285,484 42,649 26,979 25,376 231 186,306 -- 3,943
1996 . . . 286,080 41,698 26,912 14,435 148 202,273 -- 614
1997 . . . 254,861 11,534 14,389 11,900 199 216,583 -- 256
1998 . . . 227,631 11,374 9,471 3,577 1,103 201,217 -- 889
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These estimates include budgeted and forecasted plant expenditures
responsive to currently effective legislation. Projected capital expenditures
for environmental protection are subject to continuous review and periodic
revisions because of escalation in engineering and construction costs,
additions and deletions of planned facilities, changes in technology, evolving
environmental regulatory requirements and other factors beyond Edison's
control. Edison believes that costs incurred for these environmental purposes
will be recognized by the CPUC and the FERC as reasonable and necessary costs
of service for rate recovery purposes.
BUSINESS OF SOUTHERN CALIFORNIA EDISON COMPANY
Edison was incorporated under California law in 1909. Edison is a
public utility primarily engaged in the business of supplying electric energy
to a 50,000 square-mile area of central and southern California, excluding the
City of Los Angeles and certain other cities. This area includes some 800
cities and communities and a population of nearly 11 million people. As of
December 31, 1993, Edison had 16,487 full-time employees. During 1993, 37% of
Edison's total operating revenue was derived from commercial customers, 36%
from residential customers, 13% from industrial customers, 8% from public
authorities, 4% from agricultural and other customers and 2% from resale
customers. Edison comprises the major portion of the assets and revenues of
SCEcorp, its parent holding company.
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REGULATION OF EDISON
Edison's retail operations are subject to regulation by the CPUC.
The CPUC has the authority to regulate, among other things, retail rates,
issuances of securities and accounting and depreciation practices. Edison's
resale operations are subject to regulation by the Federal Energy Regulatory
Commission ("FERC"). The FERC has the authority to regulate resale rates as
well as other matters, including transmission service pricing, accounting and
depreciation practices and licensing of hydroelectric projects.
Edison is subject to the jurisdiction of the Nuclear Regulatory
Commission ("NRC") with respect to its nuclear power plants. NRC regulations
govern the granting of licenses for the construction and operation of nuclear
power plants and subject those power plants to continuing review and
regulation.
The construction, planning and siting of Edison's power plants within
California are subject to the jurisdiction of the California Energy Commission
and the CPUC. Edison is subject to rules and regulations promulgated by the
California Air Resources Board and local air pollution control districts with
respect to the emission of pollutants into the atmosphere, the regulatory
requirements of the California State Water Resources Control Board and regional
boards with respect to the discharge of pollutants into waters of the state and
the requirements of the California Department of Toxic Substances Control with
respect to handling and disposal of hazardous materials and wastes. Edison is
also subject to regulation by the EPA, which administers certain federal
statutes relating to environmental matters. Other federal, state and local
laws and regulations relating to environmental protection, land use and water
rights also impact Edison. (See previous discussion of Environmental Matters
under the Business of SCEcorp, above.)
The California Coastal Commission has continuing jurisdiction over
the coastal permit for San Onofre Nuclear Generating Station ("San Onofre")
Units 2 and 3. Although the units are operating, the permit remains open.
This jurisdiction may continue for several years because it involves oversight
on mitigation measures arising from the permit.
The Department of Energy ("DOE") has regulatory authority over
certain aspects of Edison's operations and business relating to energy
conservation, solar energy development, power plant fuel use and disposal, coal
conversion, public utility regulatory policy and natural gas pricing.
RATE MATTERS
CPUC Retail Ratemaking
The rates for electricity provided by Edison to its retail customers
comprise several major components established by the CPUC to compensate Edison
for basic business and operational costs, fuel and purchased power costs, and
the costs of adding major new facilities.
Basic business and operational costs are recovered through base
rates, which are determined in general rate case proceedings held before the
CPUC every three years. During a general rate case, the CPUC critically
reviews Edison's operations and general costs to provide service (excluding
energy costs and, in certain instances, major plant additions). The CPUC then
determines the revenue requirement to cover those costs, including items such
as depreciation, taxes, cost of capital, operation, maintenance, and
administrative and general expenses. The revenue
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requirement is forecasted on the basis of a specified test year. Following the
revenue requirement phase of a general rate case, Edison and the CPUC proceed
to a rate design phase which allocates revenue requirements and establishes
rate levels for customers.
Base rates may be adjusted in the years between general rate case
years through an attrition year allowance. The attrition year allowance is
intended to allow Edison to recover, without lengthy hearings, specific
uncontrollable cost changes in its base rate revenue requirement and thereby
preserve Edison's opportunity to earn its authorized rate of return in the
years that are not general rate case test years.
In December 1993, Edison filed an application with the CPUC in which
it proposed a performance-based ratemaking procedure for recovery of operation
and maintenance ("O&M") expenses and capital-related costs. Such costs have
traditionally been recovered through general rate cases, attrition proceedings,
and cost of capital proceedings.
Edison proposed that the CPUC authorize a base rate revenue indexing
formula which would combine O&M and capital-related cost recovery. In
addition, Edison proposed that the period between general rate cases be
lengthened from three to six years. Cost of capital proceedings would occur
only after significant changes in utility capital markets.
Edison's fuel, purchased power and energy-related costs of providing
electrical service are recovered through a balancing account mechanism called
the Energy Cost Adjustment Clause ("ECAC"). Under the ECAC balancing account
procedure, fuel, purchased power and energy-related revenues and costs are
compared and the difference is recorded as either an undercollection or
overcollection. The amount recorded in the balancing account is periodically
amortized through rate changes which return overcollections to customers by
reducing rates or collect undercollections from customers by increasing rates.
The costs recorded in the ECAC balancing account are subject to review by the
CPUC and allowed for rate recovery only to the extent they are found to be
reasonable. Certain incentive provisions are included in the ECAC that can
affect the amount of fuel and energy-related costs actually recovered. Edison
is required to make an ECAC filing for each calendar year, and must also make a
second filing for a mid-year adjustment if such filing would result in an ECAC
rate change exceeding 5% of total annual revenue.
For Edison's interest in the three units of the Palo Verde Nuclear
Generating Station ("Palo Verde"), the CPUC authorized a 10-year rate phase-in
plan which deferred $200,000,000 of investment-related revenue during the first
four years of operations for each of the three units, commencing on their
respective commercial operation dates. Revenue deferred for each unit under
the plan for years one through four was $80,000,000, $60,000,000, $40,000,000
and $20,000,000, respectively. The deferrals and related interest are being
recovered over the final six years of each unit's phase-in plan.
The CPUC has also adopted a nuclear unit incentive procedure which
provides for a sharing of additional energy costs or savings between Edison and
its ratepayers when operation of any of the units of San Onofre or Palo Verde
is outside a specified target capacity factor ("TCF") range. For San Onofre
Units 2 and 3, and Palo Verde Units 1, 2 and 3 the TCF range is 55% to 80% of
their rated capacity.
The Electric Revenue Adjustment Mechanism ("ERAM") reflects the
difference between the recorded level of base rate revenue and the authorized
level of base rate revenue. This mechanism has been adopted by the CPUC
primarily to minimize the effect on earnings of fluctuations in retail
kilowatt-hour sales.
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General Rate Case ("GRC")
In December 1991, the CPUC issued a decision on the revenue
requirement phase of Edison's 1992 test year GRC application. The CPUC
authorized a $72,000,000 or 1% increase in Edison's base rate revenues,
effective January 20, 1992. The decision did not adopt Edison's request to
capitalize, rather than expense, computer software development and research,
development and demonstration ("RD&D") expenditures, but did allow Edison to
file additional information regarding such capitalization.
In April 1992, Edison filed supplemental testimony supporting its
request to capitalize application software development costs, and proposed to
decrease its authorized level of base rate revenues ("ALBRR") by $53,000,000 in
1993 and 1994. Edison and the CPUC's Division of Ratepayer Advocates ("DRA")
entered into a settlement agreement to allow rate recovery of capitalized
software expenditures in which Edison agreed to an additional $32,000,000 base
rate revenue decrease. The CPUC approved the settlement agreement in November
1992, and authorized a $48,900,000 decrease to Edison's ALBRR effective January
1, 1993. The related base rate revenue decrease was included in Edison's
January 15, 1993, consolidated revenue change. The CPUC also authorized a
$12,900,000 increase to Edison's ALBRR effective January 1, 1994. The related
base rate revenue increase was included in Edison's January 24, 1994,
consolidated revenue change.
In September 1992, Edison filed supplemental testimony supporting its
request to capitalize RD&D expenditures. In the additional filing, Edison
proposed to capitalize approximately $9,000,000 in RD&D project expenditures.
The DRA's supplemental testimony alleged that Edison did not comply with a CPUC
order regarding joint remote meter reading and recommended a $10,000,000
penalty for non-compliance. Additionally, the DRA proposed to disallow
approximately $4,500,000 of capital costs associated with Edison's research on
off-grid generation technology. The CPUC's decision is expected by the end of
1994.
In December 1992, the CPUC approved an ALBRR increase of
$110,000,000, effective January 1, 1993, for the 1993 attrition year allowance.
The related base rate revenue increase was included in Edison's January 15,
1993 consolidated revenue change. In April 1993, the CPUC modified its
decision (pursuant to a petition by Edison), and approved an ALBRR increase of
$10,400,000 effective April 28, 1993. The related base rate revenue increase
was included in Edison's January 24, 1994, consolidated revenue change.
In December 1993, the CPUC approved an ALBRR increase of $97,200,000
effective January 1, 1994, for: (1) the 1994 attrition year allowance; (2)
increased federal income taxes pursuant to the Revenue Reconciliation Act of
1993; and, (3) reduction in Edison's California property tax liability
resulting from a settlement agreement with the California State Board of
Equalization.
Each year, the CPUC reviews the components of the cost of capital for
all the California energy utilities in a generic cost of capital proceeding.
On December 3, 1993, the CPUC issued a final decision resulting in a
$108,000,000 reduction to Edison's ALBRR effective January 1, 1994. The
decision also resulted in a reduction of Edison's overall rate of return from
9.94% to 9.17%, a reduction in return on common equity from 11.80% to 11.00%,
and an increase to Edison's common equity capital ratio from 46.00% to 47.25%
effective January 1, 1994. The related base rate revenue decrease was included
in Edison's January 24, 1994, consolidated revenue change.
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In December 1993, Edison filed with the CPUC its 1995 GRC
application. In its application, Edison requested an increase to the ALBRR of
$117,000,000 above the expected year-end 1994 ALBRR level to become effective
January 1, 1995. On March 14, 1994, the DRA issued a report which, based on
Edison's preliminary review, recommended a $269,000,000 reduction to Edison's
expected year-end 1994 authorized level of base rate revenue. Evidentiary
hearings are expected to commence in April 1994, with a final CPUC decision
anticipated in December 1994.
In January 1994, the CPUC approved an ALBRR increase of $8,800,000
effective January 24, 1994, for base rate recovery of the permanent component
of Edison's fuel oil inventory. The related base rate revenue increase was
included in Edison's January 24, 1994, consolidated revenue change.
In November 1993, the CPUC approved an ALBRR increase of: (1)
$64,400,000 effective December 31, 1993; and (2) $63,100,000 effective January
1, 1994, to reflect cost recovery of employee post-retirement benefits other
than pensions ("PBOP"). In addition, the CPUC approved an ALBRR reduction of
$39,500,000 effective December 30, 1993, to reflect the removal of costs
associated with Edison's 1992 PBOP contributions. The related base rate
revenue reduction associated with the PBOP ALBRR changes was included in
Edison's January 24, 1994, consolidated revenue change, less $16,000,000 of
rate recovery deferred until 1995.
Energy Cost Adjustment Clause
In January 1992, the DRA issued a report on the reasonableness of
Edison's non-standard, non-affiliate qualifying facilities ("QF") power
purchase contracts included in Edison's 1989 and 1990 annual ECAC applications.
With respect to both ECAC periods, the DRA asserted that Edison had incorrectly
calculated firm capacity payments and bonus capacity payments to QFs by
including certain energy deliveries which the DRA contended should be excluded
or "truncated" from the calculation. The DRA recommended disallowances of
$2,500,000 for the 1989 record period and $4,800,000 for the 1990 record
period. On April 26, 1993, the DRA withdrew its January 1992 testimony
pursuant to an Edison-DRA agreement to jointly petition the CPUC for
clarification of the CPUC's intent regarding truncation and two other QF
contract administration issues. Edison and the DRA filed their joint petition
on April 23, 1993. On November 2, 1993, the CPUC voted to dismiss the joint
petition on the basis that the issues presented were complex and could be
developed more appropriately in an ECAC proceeding or through direct
negotiations among the affected parties. Pursuant to the Edison-DRA agreement,
a dismissal on this basis permits the DRA to renew its challenge to Edison's
truncation practice beginning with the 1991 ECAC record period and thereafter
in each subsequent ECAC record period. To date, the DRA has not recommended
further disallowances attributable to the truncation issue.
In March 1992, Edison and the DRA settled disputes relating to
Edison's power purchases from the 13 non-utility generation facilities
partially owned by Mission Energy. Pursuant to the settlements, Edison agreed
not to enter into new power purchase-contracts with Mission Energy and to a
one-time disallowance. On March 10, 1993, the CPUC issued a decision approving
the settlement and authorizing a ratepayer refund of $250,000,000 over a
two-year period beginning January 1, 1994. The decision also ordered an
immediate adjustment to Edison's ECAC balancing account with interest accruing
until the rate reduction takes effect. The
8
<PAGE> 11
$250,000,000 disallowance is fully reflected in Edison's financial statements.
In October 1993, the DRA issued its report on QF reasonableness
issues for the ECAC record period April 1990 through March 1991. In its
report, the DRA recommended that the CPUC disallow $1,574,000 in power purchase
expenses incurred as a result of purchases during the record period under a QF
contract with Mojave Cogeneration Company, a nonutility generator. In its
report, the DRA also alleged that in 1990 and 1991 Edison imprudently
renegotiated Mojave Cogeneration Company's contract with Edison, resulting in
higher ratepayer costs. The DRA further alleged that ratepayers may be harmed
in the amount of $31,600,000 (present value) over the contract's twenty-year
life. The DRA found the execution of five other QF contracts to be reasonable.
Hearings will likely be held no earlier than the second half of 1994.
The DRA issued four reports addressing Edison's non-QF reasonableness
showing for the April 1, 1991 through March 31, 1992 period. The DRA
recommended: 1) a disallowance of $2,205,000 of replacement power costs
associated with extended outage duration or reduced power production at
Edison's nuclear units, which was allegedly caused by human error; and 2) a
reduction of $1,203,000 to Edison's proposed TCF reward for San Onofre Unit 3,
based on excluding generation above the unit capacity rating. A January 25,
1994 ALJ proposed decision found three nuclear plant outages unreasonable,
resulting in a potential $1,600,000 disallowance, but rejected the DRA's
recommendations for reducing Edison's TCF reward. Edison filed comments on the
proposed decision on February 14, 1994. The final CPUC decision is expected in
March 1994.
On May 28, 1993, Edison requested a $152,000,000 annual rate increase
for service beginning January 1, 1994, for changes to the Energy Cost
Adjustment Billing Factor, Electric Revenue Adjustment Balancing Accounts
("ERABF"), Low Income Surcharge and base rate levels. Edison also made a rate
stabilization proposal which defers recovery of approximately $200,000,000 of
1994 fuel and purchased-power expenses until 1995. In July 1993, Edison
updated its ECAC request to a $181,000,000 increase. The DRA proposed a
$105,000,000 increase. In October 1993, Edison and the DRA stipulated to a
proposed $164,688,000 ECAC revenue increase subject to adjustment for
incorporating Edison's forecast December 31, 1993 balance in the ECAC, Low
Income Ratepayer Assistance, and ERABF to reflect more recent recorded data.
On January 19, 1994, the CPUC issued its decision which adopted a revenue
increase of $274,600,000. When this revenue change is combined with other
revenue changes which occurred on or before January 1, 1994, the total combined
revenue change is $232,101,000.
On May 28, 1993, Edison filed the non-QF portion of its
Reasonableness of Operations Report, which included power purchases and
exchanges and the operation of its hydro, coal, gas and nuclear resources for
the period April 1, 1992 through March 31, 1993. In February 1994, the DRA
recommended: (1) a $7,200,000 disallowance relating to fuel oil inventory
management; and (2) a $5,000,000 disallowance for transmission loss revenues.
Hearings on this matter are scheduled for October 1994.
Edison filed its QF Reasonableness of Operations Report on September
1, 1993. It is presently unknown when the DRA will file testimony in the QF
reasonableness phase.
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<PAGE> 12
Palo Verde Outage Review
In March 1989, Palo Verde Units 1 and 3 experienced automatic
shutdowns. Since the resultant outages overlapped previously scheduled
refueling outages, normal refueling, maintenance, inspection, surveillance,
modification and testing activities were conducted at the units, as well as
modifications to the plants required by the NRC. Unit 3 was restored to
service on December 30, 1989, and Unit 1 was restored to service on July 5,
1990.
In December 1989, the CPUC instituted an investigation into the
outages pursuant to the California Public Utilities Code ("Code"). The Code
requires the CPUC to institute an investigation when any portion of a
utility's generating facilities has been out of service for nine consecutive
months. The CPUC order required that the subsequent collection of rates
associated with Palo Verde Units 1 and 3 be subject to refund pending review of
the outages. In November 1991, the DRA issued a report recommending
disallowances totaling more than $160,000,000 including a $63,000,000
disallowance for revenue collected during the outages (including interest).
In September 1993, Edison and the DRA agreed to settle these disputes
for $38,000,000 (including $29,000,000 for replacement power costs, $2,000,000
for capital projects and approximately $7,000,000 for interest), subject to
CPUC approval. The settlement resolves all issues related to the 1989-1990
outages at Palo Verde. The effect of the settlement has been fully reflected
in the financial statements. Edison expects a CPUC decision regarding the
settlement in mid 1994.
Mohave Order Instituting Investigation ("OII")
In April 1986, the CPUC began investigating the 1985 rupture of a
high pressure steam pipe at Mohave. Edison is the plant operator and 56%
owner. The CPUC's OII reviewed Edison's share of repair costs and replacement
fuel and energy related costs associated with the outage. Edison incurred
costs of approximately $90,000,000 (including interest) to repair damage from
the accident and provide replacement power during the six-month outage. This
total is net of Edison's recovery of expenses from the settlement of lawsuits
with contractors and insurance.
In May 1991, the DRA and its consultant issued reports alleging that
Edison imprudently operated the Mohave plant and therefore contributed to the
accident. As a result, the DRA recommended that all expenses incurred because
of the accident be disallowed in rates. The DRA did not quantify its proposed
disallowance. Edison believes that metallurgical and physical characteristics
of a weld reduced the otherwise expected pipe life to the point of failure
after 15 years of service. Edison filed testimony contesting the allegations
in May 1992, in December 1992, and on March 1, 1993. In March 1994, the CPUC
issued a decision finding that Edison acted unreasonably in failing to
implement an inspection program. The CPUC decision ordered a second phase of
this proceeding to quantify the disallowance.
High Voltage Direct Current Expansion Project ("HVDCEP")
The HVDCEP began operation in 1989. In October 1989, Edison filed a
report with the CPUC requesting recovery of $72,600,000 in project costs.
Subsequently, Edison and the DRA agreed on an accounting adjustment of
$150,000, and a settlement agreement was filed. A February 3, 1993 CPUC
decision upheld the settlement agreement allowing Edison recovery in rates of
approximately $72,450,000. In its 1995 GRC, Edison is requesting rate recovery
of an additional $7,000,000 associated with completion items and
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<PAGE> 13
other HVDCEP-related expenditures. The total amount of rate recovery for the
HVDCEP that Edison will be allowed remains subject to further adjustment
pending a final determination of the cost-effectiveness of the project in
comparison with the power exchange agreement between Edison and the Los Angeles
Department of Water and Power.
FERC Resale Ratemaking
Edison sells electricity to public power utilities (the cities of
Anaheim, Azusa, Banning, Colton, Riverside and Vernon), Southern California
Water Company and Arizona Public Service Company ("APS") under rates subject to
FERC jurisdiction. In accordance with FERC procedures resale rates are subject
to refund with interest if subsequently disallowed. Edison believes any
refunds from pending rate proceedings, would not materially affect its results
of operations or financial position.
FUEL SUPPLY
Fuel and purchased-power costs amounted to approximately $3.29
billion in 1993, a 7% increase over 1992. Sources of energy and unit costs of
fuel for 1989 through 1993 were as follows:
<TABLE>
<CAPTION>
AVERAGE COST PER MILLION
SOURCES OF ENERGY BTU'S(1)
----------------------------------- ---------------------------------------
YEAR ENDED DECEMBER 31, YEAR ENDED DECEMBER 31,
----------------------------------- ---------------------------------------
1989 1990 1991 1992 1993 1989 1990 1991 1992 1993
---- ---- ---- ---- ---- ----- ----- ----- ----- -----
<S> <C> <C> <C> <C> <C> <C> <C> <C> <C> <C>
Oil . . . . . . . . . . . 4% 2% * * * $3.03 $4.39 $4.07 $5.75 $6.08
Natural Gas . . . . . . . 24 17 18% 24% 23% 3.24 3.02 2.81 2.78 2.89
Nuclear . . . . . . . . . 17 20 21 22 18 1.04 0.94 0.87 0.66 0.51
Coal . . . . . . . . . . . 13 13 14 14 13 1.14 1.21 1.15 1.15 1.19
--- --- --- --- ---
All Fuels . . . . . . . . 58 52 53 60 54 2.15 1.90 1.64 1.65 1.77
Hydroelectric(2) . . . . . 4 3 4 3 7
Purchased Power(2):
Firm . . . . . . . . . 6 3 3 3 2
Economy . . . . . . . . 7 13 8 2 3
Other power producers:
Biomass . . . . . . . 1 2 2 2 3
Cogeneration . . . . 17 19 20 20 20
Geothermal . . . . . 5 6 7 7 8
Solar . . . . . . . . 1 1 1 1 1
Wind . . . . . . . . 1 1 2 2 2
--- --- --- --- ---
Total 100% 100% 100% 100% 100%
=== === === === ===
</TABLE>
_______________
(1) British Thermal Unit ("BTU") is the standard unit of measure for the
heat content of fuels. One BTU is the amount of heat required to
raise the temperature of one pound of water, at 39.1 degrees
Fahrenheit, by one degree Fahrenheit.
(2) There are no fuel costs associated with these categories.
* Indicates a source of less than 1%.
Average fuel costs, expressed in cents per kilowatt-hour, for the year
ended December 31, 1993, were: oil, 7.996c.; natural gas, 2.930c.; nuclear,
0.537c.; and coal, 1.226c..
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<PAGE> 14
Natural Gas Supply
Twelve of Edison's major steam electric generating units are designed
to burn oil or natural gas as a primary boiler fuel. In 1990, Edison adopted
an all-gas strategy to comply with air quality goals by eliminating burning oil
in all but very extreme conditions. In August 1991, the CPUC adopted
regulations which made Edison fully responsible for all gas procurement
activities previously performed by local distribution companies for natural
gas.
To implement its all-gas strategy, Edison acquired a balanced
portfolio of gas supply and transportation arrangements. Traditionally,
natural gas needs in southern California were met from gas production in the
southwest region of the country. To diversify its gas supply, Edison entered
into four 15-year natural gas supply agreements with major producers in western
Canada. These contracts, totaling 200,000,000 cubic feet per day, have
market-sensitive pricing arrangements. This represents about 40% of Edison's
current average annual supply needs. The rest of Edison's gas supply is
acquired under short-term contracts from West Texas, New Mexico, and the Rocky
Mountain region.
Firm transportation arrangements provide the necessary long-term
reliability for supply deliverability. To transport Canadian supplies, Edison
contracted for 200,000,000 cubic feet per day of firm transportation
arrangements on the Pacific Gas Transmission and Pacific Gas & Electric
Expansion Project connecting southern California to the low-cost gas producing
regions of western Canada. Edison has a 30-year commitment to this project,
construction of which was completed in late 1993. In addition, Edison has a
15-year commitment to 200,000,000 cubic feet per day of firm transportation
rights on El Paso Natural Gas' pipeline to transport Southwest U.S. gas
supplies.
Nuclear Fuel Supply
Edison has contractual arrangements covering 100% of the projected
nuclear fuel cycle requirements for San Onofre through the years indicated
below:
<TABLE>
<CAPTION>
UNITS
2 & 3
-----
<S> <C>
Uranium concentrates(1) . . . . . . . . . . . . . . . 1995
Conversion . . . . . . . . . . . . . . . . . . . . . . 1995
Enrichment . . . . . . . . . . . . . . . . . . . . . . 1998
Fabrication . . . . . . . . . . . . . . . . . . . . . 2000
Spent fuel storage(2) . . . . . . . . . . . . . . . . 2005/2004
</TABLE>
_______________
(1) Assumes the San Onofre participants meet their supply obligations in a
timely manner.
(2) Assumes full utilization of expanded on-site storage capacity and
normal operation of the units, including interpool transfers and
maintaining full-core reserve. To supplement existing spent fuel
storage, a contingency plan is being developed to construct additional
on-site storage capacity with initial operation scheduled for no later
than 2002. The Nuclear Waste Policy Act of 1982 requires that the DOE
provide for the disposal of utility spent nuclear fuel beginning in
1998. The DOE has stated that it is unlikely that it will be able to
start accepting spent nuclear fuel at its permanent repository before
2010.
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<PAGE> 15
Participants in Palo Verde have purchased uranium concentrates
sufficient to meet projected requirements through 1997. Independent of
arrangements made by other participants, Edison will furnish its share of
uranium concentrates requirements through at least 1995 from existing
contracts. Contracts to provide conversion services cover requirements through
1994. Enrichment and fabrication contracts will meet Palo Verde requirements
through 1995 and 1997, respectively.
Palo Verde on-site expanded spent fuel storage capacity will
accommodate needs through 2005 for Units 1 and 2 and 2006 for Unit 3, while
maintaining full-core reserve.
BUSINESS OF THE MISSION GROUP AND ITS SUBSIDIARIES
Mission Group was incorporated in 1987 to own the stock and coordinate
the activities of several companies engaged in nonutility businesses. The
principal subsidiaries of Mission Group are Mission Energy, Mission First
Financial and Mission Land. A fourth subsidiary, Mission Power Engineering
Company, discontinued operations in 1990. The businesses of these companies
are described below. For SCEcorp's business segment information for each of
the three years ended December 31, 1993, 1992 and 1991, see Note 12 of "Notes
to Consolidated Financial Statements" contained in the 1993 Annual Report to
Shareholders incorporated by reference in this report.
On December 31, 1993, Mission Group had consolidated assets of $3.3
billion and, for the year then ended, had consolidated operating revenue of
$424,500,000 and consolidated net income of $3,000,000.
Mission Group's principal executive offices are located at 18101 Von
Karman Avenue, #1700, Irvine, California 92715.
Mission Energy. Mission Energy, primarily through its subsidiary
corporations, is engaged in the business of developing, owning, and operating
cogeneration, small power, geothermal, and other principally energy-related
projects. At December 31, 1993, Mission Energy subsidiaries held interests in
33 operating power production facilities with an aggregate power production
capability of 4,105 MW, of which 1,862 MW are attributable to Mission Energy's
interests. These operating facilities are located in California, Nevada, New
Jersey, Pennsylvania, Virginia, Washington, Australia, Spain, and the United
Kingdom. In addition, facilities aggregating more than 1,746 MW, of which one
500 MW facility is located in Australia, are in construction or advanced
permitting stages. Mission Energy owns interests in oil and gas producing
operations and related facilities in Canada and U.S. locations in Texas,
Alabama, New Mexico, California and offshore Louisiana. In February 1994,
Mission Energy -- as lead developer -- and its partners, General Electric
Capital Corporation, Mitsui & Co., Ltd. and P.T. Batu Hitam Perkasa, signed a
30-year power-purchase agreement with the Indonesian government for the
1,230-MW Paiton project.
At December 31, 1993, Mission Energy had total consolidated assets of
$1.8 billion and for the year then ended, had consolidated operating revenue of
$272,800,000 and consolidated net income of $2,300,000.
Currently, most of Mission Energy's operating power production
facilities have QF status under the Public Utility Regulatory Policies Act of
1978 ("PURPA") and the regulations promulgated thereunder. QF status exempts
the projects from the application of the Holding Company Act, many provisions
of the Federal Power Act, and state laws and regulations respecting rates and
financial or organizational regulation of electric
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<PAGE> 16
utilities. Mission Energy, through wholly-owned subsidiaries, also has
ownership interests in two operating power projects that have received exempt
wholesale generator status as defined in the Holding Company Act. In addition,
some Mission Energy subsidiaries have made fuel-related investments and a
limited number of non-energy related investments.
While QF status entitles projects to the benefits of PURPA, each
project must still comply with other federal, state and local laws, including
those regarding siting, construction, operation, licensing and pollution
abatement.
Mission First Financial. Mission First Financial participates in
investment opportunities involving leveraged leasing, project financing,
affordable housing and cash management. Its investments include interests in
nuclear power, cogeneration, waste-to-energy, hydroelectric, electric
transportation and affordable housing facilities. Since its inception in 1987,
Mission First Financial has invested in 71 projects. In 1993, Mission First
Financial invested $20,000,000 in a sale/leaseback of electric locomotive
equipment with the Dutch rail authority. In addition, Mission First Financial
invested $62,000,000 in 23 completed affordable housing projects and signed
commitments to invest in 19 additional projects.
At December 31, 1993, Mission First Financial had total consolidated
assets of $972,000,000 and, for the year then ended, had consolidated operating
revenue of $31,500,000 (including interest income) and consolidated net income
of $29,200,000.
Mission Land. Mission Land is engaged, directly and through its
subsidiaries, in the business of developing, owning and managing industrial
parks and other real property investments. Mission Land owns and manages
commercial and industrial buildings in industrial parks located in Brea, Chino,
Garden Grove, Ontario, Oceanside and Rancho Cucamonga, California. Mission
Land and its subsidiaries also have interests in industrial, residential and
commercial real estate in California; Tolleson, Arizona; Munster, Indiana;
Chicago, Illinois and in other locations. SCEcorp has decided no longer to
pursue real estate development as one of its core businesses and plans to exit
this business in an orderly fashion over time.
At December 31, 1993, Mission Land had total consolidated assets of
$516,300,000 and for the year then ended, had consolidated operating revenue of
$112,500,000 and a consolidated net loss of $15,300,000. Mission Land has
reduced assets by one-third since 1991 primarily through asset sales, reduced
debt significantly, improved operating income through higher occupancy rates,
and has increased reserves. As a result, Mission Land believes it has improved
its ability to systematically exit the real estate business in a
self-sustaining way. However, Mission Land may experience additional losses if
the real estate market remains weak.
ITEM 2. PROPERTIES
EXISTING UTILITY GENERATING FACILITIES
Edison owns and operates 12 oil- and gas-fueled electric generating
plants, one diesel-fueled generating plant, 38 hydroelectric plants and an
undivided 75.05% interest (1,614 MW net) in Units 2 and 3 at San Onofre. These
plants are located in central and southern California. Palo Verde (15.8%
Edison-owned, 579 MW net) is located near Phoenix, Arizona. Palo Verde Units
1, 2 and 3 started commercial operation on February 1, 1986, September 19,
1986, and January 20, 1988, respectively. Edison owns a 48% undivided interest
(754 MW) in Units 4 and 5 at the Four
14
<PAGE> 17
Corners Generating Station ("Four Corners Project"), a coal-fueled steam
electric generating plant in New Mexico. Palo Verde and the Four Corners
Project are operated by other utilities. Edison operates and owns a 56%
undivided interest (885 MW) in Mohave, which consists of two coal-fueled steam
electric generating units in Clark County, Nevada. Edison receives an
entitlement of 277 MW from the DOE's Hoover Dam Hydroelectric Project. At
year-end 1993, the existing Edison-owned generating capacity (summer effective
rating) was comprised of approximately 67% gas, 14% nuclear, 11% coal and 8%
hydroelectric.
San Onofre, the Four Corners Project, certain of Edison's substations
and portions of its transmission, distribution and communication systems are
located on lands of the United States or others under (with minor exceptions)
licenses, permits, easements or leases or on public streets or highways
pursuant to franchises. Certain of such documents obligate Edison, under
specified circumstances and at its expense, to relocate transmission,
distribution and communication facilities located on lands owned or controlled
by federal, state or local governments.
With certain exceptions, major and certain minor hydroelectric
projects with related reservoirs, currently having an effective operating
capacity of 1,154 MW and located in whole or in part on lands of the United
States, are owned and operated by Edison under governmental licenses which
expire at various times between 1994 and 2022. Such licenses impose numerous
restrictions and obligations on Edison, including the right of the United
States to acquire the project upon payment of specified compensation. When
existing licenses expire, FERC has the authority to issue new licenses to third
parties, but only if their license application is superior to Edison's and then
only upon payment of specified compensation to Edison. Any new licenses issued
to Edison are expected to be issued under terms and conditions less favorable
than those of the expired licenses. Edison's applications for the relicensing
of certain hydroelectric projects referred to above with an aggregate effective
operating capacity of 89.0 MW are pending. Annual licenses issued for all
Edison projects, whose licenses have expired and are undergoing relicensing,
will be renewed until the new licenses are issued.
In 1993, Edison's peak demand was 16,475 MW, set on September 9, 1993.
The 1993 peak was 1,938 MW less than Edison's record peak demand of 18,413 MW
that occurred on August 17, 1992. Total area system operating capacity of
20,606 MW was available to Edison at the time of the 1993 record peak.
Substantially all of Edison's properties are subject to the lien of a
trust indenture securing First and Refunding Mortgage Bonds ("Trust
Indenture"), of which approximately $3.5 billion principal amount was
outstanding at December 31, 1993. Such lien and Edison's title to its
properties are subject to the terms of franchises, licenses, easements, leases,
permits, contracts and other instruments under which properties are held or
operated, certain statutes and governmental regulations, liens for taxes and
assessments, and liens of the trustees under the Trust Indenture. In addition,
such lien and Edison's title to its properties are subject to certain other
liens, prior rights and other encumbrances, none of which, with minor or
unsubstantial exceptions, affects Edison's right to use such properties in its
business, unless the matters with respect to Edison's interest in the Four
Corners Project and the related easement and lease referred to below may be so
considered.
Edison's rights in the Four Corners Project, which is located on land
of The Navajo Tribe of Indians under an easement from the United States and a
lease from The Navajo Tribe, may be subject to possible defects. These defects
include possible conflicting grants or encumbrances not
15
<PAGE> 18
ascertainable because of the absence of, or inadequacies in, the applicable
recording law and the record systems of the Bureau of Indian Affairs and The
Navajo Tribe, the possible inability of Edison to resort to legal process to
enforce its rights against The Navajo Tribe without Congressional consent,
possible impairment or termination under certain circumstances of the easement
and lease by The Navajo Tribe, Congress or the Secretary of the Interior and
the possible invalidity of the Trust Indenture lien against Edison's interest
in the easement, lease and improvements on the Four Corners Project.
EL PASO ELECTRIC COMPANY ("EL PASO") BANKRUPTCY
El Paso owns and leases a combined 15.8% interest in Palo Verde and
owns a 7% interest in Units 4 and 5 of the Four Corners Project. In January
1992, El Paso filed a voluntary petition to reorganize under Chapter 11 of the
Bankruptcy Code in the United States Bankruptcy Court for the Western District
of Texas. Pursuant to an agreement among the Palo Verde participants and an
agreement among the participants in Four Corners Units 4 and 5, each
participant is required to fund its proportionate share of operation and
maintenance, capital and fuel costs of Palo Verde and Four Corners Units 4 and
5, respectively. The participation agreements provide that if a participant
fails to meet its payment obligation, each non-defaulting participant must pay
its proportionate share of the payments owed by the defaulting participant. In
February 1992, the bankruptcy court approved a stipulation between El Paso and
APS, as the operating agent of Palo Verde, pursuant to which El Paso agreed to
pay its proportionate share of all Palo Verde invoices delivered to El Paso
after February 6, 1992. El Paso agreed to make these payments until such time,
if ever, the bankruptcy court orders El Paso's rejection of the participation
agreement governing the relations among the Palo Verde participants. The
stipulation also specifies that approximately $9,200,000 of El Paso's Palo
Verde payment obligations invoiced prior to February 7, 1992, are to be
considered "pre-petition" general unsecured claims of the other Palo Verde
participants.
On August 27, 1993, El Paso filed with the bankruptcy court an Amended
Plan of Reorganization and Disclosure Statement ("Amended Plan"). The Amended
Plan, which is subject to numerous conditions, proposes a reorganization
pursuant to which El Paso will become a wholly- owned subsidiary of Central and
South West Corporation. The Amended Plan also proposes, among other things,
(i) rejection of the El Paso leases and reacquisition by El Paso of the Palo
Verde interests represented by the leases, and (ii) El Paso's assumption of the
Four Corners Operating Agreement and the Arizona Nuclear Power Project
Participation Agreement. On November 19, 1993, the bankruptcy court approved a
Cure and Assumption Agreement among El Paso and the Palo Verde Participants, in
which El Paso shall (i) assume the Participation Agreement on the date the
Amended Plan becomes effective, and (ii) cure its pre-petition default on the
date the court approves the Order Confirming El Paso's Amended Plan. On
December 8, 1993, the bankruptcy court confirmed El Paso's Amended Plan.
Effectiveness of the Amended Plan is still subject to approval by numerous
state and federal agencies. El Paso estimates that it will take about 18
months to obtain all necessary regulatory approvals.
CONSTRUCTION PROGRAM AND CAPITAL EXPENDITURES
In April 1992, the CPUC decided how Edison and other California
utilities will meet their resource needs through 2002. The CPUC ruled that
Edison must obtain 624 MW of new generation through competitive bidding. The
decision required that 175 MW be reserved for renewables, such as wind, hydro
and geothermal. The competitive bid solicitation was issued in August 1993
and suspended in December 1993 due to the discovery
16
<PAGE> 19
of a bidding anomaly that raised prices above those allowed by the rules of the
solicitation. After the suspension, Edison requested the solicitation be
cancelled because current forecasts show that Edison has no need for additional
generating capacity until at least 2005.
From the solicitation results, Edison has estimated that the cost of
these resources would be approximately $530,000,000 (present value in 1997
dollars). However, two events have occurred that should reduce Edison's cost
exposure resulting from power purchases under this CPUC mandated process.
First, on March 15, 1994, Edison and Kenetech Corporation, a potential winning
bidder in Edison's solicitation, signed a memorandum of understanding for a
wind resource power purchase. Contingent upon CPUC approval, Kenetech, under
this proposed agreement, will provide lower cost resources than those
potentially awarded through Edison's solicitation. Second, on March 16, 1994,
the CPUC issued an interim decision that reduces Edison's solicitation by 25%
and gives Edison authority to eliminate the added costs from the bidding
anomaly. Although Edison will likely continue to request cancellation of the
competitive solicitation, these two events reduce Edison's exposure. The
exact amount of this reduction cannot be estimated until the methodology the
CPUC intends for implementation of these changes is known.
Cash required by SCEcorp for its capital expenditures totaled $1.26
billion in 1993, $1.24 billion in 1992, and $1.03 billion in 1991.
Construction expenditures for the 1994-1998 period are estimated as follows:
<TABLE>
<CAPTION>
(IN MILLIONS)
1994 1995 1996 1997 1998 TOTAL
------ ------ ------ ------ ------ ------
<S> <C> <C> <C> <C> <C> <C>
Electric generating plant . . . . . . . . . . . . . . $ 378 $ 353 $ 283 $ 264 $ 491 $1,769
Electric transmission lines
and substations . . . . . . . . . . . . . . . . . 131 121 153 173 252 830
Electric distribution lines
and substations . . . . . . . . . . . . . . . . . 486 559 529 560 556 2,690
Other expenditures . . . . . . . . . . . . . . . . . 184 194 145 139 92 754
Nonutility expenditures . . . . . . . . . . . . . . . 164 147 88 1 1 401
------ ------ ------ ------ ------ ------
Total . . . . . . . . . . . . . . . . . . . . . 1,343 1,374 1,198 1,137 1,392 6,444
Less: allowance for funds used
during construction . . . . . . . . . . . . . . . 38 44 43 43 43 211
------ ------ ------ ------ ---- ------
Cash required for construction expenditures . . . . . $1,305 $1,330 $1,155 $1,094 $1,349 $6,233
====== ====== ====== ====== ====== ======
</TABLE>
Edison's construction program and related expenditures are
continuously reviewed and periodically revised because of changes in estimated
system load growth, rates of inflation, receipt of adequate and timely rate
relief, the availability and timing of environmental, siting and other
regulatory approvals, the scope of modifications required by regulatory
agencies, the availability and costs of external sources of capital, the
development of new technology and other factors beyond Edison's control.
Since the completion of San Onofre Units 2 and 3 and Palo Verde Units
1, 2 and 3, construction work in progress has been significantly reduced. The
reduction in construction work in progress caused allowance for funds used
during construction ("AFUDC"), which does not represent current cash income, to
decline accordingly. Pre-tax AFUDC represented 5.7% of earnings for 1993.
In addition to cash required for construction expenditures for the
next five years as discussed above, $1.3 billion is needed to meet requirements
for long-term debt maturities, and sinking fund redemption
17
<PAGE> 20
requirements. The majority of these capital requirements are expected to be
met by internally generated sources.
Edison's estimates of cash available for operations for the five years
through 1998 assume, among other things, the receipt of adequate and timely
rate relief and the realization of its assumptions regarding cost increases,
including the cost of capital. Edison's estimates and underlying assumptions
are subject to continuous review and periodic revision.
The timing, type and amount of all additional long-term financing are
also influenced by market conditions, rate relief and other factors, including
limitations imposed by Edison's Articles of Incorporation and Trust Indenture.
NUCLEAR POWER MATTERS
Although higher energy costs will be incurred for replacement
generation during any periods the San Onofre and Palo Verde Units are not in
operation, substantially all such costs will be included in future ECAC
filings. Edison cannot predict what other effects, if any, legislative or
regulatory actions may have upon it or upon the future operation of the San
Onofre or Palo Verde Units or the extent of any additional costs it may incur
as a result thereof, except for those that follow.
San Onofre Unit 1
On November 30, 1992, Edison discontinued operation of San Onofre Unit
1. The CPUC approved an agreement between Edison and the DRA which allows
Edison recovery of its investment of approximately $350,000,000 (after deferred
taxes), including an 8.98% rate of return, by August 1996.
The agreement does not affect Unit 1's decommissioning, scheduled to
start in 2013. The estimated current-dollar decommissioning costs for Unit 1
have been recorded as a liability.
San Onofre Units 2 and 3
In 1974, the California Coastal Commission, as a condition of the San
Onofre Units 2 and 3 coastal permit, established a three-member Marine Review
Committee ("MRC") to assess the marine environmental effects caused by the
Units. In August 1989, the MRC issued its final report which alleged, in part,
that San Onofre Units 2 and 3 caused adverse effects to several species of
marine life and to the environment.
Based on the MRC findings, the Coastal Commission in 1991 revised the
coastal permit for Units 2 and 3 and required Edison to restore 150 acres of
degraded wetlands, construct a 300-acre artificial kelp reef, and install fish
behavioral barriers inside the Units' cooling water intake structure. Edison
is currently in the process of planning and designing these projects, all of
which must receive the approval of the Coastal Commission and state and federal
resource and regulatory agencies. Current estimates place Edison's share of
these capital costs at about $83,000,000 which is expected to be spent over the
next 10 to 12 years.
Palo Verde Nuclear Generating Station
On March 14, 1993, APS, as operating agent, manually shut down Palo
Verde Unit 2 as a result of a steam generator tube leak. Unit 2 remained shut
down and began its scheduled refueling outage on March 19, 1993.
An extensive inspection of the Palo Verde Unit 2 steam generators was
performed prior to the unit's return to service on September 1, 1993. APS
18
<PAGE> 21
determined that intergranular attack/intergranular stress corrosion cracking
was a major contributor to the tube leak. APS is continuing its evaluation of
the effects of possible steam generator tube degradation in all three units
(six steam generators) and has instituted several avenues of study and
corrective action.
Palo Verde Units 1, 2, and 3 will be operated at reduced power (85%)
until the investigation and other associated activities are completed. APS
expects to be able to return the units to full power after implementing
corrective action.
Nuclear Facility Decommissioning
Edison's share of costs to decommission nuclear generation facilities
is estimated to be $225,500,000 for San Onofre Unit 1; $280,900,000 for San
Onofre Unit 2; $365,400,000 for San Onofre Unit 3; $50,200,000 for Palo Verde
Unit 1; $49,800,000 for Palo Verde Unit 2; and $55,400,000 for Palo Verde Unit
3. These costs are all in 1993 dollars.
Edison is currently collecting $104,255,000 annually in rates for its
share of decommissioning costs for San Onofre Units 1, 2 and 3 and Palo Verde
Units 1, 2 and 3. As of December 31, 1993, Edison's decommissioning trust
funds totaled approximately $853,000,000 (market value).
In accordance with the Energy Policy Act of 1992, Edison's recorded
liability at December 31, 1993, of $72,300,000 represents its share of the
estimated costs to decommission three federal nuclear enrichment facilities.
This cost is based on San Onofre's and Palo Verde's past purchases of
enrichment services and will be paid over 15 years. These costs are expected
to be recovered through the ECAC procedure and from participants.
Nuclear Facility Depreciation
To reduce Edison nuclear facilities' capital cost effect on future
customer rates, Edison has filed for a $75,000,000 per year accelerated
recovery of its nuclear investments. To offset the increased cost recovery,
Edison proposes to lengthen its recovery period for transmission and
distribution assets. This proposal would have no significant effect on
customer rates. The CPUC held hearings in October 1993 and Edison expects a
decision in mid-1994.
Nuclear Insurance
Edison carries the maximum insurance coverage reasonably available to
protect against losses from damage to its nuclear units and to provide some of
its replacement energy costs in the unlikely event of an accident at any of its
nuclear units. A description of this insurance is included in Note 10 of
"Notes to Consolidated Financial Statements" incorporated herein. Although
Edison believes an accident at its nuclear units is extremely unlikely, in the
event of an accident, regardless of fault, Edison's insurance coverage might be
inadequate to cover the losses to Edison. In addition, such an accident could
result in NRC action to suspend operation of the damaged unit. Further, the
NRC could suspend operation at Edison's undamaged nuclear units and the CPUC
and FERC could deny rate recovery of related costs. Such an accident,
therefore, could materially and adversely affect the operations and earnings of
Edison.
NUCLEAR WASTE POLICY ACT
Under the Nuclear Waste Policy Act of 1982, Edison, acting as agent
for the San Onofre participants, has entered into a contract with the DOE for
disposal of spent nuclear fuel for San Onofre Units 1, 2 and 3. Under
19
<PAGE> 22
the terms of the contract, Edison is required to pay a quarterly fee of one
mill per kilowatt hour to the DOE for net nuclear power generated and sold on
and after April 7, 1983. During 1992, DOE implemented a refund process for
overpayments to the Nuclear Waste Fund through credits against future quarterly
payments.
For generation prior to April 7, 1983, the contract required payment
of a one-time fee equivalent to one mill per kilowatt hour, plus accrued
interest. The obligation for this one-time fee was being discharged by equal
quarterly payments. In October 1992 and 1993, DOE credits arising from
overpayments to the Nuclear Waste Fund were also applied to this obligation.
In October 1993, this obligation was paid in full. Expenses associated with
the disposal of spent nuclear fuel are recovered through the ECAC procedure and
from participants.
COMPETITIVE ENVIRONMENT
Under various acts of Congress, federal power projects have been
constructed in California and neighboring states. Municipally owned utilities,
cooperative utilities and other public bodies have certain preferences over
investor-owned utilities in the purchase of electric power provided by
federally funded power projects and, in addition, have certain preferences over
investor-owned utilities in connection with the acquisition of licenses to
build and/or operate hydroelectric power plants. Any energy which is or may
be generated at these projects and transmitted for the account of such other
utilities and public bodies over present or future government or utility-owned
lines into the territory or markets served by Edison would result in a loss of
sales by Edison.
Under the laws of California, utility districts may include
incorporated as well as unincorporated territory. Such districts, as well as
municipalities, have the right to construct, purchase or condemn and operate
electric facilities. In addition, when a city owning an electric system
annexes adjacent unincorporated territory which Edison has previously served,
Edison may experience a loss of customers.
Edison's construction permits for San Onofre Units 2 and 3 contain
certain conditions which require Edison (i) on timely notice, to permit
privately or publicly owned utilities, including Edison's resale customers
within or adjacent to Edison's service area, to participate on mutually
agreeable terms in future nuclear units initiated by Edison, and (ii) to
interconnect and coordinate reserves with, furnish emergency service to, sell
bulk power to and purchase bulk power from, and provide certain transmission
services for such utilities. Edison has also entered into agreements with
certain of its resale customers which contemplate their possible participation
in jointly owned generating projects initiated by Edison, and the integration
of power sources acquired by each such customer, including the dispatching,
reserve sharing, partial power-supply requirements and transmission service
required in connection with such integrated operations. Pursuant to these
agreements, two resale customers exercised an option to participate in Edison's
ownership entitlement in San Onofre Units 2 and 3. Effective November 1977,
Edison sold an undivided 3.45% interest in San Onofre Units 2 and 3 to these
two resale customers for approximately $90,000,000. Effective September 1981,
a further 1.5% interest in Units 2 and 3 was sold to one of these resale
customers for approximately $50,000,000. In addition, since 1986, six of
Edison's resale customers have acquired ownership interests in other generating
sources and made purchases from other utilities in such amounts as to decrease
Edison's revenues from resale cities from 4.4% to 1.6% of sales. This revenue
loss has not had a substantial effect on Edison's business and opportunities.
20
<PAGE> 23
PURPA has fostered the entry of nonutility companies into the electric
generation business. Under PURPA, nonutility power producers are allowed to
construct QFs for the production of electricity from certain alternative or
renewable energy resources, and utilities are required to purchase the
electrical output of these QFs at prices set pursuant to state regulations and,
in the future, pursuant to a CPUC- approved competitive bidding process.
Edison is required by contracts and state regulation to continue to
buy power generated by QFs, under long-term contracts negotiated earlier at
prices that are most often higher than the power Edison can produce or purchase
from other sources. Edison is presently managing contracts with QF developers
to reduce ratepayer impacts and to more closely match Edison's needs with
proposed development. Further, certain operators of QFs sell power they
produce to large industrial and commercial customers of Edison from projects
located on-site. Further loss of sales from such customers may be aggravated
in the future as a result of attempts by these producers to gain access to a
utility's transmission lines to sell power directly to retail customers now
being served by that utility--an activity called "retail wheeling." Edison
opposes any attempt to impose mandatory wheeling to Edison's retail customers.
In late 1992, Congress passed the Energy Policy Act of 1992. This Act
creates a new class of Exempt Wholesale Generators ("EWGs") who are exempt from
the restrictions otherwise imposed on utilities under the Public Utility
Holding Company Act. The effect of this exemption is to facilitate the
development of more independent third-party generators potentially available to
satisfy utilities' needs for increased power supplies. However, unlike
purchases from QFs, utilities have no statutory obligation to purchase power
from EWGs. Furthermore, EWGs are precluded from making direct sales to retail
electricity customers.
The Energy Policy Act also broadens the authority of the FERC to
require a utility to transmit power produced by a wholesale producer to another
utility. Municipal utilities are eligible applicants for such transmission
service. However, the FERC is precluded from ordering a utility to transmit
power from another entity directly to a retail customer. The authority of
states to order such retail wheeling is unclear; but, to the extent such
authority exists, it is explicitly preserved by the Energy Policy Act.
ITEM 3. LEGAL PROCEEDINGS
ANTITRUST MATTERS
In 1983, a public power utility, the City of Vernon, filed a complaint
against Edison in the United States District Court for the Central District of
California, alleging violation of certain antitrust laws. The complaint
alleged that Edison engaged in anticompetitive behavior by restricting access
to Edison transmission facilities and foreclosing Vernon from purchasing bulk
power supplies from other sources. Vernon also alleged that Edison unlawfully
designed its resale rates and claimed damages of approximately $60,000,000
before trebling. Edison filed three motions for Summary Judgment and the
District Court entered final judgment in favor of Edison in August 1990. In
October 1990, Vernon appealed the District Court decision to the Ninth Circuit
Court of Appeals. In February 1992, the Court of Appeals affirmed the District
Court's rulings on all issues but one, involving injunctive relief only, and
remanded that issue back to the District Court for consideration. In July
1992, Vernon filed a writ of certiorari to the U.S. Supreme Court which was
denied. On July 13, 1993, Edison and Vernon settled the remaining issue
regarding injunctive relief. The settlement is part of a broader settlement of
regulatory issues that was approved by the FERC on October 27, 1993.
21
<PAGE> 24
On January 31, 1991, California Energy Company ("CEC") filed a lawsuit
in United States District Court for the Northern District of California
against SCEcorp, Edison, several nonutility subsidiaries, selected individuals,
and Kidder, Peabody & Co. CEC alleged antitrust violations of the Sherman Act,
conspiracy to interfere with contractual relations and common law unfair
competition. CEC asked for treble damages (as proved at trial) for antitrust
violations and compensatory and punitive damages for the pendent claims.
Furthermore, CEC requested that SCEcorp divest itself of Mission Energy. On
April 30, 1993, Edison and CEC reached a settlement. In June 1993, a
nonutility affiliate and CEC settled a related lawsuit concerning construction
of CEC's power plants. Pursuant to the settlements, the case was dismissed.
Further terms of the CEC settlement relate to litigation involving
Mission Power Engineering Company in connection with a construction contract.
In June 1990, Mission Power filed suit to foreclose on mechanics liens against
CEC, Coso Finance Partners, Coso Energy Developers, Coso Power Developers
("Coso Entities") and Credit Suisse in California Superior Court in Inyo
County. Mission Power claimed damages in excess of $79,000,000 and alleged
breach of contract, fraud and negligent misrepresentation. In December 1990,
the Coso Entities filed a cross- complaint against Mission Power and The
Mission Group alleging $97,000,000 plus punitive damages for breach of
contract, negligence, and misrepresentations. On June 10, 1993, the parties
announced they had reached a settlement of all outstanding disputes regarding
construction of the Coso Geothermal Project. Under the settlement, Coso
Partnerships made a net payment of $20,000,000 to Mission Power. This was less
than the amount of revenue Mission Power had previously recorded, resulting in
a one-time charge of $11,000,000 after tax for the second quarter.
Transphase Systems, Inc. filed a lawsuit on May 3, 1993, in the United
States District Court for the Central District of California against Edison and
San Diego Gas & Electric Company ("SDG&E"). The complaint alleged that
Transphase was competitively disadvantaged because it could not directly access
the demand side management funds Edison collects from its ratepayers to fund
conservation and demand side management activities and that the utilities
willfully acquired and maintain monopoly power in the energy conservation
industry. The complaint sought $50,000,000 in damages before trebling. Edison
filed a motion to dismiss the complaint on the grounds that it was without
merit. The court granted Edison's motion on October 7, 1993, and denied
plaintiffs the opportunity to replead the case. Plaintiffs have appealed to
the Ninth Circuit Court of Appeals.
ENVIRONMENTAL LITIGATION
On November 8, 1990, an environmental organization and two individuals
filed a lawsuit against Edison in United States Federal District Court for the
Southern District of California. The lawsuit alleges Edison's operation of San
Onofre Units 2 and 3 is in violation of its National Pollutant Discharge
Elimination System permits. The basis for the allegations was a report
prepared for the California Coastal Commission on the marine environmental
effects of the generating station. The plaintiffs requested that the Court
enjoin operation of Units 2 and 3, impose civil penalties, and order Edison to
repair the alleged damage to the marine environment. After mediation by the
court, the parties agreed on a settlement that includes: (i) $2,000,000 in
wetlands research which will be undertaken by the Pacific Estuarine Research
Laboratory at San Diego State University; (ii) $7,500,000 in additional wetland
restoration within the San Dieguito River Valley; (iii) a $5,500,000, 10 year,
Marine Education Program which will be based at Edison's Redondo Generating
Station; and (iv) $1,400,000 in attorney's fees. The court approved the
settlement on June 15, 1993.
22
<PAGE> 25
On September 23, 1993, the California Department of Toxic Substances
Control ("DTSC") issued a Report of Violation to Edison, alleging various
hazardous waste violations of the California Health & Safety Code at several
Edison facilities. Edison is currently in settlement negotiations with DTSC
regarding these alleged violations and tentatively has reached an agreement in
principle for settlement in the amount of $1,900,000.
SAN ONOFRE PERSONAL INJURY LITIGATION
In 1993, a former NRC inspector who was assigned to San Onofre in 1985
and 1986 filed a lawsuit against Edison, SDG&E and a fuel rod manufacturer in
Los Angeles County Superior Court, Central District. The case was subsequently
transferred to the Federal District Court for the Southern District of
California. The inspector claimed that exposure to radioactive materials at
the plant caused her leukemia. Plant records showed that the inspector's
exposure to radiation was well below NRC regulatory levels. Plaintiff
nevertheless alleged that she was exposed to radioactive fuel particles, that
this caused a radiation exposure above the NRC levels and that this exposure
was a legal cause for her illness. Plaintiff sought compensatory and punitive
damages. The defendants denied having liability for plaintiff's illness.
A jury trial began on January 4, 1994. In closing arguments at the
end of the trial, plaintiff's counsel requested damages between $4,000,000 and
$4,500,000 for medical costs and economic losses and asked for three to five
times that amount for pain and suffering compensatory damages. After
deliberations, the jury reported that it was "hung" and could not reach a
unanimous verdict on the threshold question of whether plaintiff was exposed to
radiation levels above the NRC-defined levels. (A 7-2 majority of the jury had
concluded that plaintiffs exposure did exceed these levels). Finding itself
hung on the exposure question, the jury did not decide the other questions
regarding causation, the amount of compensatory damages and whether Edison's
conduct warranted punitive damages. If the jury had found that punitive
damages should be assessed, the trial would have resumed to decide the amount
of such damages.
On February 8, 1994, the trial judge declared a mistrial because of
the hung jury. The second trial was scheduled to begin on March 15, 1994. On
March 14, 1994, the case was settled. The amount of the settlement payment
will not have a material adverse effect on Edison's net income.
ITEM 4. SUBMISSION OF MATTERS TO A VOTE OF SECURITY HOLDERS
Inapplicable.
Pursuant to Form 10-K's General Instruction ("General Instruction")
G(3), the following information is included as an additional item in Part I:
23
<PAGE> 26
EXECUTIVE OFFICERS OF THE REGISTRANT (1)(2)
SCECORP
<TABLE>
<CAPTION>
AGE AT
DECEMBER EFFECTIVE
EXECUTIVE OFFICER 31, 1993 COMPANY POSITION DATE
- ----------------- -------- ----------------- ---------------
<S> <C> <C> <C>
John E. Bryson 50 Chairman of the Board, Chief Executive October 1, 1990
Officer and Director
Bryant C. Danner 56 Senior Vice President and General July 1, 1992
Counsel
Alan J. Fohrer 43 Senior Vice President, Treasurer and January 21, 1993
Chief Financial Officer
Richard K. Bushey 53 Vice President and Controller July 21, 1988
Kenneth S. Stewart 42 Assistant General Counsel November 19, 1992
and Corporate Secretary
</TABLE>
- ---------------------
(1) The Executive Officers of SCEcorp include the Chairman of the Board
and Chief Executive Officer, the elected Vice Presidents and the
Secretary of SCEcorp and Edison as well as the Chief Executive
Officers and Presidents, Executive Vice Presidents and Senior Vice
Presidents of Mission Energy, Mission Financial, and Mission Land
(collectively "The Mission Companies") all of whom may be deemed
policy makers of SCEcorp.
(2) Effective March 1, 1993, Michael R. Peevey retired from his position
as President of SCEcorp.
None of SCEcorp's elected executive officers are related to each other
by blood or marriage. As set forth in Article IV of SCEcorp's Bylaws, the
elected officers of SCEcorp are chosen annually by and serve at the pleasure of
SCEcorp's Board of Directors and hold their respective offices until their
resignation, removal, other disqualification from service, or until their
respective successors are elected. Each of the elected executive officers of
SCEcorp holds an identical position with Edison except for Alan J. Fohrer, who
does not hold the Treasurer position at Edison and has been actively engaged in
the business of Edison for more than five years except for Bryant C. Danner.
Those officers who have not held their present position with SCEcorp and/or
Edison for the past five years had the following business experience during
that period:
<TABLE>
<S> <C> <C>
John E. Bryson Executive Vice President and Chief May 1988 to
Financial Officer of SCEcorp September 1990
Executive Vice President and January 1985 to
Chief Financial Officer of Edison September 1990
Bryant C. Danner Partner with law firm of Latham & Watkins(1)(2) January 1970 to
June 1992
Alan J. Fohrer Vice President, Treasurer and Chief April 1991 to
Financial Officer of SCEcorp and Edison January 1993
Assistant Treasurer of SCEcorp July 1988 to
March 1991
Assistant Treasurer and Manager of Cost September 1987
Control of Edison to March 1991
</TABLE>
24
<PAGE> 27
<TABLE>
<S> <C> <C>
Kenneth S. Stewart Assistant General Counsel of Edison March 1992 to
and SCEcorp October 1992
Senior Counsel of Edison March 1989 to
February 1992
Attorney of Edison June 1987 to
February 1989
- ----------------
</TABLE>
(1) Prior to leaving the law firm of Latham & Watkins, Bryant C. Danner
was in the firm's environmental department.
(2) This entity is not a parent, subsidiary or other affiliate of Edison.
EDISON
<TABLE>
<CAPTION>
AGE AT
DECEMBER EFFECTIVE
EXECUTIVE OFFICER 31, 1993 COMPANY POSITION(1)(2) DATE
- ----------------- --------- ----------------------- ---------------
<S> <C> <C> <C>
John E. Bryson 50 Chairman of the Board, Chief October 1, 1990
Executive Officer and Director
Bryant C. Danner 56 Senior Vice President and July 1, 1992
General Counsel
Alan J. Fohrer 43 Senior Vice President and June 17, 1993
Chief Financial Officer
Charles B. McCarthy, Jr. 53 Senior Vice President June 1, 1990
Harold B. Ray 53 Senior Vice President (Power Systems) June 1, 1990
R. H. Bridenbecker 50 Vice President (Customer Solutions) June 1, 1990
Vikram S. Budhraja 46 Vice President (Planning February 1, 1992
and Technology)
Richard K. Bushey 53 Vice President and Controller January 1, 1984
Ronald Daniels 54 Vice President (Regulatory Projects) August 10, 1992
John R. Fielder 48 Vice President (Regulatory Policy and February 1, 1992
Affairs)
Robert G. Foster 46 Vice President (Public Affairs) November 18, 1993
L. D. Hamlin 49 Vice President (Power Production) February 1, 1992
Margaret H. Jordan 50 Vice President (Health Care and December 7, 1992
and Employee Services)
Russell W. Krieger 45 Vice President (Nuclear Generation) June 17, 1993
J. Michael Mendez 52 Vice President (Regional Leadership) February 8, 1993
Georgia R. Nelson 43 Vice President (Performance Support) March 18, 1993
Lewis M. Phelps 50 Vice President (Corporate Communications) May 1, 1989
Richard M. Rosenblum 43 Vice President (Engineering and June 17, 1993
Technical Services)
C. Alex Miller 36 Treasurer June 17, 1993
Kenneth S. Stewart 42 Assistant General Counsel November 19, 1992
and Corporate Secretary
</TABLE>
- ---------------
(1) Effective March 1, 1993, Michael R. Peevey retired from his position
as President of Edison, and Harry E. Morgan, Jr. retired from his
position as Vice President of Edison and Site Manager of San Onofre.
At December 31, 1993, Charles B. McCarthy, Jr. was Senior Vice
President of Edison; however, effective January 1, 1994, Mr. McCarthy
retired from this position.
(2) John E. Bryson, Bryant C. Danner, Richard K. Bushey and Kenneth S.
Stewart also hold the same positions with SCEcorp. Alan J. Fohrer
holds the office of Senior Vice President, Treasurer and Chief
Financial Officer of SCEcorp. SCEcorp is the parent holding company
of Edison.
25
<PAGE> 28
None of Edison's executive officers are related to each other by blood
or marriage. As set forth in Article IV of Edison's Bylaws, the officers of
Edison are chosen annually by and serve at the pleasure of Edison's Board of
Directors and hold their respective offices until their resignation, removal,
other disqualification from service, or until their respective successors are
elected. All of the executive officers have been actively engaged in the
business of Edison for more than five years except for Bryant C. Danner and
Margaret H. Jordan. Those officers who have not held their present position
for the past five years had the following business experience during that
period:
<TABLE>
<S> <C> <C>
John E. Bryson Executive Vice President January 1985 to
and Chief Financial Officer September 1990
Bryant C. Danner Partner with Law Firm of January 1970 to
Latham & Watkins(1)(3) June 1992
Harold B. Ray Vice President -- Nuclear Engineering August 1989
Safety and Licensing to May 1990
Vice President -- Fuel Supply, January 1988
Procurement and Material Management to July 1989
R. H. Bridenbecker Vice President and Site Manager -- September 1989 to
San Onofre Nuclear Generating Station May 1990
Vice President (Customer Service) January 1988 to
August 1989
Vikram S. Budhraja Vice President -- System Planning April 1991 to
and Fuel Supply January 1992
Manager -- Electric System Planning September 1986 to
March 1991
Ronald Daniels Vice President -- Revenue Requirements August 1989 to
July 1992
Manager -- Revenue Requirements September 1975 to
July 1989
John R. Fielder Vice President -- Information Services January 1989 to
January 1992
Alan J. Fohrer Vice President, Treasurer and April 1991 to
Chief Financial Officer January 1993
Assistant Treasurer and Manager -- Cost Control September 1987 to
March 1991
L. D. Hamlin Manager -- Steam Generation April 1990 to
January 1992
Manager -- Research, System Planning September 1986
and Research Department to April 1990
Robert G. Foster Regional Vice President (Sacramento Office) January 1988 to
October 1993
Margaret H. Jordan Vice President -- Kaiser Foundation March 1986 to
Health Plan of Texas(2)(3) December 1992
Russell W. Krieger Station Manager (San Onofre) August 1990 to
May 1993
Station Operation Manager (San Onofre) August 1985 to
July 1990
</TABLE>
26
<PAGE> 29
<TABLE>
<S> <C> <C>
J. Michael Mendez Vice President -- Human Resources August 1991 to
February 1993
Division Vice President -- Customer Service January 1991
to July 1991
Division Manager -- Customer Service September 1989
to January 1991
Manager -- Personnel and Employee September 1985 to
Relations September 1989
Georgia R. Nelson Special Assistant to the Chairman February 1992 to
March 1993
Manager -- Procurement and September 1989 to
Material Management January 1992
Manager -- Telecommunications November 1987 to
August 1989
Lewis M. Phelps Manager -- Corporate Communications July 1985 to
April 1989
Richard M. Rosenblum Manager of Nuclear Regulatory Affairs June 1989 to
May 1993
Manager of Nuclear Oversight September 1986 to
May 1989
C. Alex Miller Assistant Treasurer April 1991 to
May 1993
Manager of Financial Planning and September 1987 to
Regulatory Finance March 1991
Kenneth S. Stewart Assistant General Counsel March 1992 to
November 1992
Senior Counsel March 1989 to
February 1992
Attorney June 1987 to
February 1989
</TABLE>
- ----------------
(1) Prior to leaving the law firm of Latham & Watkins, Bryant C. Danner
was in the firm's environmental department.
(2) As Vice President of the Kaiser Foundation Health Plan of Texas,
Margaret H. Jordan was responsible for serving over 124,000 members in
10 multispecialty medical offices in the Dallas/Fort Worth area.
(3) This entity is not a parent, subsidiary or other affiliate of Edison.
THE MISSION COMPANIES
<TABLE>
<CAPTION>
AGE AT
DECEMBER EFFECTIVE
EXECUTIVE OFFICER 31, 1993 COMPANY POSITION(1) DATE
- ----------------- --------- -------------------- ---------------
<S> <C> <C> <C>
Edward R. Muller 41 President and Chief Executive August 23, 1993
Officer -- Mission Energy
Robert M. Edgell 46 Executive Vice President -- Mission Energy April 1, 1988
Robert Dietch 55 Senior Vice President, Project February 1, 1992
Management/Operations -- Mission Energy
Alan M. Fenning 43 Senior Vice President and General April 1, 1988
Counsel -- Mission Energy
</TABLE>
27
<PAGE> 30
<TABLE>
<S> <C> <C> <C>
James V. Iaco, Jr. 49 Senior Vice President and Chief January 24, 1994
Financial Officer -- Mission Energy
S. Daniel Melita 42 Senior Vice President -- Mission Energy November 1, 1993
Thomas R. McDaniel 44 President and Chief Executive January 1, 1988
Officer -- Mission First Financial
and Mission Land
Lawrence W. Yu 40 Executive Vice President October 15, 1993
-- Mission First Financial
Michael L. Noel 52 Executive Vice President -- Mission Land January 17, 1994
Charles W. Johnson 47 Executive Vice President -- Mission Land August 7, 1992
</TABLE>
____________
(1) Effective August 1, 1993, James S. Pignatelli resigned from his
position as President and Chief Executive Officer of Mission Energy.
Alan J. Fohrer served as interim Vice Chairman and interim Chief
Executive Officer of Mission Energy prior to Edward R. Muller's
appointment as President and Chief Executive Officer. John A.
Moriarty served as Senior Vice President of Mission Land until April
15, 1993; Mr. Moriarty currently serves as Vice President of Mission
Land.
None of The Mission Companies' executive officers are related to each
other by blood or marriage. As set forth in Article IV of their respective
Bylaws, the officers of The Mission Companies are chosen annually by and serve
at the pleasure of the respective Boards of Directors and hold their respective
offices until their resignation, removal, other disqualification from service,
or until their respective successors are elected. All of the executive
officers have been actively engaged in the business of the respective Mission
Companies and/or SCEcorp and Edison for more than five years except for Edward
R. Muller, James V. Iaco, Jr., S. Daniel Melita and Charles W. Johnson. Those
officers who have not held their present position for the past five years had
the following business experience during that period:
<TABLE>
<S> <C> <C>
Edward R. Muller Vice President, Chief Financial Officer, October 1992 to
General Counsel and Secretary, July 1993
Whittaker Corporation(1)(13)
Vice President, Chief Administrative March 1988 to
Officer, General Counsel and September 1992
Secretary, Whittaker Corporation(2)(13)
James V. Iaco, Jr. President, James V. Iaco & Associates(3)(4)(13) October 1993 to
January 1994
Independent Business Consultant(5)(13) October 1992 to
September 1993
Independent Business Consultant(6)(13) November 1991 to
September 1992
Senior Vice President, Chief Financial January 1990 to
Officer, Intermark, Inc.(7)(13) October 1991
Senior Vice President, Chief Financial September 1981 to
Officer and Treasurer, MAXXAM Inc.(8)(13) October 1990
Robert Dietch Vice President, Engineering, Planning January 1987 to
and Research of Edison January 1992
</TABLE>
28
<PAGE> 31
<TABLE>
<S> <C> <C>
S. Daniel Melita Vice President, Mission Energy(9)(13) September 1992 to
October 1993
Vice President, International October 1989 to
Operations of EBASCO Constructors, August 1992
Inc., EBASCO Overseas Corporation(10)(13)
Michael L. Noel Senior Vice President and Chief February 1992 to
Financial Officer of Mission Energy December 1993
Senior Vice President of Edison April 1991 to
January 1992
Vice President, Treasurer and Chief October 1990 to
Financial Officer of SCEcorp and Edison March 1991
Vice President and Treasurer of SCEcorp July 1988 to
September 1990
Vice President and Treasurer of Edison July 1980 to
September 1990
Lawrence W. Yu Senior Vice President of Mission First Financial July 1991 to
September 1993
Vice President of Mission First Financial September 1987
to June 1991
Charles W. Johnson President, Glenfed Development Corp.(11)(13) September 1990 to
June 1992
Executive Vice President/Deputy August 1987 to
Subsidiary Group Administrator, Glenfed August 1990
Service Corporation(12)(13)
</TABLE>
____________
(1) Edward R. Muller served as Chief Financial Officer and General Counsel
(the second most senior officer) of Whittaker Corporation, a company
during the period from 1992 to 1993 engaged in various aerospace
businesses.
(2) Edward R. Muller served as Chief Administrative Officer and General
Counsel (the third most senior officer) of Whittaker Corporation, a
company during the period from 1988 to 1992 engaged in various
aerospace, chemical and biotechnology businesses and which underwent
significant restructurings, including a leveraged recapitalization and
a tax-free spin off.
(3) James V. Iaco, Jr. was elected Senior Vice President and Chief
Financial Officer of Mission Energy Company effective January 24,
1994.
(4) As President of James V. Iaco & Associates, James V. Iaco, Jr.
provided consultant services specializing in mergers and acquisitions,
restructurings, financing crisis management and other management
services.
(5) As an independent business consultant, James V. Iaco, Jr. completed
the disposition of subsidiaries of Phoenix Distributors, Inc.
("Phoenix"). Phoenix was one of the largest independent industrial
gas and welding supply distributor in the United States. Mr. Iaco
acted as the Company's chief financial officer, completing the
refinancing and restructuring of the remaining operation of the
Company.
(6) James V. Iaco, Jr. served as an independent business consultant
primarily engaged as the chief operating officer of a major developer
of time-share resort properties at the request of the shareholders.
(7) As Senior Vice President, Chief Financial Officer, James V. Iaco, Jr.
developed debt reduction and restructuring plans.
29
<PAGE> 32
(8) James V. Iaco, Jr. served as Senior Vice President, Chief Financial
Officer and Treasurer at MAXXAM, Inc., a Fortune 200 company engaged
in aluminum production, forest products operations and real estate
development.
(9) As Director International Business Development, S. Daniel Melita
planned and implemented international marketing and sales strategies
for all business units and was responsible for selecting team partners
and establishing joint venture companies.
(10) As Vice President, International Operations of EBASCO Constructors,
Inc./EBASCO Overseas Corporation, S. Daniel Melita was responsible for
all overseas activities including operations and business development,
consulting construction management and lump sum turn key construction.
(11) As President, Charles W. Johnson directed all real estate operations
and business combinations which included direct development, joint
ventures and syndications.
(12) As Executive Vice President, Charles W. Johnson directed all real
estate operations where Glenfed had made a direct equity investment.
This included August Financial Corporation, Glenfed Development
Corporation and Glenfed Properties.
(13) This entity is not a parent, subsidiary or other affiliate of SCEcorp.
PART II
ITEM 5. MARKET FOR REGISTRANT'S COMMON EQUITY AND RELATED STOCKHOLDER MATTERS
Information responding to Item 5 is included in SCEcorp's Annual
Report to Shareholders for the year ended December 31, 1993, ("Annual Report")
under "Quarterly Financial Data" on page 38 and under "Shareholder Information"
on page 41, and is incorporated by reference pursuant to General Instruction
G(2). The number of Common Stock shareholders of record was 140,600 on March
4, 1994. Additional information concerning the market for SCEcorp's Common
Stock is set forth on the cover page hereof.
ITEM 6. SELECTED FINANCIAL DATA
Information responding to Item 6 is included in the Annual Report
under "Selected Financial and Operating Data: 1989-1993" on page 40, and is
incorporated herein by reference pursuant to General Instruction G(2).
ITEM 7. MANAGEMENT'S DISCUSSION AND ANALYSIS OF RESULTS OF OPERATIONS AND
FINANCIAL CONDITION
Information responding to Item 7 is included in the Annual Report
under "Management's Discussion and Analysis" on pages 21 through 29 and is
incorporated herein by reference pursuant to General Instruction G(2).
ITEM 8. FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA
Certain information responding to Item 8 is set forth after Item 14 in
Part IV. Other information responding to Item 8 is included in the Annual
Report on pages 23 through 40 and is incorporated herein by reference pursuant
to General Instruction G(2).
ITEM 9. CHANGES IN AND DISAGREEMENTS WITH ACCOUNTANTS ON ACCOUNTING AND
FINANCIAL DISCLOSURE
None.
30
<PAGE> 33
PART III
ITEM 10. DIRECTORS AND EXECUTIVE OFFICERS OF THE REGISTRANT
Information concerning executive officers of SCEcorp is set forth in
Part I in accordance with General Instruction G(3), pursuant to Instruction 3
to Item 401(b) of Regulation S-K. Other information responding to Item 10 is
included in the Joint Proxy Statement ("Proxy Statement") filed with the
Commission in connection with SCEcorp's Annual Meeting to be held on April 21,
1994, under the heading, "Election of Directors of SCEcorp and Edison," and is
incorporated herein by reference pursuant to General Instruction G(3).
ITEM 11. EXECUTIVE COMPENSATION
Information responding to Item 11 is included in the Proxy Statement
under the heading "Election of Directors of SCEcorp and Edison," and is
incorporated herein by reference pursuant to General Instruction G(3).
ITEM 12. SECURITY OWNERSHIP OF CERTAIN BENEFICIAL OWNERS AND MANAGEMENT
Information responding to Item 12 is included in the Proxy Statement
under the headings "Election of Directors of SCEcorp and Edison," and "Stock
Ownership of Certain Shareholders" and is incorporated herein by reference
pursuant to General Instruction G(3).
ITEM 13. CERTAIN RELATIONSHIPS AND RELATED TRANSACTIONS
Information responding to Item 13 is included in the Proxy Statement
under the heading "Election of Directors of SCEcorp and Edison," and is
incorporated herein by reference pursuant to General Instruction G(3).
PART IV
ITEM 14. EXHIBITS, FINANCIAL STATEMENT SCHEDULES, AND REPORTS ON FORM 8-K
(A)(1) FINANCIAL STATEMENTS
The following items contained in the 1993 Annual Report to
Shareholders are incorporated by reference in this report.
Management's Discussion and Analysis of Results of Operations
and Financial Condition
Responsibility for Financial Reporting
Report of Independent Public Accountants
Consolidated Statements of Income -- Years Ended December 31,
1993, 1992 and 1991
Consolidated Balance Sheets -- December 31, 1993, and 1992
Consolidated Statements of Cash Flows -- Years Ended December
31, 1993, 1992 and 1991
Consolidated Statements of Retained Earnings -- Years Ended
December 31, 1993, 1992 and 1991
Notes to Consolidated Financial Statements
31
<PAGE> 34
(2) REPORT OF INDEPENDENT PUBLIC ACCOUNTANTS AND SCHEDULES
SUPPLEMENTING FINANCIAL STATEMENTS
The following documents may be found in this report at the indicated
page numbers.
<TABLE>
<CAPTION>
PAGE
------
<S> <C>
Report of Independent Public Accountants on Supplemental
Schedules . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 33
Schedule III--Condensed Financial Information of Parent . . . . . . . . . . . . . . . . . . . . 34
Schedule V--Property, Plant and Equipment for the Years Ended
December 31, 1993, 1992 and 1991 . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 36
Schedule VI--Accumulated Depreciation and Amortization of
Property, Plant, and Equipment for the Years Ended
December 31, 1993, 1992 and 1991 . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 39
Schedule VII--Guarantees of Securities of Other Issuers for
the Year Ended December 31, 1993 . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 42
Schedule VIII--Valuation and Qualifying Accounts for the
Years Ended December 31, 1993, 1992 and 1991 . . . . . . . . . . . . . . . . . . . . . . . . 43
Schedule IX--Short-Term Borrowings For Each of the Three
Years in the Period Ended December 31, 1993 . . . . . . . . . . . . . . . . . . . . . . . . . 46
Schedule X--Supplementary Income Statement Information For
for Each of the Three Years in the Period
Ended December 31, 1993 . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 47
Schedule XIII--Other Investments, December 31, 1993 . . . . . . . . . . . . . . . . . . . . . . 48
</TABLE>
Schedules I through XIII, inclusive, except those referred to above, are
omitted as not required or not applicable.
(3) EXHIBITS
See Exhibit Index on page 50 of this report.
(B) REPORTS ON FORM 8-K
October 12, 1993
Item 5: Other Events: Termination of Mission Energy Company
Project in Mexico
October 27, 1993
Item 5: Other Events: Earnings Report
Item 7: Financial Statements: Pro Forma Financial Information
and Exhibits
32
<PAGE> 35
REPORT OF INDEPENDENT PUBLIC ACCOUNTANTS
ON SUPPLEMENTAL SCHEDULES
To SCEcorp:
We have audited, in accordance with generally accepted auditing
standards, the consolidated financial statements included in the 1993 Annual
Report to Shareholders of SCEcorp, incorporated by reference in this Form 10-K,
and have issued our report thereon dated February 4, 1994. Our audits of the
consolidated financial statements were made for the purpose of forming an
opinion on those basic consolidated financial statements taken as a whole. The
supplemental schedules listed in Part IV of this Form 10-K which are the
responsibility of SCEcorp's management are presented for purposes of complying
with the Securities and Exchange Commission's rules and regulations, and are
not part of the basic consolidated financial statements. These supplemental
schedules have been subjected to the auditing procedures applied in the audits
of the basic consolidated financial statements and, in our opinion, fairly
state in all material respects the financial data required to be set forth
therein in relation to the basic consolidated financial statements taken as a
whole.
ARTHUR ANDERSEN & CO.
ARTHUR ANDERSEN & CO.
Los Angeles, California
February 4, 1994
33
<PAGE> 36
SCECORP
SCHEDULE III -- CONDENSED FINANCIAL INFORMATION OF PARENT
CONDENSED BALANCE SHEETS
<TABLE>
<CAPTION>
December 31,
---------------------------
1993 1992
---------- ----------
(IN THOUSANDS)
<S> <C> <C>
ASSETS:
Cash and equivalents . . . . . . . . . . . . . . . . . . . . . . . . . . . $ 6,004 $ 11,353
Other current assets . . . . . . . . . . . . . . . . . . . . . . . . . . . 143,607 158,640
---------- ----------
Total current assets . . . . . . . . . . . . . . . . . . . . . . . . . 149,611 169,993
Investments in subsidiaries . . . . . . . . . . . . . . . . . . . . . . . 5,927,922 5,943,771
Accumulated deferred income taxes -- net . . . . . . . . . . . . . . . . . 46,768 1,030
Other assets . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 258 552
---------- ----------
Total assets . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $6,124,559 $6,115,346
========== ==========
LIABILITIES AND SHAREHOLDERS' EQUITY:
Accounts payable . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $ 4,630 $ 3,353
Other current liabilities . . . . . . . . . . . . . . . . . . . . . . . . 162,348 158,256
---------- ----------
Total current liabilities . . . . . . . . . . . . . . . . . . . . . . . 166,978 161,609
Common shareholders' equity . . . . . . . . . . . . . . . . . . . . . . . 5,957,581 5,953,737
---------- ----------
Total liabilities and shareholders' equity . . . . . . . . . . . . . . $6,124,559 $6,115,346
========== ==========
</TABLE>
CONDENSED STATEMENTS OF INCOME
FOR THE YEARS ENDED DECEMBER 31, 1993, 1992, AND 1991
<TABLE>
<CAPTION>
1993 1992 1991
---------- -------- --------
(IN THOUSANDS, EXCEPT PER-SHARE AMOUNTS)
<S> <C> <C> <C>
Operating revenue and interest income . . . . . . . . . . . . . . $ 18,914 $13,974 $ 8,662
Operating expenses and income taxes . . . . . . . . . . . . . . . 20,231 14,611 9,454
---------- -------- --------
Loss before equity in earnings of subsidiaries . . . . . . . . (1,317) (637) (792)
Equity in earnings of subsidiaries . . . . . . . . . . . . . . . 640,364 739,357 703,397
---------- -------- --------
Net income . . . . . . . . . . . . . . . . . . . . . . . . $ 639,047 $738,720 $702,605
========== ======== ========
Weighted-average shares of common stock outstanding . . . . . . . 447,754 445,489 437,321
Earnings per share . . . . . . . . . . . . . . . . . . . . . . . $ 1.43 $ 1.66 $ 1.61
========== ======== ========
Note: Per-share figures reflect the two-for-one split of
SCEcorp common stock effective June 1, 1993.
</TABLE>
34
<PAGE> 37
SCECORP
SCHEDULE III--CONDENSED FINANCIAL INFORMATION OF PARENT (CONTINUED)
CONDENSED STATEMENTS OF CASH FLOWS
FOR THE YEARS ENDED DECEMBER 31, 1993, 1992, AND 1991
<TABLE>
<CAPTION>
1993 1992 1991
-------- -------- --------
(IN THOUSANDS)
<S> <C> <C> <C>
Cash Flows From Operating Activities . . . . . . . . . . . . . . $(46,143) $ 1,404 $ (71)
-------- -------- --------
Cash Flows From Financing Activities:
Capital contributions . . . . . . . . . . . . . . . . . . . . 41,250 (64,020) 69,505
-------- -------- --------
Cash Flows From Investing Activities . . . . . . . . . . . . . . (456) 3,380 --
-------- -------- --------
Increase (Decrease) in cash and equivalents . . . . . . . . . . . (5,349) (59,236) 69,434
Cash and equivalents at beginning of period . . . . . . . . . . . 11,353 70,589 1,155
-------- -------- --------
Cash and Equivalents at the End of Period . . . . . . . . . . $ 6,004 $ 11,353 $ 70,589
======== ======== ========
Cash dividends received from Southern California
Edison Company . . . . . . . . . . . . . . . . . . . . . . . . $631,325 $613,816 $588,513
======== ======== ========
</TABLE>
35
<PAGE> 38
SCECORP
SCHEDULE V -- PROPERTY, PLANT AND EQUIPMENT
FOR THE YEAR ENDED DECEMBER 31, 1993
<TABLE>
<CAPTION>
ADD (DEDUCT)
BALANCE AT --------------------------------------- BALANCE
BEGINNING OF ADDITIONS OTHER AT END OF
DESCRIPTION PERIOD AT COST RETIREMENTS CHANGES PERIOD
----------- ------------ --------- ----------- ------- -----------
(IN THOUSANDS)
<S> <C> <C> <C> <C> <C>
Steam production . . . . . . . $2,151,082 $130,586 $ (33,221) $ 4,687 $ 2,253,134
Nuclear production . . . . . . 5,380,457 61,597 (2,958) -- 5,439,096
Hydro production . . . . . . . 571,859 11,864 (453) -- 583,270
Other production . . . . . . . 396,095 19,391 (11,432) 391 404,445
Transmission . . . . . . . . . 2,568,391 86,972 (12,499) 467 2,643,331
Distribution . . . . . . . . . 5,608,233 342,022 (51,641) 11,980 5,910,594
General . . . . . . . . . . . . 1,072,671 121,986 (14,960) 177 1,179,874
Plant held for future use . . . 16,043 (14,393) (9) -- 1,641
Experimental electric plant
unclassified . . . . . . . . 31,381 4,818 (6,221) (17,946) 12,032
Other utility plant . . . . . . 8,419 343 (45) -- 8,717
----------- -------- ---------- -------- -----------
Subtotal--utility plant . . 17,804,631 765,186 (133,439) (244) 18,436,134
Construction work in
progress . . . . . . . . . . 723,765 124,321(a) 9,139 -- 857,225
Nuclear fuel . . . . . . . . . 776,262 86,225 (129,442) 26(b) 733,071
----------- -------- ---------- -------- -----------
Gross utility plant . . . . $19,304,658 $975,732 $ (253,742) $ (218) $20,026,430
=========== ======== ========== ======== ===========
Nonutility property . . . . . . $ 1,074,009 $320,326 $ (176,586) $131,891 $ 1,349,640
=========== ======== =========== ======== ===========
</TABLE>
_______________
(a) Reflects transfers to plant in service, which are net of additions to
construction work in progress.
(b) Reflects prior-year adjustments.
36
<PAGE> 39
SCECORP
SCHEDULE V -- PROPERTY, PLANT AND EQUIPMENT
FOR THE YEAR ENDED DECEMBER 31, 1992
<TABLE>
<CAPTION>
ADD (DEDUCT)
BALANCE AT ------------------------------------ BALANCE
BEGINNING OF ADDITIONS OTHER AT END OF
DESCRIPTION PERIOD AT COST RETIREMENTS CHANGES PERIOD
----------- ------------ --------- ----------- ------- ---------
(IN THOUSANDS)
<S> <C> <C> <C> <C> <C>
Steam production . . . . . . . . $ 2,054,404 $ 96,120 $ (15,578) $ 16,136 $ 2,151,082
Nuclear production . . . . . . . 5,915,872 70,661 (606,076)(b) -- 5,380,457
Hydro production . . . . . . . . 569,322 3,519 (982) -- 571,859
Other production . . . . . . . . 394,635 5,595 (4,135) -- 396,095
Transmission . . . . . . . . . . 2,468,478 106,779 (7,491) 625 2,568,391
Distribution . . . . . . . . . . 5,291,905 376,130 (59,909) 107 5,608,233
General . . . . . . . . . . . . . 993,991 125,687 (48,290) 1,283 1,072,671
Plant held for future use . . . . 17,629 132 (61) (1,657) 16,043
Experimental electric plant
unclassified . . . . . . . . . 58,145 263 (5,839) (21,188) 31,381
Other utility plant . . . . . . . 7,692 713 (150) 164 8,419
----------- -------- --------- -------- -----------
Subtotal--utility plant . . . 17,772,073 785,599 (748,511) (4,530) 17,804,631
Construction work in
progress . . . . . . . . . . . 794,303 (60,531)(a) 9,054 (19,061) 723,765
Nuclear fuel . . . . . . . . . . 973,554 20,356 (182,978) (34,670)(b) 776,262
----------- -------- --------- -------- -----------
Gross utility plant . . . . . $19,539,930 $745,424 $(922,435) $(58,261) $19,304,658
=========== ======== ========= ======== ===========
Nonutility property . . . . . . . $ 446,723 $ 22,689 $ (10,327) $614,924 $ 1,074,009
=========== ======== ========= ======== ===========
</TABLE>
_______________
(a) Reflects transfers to plant in service, which are net of additions to
construction work in progress.
(b) Reflects removal from service of nuclear generating plant under an
agreement reached with the California Public Utilities Commission.
37
<PAGE> 40
SCECORP
SCHEDULE V -- PROPERTY, PLANT AND EQUIPMENT
FOR THE YEAR ENDED DECEMBER 31, 1991
<TABLE>
<CAPTION>
ADD (DEDUCT)
BALANCE AT ------------------------------------ BALANCE
BEGINNING OF ADDITIONS OTHER AT END OF
DESCRIPTION PERIOD AT COST RETIREMENTS CHANGES PERIOD
----------- ------------ --------- ----------- ------- ---------
(IN THOUSANDS)
<S> <C> <C> <C> <C> <C>
Steam production . . . . . . . . $ 1,960,914 $ 98,818 $ (5,328) $ -- $ 2,054,404
Nuclear production . . . . . . . 5,789,475 129,931 (3,534) -- 5,915,872
Hydro production . . . . . . . . 556,197 13,555 (373) (57) 569,322
Other production . . . . . . . . 395,963 5,039 (6,367) -- 394,635
Transmission . . . . . . . . . . 2,405,526 74,072 (11,120) -- 2,468,478
Distribution . . . . . . . . . . 4,961,068 393,032 (61,807) (388) 5,291,905
General . . . . . . . . . . . . . 920,813 97,158 (21,714) (2,266) 993,991
Plant held for future use . . . . 17,110 152 (21) 388 17,629
Experimental electric plant
unclassified . . . . . . . . . 30,314 27,831 -- -- 58,145
Other utility plant . . . . . . . 7,224 506 (38) -- 7,692
----------- -------- --------- ------- -----------
Subtotal--utility plant . . . 17,044,604 840,094 (110,302) (2,323) 17,772,073
Construction work in
progress . . . . . . . . . . . 741,040 39,471(a) 13,792 -- 794,303
Nuclear fuel . . . . . . . . . . 1,020,897 83,674 (131,017) -- 973,554
----------- -------- --------- ------- -----------
Gross utility plant . . . . . $18,806,541 $963,239 $(227,527) $(2,323) $19,539,930
=========== ======== ========= ======= ===========
Nonutility property . . . . . . . $ 418,658 $ 66,535 $ (51,136) $12,666 $ 446,723
=========== ======== ========= ======= ===========
</TABLE>
____________
(a) Reflects transfers to plant in service, which are net of additions to
construction work in progress.
(b) Restated to include consolidated statements from affiliates.
38
<PAGE> 41
SCECORP
SCHEDULE VI -- ACCUMULATED DEPRECIATION AND AMORTIZATION
OF PROPERTY, PLANT AND EQUIPMENT
FOR THE YEAR ENDED DECEMBER 31, 1993
<TABLE>
<CAPTION>
ADDITIONS
CHARGED ADD (DEDUCT)
BALANCE AT TO COSTS ------------------------------------- BALANCE
BEGINNING OF AND OTHER AT END OF
DESCRIPTION PERIOD EXPENSES RETIREMENTS CHARGES(A) SALVAGE PERIOD
----------- ------------ -------- ----------- ---------- ------- ---------
(IN THOUSANDS)
<S> <C> <C> <C> <C> <C> <C>
Steam production . . . . $1,376,609 $109,929 $(21,637) $ (15,890) $3,279 $1,452,290
Nuclear production . . . 1,835,951 315,683 (2,757) (60,047) 108 2,088,938
Hydro production . . . . 153,594 11,297 (445) (302) - 164,144
Other production . . . . 229,998 12,737 (6,080) (3,288) 319 233,686
Transmission . . . . . . 843,228 60,655 (11,483) (3,262) 2,631 891,769
Distribution . . . . . . 1,833,654 213,309 (51,555) (27,201) 6,095 1,974,302
General . . . . . . . . . 268,189 59,402 (14,542) 2,145 192 315,386
Experimental electric
plant unclassified . . 19,590 7,600 (3,165) (6,935) -- 17,090
Retirement work in
progress . . . . . . . (22,514) -- 7,538 5,058 956 (8,962)
Other utility plant
reserves . . . . . . . 5,387 4,274 (14) (1) -- 9,646
---------- -------- -------- --------- ------ ----------
Subtotal . . . . . . . 6,543,686 794,886 (104,140) (109,723) 13,580 7,138,289
Nuclear fuel
amortization . . . . . 652,653 61,848 (129,442) -- -- 585,059
---------- -------- -------- --------- ------ ----------
Total utility plant
reserves . . . . . $7,196,339 $856,734 $(233,582) $(109,723) $13,580 $7,723,348
========== ======== ======== ========= ======= ==========
Nonutility property
reserves . . . . . . . $ 50,478 $ 28,993 $ (9,252) $ 2,950 $ -- $ 73,169
========== ======== ======== ========= ======= ==========
</TABLE>
____________
(a) Includes removal costs related to facilities retired, damage claims
and relocation costs collected from others, and various other
adjustments of depreciation and amortization.
39
<PAGE> 42
SCECORP
SCHEDULE VI -- ACCUMULATED DEPRECIATION AND AMORTIZATION
OF PROPERTY, PLANT AND EQUIPMENT
FOR THE YEAR ENDED DECEMBER 31, 1992
<TABLE>
<CAPTION>
ADDITIONS
CHARGED ADD (DEDUCT
BALANCE AT TO COSTS ------------------------------------ BALANCE
BEGINNING OF AND OTHER AT END OF
DESCRIPTION PERIOD EXPENSES RETIREMENTS CHARGES(A) SALVAGE PERIOD
----------- ------------ --------- ----------- ---------- ------- ----------
(In thousands)
<S> <C> <C> <C> <C> <C> <C>
Steam production . . . . $1,301,013 $ 99,652 $ (15,798) $ (8,588) $ 330 $1,376,609
Nuclear production . . . 1,926,088 319,875 (777,264)(b) 367,166 86 1,835,951
Hydro production . . . . 143,797 11,223 (982) (444) -- 153,594
Other production . . . . 228,740 11,116 (4,090) (6,068) 300 229,998
Transmission . . . . . . 790,677 58,443 (7,017) (476) 1,601 843,228
Distribution . . . . . . 1,712,575 201,666 (59,792) (28,757) 7,962 1,833,654
General . . . . . . . . . 254,535 56,665 (48,309) 4,981 317 268,189
Experimental electric
plant unclassified . . 19,275 6,212 (5,839) (58) -- 19,590
Retirement work in . . .
progress . . . . . . . (40,590) -- 4,785 9,462 3,829 (22,514)
Other utility plant
reserves . . . . . . . 3,038 2,425 (76) -- -- 5,387
---------- --------- --------- -------- ------- ----------
Subtotal . . . . . . . 6,339,148 767,277 (914,382) 337,218 14,425 6,543,686
Nuclear fuel
amortization . . . . . 726,327 109,266 (182,978) 38 -- 652,653
---------- --------- --------- -------- ------- ----------
Total utility plant
reserves . . . . . $7,065,475 $876,543 $(1,097,360) $337,256 $14,425 $7,196,339
========== ========= ========= ======== ======= ==========
Nonutility property
reserves . . . . . . . $ 43,994 $ 11,402 $ (1,947) $ (2,971) $ -- $ 50,478
========== ========= ========= ======== ======= ==========
</TABLE>
____________
(a) Includes removal costs related to facilities retired, damage claims
and relocation costs collected from others, and various other
adjustments of depreciation and amortization.
(b) Reflects removal from service of nuclear generating plant under an
agreement reached with the California Public Utilities Commission.
40
<PAGE> 43
SCECORP
SCHEDULE VI -- ACCUMULATED DEPRECIATION AND AMORTIZATION
OF PROPERTY, PLANT AND EQUIPMENT
FOR THE YEAR ENDED DECEMBER 31, 1991
<TABLE>
<CAPTION>
ADDITIONS
CHARGED ADD (DEDUCT)
BALANCE AT TO COSTS ----------------------------------- BALANCE
BEGINNING OF AND OTHER AT END OF
DESCRIPTION PERIOD EXPENSES RETIREMENTS CHARGES(A) SALVAGE PERIOD
----------- ------------ -------- ----------- ---------- ------- ----------
(IN THOUSANDS)
<S> <C> <C> <C> <C> <C> <C>
Steam production . . . . $1,217,709 $ 88,644 $(5,112) $ (778) $ 550 $1,301,013
Nuclear production . . . 1,607,984 324,610 (3,508) (3,050) 52 1,926,088
Hydro production . . . . 135,630 8,754 (387) (240) 40 143,797
Other production . . . . 222,660 12,554 (6,365) (109) -- 228,740
Transmission . . . . . . 724,070 76,608 (10,686) (2,606) 3,291 790,677
Distribution . . . . . . 1,601,611 190,922 (61,709) (27,789) 9,540 1,712,575
General . . . . . . . . . 219,110 51,831 (21,809) 4,981 422 254,535
Experimental electric
plant unclassified . . 11,003 8,272 -- -- -- 19,275
Retirement work in . . .
progress . . . . . . . (46,557) -- 14,426 (8,239) (220) (40,590)
Other utility plant
reserves . . . . . . . 2,863 213 (39) 1 -- 3,038
---------- -------- ------- ------- ------- ----------
Subtotal . . . . . . . 5,696,083 762,408 (95,189) (37,829) 13,675 6,339,148
Nuclear fuel
amortization . . . . . 725,989 131,355 (131,017) -- -- 726,327
---------- -------- ------- ------- ------- ----------
Total utility plant
reserves . . . . . $6,422,072 $893,763 $(226,206) $(37,829) $13,675 $7,065,475
========== ======== ======= ======= ======= ==========
Nonutility property
reserves(b) . . . . . $ 39,992 $ 8,493 $ (2,653) $ (1,838) $ -- $ 43,994
========== ======== ======= ======= ======= ==========
</TABLE>
____________
(a) Includes removal costs related to facilities retired, damage claims
and relocation costs collected from others, and various other
adjustments of depreciation and amortization.
(b) Restated to include consolidated statements from affiliates.
41
<PAGE> 44
SCECORP
SCHEDULE VII -- GUARANTEES OF SECURITIES OF OTHER ISSUERS
FOR THE YEAR ENDED DECEMBER 31, 1993
(IN THOUSANDS)
<TABLE>
<CAPTION>
Amount in Nature of any default
Name of Issuer Title of issue Amount treasury of guaranteed in principal
of securities of each class Total amount owned issuer of interest, sinking fund
guarantee by of securities guaranteed and by the securities Nature of redemption provisions,
SCEcorp guaranteed outstanding Company guaranteed guarantee or payment of dividneds
- ------------- -------------- -------------- ------- ----------- ---------- -----------------------
<S> <C> <C> <C> <C> <C> <C>
Ontario Lakeshore Construction Principal
Partners Loan $15,000 --- --- and Interest None
Centrelake Construction Principal
Partners Loan $5,000 --- --- and Interest None
Carol Stream Acquisition
Developers and Development Principal
Loan $7,935 --- --- and Interest None
</TABLE>
42
<PAGE> 45
SCECORP
SCHEDULE VIII -- VALUATION AND QUALIFYING ACCOUNTS
FOR THE YEAR ENDED DECEMBER 31, 1993
<TABLE>
<CAPTION>
ADDITIONS
------------------------
BALANCE AT CHARGED TO CHARGED TO BALANCE
BEGINNING OF COSTS AND OTHER AT END
DESCRIPTION PERIOD EXPENSES ACCOUNTS DEDUCTIONS OF PERIOD
----------- ----------- ---------- ---------- ---------- ----------
(IN THOUSANDS)
<S> <C> <C> <C> <C> <C>
Group A:
Uncollectible accounts --
Customers . . . . . . . . . . . $ 8,970 $ 38,314 $ 481 $ 31,374 $ 16,391
All other . . . . . . . . . . . 32,572 12,772 (481) 3,321 41,542
-------- -------- ------- -------- --------
Total . . . . . . . . . . . $ 41,542 $ 51,086 $ -- $ 34,695(a) $ 57,933
======== ======== ======= ======== ========
Group B:
Regulatory settlement . . . . . . $113,380 $ 10,620 $ -- $124,000(b) $ --
DOE Decontamination
and Decommissioning . . . . . . 53,136 -- 19,156(c) 5,164(d) 67,128
Pension and benefits . . . . . . . 111,139 48,692 22,064(e) 50,131(f) 131,764
Insurance, casualty and
other . . . . . . . . . . . . . 64,019 51,843 -- 48,159(g) 67,703
-------- -------- ------- -------- --------
Total . . . . . . . . . . . $341,674 $111,155 $41,220 $227,454 $266,595
======== ======== ======= ======== ========
</TABLE>
________________
(a) Accounts written off, net.
(b) Represents final settlement with the California Public Utilities
Commission's Division of Ratepayer Advocates regarding affiliated
company power purchases.
(c) Represents new estimate based on actual billings.
(d) Represents amounts paid.
(e) Primarily represents transfers from the accrued paid absence allowance
account for required additions to the comprehensive disability plan
accounts.
(f) Includes pension payments to retired employees, amounts paid to active
employees during periods of illness and the funding of certain pension
benefits.
(g) Amounts charged to operations that were not covered by insurance.
43
<PAGE> 46
SCECORP
SCHEDULE VIII -- VALUATION AND QUALIFYING ACCOUNTS
FOR THE YEAR ENDED DECEMBER 31, 1992
<TABLE>
<CAPTION>
ADDITIONS
---------------------------
BALANCE AT CHARGED TO CHARGED TO BALANCE
BEGINNING OF COSTS AND OTHER AT END
DESCRIPTION PERIOD EXPENSES ACCOUNTS DEDUCTIONS OF PERIOD
----------- ------------ ---------- -------------- ---------- ---------
(IN THOUSANDS)
<S> <C> <C> <C> <C> <C>
Group A:
Uncollectible accounts ---
Customers . . . . . . . . . . $ 10,028 $ 23,041 $ --- $ 24,099 $ 8,970
All other . . . . . . . . . . 11,934 25,846 --- 5,208 32,572(a)
--------- ---------- -------- --------- ----------
Total . . . . . . . . . . . $ 21,962 $ 48,887 $ --- $ 29,307(b) $ 41,542
========= ========== ======== ========= ==========
Group B:
Regulatory settlement . . . . . $ 124,000 $ --- 9,320(c) 19,940(d) $ 113,380
DOE decontamination
and decommissioning . . . . . --- --- 53,136(e) --- 53,136
Environmental cleanup . . . . . 40,000 --- 5,000(e) 45,000(f) ---
Pension and benefits . . . . . . 112,007 30,905 20,562(g) 52,335(h) 111,139
Insurance, casualty and
other . . . . . . . . . . . . 70,513 71,040 --- 77,534(i) 64,019
--------- ---------- -------- --------- ----------
Total . . . . . . . . . . . $ 346,520 $ 101,945 $ 88,018 $ 194,809 $ 341,674
========= ========== ======== ========= ==========
</TABLE>
____________
(a) Includes reserve for net realizable value write-down.
(b) Accounts written off, net.
(c) Represents reserve addition for the settlement with the California
Public Utilities Commission's Division of Ratepayer Advocates
regarding affiliated company power purchases.
(d) Represents the amortization of the difference between the nominal
value and the present value.
(e) Represents the estimated long-term costs to be incurred and recovered
through rates over 15 years; reclassified from account 253.
(f) Represents an additional estimated liability established for
environmental cleanup costs expected to be incurred and recovered
through rates in future years.
(g) Amount reclassified to Account 253, other deferred credits.
(h) Primarily represents transfers from the accrued paid absence allowance
account for required additions to the comprehensive disability plan
accounts.
(i) Includes pension payments to retired employees, amounts paid to active
employees during periods of illness and the funding of certain pension
benefits.
(j) Amounts charged to operations that were not covered by insurance.
44
<PAGE> 47
SCECORP
SCHEDULE VIII -- VALUATION AND QUALIFYING ACCOUNTS
FOR THE YEAR ENDED DECEMBER 31, 1991
<TABLE>
<CAPTION>
ADDITIONS
---------------------------
BALANCE AT CHARGED TO CHARGED TO BALANCE
BEGINNING OF COSTS AND OTHER AT END
DESCRIPTION PERIOD EXPENSES ACCOUNTS DEDUCTIONS OF PERIOD
----------- ------------ ---------- -------------- ---------- ---------
(IN THOUSANDS)
<S> <C> <C> <C> <C> <C>
Group A:
Uncollectible accounts ---
Customers . . . . . . . . . . $ 10,423 $ 22,533 $ --- $ 22,928 $ 10,028
All other . . . . . . . . . . 7,814 9,358 --- 5,238 11,934(a)
--------- --------- -------- -------- ---------
Total . . . . . . . . . . . $ 18,237 $ 31,891 $ --- $ 28,166(b) $ 21,962
========= ========= ======== ======== =========
Group B:
Regulatory settlement . . . . . $ --- 124,000(c) $ --- $ --- $ 124,000
Environmental cleanup . . . . . --- --- 40,000(d) --- 40,000
Pension and benefits . . . . . . 98,886 29,267 18,749(e) 34,895(f) 112,007
Insurance, casualty and
other . . . . . . . . . . . . 61,620 63,901 --- 55,008(g) 70,513
--------- --------- -------- -------- ---------
Total . . . . . . . . . . . $ 160,506 $ 217,168 $ 58,749 $ 89,903 $ 346,520
========= ========= ======== ======== =========
</TABLE>
____________
(a) Includes reserve for net realizable value write-down.
(b) Accounts written off, net.
(c) Represents reserve addition for a proposed settlement with the
California Public Utilities Commission's Division of Ratepayer
Advocates regarding affiliated company power purchases.
(d) Represents an estimated minimum liability established for
environmental cleanup costs expected to be incurred and recovered
through rates in future years.
(e) Primarily represents transfers from the accrued paid absence allowance
account for required additions to the comprehensive disability plan
accounts.
(f) Includes pension payments to retired employees, amounts paid to active
employees during periods of illness and the funding of certain pension
benefits.
(g) Amounts charged to operations that were not covered by insurance.
45
<PAGE> 48
SCECORP
SCHEDULE IX -- SHORT-TERM BORROWINGS
FOR EACH OF THE THREE YEARS IN THE PERIOD ENDED DECEMBER 31, 1993
<TABLE>
<CAPTION>
WEIGHTED
MAXIMUM AVERAGE AVERAGE
WEIGHTED AMOUNT AMOUNT INTEREST
BALANCE AVERAGE OUTSTANDING OUTSTANDING RATE
AT END INTEREST DURING DURING DURING
DESCRIPTION OF PERIOD RATE THE PERIOD THE PERIOD THE PERIOD
----------- --------- -------- ----------- ----------- ----------
(A) (B)
(DOLLARS IN THOUSANDS)
<S> <C> C> <C> <C> <C>
DECEMBER 31, 1993:
Payable to holders of commercial
paper--general purpose . . . . . $ 252,000 3.47% $ 420,800 $201,800 3.36%
Payable to holders of commercial
paper--balancing accounts . . . . 163,500 3.47 246,900 119,823 3.36
Payable to holders of commercial
paper--fuel . . . . . . . . . . . 269,600(c) 3.47 269,600 225,037 3.36
Payable to holders of commercial
paper--leveraged leases . . . . . 181,600(c) 3.40 181,600 181,600 6.92
Payable to bank--general
purpose . . . . . . . . . . . . . 22,250 10.37 209,781 120,321 7.91
Payable to unconsolidated
subsidiary--fuel . . . . . . . . --- --- 31,000 28,367 3.90
DECEMBER 31, 1992:
Payable to holders of commercial
paper--general purpose . . . . . $ 197,700 3.65% $ 350,400 $ 87,000 4.03%
Payable to holders of commercial
paper--balancing accounts . . . . 246,900 3.65 455,700 361,000 4.03
Payable to holders of commercial
paper--fuel . . . . . . . . . . . 228,300(c) 3.65 400,100 318,000 4.03
Payable to bank--leveraged leases . 181,600(c) 3.77 181,600 162,840 7.09
Payable to bank--general
purpose . . . . . . . . . . . . . 119,460 7.34 534,714 182,337 7.06
Payable to unconsolidated
subsidiary--fuel . . . . . . . . 31,000 3.97 31,000 24,757 4.43
DECEMBER 31, 1991:
Payable to holders of commercial
paper--general purpose . . . . . --- --- $ 461,900 $149,633 6.39%
Payable to holders of commercial
paper--balancing accounts . . . . $ 419,600 5.14% 506,700 476,000 6.36
Payable to holders of commercial
paper--fuel . . . . . . . . . . . 372,200(c) 5.14 436,100 397,000 6.36
Payable to holders of commercial
paper--leveraged leases . . . . . 181,600(c) 4.95 186,600 94,133 7.78
Payable to bank--general
purpose . . . . . . . . . . . . . 142,310 5.58 214,785 85,614 7.28
Payable to others--fuel . . . . . . 16,000 5.57 16,000 3,995 6.10
</TABLE>
_____________
(a) Average amount outstanding during the period is computed by dividing
the total of daily outstanding principal balances by 365.
(b) Weighted-average interest rate during the period is computed by
dividing the total interest expense by the average amount outstanding.
(c) Under credit agreements with commercial banks which allow SCEcorp to
refinance short-term borrowings on a long-term basis, borrowings of
$252,000,000 as of December 31, 1993, $245,000,000 as of December 31,
1992, and $333,000,000 as of December 31, 1991, have been reclassified
as long-term debt on the Consolidated Balance Sheet in the 1993 Annual
Report.
46
<PAGE> 49
SCECORP
SCHEDULE X -- SUPPLEMENTARY INCOME STATEMENT INFORMATION
FOR EACH OF THE THREE YEARS IN THE PERIOD ENDED DECEMBER 31, 1993
<TABLE>
<CAPTION>
CHARGED
TO
EXPENSE
-------
(IN THOUSANDS)
<S> <C>
Year ended December 31, 1993:
Property taxes . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $159,661
Year ended December 31, 1992:
Property taxes . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 155,792
Year ended December 31, 1991:
Property taxes . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 151,869
</TABLE>
____________
Note: Depreciation and maintenance expenses appear on the Consolidated
Statements of Income. Royalties paid and advertising costs included
in Other Operating Expenses are less than 1% of total operating
revenue.
47
<PAGE> 50
SCECORP
SCHEDULE XIII -- OTHER INVESTMENTS
DECEMBER 31, 1993
(IN THOUSANDS)
<TABLE>
<CAPTION>
NUMBER OF SHARES AMOUNT AT WHICH
OR PRINCIPAL MARKET CARRIED IN BALANCE
DESCRIPTION AMOUNT COST VALUE SHEET
----------- ---------------- ---- ------- ------------------
<S> <C> <C> <C> <C>
INVESTMENTS IN NUCLEAR
DECOMMISSIONING TRUSTS:
Qualified trust . . . . . . . . . -- $ 681,687 $ 732,314 $ 681,687
Non-qualified trust . . . . . . . -- 106,888 121,028 106,888
---------- ---------- ----------
$ 788,575 $ 853,342 $ 788,575
========== ========== ==========
INVESTMENTS IN PARTNERSHIPS AND
UNCONSOLIDATED SUBSIDIARIES:
Energy partnerships . . . . . . . -- $ 687,504 $ 669,346 $ 664,407
Real estate partnerships . . . . . -- 260,073 260,073 218,543
Unconsolidated subsidiary . . . . -- 328,747 279,508 279,502
---------- ---------- ----------
$1,276,324 $1,208,927 $1,162,452
========== ========== ==========
INVESTMENTS IN LEVERAGED LEASES(A) . . . -- $ 354,449 $ 354,449 $ 497,469
========== ========== ==========
OTHER INVESTMENTS . . . . . . . . . . . . -- $ 20,577 $ 20,577 $ 20,577
========== ========== ==========
</TABLE>
____________
(a) Market value is assumed to equal current unrecovered investment less
deferred taxes.
48
<PAGE> 51
SIGNATURES
Pursuant to the requirements of Section 13 or 15(d) of the Securities
Exchange Act of 1934, the registrant has duly caused this report to be signed
on its behalf by the undersigned, thereunto duly authorized.
SCEcorp
By W. J. Scilacci
--------------------------------
(W. J. Scilacci,
Assistant Treasurer)
Date: March 17, 1994
Pursuant to the requirements of the Securities Exchange Act of 1934,
this report has been signed below by the following persons on behalf of the
registrant and in the capacities and on the dates indicated.
<TABLE>
<CAPTION>
SIGNATURE TITLE DATE
--------- ----- ----
<S> <C> <C>
Principal Executive Officer:
John E. Bryson* Chairman of the Board, March 17, 1994
Chief Executive Officer
and Director
Principal Financial Officer:
Alan J. Fohrer* Senior Vice President,
Treasurer and Chief March 17, 1994
Financial Officer
Controller or Principal
Accounting Officer:
Richard K. Bushey* Vice President and March 17, 1994
Controller
Majority of Board of Directors:
Howard P. Allen* Director March 17, 1994
Norman Barker, Jr.* Director March 17, 1994
Walter B. Gerken* Director March 17, 1994
Joan C. Hanley* Director March 17, 1994
Carl F. Huntsinger* Director March 17, 1994
Luis G. Nogales* Director March 17, 1994
J. J. Pinola* Director March 17, 1994
Henry T. Segerstrom* Director March 17, 1994
E. L. Shannon, Jr.* Director March 17, 1994
Daniel M. Tellep* Director March 17, 1994
James D. Watkins* Director March 17, 1994
Edward Zapanta* Director March 17, 1994
</TABLE>
By W. J. Scilacci
---------------------------------------
(W. J. Scilacci, Attorney-in-Fact)
49
<PAGE> 52
EXHIBIT INDEX
<TABLE>
<CAPTION>
EXHIBIT
NUMBER DESCRIPTION
- ------- -----------
<S> <C>
3.1 Restated Articles of Incorporation as amended through
April 25, 1988 (Registration No. 33-19541)* . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
3.2 Certificate of Amendment of Restated Articles of Incorporation of
SCEcorp (Registration No 33-37381)* . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
3.3 Bylaws as adopted by the Board of Directors on November 18, 1993 . . . . . . . . . . . . . . . . . . . . .
4.1 Trust Indenture, dated as of October 1, 1923 (Registration No. 2-1369)* . . . . . . . . . . . . . . . . .
4.2 Supplemental Indenture, dated as of March 1,1927 (Registration No. 2-1369)* . . . . . . . . . . . . . . .
4.3 Second Supplemental Indenture, dated as of April 25, 1935 (Registration No. 2-1472)* . . . . . . . . . . .
4.4 Third Supplemental Indenture, dated as of June 24, 1935 (Registration No. 2-1602)* . . . . . . . . . . . .
4.5 Fourth Supplemental Indenture, dated as of September 1, 1935 (Registration No. 2-4522)* . . . . . . . . .
4.6 Fifth Supplemental Indenture, dated as of August 15, 1939 (Registration No. 2-4522)* . . . . . . . . . . .
4.7 Sixth Supplemental Indenture, dated as of September 1, 1940 (Registration No. 2-4522)* . . . . . . . . . .
4.8 Seventh Supplemental Indenture, dated as of January 15, 1948 (Registration No. 2-7369)* . . . . . . . . .
4.9 Eighth Supplemental Indenture, dated as of August 15, 1948 (Registration No. 2-7610)* . . . . . . . . . .
4.10 Ninth Supplemental Indenture, dated as of February 15, 1951 (Registration No. 2-8781)* . . . . . . . . . .
4.11 Tenth Supplemental Indenture, dated as of August 15, 1951 (Registration No. 2-7968)* . . . . . . . . . . .
4.12 Eleventh Supplemental Indenture, dated as of August 15, 1953 (Registration No. 2-10396)* . . . . . . . . .
4.13 Twelfth Supplemental Indenture, dated as of August 15, 1954 (Registration No. 2-11049)* . . . . . . . . .
4.14 Thirteenth Supplemental Indenture, dated as of April 15, 1956 (Registration No. 2-12341)*. . . . . . . . .
4.15 Fourteenth Supplemental Indenture, dated as of February 15, 1957 (Registration No. 2-13030)* . . . . . . .
4.16 Fifteenth Supplemental Indenture, dated as of July 1, 1957 (Registration No. 2-13418)* . . . . . . . . . .
4.17 Sixteenth Supplemental Indenture, dated as of August 15, 1957 (Registration No. 2-13516)* . . . . . . . .
4.18 Seventeenth Supplemental Indenture, dated as of August 15, 1958 (Registration No. 2-14285)* . . . . . . .
4.19 Eighteenth Supplemental Indenture, dated as of January 15, 1960 (Registration No. 2-15906)* . . . . . . .
4.20 Nineteenth Supplemental Indenture, dated as of August 15, 1960 (Registration No. 2-16820)* . . . . . . . .
4.21 Twentieth Supplemental Indenture, dated as of April 1, 1961 (Registration No. 2-17668)* . . . . . . . . .
4.22 Twenty-First Supplemental Indenture, dated as of May 1, 1962 (Registration No. 2-20221)* . . . . . . . . .
4.23 Twenty-Second Supplemental Indenture, dated as of October 15, 1962 (Registration No. 2-20791)* . . . . . .
4.24 Twenty-Third Supplemental Indenture, dated as of May 15, 1963 (Registration No. 2-21346)* . . . . . . . .
</TABLE>
50
<PAGE> 53
EXHIBIT INDEX
<TABLE>
<CAPTION>
EXHIBIT
NUMBER DESCRIPTION
- ------- -----------
<S> <C>
4.25 Twenty-Fourth Supplemental Indenture, dated as of February 15, 1964 (Registration No. 2-22056)* . . . . . .
4.26 Twenty-Fifth Supplemental Indenture, dated as of February 1, 1965 (Registration No. 2-23082)* . . . . . . .
4.27 Twenty-Sixth Supplemental Indenture, dated as of May 1, 1966 (Registration No. 2-24835)* . . . . . . . . .
4.28 Twenty-Seventh Supplemental Indenture, dated as of August 15, 1966 (Registration No. 2-25314)*. . . . . . .
4.29 Twenty-Eighth Supplemental Indenture, dated as of May 1, 1967 (Registration No. 2-26323)* . . . . . . . . .
4.30 Twenty-Ninth Supplemental Indenture, dated as of February 1, 1968 (Registration No. 2-28000)* . . . . . . .
4.31 Thirtieth Supplemental Indenture, dated as of January 15, 1969 (Registration No. 2-31044)* . . . . . . . .
4.32 Thirty-First Supplemental Indenture, dated as of October 1, 1969 (Registration No. 2-34839)* . . . . . . .
4.33 Thirty-Second Supplemental Indenture, dated as of December 1, 1970 (Registration No. 2-38713)* . . . . . .
4.34 Thirty-Third Supplemental Indenture, dated as of September 15, 1971 (Registration No. 2-41527)* . . . . . .
4.35 Thirty-Fourth Supplemental Indenture, dated as of August 15, 1972 (Registration No. 2-45046)* . . . . . . .
4.36 Thirty-Fifth Supplemental Indenture, dated as of February 1, 1974 (Registration No. 2-50039)* . . . . . . .
4.37 Thirty-Sixth Supplemental Indenture, dated as of July 1, 1974 (Registration No. 2-59199)* . . . . . . . . .
4.38 Thirty-Seventh Supplemental Indenture, dated as of November 1, 1974 (Registration No. 2-52160)* . . . . . .
4.39 Thirty-Eighth Supplemental Indenture, dated as of March 1, 1975 (Registration No. 2-52776)* . . . . . . . .
4.40 Thirty-Ninth Supplemental Indenture, dated as of March 15, 1976 (Registration No. 2-55463)* . . . . . . . .
4.41 Fortieth Supplemental Indenture, dated as of July 1, 1977 (Registration No. 2-59199)* . . . . . . . . . . .
4.42 Forty-First Supplemental Indenture, dated as of November 1, 1978 (Registration No. 2-62609)* . . . . . . .
4.43 Forty-Second Supplemental Indenture, dated as of June 15, 1979 (File No.1-2313)* . . . . . . . . . . . . .
4.44 Forty-Third Supplemental Indenture, dated as of September 15, 1979 (File No. 1-2313)* . . . . . . . . . . .
4.45 Forty-Fourth Supplemental Indenture, dated as of October 1, 1979 (Registration No. 2-65493)* . . . . . . .
4.46 Forty-Fifth Supplemental Indenture, dated as of April 1, 1980 (Registration No. 2-66896)* . . . . . . . . .
4.47 Forty-Sixth Supplemental Indenture, dated as of November 15, 1980 (Registration No. 2-69609)* . . . . . . .
4.48 Forty-Seventh Supplemental Indenture, dated as of May 15, 1981 (Registration No. 2-71948)* . . . . . . . .
4.49 Forty-Eighth Supplemental Indenture, dated as of August 1, 1981 (File No. 1-2313)* . . . . . . . . . . . .
</TABLE>
51
<PAGE> 54
EXHIBIT INDEX
<TABLE>
<CAPTION>
EXHIBIT
NUMBER DESCRIPTION
- ------- -----------
<S> <C>
4.50 Forty-Ninth Supplemental Indenture, dated as of December 1, 1981
(Registration No. 2-74339)* . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
4.51 Fiftieth Supplemental Indenture, dated as of January 16, 1982
(File No. 1-2313)* . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
4.52 Fifty-First Supplemental Indenture, dated as of April 15, 1982
(Registration No. 2-76626)* . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
4.53 Fifty-Second Supplemental Indenture, dated as of November 1, 1982
(Registration No. 2-79672)* . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
4.54 Fifty-Third Supplemental Indenture, dated as of November 1, 1982
(File No. 1-2313)* . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
4.55 Fifty-Fourth Supplemental Indenture, dated as of January 1, 1983
(File No. 1-2313)* . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
4.56 Fifty-Fifth Supplemental Indenture, dated as of May 1, 1983
(File No. 1-2313)* . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
4.57 Fifty-Sixth Supplemental Indenture, dated as of December 1, 1984
(Registration No. 2-94512)* . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
4.58 Fifty-Seventh Supplemental Indenture, dated as of March 15, 1985
(Registration No. 2-96181)* . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
4.59 Fifty-Eighth Supplemental Indenture, dated as of October 1, 1985
(File No. 1-2313)* . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
4.60 Fifty-Ninth Supplemental Indenture, dated as of October 15, 1985
(File No. 1-2313)* . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
4.61 Sixtieth Supplemental Indenture, dated as of March 1, 1986
(File No. 1-2313)* . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
4.62 Sixty-First Supplemental Indenture, dated as of March 15, 1986
(File No. 1-2313)* . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
4.63 Sixty-Second Supplemental Indenture, dated as of April 15, 1986
(File No. 1-2313)* . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
4.64 Sixty-Third Supplemental Indenture, dated as of April 15, 1986
(File No. 1-2313)* . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
4.65 Sixty-Fourth Supplemental Indenture, dated as of July 1, 1986
(File No. 1-2313)* . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
4.66 Sixty-Fifth Supplemental Indenture, dated as of September 1, 1986
(File No. 1-2313)* . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
4.67 Sixty-Sixth Supplemental Indenture, dated as of September 1, 1986
(File No. 1-2313)* . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
4.68 Sixty-Seventh Supplemental Indenture, dated as of December 1, 1986
(File No. 1-2313)* . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
4.69 Sixty-Eighth Supplemental Indenture, dated as of July 1, 1987
(Registration No. 33-19541)* . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
4.70 Sixty-Ninth Supplemental Indenture, dated as of October 15, 1987
(Registration No. 33-19541)* . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
4.71 Seventieth Supplemental Indenture, dated as of November 1, 1987
(File No. 1-2313)* . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
4.72 Seventy-First Supplemental Indenture, dated as of February 15, 1988
(File No. 1-2313)* . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
4.73 Seventy-Second Supplemental Indenture, dated as of April 15, 1988
(File No. 1-2313)* . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
4.74 Seventy-Third Supplemental Indenture, dated as of July 1, 1988
(File No. 1-2313)* . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
</TABLE>
52
<PAGE> 55
EXHIBIT INDEX
<TABLE>
<CAPTION>
EXHIBIT
NUMBER DESCRIPTION
- ------- -----------
<S> <C>
4.75 Seventy-Fourth Supplemental Indenture, dated as of August 15, 1988
(File No. 1-2313)* . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
4.76 Seventy-Fifth Supplemental Indenture, dated as of September 15, 1988
(File No. 1-2313)* . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
4.77 Seventy-Sixth Supplemental Indenture, dated as of January 15, 1989
(File No. 1-2313)* . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
4.78 Seventy-Seventh Supplemental Indenture, dated as of May 1, 1990
(File No. 1-2313)* . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
4.79 Seventy-Eighth Supplemental Indenture, dated as of June 15, 1990
(File No. 1-2313)* . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
4.80 Seventy-Ninth Supplemental Indenture, dated as of August 15, 1990
(File No. 1-2313)* . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
4.81 Eightieth Supplemental Indenture, dated as of December 1, 1990
(File No. 1-2313)* . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
4.82 Eighty-First Supplemental Indenture, dated as of April 1, 1991
(File No. 1-2313)* . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
4.83 Eighty-Second Supplemental Indenture, dated as of May 1, 1991
(File No. 1-2313)* . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
4.84 Eighty-Third Supplemental Indenture, dated as of June 1, 1991
(File No. 1-2313)* . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
4.85 Eighty-Fourth Supplemental Indenture, dated as of December 1, 1991
(File No. 1-2313)* . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
4.86 Eighty-Fifth Supplemental Indenture, dated as of February 1, 1992
(File No. 1-2313)* . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
4.87 Eighty-Sixth Supplemental Indenture, dated as of April 1, 1992
(File No. 1-2313)* . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
4.88 Eighty-Seventh Supplemental Indenture, dated as of July 1, 1992
(File No. 1-2313)* . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
4.89 Eighty-Eight Supplemental Indenture, dated as of July 15, 1992
(File No. 1-2313)* . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
4.90 Eighty-Ninth Supplemental Indenture, dated as of December 1, 1992
(File No. 1-2313)* . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
4.91 Ninetieth Supplemental Indenture, dated as of January 15, 1993
(File No. 1-2313)* . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
4.92 Ninety-First Supplemental Indenture, dated as of March 1, 1993
(File No. 1-2313)* . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
4.93 Ninety-Second Supplemental Indenture, dated as of June 1, 1993 . . . . . . . . . .
4.94 Ninety-Third Supplemental Indenture, dated as of June 15, 1993
(File No. 1-2313)* . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
4.95 Ninety-Fourth Supplemental Indenture, dated as of July 15, 1993 . . . . . . . . .
(File No. 1-2313)* . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
4.96 Ninety-Fifth Supplemental Indenture, dated as of September 1, 1993
(File No. 1-2313)* . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
4.97 Ninety-Sixth Supplemental Indenture, dated as of October 1, 1993
(File No. 1-2313)* . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
10.1 Executive Supplemental Benefit Program
(File No. 1-2313)* . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
10.2 1981 Deferred Compensation Agreement
(File No. 1-2313)* . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
10.3 1985 Deferred Compensation Agreement for Executives
(File No. 1-2313)* . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
10.4 1985 Deferred Compensation Agreement for Directors
(File No. 1-2313)* . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
10.5 1987 Deferred Compensation Plan for Executives
(File No. 1-2313)* . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
</TABLE>
53
<PAGE> 56
EXHIBIT INDEX
<TABLE>
<CAPTION>
EXHIBIT
NUMBER DESCRIPTION
- ------- -----------
<S> <C>
10.6 1987 Deferred Compensation Plan for Directors
(File No. 1-2313)* . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
10.7 1988 Deferred Compensation Plan for Executives
(File No. 1-2313)* . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
10.8 1988 Deferred Compensation Plan for Directors
(File No. 1-2313)* . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
10.9 1989 Deferred Compensation Plan for Executives
(File No. 1-9936)* . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
10.10 1989 Deferred Compensation Plan for Directors
(File No. 1-9936)* . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
10.11 1990 Deferred Compensation Plan for Executives
(File No. 1-9936)* . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
10.12 1990 Deferred Compensation Plan for Directors
(File No. 1-9936)* . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
10.13 Annual Deferred Compensation Plan for Executives
(File No. 1-9936)* . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
10.14 Annual Deferred Compensation Plan for Directors
(File No. 1-9936)* . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
10.15 Executive Retirement Plan (File No. 1-2313)* . . . . . . . . . . . . . . . . . . .
10.16 Employment Agreement with Jack K. Horton (File No. 1-2313)* . . . . . . . . . . .
10.17 Employment Agreement with Howard P. Allen
(File No. 1-2313)* . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
10.18 1991 Executive Incentive Compensation Plan (File No. 1-9936)* . . . . . . . . . .
10.19 1992 Executive Incentive Compensation Plan (File No. 1-9936)*
10.20 1993 Executive Incentive Compensation Plan . . . . . . . . . . . . . . . . . . . .
10.21 Retirement Plan for Directors (File No. 1-2313)* . . . . . . . . . . . . . . . . .
10.22 Long-Term Incentive Plan for Executive Officers
(Registration No. 33-19541)* . . . . . . . . . . . . . . . . . . . . . . . . . . .
10.23 Estate and Financial Planning Program for Executive
Officers (File No. 1-9936)* . . . . . . . . . . . . . . . . . . . . . . . . . . .
10.24 Consulting Agreement with Jack K. Horton (File No. 1-9936)* . . . . . . . . . . .
10.25 Consulting Agreement with Howard P. Allen (File No. 1-9936)* . . . . . . . . . . .
10.26 Consulting Agreement with Michael R. Peevey
(File No. 1-9936)* . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
10.27 Resignation and General Release Agreement with Michael R.
Peevey (File No. 1-9936)* . . . . . . . . . . . . . . . . . . . . . . . . . . . .
10.28 Employment Agreement with Bryant C. Danner
(File No. 1-9936)* . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
10.29 Employment Agreement with Charles W. Johnson
(File No. 1-9936)* . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
10.30 Resignation Agreement with Charles B. McCarthy, Jr. . . . . . . . . . . . . . . .
11. Computation of Primary and Fully Diluted Earnings Per Share . . . . . . . . . . .
12. Computation of Ratios of Earnings to Fixed Charges . . . . . . . . . . . . . . . .
13. Selected portions of the Annual Report to Shareholders
for year ended December 31, 1993 . . . . . . . . . . . . . . . . . . . . . . . . .
21. Subsidiaries of the Registrant . . . . . . . . . . . . . . . . . . . . . . . . . .
23. Consent of Independent Public Accountants - Arthur Andersen
& Co. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
24.1 Power of Attorney . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
24.2 Certified copy of Resolution of Board of Directors
Authorizing Signature . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
- ------------
</TABLE>
* Incorporated by reference pursuant to Rule 12b-32.
54
<PAGE> 1
EXHIBIT 3.3
I, MOLLY K. BYRD, Assistant Secretary of SCEcorp, certify that the
attached is an accurate and complete copy of the Bylaws of this corporation as
amended, and in full force and effect as of this date.
Dated: March 17, 1994
Molly K. Byrd
------------------------------------
Assistant Secretary
SCEcorp
<PAGE> 2
To Holders of the Company's Bylaws:
Effective November 18, 1993, Article III, Section 6, was amended to change the
hour of the regular Board meetings from 10:00 a.m. to 9:30 a.m.
and Article III, Section 7, was amended to provide for facsimile and
electronic mail notification of Special meetings.
KENNETH S. STEWART
Corporate Secretary
BYLAWS
OF
SCEcorp
AS AMENDED TO AND INCLUDING
NOVEMBER 18, 1993
<PAGE> 3
INDEX
<TABLE>
<CAPTION>
PAGE
----
<S> <C> <C>
ARTICLE I -- PRINCIPAL OFFICE
Section 1. Principal Office . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 1
ARTICLE II -- SHAREHOLDERS
Section 1. Meeting Locations . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 1
Section 2. Annual Meetings . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 1
Section 3. Special Meetings . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 2
Section 4. Notice of Annual or Special Meeting . . . . . . . . . . . . . . . . . . . . . . . 2
Section 5. Quorum . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 3
Section 6. Adjourned Meeting and Notice Thereof . . . . . . . . . . . . . . . . . . . . . . . 4
Section 7. Voting . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 4
Section 8. Record Date . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 6
Section 9. Consent of Absentees . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 7
Section 10. Action Without Meeting . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 7
Section 11. Proxies . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 7
Section 12. Inspectors of Election . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 8
ARTICLE III -- DIRECTORS
Section 1. Powers . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 8
Section 2. Number of Directors . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 9
Section 3. Election and Term of Office . . . . . . . . . . . . . . . . . . . . . . . . . . . 10
Section 4. Vacancies . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 10
Section 5. Place of Meeting . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 11
Section 6. Regular Meetings . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 11
Section 7. Special Meetings . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 11
Section 8. Quorum . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 12
Section 9. Participation in Meetings by Conference
Telephone . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 12
Section 10. Waiver of Notice . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 12
Section 11. Adjournment . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 12
Section 12. Fees and Compensation . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 13
Section 13. Action Without Meeting . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 13
Section 14. Rights of Inspection . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 13
Section 15. Committees . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 13
</TABLE>
i
<PAGE> 4
<TABLE>
<S> <C> <C>
ARTICLE IV -- OFFICERS
Section 1. Officers . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 14
Section 2. Election . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 14
Section 3. Eligibility of Chairman or President . . . . . . . . . . . . . . . . . . . . . . . 15
Section 4. Removal and Resignation . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 15
Section 5. Appointment of Other Officers . . . . . . . . . . . . . . . . . . . . . . . . . . 15
Section 6. Vacancies . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 15
Section 7. Salaries . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 15
Section 8. Furnish Security for Faithfulness . . . . . . . . . . . . . . . . . . . . . . . . 16
Section 9. Chairman's Duties; Succession to Such Duties
in Chairman's Absence or Disability . . . . . . . . . . . . . . . . . . . . . . 16
Section 10. President's Duties . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 16
Section 11. Chief Financial Officer . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 16
Section 12. Vice President's Duties . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 17
Section 13. General Counsel's Duties . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 17
Section 14. Associate General Counsel's and
Assistant General Counsel's Duties . . . . . . . . . . . . . . . . . . . . . . . 17
Section 15. Controller's Duties . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 17
Section 16. Assistant Controllers' Duties . . . . . . . . . . . . . . . . . . . . . . . . . . 17
Section 17. Treasurer's Duties . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 17
Section 18. Assistant Treasurers' Duties . . . . . . . . . . . . . . . . . . . . . . . . . . . 18
Section 19. Secretary's Duties . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 18
Section 20. Assistant Secretaries' Duties . . . . . . . . . . . . . . . . . . . . . . . . . . 19
Section 21. Secretary Pro Tempore . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 19
Section 22. Election of Acting Treasurer or
Acting Secretary . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 19
Section 23. Performance of Duties . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 19
ARTICLE V -- OTHER PROVISIONS
Section 1. Inspection of Corporate Records . . . . . . . . . . . . . . . . . . . . . . . . . 20
Section 2. Inspection of Bylaws . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 20
Section 3. Contracts and Other Instruments, Loans,
Notes and Deposits of Funds . . . . . . . . . . . . . . . . . . . . . . . . . . 21
Section 4. Certificates of Stock . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 21
Section 5. Transfer Agent, Transfer Clerk and Registrar . . . . . . . . . . . . . . . . . . . 22
Section 6. Representation of Shares of Other
Corporations . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 22
</TABLE>
ii
<PAGE> 5
<TABLE>
<S> <C> <C>
ARTICLE V -- OTHER PROVISIONS (continued)
Section 7. Stock Purchase Plans . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 22
Section 8. Fiscal Year and Subdivisions . . . . . . . . . . . . . . . . . . . . . . . . . . . 23
Section 9. Construction and Definitions . . . . . . . . . . . . . . . . . . . . . . . . . . . 23
ARTICLE VI -- INDEMNIFICATION
Section 1. Indemnification of Directors and Officers . . . . . . . . . . . . . . . . . . . . 23
Section 2. Indemnification of Employees and Agents . . . . . . . . . . . . . . . . . . . . . 25
Section 3. Right of Directors and Officers to
Bring Suit . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 25
Section 4. Successful Defense . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 26
Section 5. Non-Exclusivity of Rights . . . . . . . . . . . . . . . . . . . . . . . . . . . . 26
Section 6. Insurance . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 26
Section 7. Expenses as a Witness . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 26
Section 8. Indemnity Agreements . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 27
Section 9. Separability . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 27
Section 10. Effect of Repeal or Modification . . . . . . . . . . . . . . . . . . . . . . . . . 27
ARTICLE VII -- EMERGENCY PROVISIONS
Section 1. General . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 27
Section 2. Unavailable Directors . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 28
Section 3. Authorized Number of Directors . . . . . . . . . . . . . . . . . . . . . . . . . . 28
Section 4. Quorum . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 28
Section 5. Creation of Emergency Committee . . . . . . . . . . . . . . . . . . . . . . . . . 28
Section 6. Constitution of Emergency Committee . . . . . . . . . . . . . . . . . . . . . . . 28
Section 7. Powers of Emergency Committee . . . . . . . . . . . . . . . . . . . . . . . . . . 29
Section 8. Directors Becoming Available . . . . . . . . . . . . . . . . . . . . . . . . . . . 29
Section 9. Election of Board of Directors . . . . . . . . . . . . . . . . . . . . . . . . . . 29
Section 10. Termination of Emergency Committee . . . . . . . . . . . . . . . . . . . . . . . . 29
ARTICLE VIII -- AMENDMENTS
Section 1. Amendments . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 30
</TABLE>
iii
<PAGE> 6
BYLAWS
Bylaws for the regulation, except as otherwise provided
by statute or its Articles of Incorporation
OF
SCECORP
AS AMENDED TO AND INCLUDING
NOVEMBER 18, 1993
ARTICLE I -- PRINCIPAL OFFICE
SECTION 1. PRINCIPAL OFFICE.
The principal office of the Corporation is hereby fixed and located at
2244 Walnut Grove Avenue, in the City of Rosemead, County of Los Angeles, State
of California. The Board of Directors is hereby granted full power and
authority to change said principal office from one location to another.
ARTICLE II -- SHAREHOLDERS
SECTION 1. MEETING LOCATIONS.
All meetings of shareholders shall be held at the principal office of
the corporation or at such other place or places within or without the State of
California as may be designated by the Board of Directors (the "Board"). In
the event such places shall prove inadequate in capacity for any meeting of
shareholders, an adjournment may be taken to and the meeting held at such other
place of adequate capacity as may be designated by the officer of the
corporation presiding at such meeting.
SECTION 2. ANNUAL MEETINGS.
The annual meeting of shareholders shall be held on the third Thursday
of the month of April of each year at 10:00 a.m. on said day to elect directors
to hold office for the year next ensuing and until their successors shall be
elected, and to consider and act upon such other matters as may lawfully be
presented to such meeting; provided, however, that should said day fall upon a
legal holiday, then any such annual meeting of shareholders shall be held at
the same time and place on the next day thereafter ensuing which is not a legal
holiday.
<PAGE> 7
ARTICLE II
SECTION 3. SPECIAL MEETINGS.
Special meetings of the shareholders may be called at any time by the
Board, the Chairman of the Board, the President, or upon written request of any
three members of the Board, or by the holders of shares entitled to cast not
less than ten percent of the votes at such meeting. Upon request in writing to
the Chairman of the Board, the President, any Vice President or the Secretary
by any person (other than the Board) entitled to call a special meeting of
shareholders, the officer forthwith shall cause notice to be given to the
shareholders entitled to vote that a meeting will be held at a time requested
by the person or persons calling the meeting, not less than thirty-five nor
more than sixty days after the receipt of the request. If the notice is not
given within twenty days after receipt of the request, the persons entitled to
call the meeting may give the notice.
SECTION 4. NOTICE OF ANNUAL OR SPECIAL MEETING.
Written notice of each annual or special meeting of shareholders shall
be given not less than ten (or if sent by third-class mail, thirty) nor more
than sixty days before the date of the meeting to each shareholder entitled to
vote thereat. Such notice shall state the place, date, and hour of the meeting
and (i) in the case of a special meeting, the general nature of the business to
be transacted, and no other business may be transacted, or (ii) in the case of
an annual meeting, those matters which the Board, at the time of the mailing of
the notice, intends to present for action by the shareholders, but, subject to
the provisions of applicable law and these Bylaws, any proper matter may be
presented at an annual meeting for such action. The notice of any special or
annual meeting at which directors are to be elected shall include the names of
nominees intended at the time of the notice to be presented by the Board for
election. For any matter to be presented by a shareholder at an annual meeting
held after December 31, 1993, including the nomination of any person (other
than a person nominated by or at the direction of the Board) for election to
the Board, written notice must be received by the Secretary of the corporation
from the shareholder not less than sixty nor more than one hundred twenty days
prior to the date of the annual meeting specified in these Bylaws and to which
the shareholder's notice relates; provided however, that in the event the
annual meeting to which the shareholder's written notice relates is to be held
on a date which is more than thirty days earlier than the date of the annual
meeting specified in these Bylaws, the notice from a shareholder must be
received by the Secretary not later than the close of business on the tenth day
following the date on which public disclosure of the date of the annual meeting
was made or given to the shareholders. The shareholder's notice to the
Secretary shall set forth (a) a brief description of each matter to be
presented at the annual meeting by the shareholder; (b) the name and address,
as they appear on the corporation's books, of the shareholder; (c) the class
and number of shares of the corporation
2
<PAGE> 8
ARTICLE II
which are beneficially owned by the shareholder; and (d) any material interest
of the shareholder in the matters to be presented. Any shareholder who intends
to nominate a candidate for election as a director shall also set forth in such
a notice (i) the name, age, business address and residence address of each
nominee that he or she intends to nominate at the meeting, (ii) the principal
occupation or employment of each nominee, (iii) the number of shares of capital
stock of the corporation beneficially owned by each nominee, and (iv) any other
information concerning the nominee that would be required under the rules of
the Securities and Exchange Commission in a proxy statement soliciting proxies
for the election of the nominee. The notice shall also include a consent,
signed by the shareholder's nominees, to serve as a director of the corporation
if elected. Notwithstanding anything in these Bylaws to the contrary, and
subject to the provisions of any applicable law, no business shall be conducted
at a special or annual meeting except in accordance with the procedures set
forth in this Section 4.
Notice of a shareholders' meeting shall be given either personally or
by first-class mail (or, if the outstanding shares of the corporation are held
of record by 500 or more persons on the record date for the meeting, by
third-class mail) or by other means of written communication, addressed to the
shareholder at the address of such shareholder appearing on the books of the
corporation or given by the shareholder to the corporation for the purpose of
notice; or, if no such address appears or is given, at the place where the
principal office of the corporation is located or by publication at least once
in a newspaper of general circulation in the county in which the principal
office is located. Notice by mail shall be deemed to have been given at the
time a written notice is deposited in the United States mails, postage prepaid.
Any other written notice shall be deemed to have been given at the time it is
personally delivered to the recipient or is delivered to a common carrier for
transmission, or actually transmitted by the person giving the notice by
electronic means, to the recipient.
SECTION 5. QUORUM.
A majority of the shares entitled to vote, represented in person or by
proxy, shall constitute a quorum at any meeting of shareholders. The
affirmative vote of a majority of the shares represented and voting at a duly
held meeting at which a quorum is present (which shares voting affirmatively
also constitute at least a majority of the required quorum) shall be the act of
the shareholders, unless the vote of a greater number or voting by classes is
required by law or the Articles; provided, however, that the shareholders
present at a duly called or held meeting at which a quorum is present may
continue to do business until adjournment, notwithstanding the withdrawal of
enough shareholders to have less than a quorum, if any action taken (other than
adjournment) is approved by at least a majority of the shares required to
constitute a quorum.
3
<PAGE> 9
ARTICLE II
SECTION 6. ADJOURNED MEETING AND NOTICE THEREOF.
Any shareholders' meeting, whether or not a quorum is present, may be
adjourned from time to time by the vote of a majority of the shares, the
holders of which are either present in person or represented by proxy thereat,
but in the absence of a quorum (except as provided in Section 5 of this
Article) no other business may be transacted at such meeting.
It shall not be necessary to give any notice of the time and place of
the adjourned meeting or of the business to be transacted thereat, other than
by announcement at the meeting at which such adjournment is taken. At the
adjourned meeting, the corporation may transact any business which might have
been transacted at the original meeting. However, when any shareholders'
meeting is adjourned for more than forty-five days or, if after adjournment a
new record date is fixed for the adjourned meeting, notice of the adjourned
meeting shall be given as in the case of an original meeting.
SECTION 7. VOTING.
The shareholders entitled to notice of any meeting or to vote at any
such meeting shall be only persons in whose name shares stand on the stock
records of the corporation on the record date determined in accordance with
Section 8 of this Article.
Voting shall in all cases be subject to the provisions of Chapter 7 of
the California General Corporation Law, and to the following provisions:
(a) Subject to clause (g), shares held by an administrator,
executor, guardian, conservator or custodian may be voted by such holder either
in person or by proxy, without a transfer of such shares into the holder's
name; and shares standing in the name of a trustee may be voted by the trustee,
either in person or by proxy, but no trustee shall be entitled to vote shares
held by such trustee without a transfer of such shares into the trustee's name.
(b) Shares standing in the name of a receiver may be voted by such
receiver; and shares held by or under the control of a receiver may be voted by
such receiver without the transfer thereof into the receiver's name if
authority to do so is contained in the order of the court by which such
receiver was appointed.
4
<PAGE> 10
ARTICLE II
(c) Subject to the provisions of Section 705 of the California
General Corporation Law and except where otherwise agreed in writing between
the parties, a shareholder whose shares are pledged shall be entitled to vote
such shares until the shares have been transferred into the name of the
pledgee, and thereafter the pledgee shall be entitled to vote the shares so
transferred.
(d) Shares standing in the name of a minor may be voted and the
corporation may treat all rights incident thereto as exercisable by the minor,
in person or by proxy, whether or not the corporation has notice, actual or
constructive, of the non-age unless a guardian of the minor's property has been
appointed and written notice of such appointment given to the corporation.
(e) Shares standing in the name of another corporation, domestic
or foreign, may be voted by such officer, agent or proxyholder as the bylaws of
such other corporation may prescribe or, in the absence of such provision, as
the Board of Directors of such other corporation may determine or, in the
absence of such determination, by the chairman of the board, president or
any vice president of such other corporation, or by any other person authorized
to do so by the chairman of the board, president or any vice president of such
other corporation. Shares which are purported to be voted or any proxy
purported to be executed in the name of a corporation (whether or not any title
of the person signing is indicated) shall be presumed to be voted or the proxy
executed in accordance with the provisions of this subdivision, unless the
contrary is shown.
(f) Shares of the corporation owned by any of its subsidiaries
shall not be entitled to vote on any matter.
(g) Shares of the corporation held by the corporation in a
fiduciary capacity, and shares of the corporation held in a fiduciary capacity
by any of its subsidiaries, shall not be entitled to vote on any matter, except
to the extent that the settlor or beneficial owner possesses and exercises a
right to vote or to give the corporation binding instructions as to how to vote
such shares.
(h) If shares stand of record in the names of two or more persons,
whether fiduciaries, members of a partnership, joint tenants, tenants in
common, husband and wife as community property, tenants by the entirety, voting
trustees, persons entitled to vote under a shareholder voting agreement or
otherwise, or if two or more persons (including proxyholders) have the same
fiduciary relationship respecting the same shares, unless the secretary of the
corporation is given written notice to the contrary and is furnished with a
copy of the instrument or order appointing them or creating the relationship
wherein it is so provided, their acts with respect to voting shall have the
following effect:
5
<PAGE> 11
ARTICLE II
(i) If only one votes, such act binds all;
(ii) If more than one vote, the act of the majority so
voting binds all;
(iii) If more than one vote, but the vote is evenly split
on any particular matter, each faction may vote the
securities in question proportionately.
If the instrument so filed or the registration of the shares shows that any
such tenancy is held in unequal interests, a majority or even split for the
purpose of this section shall be a majority or even split in interest.
No shareholder of any class of stock of this corporation shall be
entitled to cumulate votes at any election of directors of this corporation.
Elections for directors need not be by ballot; provided, however, that
all elections for directors must be by ballot upon demand made by a shareholder
at the meeting and before the voting begins.
In any election of directors, the candidates receiving the highest
number of votes of the shares entitled to be voted for them up to the number of
directors to be elected by such shares are elected.
SECTION 8. RECORD DATE.
The Board may fix, in advance, a record date for the determination of
the shareholders entitled to notice of any meeting or to vote or entitled to
receive payment of any dividend or other distribution, or any allotment of
rights, or to exercise rights in respect of any other lawful action. The
record date so fixed shall be not more than sixty days nor less than ten days
prior to the date of the meeting nor more than sixty days prior to any other
action. When a record date is so fixed, only shareholders of record at the
close of business on that date are entitled to notice of and to vote at the
meeting or to receive the dividend, distribution, or allotment of rights, or to
exercise the rights, as the case may be, notwithstanding any transfer of shares
on the books of the corporation after the record date, except as otherwise
provided by law or these Bylaws. A determination of shareholders of record
entitled to notice of or to vote at a meeting of shareholders shall apply to
any adjournment of the meeting unless the Board fixes a new record date for the
adjourned meeting. The Board shall fix a new record date if the meeting is
adjourned for more than forty-five days.
If no record date is fixed by the Board, the record date for
determining shareholders entitled to notice of or to vote at a meeting of
shareholders shall be at the close of business on the business day next
preceding the day on which notice is given or, if notice is waived, at the
close of business on the business
6
<PAGE> 12
ARTICLE II
day next preceding the day on which the meeting is held. The record date for
determining shareholders for any purpose other than as set forth in this
Section 8 or Section 10 of this Article shall be at the close of business on
the day on which the Board adopts the resolution relating thereto, or the
sixtieth day prior to the date of such other action, whichever is later.
SECTION 9. CONSENT OF ABSENTEES.
The transactions of any meeting of shareholders, however called and
noticed, and wherever held, are as valid as though had at a meeting duly held
after regular call and notice, if a quorum is present either in person or by
proxy, and if, either before or after the meeting, each of the persons entitled
to vote, not present in person or by proxy, signs a written waiver of notice or
a consent to the holding of the meeting or an approval of the minutes thereof.
All such waivers, consents or approvals shall be filed with the corporate
records or made a part of the minutes of the meeting. Neither the business to
be transacted at nor the purpose of any regular or special meeting of
shareholders need be specified in any written waiver of notice, consent to the
holding of the meeting or approval of the minutes thereof, except as provided
in Section 601 (f) of the California General Corporation Law.
SECTION 10. ACTION WITHOUT MEETING.
Subject to Section 603 of the California General Corporation Law, any
action which, under any provision of the California General Corporation Law,
may be taken at any annual or special meeting of shareholders may be taken
without a meeting and without prior notice if a consent in writing, setting
forth the action so taken, shall be signed by the holders of outstanding shares
having not less than the minimum number of votes that would be necessary to
authorize or take such action at a meeting at which all shares entitled to vote
thereon were present and voted. Unless a record date for voting purposes be
fixed as provided in Section 8 of this Article, the record date for determining
shareholders entitled to give consent pursuant to this Section 10, when no
prior action by the Board has been taken, shall be the day on which the first
written consent is given.
SECTION 11. PROXIES.
Every person entitled to vote shares has the right to do so either in
person or by one or more persons, not to exceed three, authorized by a written
proxy executed by such shareholder and filed with the Secretary. Subject to the
following sentence, any proxy duly executed continues in full force and effect
until revoked by the person executing it prior to the vote pursuant thereto by
a writing delivered to the corporation stating that the proxy is revoked or by
a
7
<PAGE> 13
ARTICLE III
subsequent proxy executed by the person executing the prior proxy and presented
to the meeting, or by attendance at the meeting and voting in person by the
person executing the proxy; provided, however, that a proxy is not revoked by
the death or incapacity of the maker unless, before the vote is counted,
written notice of such death or incapacity is received by this corporation. No
proxy shall be valid after the expiration of eleven months from the date of its
execution unless otherwise provided in the proxy.
SECTION 12. INSPECTORS OF ELECTION.
In advance of any meeting of shareholders, the Board may appoint any
persons other than nominees as inspectors of election to act at such meeting
and any adjournment thereof. If inspectors of election are not so appointed,
or if any persons so appointed fail to appear or refuse to act, the chairman
of any such meeting may, and on the request of any shareholder or shareholder's
proxy shall, make such appointments at the meeting. The number of inspectors
shall be either one or three. If appointed at a meeting on the request of one
or more shareholders or proxies, the majority of shares present shall determine
whether one or three inspectors are to be appointed.
The duties of such inspectors shall be as prescribed by Section 707
(b) of the California General Corporation Law and shall include: determining
the number of shares outstanding and the voting power of each, the shares
represented at the meeting, the existence of a quorum, and the authenticity,
validity and effect of proxies; receiving votes, ballots or consents; hearing
and determining all challenges and questions in any way arising in connection
with the right to vote; counting and tabulating all votes or consents;
determining when the polls shall close; determining the result; and doing such
acts as may be proper to conduct the election or vote with fairness to all
shareholders. If there are three inspectors of election, the decision, act or
certificate of a majority is effective in all respects as the decision, act or
certificate of all. Any report or certificate made by the inspectors of
election is prima facie evidence of the facts stated therein.
ARTICLE III -- DIRECTORS
SECTION 1. POWERS.
Subject to limitations of the Articles, of these Bylaws and of the
California General Corporation Law relating to action required to be approved
by the shareholders or by the outstanding shares, the business and affairs of
the corporation shall be managed and all corporate
8
<PAGE> 14
ARTICLE III
powers shall be exercised by or under the direction of the Board. The Board
may delegate the management of the day-to-day operation of the business of the
corporation provided that the business and affairs of the corporation shall be
managed and all corporate powers shall be exercised under the ultimate
direction of the Board. Without prejudice to such general powers, but subject
to the same limitations, it is hereby expressly declared that the Board shall
have the following powers in addition to the other powers enumerated in these
Bylaws:
(a) To select and remove all the other officers, agents and
employees of the corporation, prescribe the powers and duties for them as may
not be inconsistent with law, with the Articles or these Bylaws, fix their
compensation and require from them security for faithful service.
(b) To conduct, manage and control the affairs and business of the
corporation and to make such rules and regulations therefor not inconsistent
with law, or with the Articles or these Bylaws, as they may deem best.
(c) To adopt, make and use a corporate seal, and to prescribe the
forms of certificates of stock, and to alter the form of such seal and of such
certificates from time to time as in their judgment they may deem best.
(d) To authorize the issuance of shares of stock of the
corporation from time to time, upon such terms and for such consideration as
may be lawful.
(e) To borrow money and incur indebtedness for the purposes of the
corporation, and to cause to be executed and delivered therefor, in the
corporate name, promissory notes, bonds, debentures, deeds of trust,
mortgages, pledges, hypothecations or other evidences of debt and securities
therefor.
SECTION 2. NUMBER OF DIRECTORS.
The authorized number of directors shall be not less than fifteen nor
more than twenty until changed by amendment of the Articles or by a Bylaw duly
adopted by the shareholders. The exact number of directors shall be fixed,
within the limits specified, by the Board by adoption of a resolution or by the
shareholders in the same manner provided in these Bylaws for the amendment
thereof.
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<PAGE> 15
ARTICLE III
SECTION 3. ELECTION AND TERM OF OFFICE.
The directors shall be elected at each annual meeting of the
shareholders, but if any such annual meeting is not held or the directors are
not elected thereat, the directors may be elected at any special meeting of
shareholders held for that purpose. Each director shall hold office until the
next annual meeting and until a successor has been elected and qualified.
SECTION 4. VACANCIES.
Any director may resign effective upon giving written notice to the
Chairman of the Board, the President, the Secretary or the Board, unless the
notice specifies a later time for the effectiveness of such resignation. If
the resignation is effective at a future time, a successor may be elected to
take office when the resignation becomes effective.
Vacancies in the Board, except those existing as a result of a removal
of a director, may be filled by a majority of the remaining directors, though
less than a quorum, or by a sole remaining director, and each director so
elected shall hold office until the next annual meeting and until such
director's successor has been elected and qualified. Vacancies existing as a
result of a removal of a director may be filled by the shareholders as provided
by law.
A vacancy or vacancies in the Board shall be deemed to exist in case
of the death, resignation or removal of any director, or if the authorized
number of directors be increased, or if the shareholders fail, at any annual or
special meeting of shareholders at which any director or directors are elected,
to elect the full authorized number of directors to be voted for at that
meeting.
The Board may declare vacant the office of a director who has been
declared of unsound mind by an order of court or convicted of a felony.
The shareholders may elect a director or directors at any time to fill
any vacancy or vacancies not filled by the directors. Any such election by
written consent other than to fill a vacancy created by removal requires the
consent of a majority of the outstanding shares entitled to vote. If the Board
accepts the resignation of a director tendered to take effect at a future time,
the Board or the shareholders shall have power to elect a successor to take
office when the resignation is to become effective.
No reduction of the authorized number of directors shall have the
effect of removing any director prior to the expiration of the director's term
of office.
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<PAGE> 16
ARTICLE III
SECTION 5. PLACE OF MEETING.
Regular or special meetings of the Board shall be held at any place
within or without the State of California which has been designated from time
to time by the Board or as provided in these Bylaws. In the absence of such
designation, regular meetings shall be held at the principal office of the
corporation.
SECTION 6. REGULAR MEETINGS.
Promptly following each annual meeting of shareholders the Board shall
hold a regular meeting for the purpose of organization, election of officers
and the transaction of other business.
Regular meetings of the Board shall be held without notice on the
third Thursday of each month, except the months of August and December, at the
hour of 9:30 a.m. at the principal office of the corporation. Call and notice
of all regular meetings of the Board are not required.
SECTION 7. SPECIAL MEETINGS.
Special meetings of the Board for any purpose or purposes may be
called at any time by the Chairman of the Board, the President, any Vice
President, the Secretary or by any two directors.
Special meetings of the Board shall be held upon four days' written
notice or forty-eight hours' notice given personally or by telephone,
telegraph, telex, facsimile, electronic mail or other similar means of
communication. Any such notice shall be addressed or delivered to each
director at such director's address as it is shown upon the records of the
corporation or as may have been given to the corporation by the director for
purposes of notice or, if such address is not shown on such records or is not
readily ascertainable, at the place in which the meetings of the directors are
regularly held. The notice need not specify the purpose of such special
meeting.
Notice by mail shall be deemed to have been given at the time a
written notice is deposited in the United States mail, postage prepaid. Any
other written notice shall be deemed to have been given at the time it is
personally delivered to the recipient or is delivered to a common carrier for
transmission, or actually
11
<PAGE> 17
ARTICLE III
transmitted by the person giving the notice by electronic means to the
recipient. Oral notice shall be deemed to have been given at the time it is
communicated, in person or by telephone, radio or other similar means to the
recipient or to a person at the office of the recipient who the person giving
the notice has reason to believe will promptly communicate it to the recipient.
SECTION 8. QUORUM.
One-third of the maximum number of authorized directors constitutes a
quorum of the Board for the transaction of business, except to adjourn as
provided in Section II of this Article. As defined in Article III, Section 2,
the maximum number of authorized directors is eighteen. Every act or decision
done or made by a majority of the directors present at a meeting duly held at
which a quorum is present shall be regarded as the act of the Board, unless a
greater number is required by law or by the Articles; provided, however, that a
meeting at which a quorum is initially present may continue to transact
business notwithstanding the withdrawal of directors, if any action taken is
approved by at least a majority of the required quorum for such meeting.
SECTION 9. PARTICIPATION IN MEETINGS BY CONFERENCE TELEPHONE.
Members of the Board may participate in a meeting through use of
conference telephone or similar communications equipment, so long as all
members participating in such meeting can hear one another. Such
participation constitutes presence in person at such meeting.
SECTION 10. WAIVER OF NOTICE.
The transactions of any meeting of the Board, however called and
noticed or wherever held, are as valid as though had at a meeting duly held
after regular call and notice if a quorum is present and if, either before or
after the meeting, each of the directors not present signs a written waiver of
notice, a consent to holding such meeting or an approval of the minutes
thereof. All such waivers, consents or approvals shall be filed with the
corporate records or made a part of the minutes of the meeting.
SECTION 11. ADJOURNMENT.
A majority of the directors present, whether or not a quorum is
present, may adjourn any directors' meeting to another time and place. Notice
of the time and place of holding an adjourned meeting need not be given to
absent directors if the time and place is fixed at the meeting adjourned. If
the meeting is adjourned for more than twenty-four hours, notice of any
adjournment to another time or place shall be given prior to the time of the
adjourned meeting to the directors who were not present at the time of the
adjournment.
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<PAGE> 18
ARTICLE III
SECTION 12. FEES AND COMPENSATION.
Directors and members of committees may receive such compensation, if
any, for their services, and such reimbursement for expenses, as may be fixed
or determined by the Board.
SECTION 13. ACTION WITHOUT MEETING.
Any action required or permitted to be taken by the Board may be taken
without a meeting if all members of the Board shall individually or
collectively consent in writing to such action. Such written consent or
consents shall have the same force and effect as a unanimous vote of the Board
and shall be filed with the minutes of the proceedings of the Board.
SECTION 14. RIGHTS OF INSPECTION.
Every director shall have the absolute right at any reasonable time to
inspect and copy all books, records and documents of every kind and to inspect
the physical properties of the corporation and also of its subsidiary
corporations, domestic or foreign. Such inspection by a director may be made
in person or by agent or attorney and includes the right to copy and make
extracts.
SECTION 15. COMMITTEES.
The Board may appoint one or more committees, each consisting of two
or more directors, to serve at the pleasure of the Board. The Board may
delegate to such committees any or all of the authority of the Board except
with respect to:
(a) The approval of any action for which the California General
Corporation Law also requires shareholders' approval or approval of the
outstanding shares;
(b) The filling of vacancies on the Board or in any committee;
(c) The fixing of compensation of the directors for serving on the
Board or on any committee;
(d) The amendment or repeal of Bylaws or the adoption of new
Bylaws;
(e) The amendment or repeal of any resolution of the Board which
by its express terms is not so amendable or repealable;
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ARTICLE IV
(f) A distribution to the shareholders of the corporation except
at a rate or in a periodic amount or within a price range determined by the
Board; or
(g) The appointment of other committees of the Board or the
members thereof.
Any such committee, or any member or alternate member thereof, must be
appointed by resolution adopted by a majority of the exact number of authorized
directors as specified in Section 2 of this Article. The Board shall have the
power to prescribe the manner and timing of giving of notice of regular or
special meetings of any committee and the manner in which proceedings of any
committee shall be conducted. In the absence of any such prescription, such
committee shall have the power to prescribe the manner in which its proceedings
shall be conducted. Unless the Board or such committee shall otherwise
provide, the regular and special meetings and other actions of any such
committee shall be governed by the provisions of this Article applicable to
meetings and actions of the Board. Minutes shall be kept of each meeting of
each committee.
ARTICLE IV -- OFFICERS
SECTION 1. OFFICERS.
The officers of the corporation shall be a Chairman of the Board, a
President, a Chief Financial Officer, one or more Vice Presidents, a General
Counsel and a Secretary. The corporation may also have, at the discretion of
the Board, one or more Associate General Counsel, one or more Assistant General
Counsel, a Controller, one or more Assistant Controllers, a Treasurer, one or
more Assistant Treasurers and one or more Assistant Secretaries, and such other
officers as may be elected or appointed in accordance with Section 5 of this
Article. The Board, the Chairman of the Board or the President may confer a
special title upon any Vice President not specified herein.
SECTION 2. ELECTION.
The officers of the corporation, except such officers as may be
elected or appointed in accordance with the provisions of Section 5 or Section
6 of this Article, shall be chosen annually by, and shall serve at the
pleasure of the Board, and shall hold their respective offices until their
resignation, removal, or other disqualification from service, or until their
respective successors shall be elected.
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ARTICLE IV
SECTION 3. ELIGIBILITY OF CHAIRMAN OR PRESIDENT.
No person shall be eligible for the office of Chairman of the Board or
President unless such person is a member of the Board of the corporation; any
other officer may or may not be a director.
SECTION 4. REMOVAL AND RESIGNATION.
Any officer may be removed, either with or without cause, by the Board
at any time or by any officer upon whom such power or removal may be conferred
by the Board. Any such removal shall be without prejudice to the rights, if
any, of the officer under any contract of employment of the officer.
Any officer may resign at any time by giving written notice to the
corporation, but without prejudice to the rights, if any, of the corporation
under any contract to which the officer is a party. Any such resignation shall
take effect at the date of the receipt of such notice or at any later time
specified therein and, unless otherwise specified therein, the acceptance of
such resignation shall not be necessary to make it effective.
SECTION 5. APPOINTMENT OF OTHER OFFICERS.
The Board may appoint such other officers as the business of the
corporation may require, each of whom shall hold office for such period, have
such authority, and perform such duties as are provided in the Bylaws or as the
Board may from time to time determine.
SECTION 6. VACANCIES.
A vacancy in any office because of death, resignation, removal,
disqualification or any other cause shall be filled at any time deemed
appropriate by the Board in the manner prescribed in these Bylaws for regular
election or appointment to such office.
SECTION 7. SALARIES.
The salaries of the Chairman of the Board, President, Chief Financial
Officer, Vice Presidents, General Counsel, Controller, Treasurer and Secretary
of the corporation shall be fixed by the Board. Salaries of all other officers
shall be as approved from time to time by the chief executive officer.
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ARTICLE IV
SECTION 8. FURNISH SECURITY FOR FAITHFULNESS.
Any officer or employee shall, if required by the Board, furnish to
the corporation security for faithfulness to the extent and of the character
that may be required.
SECTION 9. CHAIRMAN'S DUTIES; SUCCESSION TO SUCH DUTIES IN CHAIRMAN'S
ABSENCE OR DISABILITY.
The Chairman of the Board shall be the chief executive officer of the
corporation and shall preside at all meetings of the shareholders and of the
Board. Subject to the Board, the Chairman of the Board shall have charge of
the business of the corporation. The Chairman of the Board shall keep the
Board fully informed, and shall freely consult them concerning the business of
the corporation.
In the absence or disability of the Chairman of the Board, the
President shall act as the chief executive officer of the corporation; in the
absence or disability of the Chairman of the Board and the President, the next
in order of election by the Board of the Vice Presidents shall act as chief
executive officer of the corporation.
In the absence or disability of the Chairman of the Board, the
President shall act as Chairman of the Board at meetings of the Board; in the
absence or disability of the Chairman of the Board and the President, the next,
in order of election by the Board, of the Vice Presidents who is a member of
the Board shall act as Chairman of the Board at any such meeting of the Board;
in the absence or disability of the Chairman of the Board, the President, and
such Vice Presidents who are members of the Board, the Board shall designate a
temporary Chairman to preside at any such meeting of the Board.
SECTION 10. PRESIDENT'S DUTIES.
The President shall perform such other duties as the Chairman of the
Board shall delegate or assign to such officer.
SECTION 11. CHIEF FINANCIAL OFFICER.
The Chief Financial Officer of the corporation shall be the chief
consulting officer in all matters of financial import and shall have control
over all financial matters concerning the corporation. If the corporation does
not have a currently elected and acting Controller, the Chief Financial Officer
shall also be the Chief Accounting Officer of the corporation.
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ARTICLE IV
SECTION 12. VICE PRESIDENTS' DUTIES.
The Vice Presidents shall perform such other duties as the chief
executive officer shall designate.
SECTION 13. GENERAL COUNSEL'S DUTIES.
The General Counsel shall be the chief consulting officer of the
corporation in all legal matters and, subject to the chief executive officer,
shall have control over all matters of legal import concerning the corporation.
SECTION 14. ASSOCIATE GENERAL COUNSEL'S AND ASSISTANT GENERAL COUNSEL'S
DUTIES.
The Associate General Counsel shall perform such of the duties of the
General Counsel as the General Counsel shall designate, and in the absence or
disability of the General Counsel, the Associate General Counsel, in order of
election to that office by the Board at its latest organizational meeting,
shall perform the duties of the General Counsel. The Assistant General Counsel
shall perform such duties as the General Counsel shall designate.
SECTION 15. CONTROLLER'S DUTIES.
The Controller shall be the chief accounting officer of the
Corporation and, subject to the Chief Financial Officer, shall have control
over all accounting matters concerning the Corporation and shall perform such
other duties as the Chief Executive Officer shall designate.
SECTION 16. ASSISTANT CONTROLLERS' DUTIES.
The Assistant Controllers shall perform such of the duties of the
Controller as the Controller shall designate, and in the absence or disability
of the Controller, the Assistant Controllers, in order of election to that
office by the Board at its latest organizational meeting, shall perform the
duties of the Controller.
SECTION 17. TREASURER'S DUTIES.
It shall be the duty of the Treasurer to keep in custody or control
all money, stocks, bonds, evidences of debt, securities and other items of
value that may belong to, or be in the possession or control of, the
corporation, and to dispose of the same in such manner as the Board or the
chief executive officer may direct, and to perform all acts incident to the
position of Treasurer.
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ARTICLE IV
SECTION 18. ASSISTANT TREASURERS' DUTIES.
The Assistant Treasurers shall perform such of the duties of the
Treasurer as the Treasurer shall designate, and in the absence or disability
of the Treasurer, the Assistant Treasurers, in order of election to that office
by the Board at its latest organizational meeting, shall perform the duties of
the Treasurer, unless action is taken by the Board as contemplated in Article
IV, Section 22.
SECTION 19. SECRETARY'S DUTIES.
The Secretary shall keep or cause to be kept full and complete records
of the proceedings of shareholders, the Board and its committees at all
meetings, and shall affix the corporate seal and attest by signing copies of
any part thereof when required.
The Secretary shall keep, or cause to be kept, a copy of the Bylaws of
the corporation at the principal office in accordance with Section 213 of the
California General Corporation Law.
The Secretary shall be the custodian of the corporate seal and shall
affix it to such instruments as may be required.
The Secretary shall keep on hand a supply of blank stock certificates
of such forms as the Board may adopt.
The Secretary shall serve or cause to be served by publication or
otherwise, as may be required, all notices of meetings and of other corporate
acts that may by law or otherwise be required to be served, and shall make or
cause to be made and filed in the principal office of the corporation, the
necessary certificate or proofs thereof.
An affidavit of mailing of any notice of a shareholders' meeting or of
any report, in accordance with the provisions of Section 601 (b) of the
California General Corporation Law, executed by the Secretary shall be prima
facie evidence of the fact that such notice or report had been duly given.
The Secretary may, with the Chairman of the Board, the President, or a
Vice President, sign certificates of ownership of stock in the corporation, and
shall cause all certificates so signed to be delivered to those entitled
thereto.
The Secretary shall keep all records required by the California
General Corporation Law.
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ARTICLE IV
The Secretary shall generally perform the duties usual to the office
of secretary of corporations, and such other duties as the chief executive
officer shall designate.
SECTION 20. ASSISTANT SECRETARIES' DUTIES.
Assistant Secretaries shall perform such of the duties of the
Secretary as the Secretary shall designate, and in the absence or disability of
the Secretary, the Assistant Secretaries, in the order of election to that
office by the Board at its latest organizational meeting, shall perform the
duties of the Secretary, unless action is taken by the Board as contemplated in
Article IV, Sections 21 and 22 of these Bylaws.
SECTION 21. SECRETARY PRO TEMPORE.
At any meeting of the Board or of the shareholders from which the
Secretary is absent, a Secretary pro tempore may be appointed and act.
SECTION 22. ELECTION OF ACTING TREASURER OR ACTING SECRETARY.
The Board may elect an Acting Treasurer, who shall perform all the
duties of the Treasurer during the absence or disability of the Treasurer, and
who shall hold office only for such a term as shall be determined by the Board.
The Board may elect an Acting Secretary, who shall perform all the
duties of the Secretary during the absence or disability of the Secretary, and
who shall hold office only for such a term as shall be determined by the Board.
Whenever the Board shall elect either an Acting Treasurer or Acting
Secretary, or both, the officers of the corporation as set forth in Article IV,
Section 1 of these Bylaws, shall include as if therein specifically set out, an
Acting Treasurer or an Acting Secretary, or both.
SECTION 23. PERFORMANCE OF DUTIES.
Officers shall perform the duties of their respective offices as
stated in these Bylaws, and such additional duties as the Board shall
designate.
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ARTICLE V
ARTICLE V -- OTHER PROVISIONS
SECTION 1. INSPECTION OF CORPORATE RECORDS.
(a) A shareholder or shareholders holding at least five percent in
the aggregate of the outstanding voting shares of the corporation or who hold
at least one percent of such voting shares and have filed a Schedule 14B with
the United States Securities and Exchange Commission relating to the election
of directors of the corporation shall have an absolute right to do either or
both of the following:
(i) Inspect and copy the record of shareholders' names
and addresses and shareholdings during usual business hours upon five business
days' prior written demand upon the corporation; or
(ii) Obtain from the transfer agent, if any, for the
corporation, upon five business days' prior written demand and upon the tender
of its usual charges for such a list (the amount of which charges shall be
stated to the shareholder by the transfer agent upon request), a list of the
shareholders' names and addresses who are entitled to vote for the election of
directors and their shareholdings, as of the most recent record date for which
it has been compiled or as of a date specified by the shareholder subsequent to
the date of demand.
(b) The record of shareholders shall also be open to inspection
and copying by any shareholder or holder of a voting trust certificate at any
time during usual business hours upon written demand on the corporation, for a
purpose reasonably related to such holder's interest as a shareholder or holder
of a voting trust certificate.
(c) The accounting books and records and minutes of proceedings of
the shareholders and the Board and committees of the Board shall be open to
inspection upon written demand on the corporation of any shareholder or holder
of a voting trust certificate at any reasonable time during usual business
hours, for a purpose reasonably related to such holder's interests as a
shareholder or as a holder of such voting trust certificate.
(d) Any such inspection and copying under this Article may be made
in person or by agent or attorney.
SECTION 2. INSPECTION OF BYLAWS.
The corporation shall keep in its principle office the original or a
copy of these Bylaws as amended to date, which shall be open to inspection by
shareholders at all reasonable times during office hours.
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ARTICLE V
SECTION 3. CONTRACTS AND OTHER INSTRUMENTS, LOANS, NOTES AND DEPOSITS OF
FUNDS.
The Chairman of the Board, the President, or a Vice President, either
alone or with the Secretary or an Assistant Secretary, or the Secretary alone,
shall execute in the name of the corporation such written instruments as may be
authorized by the Board and, without special direction of the Board, such
instruments as transactions of the ordinary business of the corporation may
require and, such officers without the special direction of the Board may
authenticate, attest or countersign any such instruments when deemed
appropriate. The Board may authorize any person, persons, entity, entities,
attorney, attorneys, attorney-in-fact, attorneys-in-fact, agent or agents, to
enter into any contract or execute and deliver any instrument in the name of
and on behalf of the corporation, and such authority may be general or confined
to specific instances.
No loans shall be contracted on behalf of the corporation and no
evidences of such indebtedness shall be issued in its name unless authorized by
the Board as it may direct. Such authority may be general or confined to
specific instances.
All checks, drafts, or other similar orders for the payment of money,
notes, or other such evidences of indebtedness issued in the name of the
corporation shall be signed by such officer or officers, agent or agents of the
corporation and in such manner as the Board or chief executive officer may
direct.
Unless authorized by the Board or these Bylaws, no officer, agent,
employee or any other person or persons shall have any power or authority to
bind the corporation by any contract or engagement or to pledge its credit or
to render it liable for any purpose or amount.
All funds of the corporation not otherwise employed shall be deposited
from time to time to the credit of the corporation in such banks, trust
companies, or other depositories as the Board may direct.
SECTION 4. CERTIFICATES OF STOCK.
Every holder of shares of the corporation shall be entitled to have a
certificate signed in the name of the corporation by the Chairman of the Board,
the President, or a Vice President and by the Treasurer or an Assistant
Treasurer or the Secretary or an Assistant Secretary, certifying the number of
shares and the class or series of shares owned by the shareholder. Any or all
of the signatures on the certificate may be facsimile. In case any officer,
transfer agent or registrar who has signed or whose facsimile signature has
been placed
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ARTICLE V
upon a certificate shall have ceased to be such officer, transfer agent or
registrar before such certificate is issued, it may be issued by the
corporation with the same effect as if such person were an officer, transfer
agent or registrar at the date of issue.
Certificates for shares may be used prior to full payment under such
restrictions and for such purposes as the Board may provide; provided, however,
that on any certificate issued to represent any partly paid shares, the total
amount of the consideration to be paid therefor and the amount paid thereon
shall be stated.
Except as provided in this Section, no new certificate for shares
shall be issued in lieu of an old one unless the latter is surrendered and
canceled at the same time. The Board may, however, if any certificate for
shares is alleged to have been lost, stolen or destroyed, authorize the
issuance of a new certificate in lieu thereof, and the corporation may require
that the corporation be given a bond or other adequate security sufficient to
indemnify it against any claim that may be made against it (including expense
or liability) on account of the alleged loss, theft or destruction of such
certificate or the issuance of such new certificate.
SECTION 5. TRANSFER AGENT, TRANSFER CLERK AND REGISTRAR.
The Board may, from time to time, appoint transfer agents, transfer
clerks, and stock registrars to transfer and register the certificates of the
capital stock of the corporation, and may provide that no certificate of
capital stock shall be valid without the signature of the stock transfer agent
or transfer clerk, and stock registrar.
SECTION 6. REPRESENTATION OF SHARES OF OTHER CORPORATIONS.
The chief executive officer or any other officer or officers
authorized by the Board or the chief executive officer are each authorized to
vote, represent and exercise on behalf of the corporation all rights incident
to any and all shares of any other corporation or corporations standing in the
name of the corporation. The authority herein granted may be exercised either
by any such officer in person or by any other person authorized so to do by
proxy or power of attorney duly executed by said officer.
SECTION 7. STOCK PURCHASE PLANS.
The corporation may adopt and carry out a stock purchase plan or
agreement or stock option plan or agreement providing for the issue and sale
for
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ARTICLE VI
such consideration as may be fixed of its unissued shares, or of issued shares
acquired, to one or more of the employees or directors of the corporation or of
a subsidiary or to a trustee on their behalf and for the payment for such
shares in installments or at one time, and may provide for such shares in
installments or at one time, and may provide for aiding any such persons in
paying for such shares by compensation for services rendered, promissory notes
or otherwise.
Any such stock purchase plan or agreement or stock option plan or
agreement may include, among other features, the fixing of eligibility for
participation therein, the class and price of shares to be issued or sold under
the plan or agreement, the number of shares which may be subscribed for, the
method of payment therefor, the reservation of title until full payment
therefor, the effect of the termination of employment and option or obligation
on the part of the corporation to repurchase the shares upon termination of
employment, restrictions upon transfer of the shares, the time limits of and
termination of the plan, and any other matters, not in violation of applicable
law, as may be included in the plan as approved or authorized by the Board or
any committee of the Board.
SECTION 8. FISCAL YEAR AND SUBDIVISIONS.
The calendar year shall be the corporate fiscal year of the
corporation. For the purpose of paying dividends, for making reports and for
the convenient transaction of the business of the corporation, the Board may
divide the fiscal year into appropriate subdivisions.
SECTION 9. CONSTRUCTION AND DEFINITIONS.
Unless the context otherwise requires, the general provisions, rules
of construction and definitions contained in the General Provisions of the
California Corporations Code and in the California General Corporation Law
shall govern the construction of these Bylaws.
ARTICLE VI -- INDEMNIFICATION
SECTION 1. INDEMNIFICATION OF DIRECTORS AND OFFICERS.
Each person who was or is a party or is threatened to be made a party
to or is involved in any threatened, pending or completed action, suit or
proceeding, formal or informal, whether brought in the name of the corporation
or otherwise and whether of a civil, criminal, administrative or investigative
nature (hereinafter a "proceeding"), by reason of the fact that he or she, or a
person of whom he or she is the legal representative, is or was a director or
officer of the corporation or is or was serving at the request of the
corporation as a director, officer,
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ARTICLE VI
employee or agent of another corporation or of a partnership, joint venture,
trust or other enterprise, including service with respect to employee benefit
plans, whether the basis of such proceeding is an alleged action or inaction in
an official capacity or in any other capacity while serving as a director or
officer, shall, subject to the terms of any agreement between the corporation
and such person, be indemnified and held harmless by the corporation to the
fullest extent permissible under California law and the corporation's Articles
of Incorporation, against all costs, charges, expenses, liabilities and losses
(including attorneys' fees, judgments, fines, ERISA excise taxes or penalties
and amounts paid or to be paid in settlement) reasonably incurred or suffered
by such person in connection therewith, and such indemnification shall continue
as to a person who has ceased to be a director or officer and shall inure to
the benefit of his or her heirs, executors and administrators; provided,
however, that (A) the corporation shall indemnify any such person seeking
indemnification in connection with a proceeding (or part thereof) initiated by
such person only if such proceeding (or part thereof) was authorized by the
Board of the corporation; (B) the corporation shall indemnify any such person
seeking indemnification in connection with a proceeding (or part thereof) other
than a proceeding by or in the name of the corporation to procure a judgment in
its favor only if any settlement of such a proceeding is approved in writing by
the corporation; (C) that no such person shall be indemnified (i) except to the
extent that the aggregate of losses to be indemnified exceeds the amount of
such losses for which the director or officer is paid pursuant to any
directors' and officers' liability insurance policy maintained by the
corporation; (ii) on account of any suit in which judgment is rendered against
such person for an accounting of profits made from the purchase or sale by such
person of securities of the corporation pursuant to the provisions of Section
16(b) of the Securities Exchange Act of 1934 and amendments thereto or similar
provisions of any federal, state or local statutory law; (iii) if a court of
competent jurisdiction finally determines that any indemnification hereunder is
unlawful; and (iv) as to circumstances in which indemnity is expressly
prohibited by Section 317 of the General Corporation Law of California (the
"Law"); and (D) that no such person shall be indemnified with regard to any
action brought by or in the right of the corporation for breach of duty to the
corporation and its shareholders (a) for acts or omissions involving
intentional misconduct or knowing and culpable violation of law; (b) for acts
or omissions that the director or officer believes to be contrary to the best
interests of the corporation or its shareholders or that involve the absence of
good faith on the part of the director or officer; (c) for any transaction from
which the director or officer derived an improper personal benefit; (d) for
acts or omissions that show a reckless disregard for the director's or
officer's duty to the corporation or its shareholders in circumstances in which
the director or officer was aware, or should have been aware, in the ordinary
course of performing his or her duties, of a risk of serious injury to the
corporation or its shareholders; (e) for acts or omissions that constitute an
unexcused pattern of
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ARTICLE VI
inattention that amounts to an abdication of the director's or officer's duties
to the corporation or its shareholders; and (f) for costs, charges, expenses,
liabilities and losses arising under Section 310 or 316 of the Law. The right
to indemnification conferred in this Article shall include the right to be paid
by the corporation expenses incurred in defending any proceeding in advance of
its final disposition; provided, however, that if the Law permits the payment
of such expenses incurred by a director or officer in his or her capacity as a
director or officer (and not in any other capacity in which service was or is
rendered by such person while a director or officer, including, without
limitation, service to an employee benefit plan) in advance of the final
disposition of a proceeding, such advances shall be made only upon delivery to
the corporation of an undertaking, by or on behalf of such director or officer,
to repay all amounts to the corporation if it shall be ultimately determined
that such person is not entitled to be indemnified.
SECTION 2. INDEMNIFICATION OF EMPLOYEES AND AGENTS.
A person who was or is a party or is threatened to be made a party to
or is involved in any proceeding by reason of the fact that he or she is or was
an employee or agent of the corporation or is or was serving at the request of
the corporation as an employee or agent of another enterprise, including
service with respect to employee benefit plans, whether the basis of such
action is an alleged action or inaction in an official capacity or in any other
capacity while serving as an employee or agent, may, subject to the terms of
any agreement between the corporation and such person, be indemnified and held
harmless by the corporation to the fullest extent permitted by California law
and the corporation's Articles of Incorporation, against all costs, charges,
expenses, liabilities and losses, (including attorneys' fees, judgments, fines,
ERISA excise taxes or penalties and amounts paid or to be paid in settlement)
reasonably incurred or suffered by such person in connection therewith.
SECTION 3. RIGHT OF DIRECTORS AND OFFICERS TO BRING SUIT.
If a claim under Section 1 of this Article is not paid in full by the
corporation within 30 days after a written claim has been received by the
corporation, the claimant may at any time thereafter bring suit against the
corporation to recover the unpaid amount of the claim and, if successful in
whole or in part, the claimant shall also be entitled to be paid the expense of
prosecuting such claim. Neither the failure of the corporation (including its
Board, independent legal counsel, or its shareholders) to have made a
determination prior to the commencement of such action that indemnification of
the claimant is permissible in the circumstances because he or she has met the
applicable standard of conduct, if any, nor an actual determination by the
corporation (including its Board, independent legal counsel, or its
shareholders) that the claimant has not met the applicable standard of conduct,
shall be a
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ARTICLE VI
defense to the action or create a presumption for the purpose of an action that
the claimant has not met the applicable standard of conduct.
SECTION 4. SUCCESSFUL DEFENSE.
Notwithstanding any other provision of this Article, to the extent
that a director or officer has been successful on the merits or otherwise
(including the dismissal of an action without prejudice or the settlement of a
proceeding or action without admission of liability) in defense of any
proceeding referred to in Section 1 or in defense of any claim, issue or matter
therein, he or she shall be indemnified against expenses (including attorneys'
fees) actually and reasonably incurred in connection therewith.
SECTION 5. NON-EXCLUSIVITY OF RIGHTS.
The right to indemnification provided by this Article shall not be
exclusive of any other right which any person may have or hereafter acquire
under any statute, bylaw, agreement, vote of shareholders or disinterested
directors or otherwise.
SECTION 6. INSURANCE.
The corporation may maintain insurance, at its expense, to protect
itself and any director, officer, employee or agent of the corporation or
another corporation, partnership, joint venture, trust or other enterprise
against any expense, liability or loss, whether or not the corporation would
have the power to indemnify such person against such expense, liability or loss
under the Law.
SECTION 7. EXPENSES AS A WITNESS.
To the extent that any director, officer, employee or agent of the
corporation is by reason of such position, or a position with another entity
at the request of the corporation, a witness in any action, suit or proceeding,
he or she shall be indemnified against all costs and expenses actually and
reasonably incurred by him or her on his or her behalf in connection therewith.
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ARTICLE VII
SECTION 8. INDEMNITY AGREEMENTS.
The corporation may enter into agreements with any director, officer,
employee or agent of the corporation providing for indemnification to the
fullest extent permissible under the Law and the corporation's Articles of
Incorporation.
SECTION 9. SEPARABILITY.
Each and every paragraph, sentence, term and provision of this Article
is separate and distinct so that if any paragraph, sentence, term or provision
hereof shall be held to be invalid or unenforceable for any reason, such
invalidity or unenforceability shall not affect the validity or enforceability
of any other paragraph, sentence, term or provision hereof. To the extent
required, any paragraph, sentence, term or provision of this Article may be
modified by a court of competent jurisdiction to preserve its validity and to
provide the claimant with, subject to the limitations set forth in this Article
and any agreement between the corporation and claimant, the broadest possible
indemnification permitted under applicable law.
SECTION 10. EFFECT OF REPEAL OR MODIFICATION.
Any repeal or modification of this Article shall not adversely affect
any right of indemnification of a director or officer existing at the time of
such repeal or modification with respect to any action or omission occurring
prior to such repeal or modification.
ARTICLE VII -- EMERGENCY PROVISIONS
SECTION 1. GENERAL.
The provisions of this Article shall be operative only during a
national emergency declared by the President of the United States or the person
performing the President's functions, or in the event of a nuclear, atomic or
other attack on the United States or a disaster making it impossible or
impracticable for the corporation to conduct its business without recourse to
the provisions of this Article. Said provisions in such event shall override
all other Bylaws of the corporation in conflict with any provisions of this
Article, and shall remain operative so long as it remains impossible or
impracticable to continue the business of the corporation otherwise, but
thereafter shall be inoperative; provided that all actions taken in good faith
pursuant to such provisions shall thereafter remain in full force and effect
unless and until revoked by action taken pursuant to the provisions of the
Bylaws other than those contained in this Article.
27
<PAGE> 33
ARTICLE VII
SECTION 2. UNAVAILABLE DIRECTORS.
All directors of the corporation who are not available to perform
their duties as directors by reason of physical or mental incapacity or for any
other reason or who are unwilling to perform their duties or whose whereabouts
are unknown shall automatically cease to be directors, with like effect as if
such persons had resigned as directors, so long as such unavailability
continues.
SECTION 3. AUTHORIZED NUMBER OF DIRECTORS.
The authorized number of directors shall be the number of directors
remaining after eliminating those who have ceased to be directors pursuant to
Section 2, or the minimum number required by law, whichever number is greater.
SECTION 4. QUORUM.
The number of directors necessary to constitute a quorum shall be
one-third of the authorized number of directors as specified in the foregoing
Section, or such other minimum number as, pursuant to the law or lawful decree
then in force, it is possible for the Bylaws of a corporation to specify.
SECTION 5. CREATION OF EMERGENCY COMMITTEE.
In the event the number of directors remaining after eliminating those
who have ceased to be directors pursuant to Section 2 is less than the minimum
number of authorized directors required by law, then until the appointment of
additional directors to make up such required minimum, all the powers and
authorities which the Board could by law delegate, including all powers and
authorities which the Board could delegate to a committee, shall be
automatically vested in an emergency committee, and the emergency committee
shall thereafter manage the affairs of the corporation pursuant to such powers
and authorities and shall have all other powers and authorities as may by law
or lawful decree be conferred on any person or body of persons during a period
of emergency.
SECTION 6. CONSTITUTION OF EMERGENCY COMMITTEE.
The emergency committee shall consist of all the directors remaining
after eliminating those who have ceased to be directors pursuant to Section 2,
provided that such remaining directors are not less than three in number. In
the event such remaining directors are less than three in number the emergency
committee shall consist of three persons, who shall be the remaining director
or
28
<PAGE> 34
ARTICLE VII
directors and either one or two officers or employees of the corporation, as
the remaining director or directors may in writing designate. If there is no
remaining director, the emergency committee shall consist of the three most
senior officers of the corporation who are available to serve, and if and to
the extent that officers are not available, the most senior employees of the
corporation. Seniority shall be determined in accordance with any designation
of seniority in the minutes of the proceedings of the Board, and in the absence
of such designation, shall be determined by rate of remuneration. In the event
that there are no remaining directors and no officers or employees of the
corporation available, the emergency committee shall consist of three persons
designated in writing by the shareholder owning the largest number of shares of
record as of the date of the last record date.
SECTION 7. POWERS OF EMERGENCY COMMITTEE.
The emergency committee, once appointed, shall govern its own
procedures and shall have power to increase the number of members thereof
beyond the original number, and in the event of a vacancy or vacancies therein,
arising at any time, the remaining member or members of the emergency committee
shall have the power to fill such vacancy or vacancies. In the event at any
time after its appointment all members of the emergency committee shall die or
resign or become unavailable to act for any reason whatsoever, a new emergency
committee shall be appointed in accordance with the foregoing provisions of
this Article.
SECTION 8. DIRECTORS BECOMING AVAILABLE.
Any person who has ceased to be a director pursuant to the provisions
of Section 2 and who thereafter becomes available to serve as a director shall
automatically become a member of the emergency committee.
SECTION 9. ELECTION OF BOARD OF DIRECTORS.
The emergency committee shall, as soon after its appointment as is
practicable, take all requisite action to secure the election of a board of
directors, and upon such election all the powers and authorities of the
emergency committee shall cease.
SECTION 10. TERMINATION OF EMERGENCY COMMITTEE.
In the event, after the appointment of an emergency committee, a
sufficient number of persons who ceased to be directors pursuant to Section 2
become available to serve as directors, so that if they had not ceased to be
directors as aforesaid, there would be enough directors to constitute the
29
<PAGE> 35
ARTICLE VIII
minimum number of directors required by law, then all such persons shall
automatically be deemed to be reappointed as directors and the powers and
authorities of the emergency committee shall be at an end.
ARTICLE VIII -- AMENDMENTS
SECTION 1. AMENDMENTS.
These Bylaws may be amended or repealed either by approval of the
outstanding shares or by the approval of the Board; provided, however, that a
Bylaw specifying or changing a fixed number of directors or the maximum or
minimum number or changing from a fixed to a variable Board or vice versa may
only be adopted by approval of the outstanding shares. The exact number of
directors within the maximum and minimum number specified in these Bylaws may
be amended by the Board alone.
30
<PAGE> 1
EXHIBIT 4.93
================================================================================
NINETY-SECOND SUPPLEMENTAL INDENTURE
------------------
SOUTHERN CALIFORNIA EDISON COMPANY
TO
HARRIS TRUST AND SAVINGS BANK
AND
R. G. MASON,
TRUSTEES
------------------
DATED AS OF JUNE 1, 1993
================================================================================
<PAGE> 2
This Ninety-Second Supplemental Indenture, dated as of the 1st
day of June, 1993, by and between Southern California Edison Company (between
1930 and 1947 named "Southern California Edison Company Ltd."), a corporation
duly organized and existing under and by virtue of the laws of the State of
California and having its principal office and mailing address at 2244 Walnut
Grove Avenue, in the City of Rosemead, County of Los Angeles, State of
California 91770, and qualified to do business in the States of Arizona, New
Mexico, Nevada and Utah (hereinafter sometimes termed the "Company"), and
Harris Trust and Savings Bank, a corporation duly organized and existing under
and by virtue of the laws of the State of Illinois and having its principal
office and mailing address at 111 West Monroe Street, in the City of Chicago,
State of Illinois 60603 (successor by merger to an Illinois corporation of the
same name), and R. G. Mason of 111 West Monroe Street, in the City of Chicago,
State of Illinois 60603 (successor Trustee to Wells Fargo Bank, National
Association which was successor trustee to Security Pacific National Bank,
formerly named Security First National Bank and Security-First National Bank of
Los Angeles, successor, by consolidation and merger, to Pacific-Southwest Trust
& Savings Bank), as Trustees (hereinafter sometimes termed the "Trustees");
WITNESSETH:
WHEREAS, the Company heretofore executed and delivered to said
Harris Trust and Savings Bank and said Pacific-Southwest Trust & Savings Bank,
a corporation organized under the laws of the State of California, trustees, a
certain Indenture of Mortgage or Deed of Trust dated as of October 1, 1923,
which said indenture was duly filed for record and recorded in the offices of
the respective recorders of the following counties: in the State of California
- -- Fresno County, Volume 397 of Official Records, page 1; Imperial County, Book
1174 of Official Records, page 966; Inyo County, Volume 154 of Official
Records, page 417; Kern County, Book 379 of Trust Deeds, page 196; Kings
County, Volume 84 of Deeds, page 1; Los Angeles County, Book 2963 of Official
Records, page 1; Madera County, Volume 9 of Official Records, page 63; Merced
County, Volume 363 of Official Records, page 1; Modoc County, Volume 230 of
Official Records, page 119 et seq.; Mono County, Volume 64 of Official Records,
page 29; Orange County, Book 496 of Deeds, page 1; Riverside County, Book 594
of Deeds, page 252; San Bernardino County, Book 825 of Deeds, page 1; San Diego
County, Series 5 Book 1964, page 84061; Santa Barbara County, Book 229 of
Deeds, page 30; Stanislaus County, Volume 465 of Official Records, page 370;
Tulare County, Volume 50 of Official Records, page 1; Tuolumne County, Volume
274 of Official Records, page 568; and Ventura County, Volume 33 of Official
Records, page 1; in the State of Nevada -- Clark County, Book 8 of Mortgages;
Churchill County, Book 40 of Official Records, page 235; Lyon County, Book 39
of Mortgages, page 1; Mineral County, Book 13 of Official Records, page 794;
Pershing County, Book 15 of Official Records, page 612; and Washoe County, Book
83 of Mortgages, page 301; in the State of Arizona -- La Paz County, Instrument
No. 83-000212 of Official Records; Mohave County, Book 11 of Realty Mortgages;
Maricopa County, Docket 4349 of Official Records, page 197; and Yuma County,
Docket 369, page 310; and in the offices of the county clerks of the following
counties in the State of New Mexico -- McKinley County, Book Mtg. 50, page 187
and filed as Document No. 10536 in the Chattel Records; and San Juan County,
Book Mtg. 630, page 13 and filed as Document No. 17838 in the Chattel Records
(hereinafter referred to as the "Original Indenture"), to secure the payment of
the principal of and interest on all bonds of the Company at any time
outstanding thereunder, and (as to certain such filings or recordings) the
principal of and interest on all Debentures of 1919 (referred to in the
Original Indenture and now retired) outstanding; and
2
<PAGE> 3
WHEREAS, the Company has heretofore executed and delivered to
the Trustees ninety-one certain supplemental indentures, dated, respectively,
as of March 1, 1927, April 25, 1935, June 24, 1935, September 1, 1935, August
15, 1939, September 1, 1940, January 15, 1948, August 15, 1948, February 15,
1951, August 15, 1951, August 15, 1953, August 15, 1954, April 15, 1956,
February 15, 1957, July 1, 1957, August 15, 1957, August 15, 1958, January 15,
1960, August 15, 1960, April 1, 1961, May 1, 1962, October 15, 1962, May 15,
1963, February 15, 1964, February 1, 1965, May 1, 1966, August 15, 1966, May 1,
1967, February 1, 1968, January 15, 1969, October 1, 1969, December 1, 1970,
September 15, 1971, August 15, 1972, February 1, 1974, July 1, 1974, November
1, 1974, March 1, 1975, March 15, 1976, July 1, 1977, November 1, 1978, June
15, 1979, September 15, 1979, October 1, 1979, April 1, 1980, November 15,
1980, May 15, 1981, August 1, 1981, December 1, 1981, January 16, 1982, April
15, 1982, November 1, 1982, November 1, 1982, January 1, 1983, May 1, 1983,
December 1, 1984, March 15, 1985, October 1, 1985, October 15, 1985, March 1,
1986, March 15, 1986, April 15, 1986, April 15, 1986, July 1, 1986, September
1, 1986, September 1, 1986, December 1, 1986, July 1, 1987, October 15, 1987,
November 1, 1987, February 15, 1988, April 15, 1988, July 1, 1988, August 15,
1988, September 15, 1988, January 15, 1989, May 1, 1990, June 15, 1990, August
15, 1990, December 1, 1990, April 1, 1991, May 1, 1991, June 1, 1991, December
1, 1991, February 1, 1992, April 1, 1992, July 1, 1992, July 15, 1992, December
1, 1992, January 15, 1993 and March 1, 1993 which modify, amend and supplement
the Original Indenture, such Original Indenture, as so modified, amended and
supplemented, being hereinafter referred to as the "Amended Indenture"; and
WHEREAS, there have been issued and are now outstanding and
entitled to the benefits of the Amended Indenture, First and Refunding Mortgage
Bonds as follows:
<TABLE>
<CAPTION>
Principal Principal
Series Due Amount Series Due Amount
------ ---- ---------- ------ ---- ---------
<S> <C> <C> <C> <C> <C>
DDP 1999 12,525,000 88E 1995 125,000,000
HH 2002 125,000,000 89A 2020 17,581,000
VVP 2012 46,760,000 90B 2021 200,000,000
WWP 2003 42,850,000 90C 1993 100,000,000
XXP 2003 20,000,000 90D 2022 200,000,000
YYP 2013 44,930,000 91A 2021 104,460,000
86A 2016 110,000,000 91B 2023 200,000,000
86B 2018 200,000,000 91C 2024 200,000,000
86C 2019 200,000,000 91D 2017 28,585,000
86D, E, F and G 2008 196,000,000 92A 1995 200,000,000
86J 2015 8,300,000 92B 1999 150,000,000
86K 2017 125,000,000 92C 2027 30,000,000
87A, B, C and D 2008 135,000,000 92D 1997 300,000,000
87E, F, G and H 2008 100,000,000 92E 2004 190,000,000
88B 1998 150,000,000 93A 2000 225,000,000
88C 2020 100,000,000 93B 1997 200,000,000
88D 2006 30,000,000 93C 2026 300,000,000
</TABLE>
WHEREAS, the Company proposes presently to issue in
fully registered form only, without coupons, $154,540,000 aggregate principal
amount of a new series of the Company's First and Refunding Mortgage Bonds,
said new series to be designated "Series 93D, Due 2023" the bonds of said
series to be dated as of June 1, 1993, and to mature June 1, 2023, (hereinafter
sometimes referred to as the "Bonds"), and the Company's authorized bonded
indebtedness has been increased to provide for the issuance of said series; and
3
<PAGE> 4
WHEREAS, the Company has acquired real and personal
property since the execution and delivery of the Ninety- First Supplemental
Indenture which, with certain exceptions, is subject to the lien of the Amended
Indenture by virtue of the after-acquired property clauses and other clauses
thereof, and the Company now desires in this Ninety-Second Supplemental
Indenture (hereinafter sometimes referred to as the "Supplemental Indenture")
expressly to convey and confirm unto the Trustees all properties, whether real,
personal or mixed, now owned by the Company (with the exceptions hereinafter
noted); and
WHEREAS, for the purpose of further safeguarding the
rights and interests of the holders of bonds under the Amended Indenture, the
Company desires, in addition to such conveyance, to enter into certain
covenants with the Trustees; and
WHEREAS, the making, executing, acknowledging,
delivering and recording of this Supplemental Indenture have been duly
authorized by proper corporate action of the Company, and the Trustees have
each duly determined to execute and accept this Supplemental Indenture;
NOW, THEREFORE, in order further to secure the payment
of the principal of and interest on all of the bonds of the Company at any time
outstanding under the Amended Indenture, as from time to time amended and
supplemented, including specifically, but without limitation, the First and
Refunding Mortgage Bonds, Series DDP, Series HH, Series VVP, Series WWP, Series
XXP, Series YYP, Series 86A, Series 86B, Series 86C, Series 86D, Series 86E,
Series 86F, Series 86G, Series 86J, Series 86K, Series 87A, Series 87B, Series
87C, Series 87D, Series 87E, Series 87F, Series 87G, Series 87H, Series 88B,
Series 88C, Series 88D, Series 88E, Series 89A, Series 90B, Series 90C, Series
90D, Series 91A, Series 91B, Series 91C, Series 91D, Series 92A, Series 92B,
Series 92C, Series 92D, Series 92E, Series 93A, Series 93B and Series 93C
referred to above, all of said bonds having been heretofore issued and being
now outstanding, and the Bonds, of the aggregate principal amount of
$154,540,000 to be presently issued and outstanding; and to secure the
performance and observance of each and every of the covenants and agreements in
the Amended Indenture contained, and without in any way limiting (except as
hereinafter specifically provided) the generality or effect of the Original
Indenture or any of said Supplemental Indentures executed and delivered prior
to the execution and delivery of this Supplemental Indenture insofar as by any
provision of any said indenture any of the properties hereinafter referred to
are subject to the lien and operation thereof, but to such extent (except as
hereinafter specifically provided) confirming such lien and operation, and for
and in consideration of the premises, and of the sum of One Dollar ($1.00) to
the Company duly paid by the Trustees, at or upon the ensealing and delivery of
these presents (the receipt whereof is hereby acknowledged), the Company has
executed and delivered this Supplemental Indenture and has granted, bargained,
sold, aliened, released, conveyed, assigned, transferred, warranted, mortgaged
and pledged, and by these presents does grant, bargain, sell, alien, release,
convey, assign, transfer, warrant, mortgage and pledge unto the Trustees, their
successors in trust and their assigns forever, in trust, with power of sale,
all of the following:
All and singular the plants, properties (including goods
which are or are to become fixtures), equipment and generating, transmission,
feeding, storing and distributing systems, and facilities and utilities of the
Company in the Counties of Fresno, Imperial, Inyo, Kern, Kings, Los Angeles,
Madera, Merced, Modoc, Mono, Orange, Riverside, San Bernardino, San Diego,
Santa Barbara, Stanislaus, Tulare, Tuolumne and Ventura, in the State of
California, Churchill, Clark, Lyon, Mineral, Pershing and Washoe, in the
State of Nevada, La Paz, Maricopa and Mohave, in the State of
4
<PAGE> 5
Arizona, and McKinley and San Juan, in the State of New Mexico, and elsewhere
either within or without said States, with all and singular the franchises,
ordinances, grants, easements, rights-of-way, permits, privileges, contracts,
appurtenances, tenements and other rights and property thereunto appertaining
or belonging, as the same now exist and as the same or any and all parts
thereof may hereafter exist or be improved, added to, enlarged, extended or
acquired in said Counties, or elsewhere either within or without said States;
Together with, to the extent permitted by law, all other
properties, real, personal and mixed (including goods which are or are to
become fixtures), except as herein expressly excepted, of every kind, nature
and description, including those kinds and classes of property described or
referred to (whether specifically or generally or otherwise) in the Original
Indenture and/or in any one or more of the indentures supplemental thereto, now
or hereafter owned, possessed, acquired or enjoyed by or in any manner
appertaining to the Company, and the reversion and reversions, remainder and
remainders, tolls, incomes, revenues, rents, issues and profits thereof; it
being hereby intended and expressly agreed that all the business, franchises
and properties, real, personal and mixed (except as herein expressly excepted),
of every kind and nature whatsoever and wherever situated, now owned, possessed
or enjoyed and which may hereafter be in anywise owned, possessed, acquired or
enjoyed by the Company, shall be as fully embraced within the provisions hereof
and be subject to the lien created hereby and by the Original Indenture and
said supplemental indentures executed and delivered prior to the execution and
delivery of this Supplemental Indenture, as if said properties were
particularly described herein;
Saving and excepting, however, anything contained herein
or in the granting clauses of the Original Indenture, or of the above mentioned
indentures supplemental thereto, or elsewhere contained in the Original
Indenture or said supplemental indentures, to the contrary notwithstanding,
from the property hereby or thereby mortgaged and pledged, all of the following
property (whether now owned by the Company or hereafter acquired by it): all
bills, notes, warrants, customers' service and extension deposits, accounts
receivable, cash on hand or deposited in banks or with any governmental agency,
contracts, choses in action, operating agreements and leases to others (as
distinct from the property leased and without limiting any rights of the
Trustees with respect thereto under any of the provisions of the Amended
Indenture), all bonds, obligations, evidences of indebtedness, shares of stock
and other securities, and certificates or evidences of interest therein, all
office furniture and office equipment, motor vehicles and tools therefor, all
materials, goods, merchandise and supplies acquired for the purpose of sale in
the ordinary course of business or for consumption in the operation of any
property of the Company, and all electrical energy and other materials or
products produced by the Company for sale, distribution or use in the ordinary
conduct of its business -- other than any of the foregoing which has been or
may be specifically transferred or assigned to or pledged or deposited with the
Trustees, or any of them, under the Amended Indenture, or required by the
provisions of the Amended Indenture, so to be; provided, however, that if, upon
the occurrence of a default under the Amended Indenture, the Trustees, or any
of them, or any receiver appointed under the Amended Indenture, shall enter
upon and take possession of the mortgaged and pledged property, the Trustees,
or such Trustee or such receiver may, to the extent permitted by law, at the
same time likewise take possession of any and all of the property excepted by
this paragraph then on hand which is used or useful in connection with the
business of the Company, and collect, impound, use and administer the same to
the same extent as if such property were part of the mortgaged and
5
<PAGE> 6
pledged property and had been specifically mortgaged and pledged hereunder,
unless and until such default shall be remedied or waived and possession of the
mortgaged and pledged property restored to the Company, its successors or
assigns, and provided further, that upon the taking of such possession and
until possession shall be restored as aforesaid, all such excepted property of
which the Trustees, or such Trustee or such receiver shall have so taken
possession, shall be and become subject to the lien hereof, subject, however,
to any liens then existing on such excepted property.
And the Company does hereby covenant and agree with the
Trustees, and the Trustees with the Company, as follows:
PART I
The Trustees shall have and hold all and singular the
properties conveyed, assigned, mortgaged and pledged hereby or by the Amended
Indenture, including property hereafter as well as heretofore acquired, in
trust for the equal and proportionate benefit and security of all present and
future holders of the bonds and interest obligations issued and to be issued
under the Amended Indenture, as from time to time amended and supplemented,
without preference of any bond over any other bond by reason of priority in
date of issuance, negotiation, time of maturity, or for any other cause
whatsoever, except as otherwise in the Amended Indenture, as from time to time
amended and supplemented, permitted, and to secure the payment of all bonds now
or at any time hereafter outstanding under the Amended Indenture, as from time
to time amended and supplemented, and the performance of and compliance with
the covenants and conditions of the Amended Indenture, as from time to time
amended and supplemented, and under and subject to the provisions and
conditions and for the uses set forth in the Amended Indenture, as from time to
time amended and supplemented.
PART II
Article I to Article Twenty-One, inclusive, of the
Amended Indenture are hereby incorporated by reference herein and made a part
hereof as fully as though set forth at length herein.
PART III
All of the terms appearing herein shall be defined as
the same are now defined under the provisions of the Amended Indenture, except
when expressly herein otherwise defined.
PART IV
Pursuant to Section 1 of Article Five of the Original
Indenture, as amended by Part IV, Subpart C, of the Sixth Supplemental
Indenture, dated as of September 1, 1940, the notice to be given with respect
to the redemption of the Bonds in whole or in part, shall be limited to and
shall consist of the giving by the Company or Harris Trust and Savings Bank,
Trustee, of a written notice of such redemption by first class mail, postage
prepaid, at least 30 days prior to the date fixed for redemption to the holder
of each Bond called for redemption at the holder's last address shown on the
registry books of the Company. Failure to so mail such notice to the holder of
any Bond shall not affect the validity of the redemption proceedings with
respect to any other Bond.
6
<PAGE> 7
PART V
All, but only, the duties, responsibilities,
liabilities, immunities, rights, powers and indemnities against liability, of
the Trustees and each of them, with respect to the trust created by the Amended
Indenture, are hereby assumed by and given to the Trustees, and each of them,
with respect to the trust hereby created, and are so assumed and given subject
to all the terms and provisions with respect thereto as set forth in the
Amended Indenture, as fully and to all intents and purposes as if the same were
herein set forth at length; and this Supplemental Indenture is executed by the
Trustees for the purpose of evidencing their consent to the foregoing.
The recitals contained herein, except the recital that
the Trustees have each duly determined to execute and deliver this Supplemental
Indenture, shall be taken as the statements of the Company, and the Trustees
assume no responsibility for the correctness thereof. The Trustees make no
representations as to the validity of this Supplemental Indenture.
PART VI
As amended and supplemented by this Supplemental
Indenture, the Amended Indenture is in all respects ratified and confirmed, and
the Original Indenture and all said indentures supplemental thereto including
this Supplemental Indenture, shall be read, taken and considered as one
instrument, and the Company agrees to conform to and comply with all and
singular the terms, provisions, covenants and conditions set forth therein and
herein.
PART VII
In case any one or more of the provisions contained in
this Supplemental Indenture should be invalid, illegal or unenforceable in any
respect, such invalidity, illegality or unenforceability shall not affect any
other provisions contained in this Supplemental Indenture, and, to the extent
and only to the extent that any such provision is invalid, illegal or
unenforceable, this Supplemental Indenture shall be construed as if such
provision had never been contained herein.
PART VIII
This Supplemental Indenture may be simultaneously
executed and delivered in any number of counterparts, each of which, when so
executed and delivered, shall be deemed to be an original.
7
<PAGE> 8
IN WITNESS WHEREOF, the Company has caused its corporate
name and seal to be hereunto affixed and this Supplemental Indenture to be
signed by its Chairman of the Board, its President or one of its Vice
Presidents and attested by the signature of its Secretary or one of its
Assistant Secretaries, for and in its behalf; said Harris Trust and Savings
Bank has caused its corporate name and seal to be hereunto affixed, and this
Supplemental Indenture to be signed, by one of its Vice Presidents or Assistant
Vice Presidents and attested by the signature of one of its Assistant
Secretaries, and said R. G. Mason has hereunto executed this Supplemental
Indenture; all as of the day and year first above written. Executed in
multiple.
Southern California Edison Company
By /s/Alan J. Fohrer
--------------------------------
Alan J. Fohrer
Senior Vice President, Treasurer and
Chief Financial Officer
Attest:
/s/Kenneth S. Stewart
--------------------------------------
Kenneth S. Stewart
Secretary
(Seal)
Harris Trust and Savings Bank, Trustee
By /s/C. Potter
--------------------------------
C. Potter
Assistant Vice President
Attest:
/s/D. G. Donovan
--------------------------------------
D. G. Donovan
Assistant Secretary
(Seal)
/s/R. G. Mason
- ----------------------------------
R. G. Mason
Trustee
8
<PAGE> 9
STATE OF CALIFORNIA }
} ss.
COUNTY OF LOS ANGELES }
On this 25th day of May, 1993, before me, Dorothy J. Fulco, a
Notary Public, personally appeared Alan J. Fohrer and Kenneth S. Stewart,
personally known to me (or proved to me on the basis of satisfactory evidence)
to be the persons whose names are subscribed to the within instrument and
acknowledged to me that they executed the same in their authorized capacities
and that by their signatures on the instrument the persons, or the entity upon
behalf of which the persons acted, executed the instrument.
WITNESS my hand and official seal.
/s/ Dorothy J. Fulco
----------------------------------
Dorothy J. Fulco
Notary Public, State of California
(Seal)
My Commission expires on March 20, 1995
9
<PAGE> 10
STATE OF ILLINOIS }
} ss.
COUNTY OF COOK }
On this 26th day of May, 1993, before me personally appeared
C. Potter and D. G. Donovan, Assistant Vice President and Assistant Secretary
of Harris Trust and Savings Bank, respectively, known to me to be the persons
who executed the within instrument on behalf of the corporation therein named
and acknowledged to me that such corporation executed the within instrument
pursuant to its by-laws or a resolution of its board of directors.
/s/T. Muzquiz
------------------------------
T. Muzquiz
Notary Public, Cook County, State of Illinois
(Seal)
My Commission expires on July 12, 1993
10
<PAGE> 11
STATE OF ILLINOIS }
} ss.
COUNTY OF COOK }
On this 26th day of May, 1993, before me personally appeared
R. G. Mason, known to me to be the person who executed the within instrument,
as Trustee, and acknowledged to me that he executed the within instrument as
his free and voluntary act and deed, for the uses and purposes therein
mentioned.
/s/T. Muzquiz
---------------------------------------
T. Muzquiz
Notary Public, Cook County, State of Illinois
(Seal)
My commission expires on July 12, 1993
11
<PAGE> 1
EXHIBIT 10.20
SOUTHERN CALIFORNIA EDISON COMPANY
1993 EXECUTIVE INCENTIVE COMPENSATION PLAN
AS ADOPTED DECEMBER 17, 1992
WHEREAS, it has been determined that it is in the best interest of the
Southern California Edison Company to offer and maintain competitive executive
compensation programs designed to attract and retain qualified executives; and
WHEREAS, it has been determined that providing financial incentives to
executives which reinforce and recognize Company, organizational and individual
performance and accomplishments will enhance the financial and operational
performance of the Company; and
WHEREAS, it has been determined that an incentive compensation program
would encourage the attainment of short-term corporate goals and objectives;
NOW, THEREFORE, the Southern California Edison Company 1993 Executive
Incentive Compensation Plan has been established by the Compensation Committee
of the Board of Directors effective January 1, 1993 and made available to
eligible executives of the Company subject to the following terms and
conditions:
1. DEFINITIONS. When capitalized herein, the following terms are defined
as indicated:
"Base Salary" is defined to be the annual salary for the Participant
as of January 1st of the Performance Period, as fixed by the Board of Directors
or by the executive officers of the Company.
"Board" shall mean the Board of Directors of the Company.
"Chairman" shall refer to the Chairman of the Board and Chief
Executive Officer of the Company.
"Code" shall refer to the Internal Revenue Code of 1986, as amended.
"Company" shall mean the Southern California Edison Company.
"Committee" shall mean the Compensation Committee of the Board.
"Participant" shall include the Chairman of the Board and Chief Executive
<PAGE> 2
Officer, President, Executive Vice Presidents, Senior Vice Presidents,
Corporate Vice Presidents, Corporate Secretary, appointed Division and Regional
Vice Presidents, and managers who are in Salary Grades 13 and 14, and whose
participation in this Plan has been approved by the Chairman.
"Plan" is defined to be the Southern California Edison Company 1993
Executive Incentive Compensation Plan.
2. ELIGIBILITY. To be eligible for the full amount of any
incentive award, an individual must have been a participant for the entire
calendar year. Pro-rata awards may be distributed to participants who are
discharged for reasons other than incompetence, misconduct or fraud, or who
resigned, retired or became disabled during the calendar year, or who were
participants for less than the full year. A pro-rata award may be made to a
participant's designated beneficiary in the event of death of a participant
during a calendar year prior to an award being made.
3. COMPANY PERFORMANCE GOALS. The Chairman will furnish
recommended Company achievement areas to the Committee, out of which the
Committee will, in consultation with the Chairman, select those areas of
achievement upon which they wish the Company to focus particular attention and
identify performance goals for the year.
The performance goals must represent relatively optimistic, but
reasonably attainable goals the accomplishment of which will contribute
significantly to the attainment of Company objectives.
4. INDIVIDUAL INCENTIVE AWARD LEVELS. Company, organizational
and individual performance relative to the pre- established goals will
determine the award a Participant can receive.
Although most performance goals will be stated in terms of results to
be achieved during the calendar year, it is important that long-range goals and
objectives be included. These long-range goals and objectives will have
payoffs later than the year in question, but short-term sub-goals may be
established for the calendar year.
If the Committee determines Company performance goals have been met,
Participants will be eligible for individual incentive awards not to exceed the
following maximum award percentages:
65% of year-end base salary for the Chairman;
60% of year-end base salary for the President;
55% of year-end base salary for each Executive Vice President;
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45% of year-end base salary for each Senior Vice President;
40% of year-end base salary for each Corporate Vice President and the
Corporate Secretary;
35% of year-end base salary for each appointed Divisional and Regional
Vice President; and
25% of year-end base salary for each manager who is in Salary Grade 13
or 14.
Each award shall be approved by the Committee and reported to the
Board. Incentive awards will be determined by evaluation of budget control,
organizational and management effectiveness, productivity, ingenuity and
dedication to work as outlined in each organization's Executive Plan and
Budget.
5. APPROVAL AND PAYMENT OF INDIVIDUAL AWARDS. During the first
quarter of the year following the completion of the calendar year, the Chairman
will assess the degree to which executive plans and budgets have been achieved
and will develop suggested incentive awards for eligible Participants other
than the Chairman. The Committee will receive a report by the Chairman as to
overall Company performance, will deliberate on the Chairman's recommendations,
will develop an incentive award for the Chairman, and make its determination as
to the approval of the recommended awards. The Committee will then present
individual award recommendations to the Board for their review. All decisions
of the Committee regarding individual incentive awards shall be final and
conclusive.
Incentive award payments will be made as soon after the review by the
Board as practical, and payment will be made in cash, unless any award has been
elected to be deferred pursuant to the terms of a deferred compensation plan of
the Company. Any payments made shall be subject to any income tax withholding
or other deductions as may from time-to-time be required by Federal, State or
local law.
Payments under this Plan will not be considered to be salary or other
compensation for the purpose of computing benefits to which the Participant may
be entitled under any pension plan, stock bonus plan, including but not limited
to the Southern California Edison Company Retirement Plan, Stock Savings Plus
Plan, Employee Stock Ownership Plan, or other plan or arrangement of the
Company for the benefit of its employees if such plan or arrangement is a plan
qualified under Section 401(a) of the Code and is a trust exempt from Federal
income tax under Section 501(a) of the Code.
Any awards owing to participants under this Plan shall constitute an
unsecured general obligation of the Company, and no special fund or trust shall
be created, nor shall any notes or securities be issued with respect to any
awards.
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6. PLAN MODIFICATIONS AND ADJUSTMENTS. In order to ensure the
incentive features of the plan, avoid distortion in its operation and
compensate for or reflect extraordinary changes which may have occurred during
the calendar year, the Committee may make adjustments to the Plan's performance
goals and percentage allocations before, during or after the end of the
calendar year to the extent it determine appropriate in its sole discretion.
Adjustments to the Plan shall be conclusive and binding upon all parties
concerned. The Plan may be modified or terminated by the Board at any time.
7. PLAN ADMINISTRATION. This Plan and any awards under it are to
be approved by the Committee. The Plan will be administered by the Chairman,
or a Vice President if authorized to act on behalf of the Chairman, who shall
be authorized to approve ministerial changes or amendments to the Plan, to
interpret Plan provisions, and to approve changes as may from time-to-time be
required by law or regulation.
No member of the Board, nor its designee, shall be liable to any
person for any action taken or omitted in connection with the interpretation
and administration of the Plan.
8. SUCCESSORS AND ASSIGNS. This Plan shall be binding upon and
inure to the benefit of the heirs, legal representatives, successors and
assigns of the Company and Participant. Notwithstanding the foregoing, any
right to receive payment hereunder is hereby expressly declared to be personal,
nonassignable and nontransferable, except by will, intestacy, or as otherwise
required by law, and in the event of any attempted assignment, alienation or
transfer of such rights contrary to the provisions hereof, the Company shall
have no further liability for payments hereunder.
9. BENEFICIARIES. In the event of the death of a Participant
during a calendar year prior to the making of any individual incentive award, a
pro-rata award may, at the discretion of the Board, be made. Any such payment
will be made to the Participant's most recently designated beneficiary or
beneficiaries under the Long-Term Incentive Compensation Plan of the Company.
If no such designated beneficiary or beneficiaries survive the Participant, or
if a designated beneficiary should die before the award has been paid, any
award will be paid in one lump-sum payment to his or her estate as soon as
practicable following the Participant's or the designated beneficiary's death.
10. CAPACITY. If any person entitled to payments under this Plan
is, in the opinion of the Board or its designee, incapacitated and unable to
use such payments in his or her own best interest, the Board or its designee
may direct that payments (or any portion) be made to that person's legal
guardian or conservator, or that person's spouse, as an alternative to the
payment to the person unable to use the payments. The Board or its designee
shall have no obligation to supervise the use of such payments, and
court-appointed guardianship or conservatorship may be required.
11. NO RIGHT OF EMPLOYMENT. Nothing contained herein shall be
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construed as conferring upon the Participant the right to continue in the
employ of the Company as an Officer or Manager of the Company or in any other
capacity.
12. SEVERABILITY AND CONTROLLING LAW. This Plan shall be governed
by the laws of the State of California.
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<PAGE> 1
EXHIBIT 10.30
AGREEMENT
This Agreement ("Agreement"), is entered into by and between
Charles B. McCarthy, Jr. ("CBM"), an individual, and Southern California Edison
Company ("Edison"), a corporation.
In consideration of the covenants undertaken and the releases
contained in this Agreement and of CBM's more than 23 years of valued service
to Edison, CBM on the one hand, and Edison on the other hand, agree as follows:
1. CBM shall irrevocably resign from his position as
Senior Vice President of Edison and terminate his employment with Edison by
executing the resignation letter attached hereto as Exhibit A and incorporated
herein by reference. CBM's resignation from, and termination of employment
with, Edison shall be effective, at CBM's option, on any date on or after the
date this Agreement is signed, provided that such resignation and termination
shall be effective no later than December 31, 1993.
2. CBM's 1993 Executive Incentive Compensation Award
shall be payable on the effective date of his resignation and termination of
employment (hereinafter, "Termination Date") and shall be calculated as 80%
his maximum potential award, prorated for his 1993 time as an employee of
Edison. By way of example and without limitation or warranty, if CBM's
Termination Date were December 31, 1993, his 1993 bonus would be the product
<PAGE> 2
of $226,000 (annual base salary) times .45 (maximum potential award factor)
times .8 (80%) times 12/12 (fraction of 1993 worked), which would equal
$81,360.
3. CBM shall receive benefits under the Involuntary
Severance Plan for Management and Administrative Employees established by
Edison effective August 11, 1993 (the "1993 Severance Plan"). The benefits
available under the 1993 Severance Plan are described in the relevant plan
document. CBM will execute the document entitled Severance Agreement and
Release for Employees Electing Special Retirement Window Option (the "Special
Retirement Window Release") and will be considered to have elected the
following benefits under or in conjunction with the 1993 Severance Plan:
a. "Basic Severance" pay equal to 4 weeks base
pay plus 1 week of base pay for each year of service (assuming a
December 31, 1993, Termination Date, CBM's Basic Severance payment
should be approximately $119,500);
b. "Special Retirement Window" benefits,
beginning on termination (assuming a December 31, 1993, Termination
Date, and given that CBM will be age 53 and will have 23 years of
service at termination, CBM's monthly retirement benefit under the
Special Retirement Window would commence January 1, 1994, and should
be approximately $3,921); and
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c. "Retiree Health Care Benefits" on the same
basis as other Edison employees retiring in 1993.
4. In addition to the Basic Severance paid under the
1993 Severance Plan, Edison shall pay to CBM the sum of $106,500 within 2 weeks
following the date which is six months after CBM's Termination Date. CBM
understands and agrees that such payment shall be subject to tax withholding.
5. Upon execution of this Agreement:
a. CBM shall become the owner of the personal
computers and related equipment Edison provided to him for his use at
his residence, and CBM shall become the owner of the current
automobile and car phone Edison provided to him. The automobile and
the equipment shall be transferred to CBM free of all liens and with
clear title. Edison will do the necessary paperwork to transfer
ownership of each of these items of personal property to CBM. CBM
understands and agrees that the value of such items are subject to
treatment as imputed income and can result in tax withholdings.
b. CBM shall be entitled to out-placement
consulting services, which services shall be rendered to CBM on a
one-on-one basis. Edison shall pay for such out-placement consulting
services provided to CBM on or before the second anniversary of his
Termination Date. The total
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cost to Edison for out-placement services provided to CBM under this
Paragraph 5b of this Agreement and under Paragraph 3 of the Special
Retirement Window Release shall not exceed $45,000.
6. CBM and Edison expressly agree that, except to the
extent this Agreement imposes obligations upon the parties, this Agreement
shall never, at any time, for any purpose whatsoever, be considered as an
admission of liability or responsibility of the parties or any of them.
Moreover, neither this Agreement nor anything in this Agreement shall be
construed to be or shall be admissible in any proceeding as evidence of or an
admission by Edison, SCEcorp or any of SCEcorp's other subsidiaries or
affiliates of any violation of its or their policies or procedures, or of state
or federal laws or regulations. This Agreement may be introduced, however, in
any proceeding to enforce this Agreement. Such introduction shall be pursuant
to an order protecting the confidentiality of this Agreement.
7. Edison may withhold from any compensation or benefits
payable under this Agreement all federal, state and other taxes as shall be
required pursuant to any law or governmental regulation or ruling. CBM agrees
that he shall be exclusively liable for the payment of all federal and state
taxes which may be due from him as the result of the consideration received
from Edison herein, and as fees as set forth in paragraph 19 hereof.
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8. CBM shall be granted no further options to purchase
shares of common stock in Edison's parent company, SCEcorp. Those stock
options presently held by him (whether presently vested or presently nonvested)
shall become fully vested on CBM's Termination Date and shall be fully
exercisable for their full terms, as provided in the instruments granting such
options.
9. In addition to the Special Retirement Window benefits
paid to CBM in conjunction with the 1993 Severance Plan, CBM shall receive
certain benefits under the Executive Retirement Plan ("ERP"). With respect to
CBM's benefits under the ERP, the parties understand and agree as follows:
a. CBM or his surviving spouse have the absolute
and unconditional right to receive benefits under the ERP;
b. CBM shall begin receiving benefits under the
ERP upon reaching age 55;
c. Edison will calculate CBM's monthly pension
benefit under the ERP using the current Executive Incentive
Compensation Award factor and applying the following "factors" --
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(1) His monthly pension benefit shall be
determined as if CBM were 58-years-old when his employment
with Edison ended; and
(2) His monthly pension benefit shall be
calculated as if CBM had worked 25 years for Edison when his
employment ended.
d. Based upon the above and various other
assumptions, and without warranty, Edison calculates that the total
monthly pension benefit payment to CBM under the ERP upon his
attaining age 55 will commence on September 1, 1995, in accordance
with plan practice and will be approximately $5,095, such that CBM's
monthly pension benefits under the ERP ($5,095) and the Special
Retirement Window provided in conjunction with the 1993 Severance Plan
($3,921) will total $9,016;
e. Whether CBM dies before or after attaining
age 55, his surviving spouse will receive a 50% survivor annuity under
the ERP beginning at his death and calculated in the same manner as
set forth in this paragraph; a survivor annuity will be provided under
the Special Retirement Window to the extent provided under the Edison
Retirement Plan document.
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10. CBM hereby irrevocably elects the Executive
Supplemental Retirement Income Plan option. Beginning when he reaches age 55,
CBM will receive benefits under the Executive Supplemental Retirement Income
Plan and the amount of these benefits (payable for 120 months, commencing
September 1, 1995, in accordance with plan practice) would be determined by
assuming that CBM was 58 years old when his employment with Edison ended.
Based on the above, and various other assumptions, and without warranty, Edison
calculates that the monthly payments under the Executive Supplemental
Retirement Income Plan will be approximately $2,336.25.
11. CBM will receive benefits under the 1985 (non-ERISA)
Deferred Compensation Plan. With respect to benefits under such Plan, and
subject to the rights reserved to the Edison Board under the Plan to amend or
terminate the Plan, the parties understand and agree as follows:
a. CBM, his surviving spouse and/or his estate
or designee have the absolute and unconditional right to receive
benefits under such Plan in accordance with its terms;
b. While monthly benefit payments under such
Plan would ordinarily commence on retirement, CBM has requested that
such commencement be deferred until CBM reaches age 60; in response to
this request, Edison has
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agreed that such commencement will be deferred until CBM reaches age
55 and that, as soon as practicable in 1994, Edison will, in good
faith, make a decision on CBM's request for a further deferral until
CBM reaches age 60; if the deferral to age 60 is granted, CBM shall be
entitled to decline such deferral and to begin receiving benefit
payments at age 55 if in his opinion, the conditions on the deferral
are not in his best interest.
c. Based upon present actuarial assumptions, but
without warranty, Edison calculates that (assuming payments commence
when CBM reaches age 55) payments under the Plan will be $7,010.00 per
month for 180 months.
12. Beginning at age 55, and effective September 1, 1995
in accordance with plan practice, CBM will commence to receive payments due
under the 1981A, 1981B and Annual Deferred Compensation Plans, if any.
Moreover, if CBM has a right as a former employee and retiree to receive any
other benefits under Edison benefit plans not described herein (by way of
example and not by way of limitation or warrantee, plans such as the Stock
Savings Plus Plan), CBM and his beneficiaries continue to have the right to
such other benefits in accordance with the terms of the respective plans.
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<PAGE> 9
13. With respect to CBM's employment by and/or business
dealings with third parties to this Agreement, the parties understand and agree
as follows:
a. CBM agrees that, except as provided in
subparagraph 13.b., below, he will not, for a period of twelve 12
months commencing on his Termination Date, directly or indirectly own
an interest in, operate, join, control, or participate in, render
services to or be connected as an officer, employee, agent,
independent contractor, partner, shareholder, or principal of any
corporation, partnership, proprietorship, firm, association, person,
or other entity which is directly or indirectly engaged in any of the
following business activities --
(1) Electrical generation, distribution
or transmission; or
(2) Provision of energy or energy
efficiency services;
b. The limitations in subparagraph 13.a., above,
shall not apply if --
(1) Edison's CEO is advised in advance
of, and expressly consents in writing to, CBM's
actions; or
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(2) such business entity is an
investor-owned or municipal utility which has no involvement
with any business activity that directly competes with Edison,
SCEcorp or any of SCEcorp's other subsidiaries or affiliates;
(3) It shall not be a violation of this
Agreement for CBM to have investments in publicly traded
mutual funds regardless of the stocks or investments which may
be purchased or made by such fund or funds.
c. CBM agrees that, except as provided in
subparagraph 13.d., below, he will not, for a period of twelve 12
months commencing on his Termination Date, directly or indirectly, own
an interest in, operate, join, control, or participate in, render
services to or be connected as an officer, employee, agent,
independent contractor, partner, shareholder, or principal of any
corporation, partnership, proprietorship, firm, association, person,
or other entity which has or is considering any direct or indirect
business relationship with, Edison, SCEcorp or any of SCEcorp's other
subsidiaries or affiliates;
d. The limitations in subparagraph 13.c., above,
shall not apply if --
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(1) Edison's CEO is advised in advance
of, and expressly consents in writing to, CBM's actions; or
(2) if such business entity's only
business relationship with Edison, SCEcorp or any of their
subsidiaries or affiliates is --
(a) as a utility customer of
Edison; or
(b) a supplier of equipment or
services to Edison, SCEcorp or any of SCEcorp's other
subsidiaries or affiliates, and CBM is not involved
in, and his compensation is not related to, that
entity's business relationship with Edison, SCEcorp
or any of SCEcorp's other subsidiaries or affiliates.
14. CBM acknowledges that he is in possession of
confidential trade secret and business information not publicly available
concerning Edison, SCEcorp and SCEcorp's other subsidiaries and affiliates.
CBM specifically agrees that he will not at any time, in any fashion, form, or
manner, use or divulge, disclose or communicate to any person, firm, or
corporation, in any manner whatsoever, any such confidential information
concerning any matters affecting or relating to the business of Edison, SCEcorp
or any of SCEcorp's other subsidiaries or affiliates.
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15. This Agreement shall be administered by Edison, which
shall have the general responsibility of reasonably interpreting this
Agreement. Any controversy or claim arising out of or relating to this
Agreement or breach thereof which cannot be resolved by the parties shall be
settled by arbitration to be held in the County of Los Angeles in accordance
with the Rules of the American Arbitration Association, and judgment upon the
award rendered by the arbitrator may be entered in any court having
jurisdiction thereof. The parties shall equally divide the arbitrator's fee.
The prevailing party shall be entitled to recover its one-half share of the
arbitrator's fee from the non-prevailing party as a component of his or its
costs pursuant to Paragraph 32, below.
16. This Agreement shall be binding upon any successor in
interest of Edison. Neither this Agreement nor any right or interest hereunder
shall be assignable by CBM without Edison's prior written consent which consent
shall not be unreasonably withheld. Nothing herein shall restrict CBM's right
to designate beneficiaries under any of the plans in which he is a participant,
provided such designations are not prohibited by the applicable plan documents
and are otherwise lawful, or to transfer rights to income to any trust or other
entity which he may establish for estate planning purposes. Except as required
by law, no right to receive payments under this Agreement shall be subject to
anticipation, commutation, alienation, sale, assignment, encumbrance, charge,
pledge, or hypothecation or to
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execution, attachment, levy, or similar process or assignment by operation of
law, and any attempt to effect such action shall be null, void and of no
effect.
17. No provision of this Agreement may be amended,
modified or waived except by written agreement signed by the parties hereto.
18. CBM acknowledges and understands that the
confidentiality of this Agreement is of the utmost concern to Edison and that
this Agreement would not have been entered into by Edison without his promise
to keep such matter confidential. Accordingly, CBM agrees that, except to the
extent disclosure is required by law, the terms and conditions of this
Agreement and the Agreement document itself shall remain confidential as
between the parties and he shall not disclose them to any other person, other
than his wife, immediate family members, legal advisor and/or other
professional personal advisors, who shall also be advised of its
confidentiality and who shall agree to be bound by this confidentiality
agreement. Said confidentiality provision in this Paragraph 18 of this
Agreement is in no way limited by the confidentiality provision set forth in
Paragraph 7 of the Special Retirement Window Release.
19. Subject to the exceptions set forth in its by-laws,
Edison agrees to indemnify CBM for any and all expenses actually and reasonably
incurred by CBM in the defense,
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settlement or satisfaction of any judgment arising from any threatened or
actual claim, issue or matter, the basis for which is in any way related to
CBM's position as an employee of Edison. Said indemnification shall inure to
the benefit of CBM's heirs, executors and administrators.
20. As consideration for this Agreement, and in
particular paragraphs 13 and 14 hereto, Edison shall pay to CBM on his
Termination Date the sum of $25,000 as a retainer fee for CBM to remain
available for a period of 12 months following his Termination Date to provide,
upon request by Edison's CEO, information and assistance to Edison with respect
to any matters handled by CBM or with which he became familiar while he was
employed by Edison. CBM agrees to make himself available to provide such
information and assistance at reasonable times not to exceed 25 hours per
month. Edison agrees to reimburse CBM for any expenses reasonably incurred by
him and, in addition to the retainer fee, to compensate CBM at the rate of
$150.00 per hour for the time he actually expends in providing such assistance
and/or information. CBM shall submit written statements accounting for his
time and expenses on a monthly basis, and Edison will reimburse CBM for these
expenses within 2 weeks after each submittal.
21. Except for obligations granted by or arising out of
this Agreement, and Edison's retirement, deferred compensation, stock options,
savings and/or ownership and welfare
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benefit plans, CBM, on his own behalf, and on behalf of his descendants,
dependents, heirs, executors, administrators, assigns and successors, as such,
does hereby covenant not to sue and acknowledges complete satisfaction of and
hereby releases, absolves and discharges Edison and its parent, successors and
assigns, subsidiaries, divisions and affiliated corporations, past and present
(including without limitation Edison's parent, SCEcorp), and their trustees,
directors, officers, shareholders, agents, attorneys, insurers and employees,
past and present, and each of them, as such (hereinafter in paragraphs 21 and
22 of this Agreement collectively referred to as "Edison Releasees") with
respect to and from any and all claims, demands, liens, agreements, contracts,
covenants, actions, suits, causes of action, wages, obligations, debts,
expenses, attorneys' fees, damages, judgments, orders and liabilities of
whatever kind or nature in law, equity or otherwise, without any exception
whatsoever, which CBM now owns or holds or has at any time heretofore owned or
held, as against said Edison Releasees, or any of them, including specifically,
but not exclusively, and without limiting the generality of the foregoing, and
without any exception whatsoever, any and all claims, demands, agreements,
obligations and causes of action, known or unknown, suspected or unsuspected,
by CBM arising out of or in any way concerning the events and/or circumstances
surrounding his employment with Edison or separation therefrom. Said release
in this Paragraph 21 of this Agreement is in no way limited by the release set
forth in Paragraph 4 of the Special Retirement Window Release.
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22. CBM understands and expressly agrees that the Release
given by him in paragraph 21, above, without any exception whatsoever, extends
to all claims, injuries, damages or losses to his person and property, whether
known, unknown, foreseen, patent or latent, which he may have against the
Edison Releasees or any of them. CBM specifically and expressly waives all his
rights under SECTION 1542 of THE CALIFORNIA CIVIL CODE which provides as
follows:
"A GENERAL RELEASE DOES NOT EXTEND TO CLAIMS WHICH THE
CREDITOR DOES NOT KNOW OR SUSPECT TO EXIST IN HIS FAVOR AT THE
TIME OF EXECUTING THE RELEASE, WHICH IF KNOWN BY HIM MUST HAVE
MATERIALLY AFFECTED HIS SETTLEMENT WITH THE DEBTOR."
Said waiver in this Paragraph 22 of this Agreement is in no way limited by the
waiver set forth in Paragraph 5 of the Special Retirement Window Release.
23. CBM expressly acknowledges and agrees that, by
entering into this Agreement, he is waiving any and all rights or claims that
he may have arising under the Age Discrimination in Employment Act of 1967, as
amended, which have arisen on or before the date of execution of this
Agreement. CBM further expressly acknowledges and agrees that:
a. In return for this Agreement, he will receive
compensation beyond that which he was already entitled to receive
before entering into this Agreement;
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b. He is hereby advised in writing by this
Agreement to consult with an attorney before signing this Agreement;
c. He was given a copy of this Agreement on
November 5, 1993, and informed that he had 45 days within which to
consider the Agreement and voluntarily executed this Agreement before
expiration of that 45-day period; and
d. He was informed that he has seven days
following the date of execution of the Agreement in which to revoke
the Agreement.
24. Except for obligations granted by or arising out of
this Agreement and except for the provisos contained in Paragraph 26, below,
Edison, on its own behalf, and on behalf of its successors and assigns, parent,
subsidiaries, divisions and affiliated corporations, past and present and each
of them, (hereinafter in Paragraphs 24 through 26 of this Agreement
collectively referred to as "Releasors"), do hereby covenant not to sue and
acknowledge complete satisfaction of and hereby release, absolve and discharge
CBM and his descendants, dependents, heirs, executors, administrators, agents,
attorneys, assigns and successors, and each of them, as such ("CBM Releasees")
with respect to and from any and all claims, demands, liens, agreements,
contracts, covenants, actions, suits, causes of action, wages, obligations,
debts, expenses, attorneys' fees,
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damages, judgments, orders and liabilities of whatever kind or nature in law,
equity or otherwise, without any exception whatsoever, which Releasors now own
or hold or have at any time heretofore owned or held as against CBM arising out
of or in any way concerning the events and/or circumstances surrounding CBM's
employment with Edison or separation therefrom.
25. Edison understands and expressly agrees that the
Release given by the Releasors in paragraph 24, above, extends to all claims,
injuries, damages or losses to their person and property which are referred in
paragraph 24. Edison specifically and expressly waives all of its rights under
SECTION 1542 of THE CALIFORNIA CIVIL CODE which provides as follows:
"A GENERAL RELEASE DOES NOT EXTEND TO CLAIMS WHICH THE
CREDITOR DOES NOT KNOW OR SUSPECT TO EXIST IN HIS FAVOR AT THE
TIME OF EXECUTING THE RELEASE, WHICH IF KNOWN BY HIM MUST HAVE
MATERIALLY AFFECTED HIS SETTLEMENT WITH THE DEBTOR."
26. The Release given by the Releasors in paragraphs 24
and 25 does not cover or extend to any claims, suits, causes of action, and
liabilities for:
i) profits made by CBM from the
purchase or sale by CBM of securities of Edison or SCEcorp pursuant to the
provisions of Section 16(b) of the Securities Exchange Act of 1934 and
amendments thereto or similar provisions of any federal, state or local
statutory law;
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ii) conduct by CBM for which
indemnity is expressly prohibited by Section 317 of the General Corporation Law
of California (the "Law");
iii) breach of duty owed by CBM to
Edison, SCEcorp or their shareholders --
a. for acts or omissions involving intentional
misconduct or knowing and culpable violation of law;
b. for acts or omissions that CBM believed to be
contrary to the best interests of Edison, SCEcorp or their
shareholders or that involved the absence of good faith on the part of
CBM as a director or officer;
c. for any transaction from which CBM derived an
improper personal benefit;
d. for acts or omissions that show a reckless
disregard for CBM's duty to Edison or SCEcorp or their shareholders in
circumstances in which as a director or officer CBM was aware, or
should have been aware, in the ordinary course of performing his
duties, of a risk of serious injury to Edison, SCEcorp or their
shareholders;
e. for acts or omissions that constitute an
unexcused pattern of inattention that amounts to an
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abdication of CBM's duties to Edison, SCEcorp or their shareholders;
and
f. for costs, charges, expenses, liabilities,
and losses arising under Section 310 or 316 of the Law.
27. This Agreement shall be deemed to have been entered
into in the State of California and all questions concerning the validity,
interpretation or performance of any of its terms or provisions, or of any
rights or obligations of the parties hereto, shall be governed and resolved in
accordance with the laws of the state of California. Furthermore, no provision
of this Agreement is to be interpreted for or against either party because that
party, or his legal representative, drafted such provision.
28. CBM represents and agrees that he has carefully read
and understands this Agreement, and agrees that neither Edison nor any officer,
agent or employee of Edison, SCEcorp or any other subsidiary of SCEcorp has
made any representations other than those contained herein or in the Special
Retirement Window Release. Edison agrees that neither CBM nor any of his
representatives has made any representations other than those contained herein.
Further CBM and Edison expressly agree that they have entered into this
Agreement freely and voluntarily and without pressure or coercion from the
other or from their respective officers, agents, employees, or anyone else
acting on
20
<PAGE> 21
their behalf. CBM further expressly agrees that prior to the execution of this
Agreement, he was advised to seek independent legal advice concerning the
terms, conditions and effect of this Agreement, and that he sought such advice
from Harris Kershnar of Wallin & Klarich who reviewed and proposed changes to
this Agreement.
29. CBM and Edison represent and agree that this
Agreement and the Special Retirement Window Release contain the entire
agreement and understanding between the parties hereto concerning CBM's
employment with and separation of employment from Edison, and other subject
matters addressed herein. CBM and Edison further represent and agree that this
Agreement and the Special Retirement Window Release supersede and replace all
prior negotiations and agreements, proposed or otherwise, whether written or
oral, concerning the subject matter hereof and that this is an integrated
agreement, the terms of which are contractual in nature and not a mere recital.
This Agreement is deemed to have been executed at the same time as or after the
Special Retirement Window Release is executed and, thus, shall not be
superseded pursuant to Paragraph 11 of such Special Retirement Window Release.
The Special Retirement Window Release shall not restrict CBM's right to receive
benefits, or other rights, provided in this Agreement.
30. If any provision of this Agreement or the application
thereof is held invalid, the invalidity shall not
21
<PAGE> 22
affect other provisions or applications of this Agreement which can be given
effect without the invalid provisions or applications, and to this extent, the
provisions of this Agreement are declared to be severable.
31. This Agreement may be executed in counterparts, and
each counterpart, when executed, shall have the efficacy of a signed original.
Photographic copies of such signed counterparts may be used in lieu of the
original for any purpose.
32. In the event that there is an adversarial proceeding,
or proceedings as referenced in Paragraph 15 above, arising out of the subject
matter of this Agreement or the breach or alleged breach of this Agreement, or
to enforce or interpret this Agreement, the prevailing party shall recover
against the other party reasonable attorneys' fees, expenses and costs incurred
in connection with such proceedings.
33. Approval by the Compensation Committees of the Boards
is a condition precedent to this Agreement's being effective. The CEO and
Chairman of the Boards of Edison and
22
<PAGE> 23
SCEcorp have recommended, and the Compensation Committees have given, such
approval, as evidenced by the execution of this Agreement on behalf of Edison.
IN WITNESS WHEREOF, CBM and Edison have executed this
Agreement on the dates opposite their signatures.
I declare under penalty of perjury under the laws of the State
of California that I have carefully read the foregoing Agreement and know and
fully understand the terms and contents thereof and I accept and agree to the
provisions it contains and hereby execute it voluntarily and as my own free act
with full understanding of its consequences.
DATED: 12/20/93 Charles B. McCarthy, Jr.
------------------------
Charles B. McCarthy, Jr.
at Yorba Linda, California
23
<PAGE> 24
I warrant and represent that I have the authority to execute
this Agreement on behalf of Edison.
SOUTHERN CALIFORNIA EDISON
COMPANY
DATED: 12/20/93 By John E. Bryson
at Rosemead, California ----------------------------
John E. Bryson
Chairman and Chief Executive
Officer
APPROVED AS TO FORM:
Harris E . Kershnar
- -------------------------
Harris E. Kershnar
Attorney for
Charles B. McCarthy, Jr.
Gordon E. Krischer
- -------------------------
Gordon E. Krischer
Attorney for Southern
California Edison Company
24
<PAGE> 25
I have carefully read the foregoing Agreement and I know and
fully understand the terms and contents thereof. I understand, that California
is a community property state and to the extent I now or in the future may have
any right, title or interest in anything released, bargained for, received, or
agreed to, in the Agreement, I hereby expressly agree to be completely bound by
all provisions of the Agreement. I have signed this statement as my own free
act.
DATE: 12/20/93
------------------ Anita G. McCarthy
at Yorba Linda, California --------------------------
Anita G. McCarthy
WITNESSED BY:
DATE: 12/20/93 M. D. McDonald
------------------ --------------------------
25
<PAGE> 26
EXHIBIT A
Southern California Edison Company
P.O. Box 800
2244 Walnut Grove Avenue
Rosemead, California 91770
Re: Resignation
This is to advise you that effective December 31, 1993, I
hereby irrevocably and voluntarily resign my position as Senior Vice President
of Southern California Edison Company ("Edison"), and as an employee in any
other capacity with Edison, and will not seek reemployment with Edison, SCEcorp
or any of SCEcorp's other subsidiaries or affiliates.
Sincerely yours,
Charles B. McCarthy, Jr.
-------------------------------
Charles B. McCarthy, Jr.
NAME: Charles B. McCarthy, Jr.
SS#: ###-##-####
AGREED TO AND ACCEPTED BY
Kenneth S. Stewart DATE: 12/21/93
- -------------------------- -------------
26
<PAGE> 1
EXHIBIT 11
SCECORP
COMPUTATION OF PRIMARY AND FULLY DILUTED EARNINGS PER SHARE
(UNAUDITED)
<TABLE>
<CAPTION>
YEAR ENDED DECEMBER 31,
----------------------------------------------
1993 1992 1991
-------- -------- --------
(IN THOUSANDS, EXCEPT PER SHARE AMOUNTS)
<S> <C> <C> <C>
Consolidated net income . . . . . . . . . . . . . . . . $ 639,047 $ 738,720 $ 702,605
Primary and fully diluted weighted average shares(a) . 447,754,621 445,489,078 437,320,546
------------ ------------ ------------
Primary and fully diluted earnings per share . . . . . $1.43 $1.66 $1.61
</TABLE>
- ------------
(a) Share amounts reflect the two-for-one split of SCEcorp Common Stock
effective June 1, 1993.
<PAGE> 1
EXHIBIT 12
SCECORP
COMPUTATION OF RATIOS OF EARNINGS TO FIXED CHARGES
(UNAUDITED)
<TABLE>
<CAPTION>
YEAR ENDED DECEMBER 31,
---------------------------------------------------------------
1989 1990 1991 1992 1993
-------- -------- -------- -------- --------
(IN THOUSANDS)
<S> <C> <C> <C> <C> <C>
EARNINGS BEFORE INCOME TAXES
AND FIXED CHARGES: (7)
INCOME BEFORE INTEREST EXPENSE (1) . . . . $1,406,256 $1,426,257 $1,326,008 $1,325,569 $1,203,577
ADD:
Taxes on income (2) . . . . . . . . . . . 576,348 506,252 435,853 466,006 353,706
Rentals (3) . . . . . . . . . . . . . . . 9,843 8,840 7,539 4,460 3,463
Allocable portion of interest
on long-term contracts for
the purchase of power (4) . . . . . . 19,361 10,600 1,925 1,908 1,890
Interest on partnership
indebtedness (5) . . . . . . . . . . . 29,791 47,054 45,996 38,070 41,091
Spent nuclear fuel interest (8) . . . . . 2,273 1,994 1,683 1,339 487
Amortization of previously
capitalized fixed charges . . . . . . 33,636 35,399 32,845 24,170 6,760
---------- ---------- ---------- ---------- ----------
TOTAL EARNINGS BEFORE INCOME
TAXES AND FIXED CHARGES (A) . . . . . . . $2,077,508 $2,036,396 $1,851,849 $1,861,522 $1,610,974
========== ========== ========== ========== ==========
FIXED CHARGES: (7)
Interest and amortization . . . . . . . . $ 583,509 $ 595,771 $ 581,165 $ 544,593 $ 523,808
Rentals (3) . . . . . . . . . . . . . . . 9,843 8,840 7,539 4,460 3,463
Capitalized interest (6) . . . . . . . . 23,253 21,069 24,053 35,115 73,808
Allocable portion of interest on
long-term contracts for
the purchase of power (4) . . . . . . 19,361 10,600 1,925 1,908 1,890
Spent nuclear fuel interest (8) . . . . . 2,273 1,994 1,683 1,339 487
Interest on partnership
indebtedness (5) . . . . . . . . . . . 29,791 47,054 45,996 38,070 41,091
Subsidiary preferred and preference
stock dividends -- pre-tax basis . . . 77,469 72,528 68,435 68,911 63,261
---------- --------- ---------- ---------- ----------
TOTAL FIXED CHARGES (B) . . . . . . . . . . $ 745,499 $ 757,856 $ 730,796 $ 694,396 $ 707,808
========== ========== ========== ========== ==========
RATIO OF EARNINGS TO
FIXED CHARGES (A)/(B): . . . . . . . . . 2.79 2.69* 2.53* 2.68 2.28
========== ========== ========== ========== ==========
</TABLE>
(1) Includes allowance for funds used during construction and accrual of
unbilled revenue.
(2) Includes allocation of federal income and state franchise taxes to
other income.
(3) Rentals include the interest factor relating to certain significant
rentals plus one-third of all remaining annual rentals.
(4) Allocable portion of interest included in annual minimum debt service
requirement of supplier.
(5) Includes the allocable portion of interest on project indebtedness of
fifty-percent partnership investments by other wholly-owned
subsidiaries of SCEcorp.
(6) Includes the fixed charges associated with the Nuclear Fuel Lease and
capitalized interest of fifty-percent owned partnerships.
(7) Effective July 1, 1988, SCEcorp acquired all of the issued and
outstanding common stock of Southern California Edison Company
(Edison). Pursuant to Securities and Exchange Commission Rules,
SCEcorp's fixed charges include the pre-tax dividend requirements for
Edison's preferred and preference stock.
(8) Represents interest on spent nuclear fuel disposal obligation.
* Reflects restatement of The Mission Group financial statements.
<PAGE> 1
EXHIBIT 13
SCEcorp
1993
Annual Report: Focus on Competitive Performance
<PAGE> 2
21
Financial Information
Management's Discussion and Analysis: SCEcorp and Subsidiaries
Results of Operations
Earnings
SCEcorp's 1993 earnings per share were $1.43, compared with $1.66 in
1992 and $1.61 in 1991. In 1993, Edison contributed $1.42 per share of
SCEcorp's earnings, unchanged from 1992 and up 8 cents per share from 1991. In
1993, the Mission companies contributed 1 cent per SCEcorp share, down 23 cents
from 1992 and 26 cents from 1991.
SCEcorp's 1993 earnings reflect special charges of 18 cents per share.
Mission Energy recorded special charges of 13 cents, including 7 cents to
recognize the reduced value of investments in five geothermal power plants, 4
cents to terminate its investment in the Carbon II project in Mexico, and 2
cents for additional reserves for project development and other costs. Mission
Power Engineering, which ceased operations in 1990, recorded a 3-cent-per-share
charge resulting from settlement of all remaining litigation for its Coso
geothermal project. Mission Land recorded special charges of 2 cents per share
to reflect the reduced value of several real estate projects and joint venture
project restructuring costs.
SCEcorp's 1992 earnings included a 5-cent-per-share charge to settle
litigation between Edison and Tucson Electric Power Company and a
3-cent-per-share charge in anticipation of real estate losses at Mission Land.
SCEcorp's 1991 earnings included a 21-cent-per-share charge for a
purchased-power regulatory settlement, legal and regulatory reserves, and a
corporate restructuring program at Edison.
All per-share amounts have been restated to reflect the two-for-one
common stock split effective June 1, 1993.
1993 vs. 1992
Excluding the special charges noted above, SCEcorp's earnings declined
13 cents per share -- 5 cents at Edison and 8 cents at the Mission companies.
Edison's decline is mainly due to a lower authorized return on common equity,
partially offset by a decline in interest expense as the result of an
aggressive refinancing program. The Mission companies' decrease from 1992 is
primarily due to higher administrative, general, project development and
start-up costs at Mission Energy and reduced earnings at Mission Land.
In addition to establishing its reserve for the geothermal projects,
Mission Energy discontinued recording earnings from these projects in the third
quarter of 1993, and will continue to forgo recording earnings through the 10th
year of each contract. This will not affect the expected cash flow from each
contract, but will significantly impact Mission Energy's earnings for 1994 and
possibly beyond.
1992 vs. 1991
Excluding special charges, SCEcorp's 1992 earnings declined 8 cents per
share, attributed to a lower authorized return on common equity and reduced
interest income at Edison.
Operating Revenue
Electric utility revenue decreased in 1993 compared to 1992, mostly due
to a 2.9% rate decrease authorized by the California Public Utilities
Commission (CPUC) and a 2% decline in retail sales volume. In 1992, electric
utility revenue increased 6% compared to 1991, mostly due to warmer weather
during the summer of 1992. In addition, retail rates rose in 1992, reflecting a
CPUC-authorized increase of 1.9% for Edison's higher operating and maintenance
expenses and capital-related costs. Retail rates account for over 98% of
electric revenue and are regulated by the CPUC. Wholesale rates are regulated
by the Federal Energy Regulatory Commission. Revenue from diversified
operations increased 62% in 1993 compared to 1992, mostly due to Mission
Energy's electric revenue from its Lakeland and Loy Yang B projects and Mission
Land's real estate rent and sales revenue.
The changes in electric revenue resulted from:
<TABLE>
<CAPTION>
Year ended December 31,
------------------------
In millions 1993 1992 1991
- ----------- ---- ---- ----
<S> <C> <C> <C>
Electric revenue--
Rate changes $(251) $170 $353
Sales volume changes (124) 270 (73)
Other 50 (16) 31
---- --- ---
Total $(325) $424 $311
===== ==== ====
</TABLE>
<PAGE> 3
22
Management's Discussion and Analysis: SCEcorp and Subsidiaries
Results of Operations
Operating Expenses
Fuel expense decreased minimally in 1993, due to a $44 million decrease
at Edison, partially offset by a $42 million increase at Mission Energy.
Edison's lower expense in 1993 was primarily due to an 11% decrease in power
generation, as the result of an increase in required purchases from nonutility
generators. Mission Energy's increase was related to its Lakeland and Loy Yang
B projects. Fuel expense was 18% higher in 1992, primarily due to Edison's
increased power generation compared to the previous year.
Purchased-power expense increased 11% in 1993 and 2% in 1992,
reflecting higher prices and an increased volume of federally required
purchases by Edison from nonutility generators. These purchases were made under
contracts with CPUC-mandated pricing. In 1993, these contracts cost about $800
million more than power available from other sources.
The provisions for regulatory adjustment clauses minimize rate
fluctuations by adjusting for differences between estimated and actual
kilowatt-hour sales or energy costs. These differences are accumulated in
balancing accounts for subsequent rate adjustment. Prior-period rate
adjustments are also reflected in these provisions. The 1993 and 1992 decreases
were mostly due to Edison's energy costs exceeding CPUC-authorized estimates.
The 1992 decrease was partially offset by kilowatt-hour sales exceeding
authorized estimates.
Other operating expenses increased 23% in 1993, primarily due to
Mission Energy's pretax charges of $28 million to terminate its investment in
Carbon II and $52 million to reflect the reduced value of its investments in
five geothermal projects. Additionally, Mission Land had increased costs
resulting from the sale of properties in Dallas and Chicago, the reduced value
of certain real estate projects and the related restructuring costs. In 1992,
other operating expenses increased 6%, reflecting Edison's authorized increases
in energy conservation programs and increased funding levels for postretirement
benefits other than pensions, and Mission Land's reserve for real estate
losses.
Depreciation and decommissioning expense increased 14% in 1993 compared
to 1992, mainly due to Edison's accelerated recovery of its investment in San
Onofre Nuclear Generating Station Unit 1.
Income taxes decreased 14% in 1993, mostly due to Mission Energy's
lower operating income resulting from the charges for its geothermal and Carbon
II projects.
Other Income and Deductions
The provision for rate phase-in plan reflects a CPUC-authorized,
10-year rate phase-in plan for the three Palo Verde Nuclear Generating Station
units. Phase-in plans minimize the effect on customer rates of placing newly
constructed plants in service by gradually implementing rate increases. Palo
Verde's plan deferred $200 million of revenue for each unit during the first
four years of operation. The deferred revenue, including interest, is being
collected evenly over six years ending in 1996 for Units 1 and 2, and in 1998
for Unit 3. The provision is a non-cash offset to the collection of deferred
revenue.
Other nonoperating income decreased 6% in 1993 and 34% in 1992,
reflecting a decrease in interest income due to lower interest rates and lower
balances in Edison's Palo Verde phase-in plan and balancing accounts. In
addition, Edison had a $40 million settlement of litigation in 1992 with Tucson
Electric. The case arose when San Diego Gas & Electric Company (SDG&E) withdrew
from its 1988 merger agreement with Tucson Electric and agreed to merge with
Edison. The CPUC later denied Edison's and SDG&E's merger application. Tucson
Electric had alleged that Edison wrongfully interfered with Tucson Electric's
and SDG&E's proposed merger.
Interest Expense
Interest on long-term debt increased in 1993, mainly due to more
long-term borrowings at Mission Energy related to two international projects,
Loy Yang B and Lakeland, partially offset by savings from Edison's $2 billion
refinancing program to take advantage of lower interest rates.
Other interest expense decreased 32% in 1993, primarily due to
regulatory balancing account adjustments for Edison's CPUC-approved
purchased-power settlement in 1992 and lower interest rates in 1993.
Capitalized interest increased in 1993 and in 1992, due to increased
construction activity at Mission Energy.
<PAGE> 4
23
Consolidated Statements of Income SCEcorp and Subsidiaries
<TABLE>
<CAPTION>
In millions, except
per-share amounts Year ended December 31, 1993 1992 1991
- ------------------- ----------------------- ---- ---- ----
<S> <C> <C> <C>
Electric revenue $7,397 $7,722 $7,298
Diversified operations 424 262 258
------ ------ ------
Total operating revenue 7,821 7,984 7,556
------ ------ ------
Fuel 834 836 709
Purchased power 2,499 2,251 2,203
Provisions for regulatory adjustment
clauses -- net (287) 340 384
Other operating expenses 1,588 1,294 1,215
Maintenance 363 362 383
Depreciation and decommissioning 922 807 767
Income taxes 465 544 453
Property and other taxes 220 207 203
------ ------ ------
Total operating expenses 6,604 6,641 6,317
------ ------ ------
Operating income 1,217 1,343 1,239
------ ------ ------
Provision for rate phase-in plan (137) (147) (82)
Allowance for equity funds used
during construction 20 20 16
Other nonoperating income -- net 87 93 141
------ ------ ------
Total other income (deductions) -- net (30) (34) 75
------ ------ ------
Income before interest and other expenses 1,187 1,309 1,314
------ ------ ------
Interest on long-term debt 528 477 491
Other interest expense 65 96 103
Allowance for borrowed funds used
during construction (16) (17) (12)
Capitalized interest (70) (28) (13)
Dividends on subsidiary preferred stock 41 42 42
------ ------ ------
Total interest and other expenses -- net 548 570 611
------ ------ ------
Net income $ 639 $ 739 $ 703
====== ====== ======
Weighted-average shares of common stock
outstanding 448 445 437
Earnings per share $1.43 $1.66 $1.61
</TABLE>
Consolidated Statements of Retained Earnings
<TABLE>
<CAPTION>
In millions, except
per-share amounts Year ended December 31, 1993 1992 1991
- ------------------- ----------------------- ---- ---- ----
<S> <C> <C> <C>
Balance at beginning of year $3,263 $3,150 $3,038
Net income 639 739 703
Dividends declared on common stock (636) (626) (591)
------ ------ ------
Balance at end of year $3,266 $3,263 $3,150
====== ====== ======
Dividends declared per common share $1.415 $1.39 $1.35
</TABLE>
The accompanying notes are an integral part of these financial
statements.
<PAGE> 5
24
Consolidated Balance Sheets
<TABLE>
<CAPTION>
In millions,
except share amounts December 31, 1993 1992
- -------------------- ------------ ---- ----
<S> <C> <C>
ASSETS
Utility plant, at original cost $18,436 $17,805
Less -- accumulated provision for
depreciation and decommissioning 7,138 6,544
------- -------
11,298 11,261
Construction work in progress 857 724
Nuclear fuel, at amortized cost 148 123
------- -------
Total utility plant 12,303 12,108
------- -------
Nonutility property -- less accumulated
provision for depreciation
of $73 and $50 at respective dates 1,276 1,024
Nuclear decommissioning trusts 789 648
Investments in partnerships and unconsolidated
subsidiaries 1,163 1,453
Investments in leveraged leases 497 462
Other investments 21 19
------- -------
Total other property and investments 3,746 3,606
------- -------
Cash and equivalents 421 496
Receivables, including unbilled revenue,
less allowances of $19 and $13
for uncollectible accounts at respective dates 880 876
Fuel inventory 121 108
Materials and supplies, at average cost 104 110
Accumulated deferred income taxes -- net 204 194
Prepayments and other current assets 118 201
------- -------
Total current assets 1,848 1,985
------- -------
Unamortized debt issuance and
reacquisition expense 382 301
Rate phase-in plan 364 488
Unamortized nuclear plant -- net 274 380
Income tax-related deferred charges 2,016 --
Other deferred charges 446 443
------- -------
Total deferred charges 3,482 1,612
------- -------
Total assets $21,379 $19,311
======= =======
</TABLE>
The accompanying notes are an integral part of these financial
statements.
<PAGE> 6
25
SCEcorp and Subsidiaries
<TABLE>
<CAPTION>
In millions, except share amounts December 31, 1993 1992
- --------------------------------- ------------ ---- ----
<S> <C> <C>
CAPITALIZATION AND LIABILITIES
Common shareholders' equity:
Common stock (447,799,172 and 447,736,054 shares
outstanding at respective dates) $ 2,692 $ 2,691
Retained earnings 3,266 3,263
------- -------
5,958 5,954
Preferred stock:
Not subject to mandatory redemption 359 359
Subject to mandatory redemption 275 278
Long-term debt 6,459 6,320
------- -------
Total capitalization 13,051 12,911
------- -------
Other long-term liabilities 267 342
------- -------
Current portion of long-term debt and redeemable
preferred stock 349 219
Short-term debt 655 758
Accounts payable 373 391
Accrued taxes 411 342
Accrued interest 101 120
Dividends payable 163 161
Regulatory balancing accounts -- net 58 88
Deferred unbilled revenue and other current liabilities 741 719
------- -------
Total current liabilities 2,851 2,798
------- -------
Accumulated deferred income taxes -- net 4,169 2,245
Accumulated deferred investment tax credits 456 462
Customer advances and other deferred credits 585 553
------- -------
Total deferred credits 5,210 3,260
------- -------
Commitments and contingencies (Notes 2, 8, 9 and 10)
Total capitalization and liabilities $21,379 $19,311
======= =======
</TABLE>
The accompanying notes are an integral part of these financial statements.
<PAGE> 7
26
Management's Discussion and Analysis: SCEcorp and Subsidiaries
Financial Condition
SCEcorp's liquidity is primarily affected by debt maturities, dividend
payments, and capital expenditures. Although SCEcorp is committed to a strong
dividend, recent CPUC decisions (see Regulatory Matters) may affect its ability
to raise or retain current dividend levels. Capital resources include cash from
operations and external financings.
Cash Flows from Operating Activities
Net cash provided by operating activities totaled approximately $2.0
billion per year in 1993, 1992 and 1991. SCEcorp continues to meet most of its
capital requirements with cash from operations.
Cash Flows from Financing Activities
Edison's short-term debt is used to finance fuel inventories, balancing
account undercollections and general cash requirements. The Mission companies'
short-term debt is used mainly for construction projects until long-term
construction or project loans are secured. Long-term debt is used mainly to
finance capital expenditures. Edison's external financings are influenced by
market conditions and other factors, including limitations imposed by its
articles of incorporation and trust indenture. As of December 31, 1993, Edison
could issue approximately $6.6 billion of additional first and refunding
mortgage bonds and $4.4 billion of preferred stock at current interest and
dividend rates.
SCEcorp has lines of credit of $1.7 billion -- $1.2 billion for
short-term debt and $500 million for the long-term refinancing of Edison's
variable-rate pollution-control bonds. Of the $1.2 billion for short-term debt,
the Mission companies have $600 million to finance general cash requirements.
Two credit rating agencies affirmed Edison's credit rating following
the CPUC's 1994 cost-of-capital proceedings (see Regulatory Matters). One of
these agencies also lowered Edison's commercial paper rating to be consistent
with the previous overall downgrade in November 1992, from double-A to
single-A-plus.
California law prohibits Edison from incurring or guaranteeing debt for
its nonutility affiliates. Additionally, the CPUC regulates Edison's capital
structure, limiting the dividends Edison may pay SCEcorp. These restrictions
are not expected to affect SCEcorp's ability to meet its cash obligations.
Cash Flows from Investing Activities
The primary uses of cash for investing activities are additions to
property and plant, Mission companies' investments and contributions to nuclear
decommissioning trusts. Cash used for the Mission companies' investing
activities was $289 million in 1993, $763 million in 1992 and $75 million in
1991. Edison contributes approximately $96 million per year to nuclear
decommissioning trusts. Trust contributions will continue until decommissioning
begins.
Projected Capital Requirements
SCEcorp's projected capital requirements for the years 1994 through
1998 are:
<TABLE>
<CAPTION>
In millions 1994 1995 1996 1997 1998
- ----------- ---- ---- ---- ---- ----
<S> <C> <C> <C> <C> <C>
Construction expenditures $1,305 $1,330 $1,156 $1,094 $1,349
Maturities of long-term debt 336 272 297 570 523
------ ------ ------ ------ ------
Total $1,641 $1,602 $1,453 $1,664 $1,872
====== ====== ====== ====== ======
</TABLE>
<PAGE> 8
27
Consolidated Statements of Cash Flows SCEcorp and Subsidiaries
<TABLE>
<CAPTION>
In millions Year ended December 31, 1993 1992 1991
- ----------- ----------------------- ------- ------- --------
<S> <C> <C> <C>
Cash flows from operating activities:
Net income $ 639 $ 739 $ 703
Adjustments for noncash items:
Depreciation and decommissioning 922 807 767
Amortization 107 150 166
Rate phase-in plan 123 125 43
Deferred income taxes and investment tax credits 95 32 103
Equity in income from partnerships and
unconsolidated subsidiaries (135) (148) (140)
Other long-term liabilities (75) 36 146
Nonrecurring charges 99 -- 79
Other -- net 10 26 21
Changes in working capital components:
Receivables 56 (17) (73)
Regulatory balancing accounts (30) 246 68
Fuel inventory, materials and supplies (7) 58 10
Prepayments and other current assets 115 (30) (73)
Accrued interest and taxes (160) (62) (25)
Accounts payable and other current liabilities (29) (118) 16
Distributions from partnerships and
unconsolidated subsidiaries 271 124 149
------- ------- -------
Net cash provided by operating activities 2,001 1,968 1,960
------- ------- -------
Cash flows from financing activities:
Issuances of long-term debt 2,496 1,611 819
Issuances of preferred stock 75 296 --
Repayment of long-term debt (2,291) (1,332) (363)
Redemption of preferred stock (86) (232) (12)
Nuclear fuel financing -- net 8 (126) 23
Proceeds from sales of common stock 1 160 67
Short-term debt financings -- net (167) (36) (558)
Dividends paid (631) (614) (586)
------- ------- -------
Net cash used by financing activities (595) (273) (610)
------- ------- -------
Cash flows from investing activities:
Additions to property and plant (1,259) (1,241) (1,033)
Nuclear decommissioning trusts (141) (132) (131)
Investments in partnerships and
unconsolidated subsidiaries (14) (257) (238)
Other -- net (67) (48) 48
------- ------- -------
Net cash used by investing activities (1,481) (1,678) (1,354)
------- ------- -------
Net increase (decrease) in cash and equivalents (75) 17 (4)
Cash and equivalents, beginning of year 496 479 483
------- ------- -------
Cash and equivalents, end of year $ 421 $ 496 $ 479
======= ======= =======
Cash payments for interest and taxes:
Interest $ 468 $ 459 $ 520
Taxes 415 457 380
Noncash investing and financing activities:
Obligation to fund investment in partnerships
and unconsolidated subsidiaries 118 69 102
</TABLE>
The accompanying notes are an integral part of these financial statements.
<PAGE> 9
28
Management's Discussion and Analysis SCEcorp and Subsidiaries
Regulatory Matters
The CPUC increased Edison's authorized revenue by $232 million, or
3.2%, for 1994. The increase includes a $275 million increase for fuel and
related costs and an $82 million increase for higher operating costs, partially
offset by a $108 million decrease for the lower costs of debt and equity.
In its 1994 cost-of-capital decision, the CPUC approved Edison's
request to increase its equity ratio from 46% to 47.25%. The increase reflects
the CPUC's recognition of Edison's need to reduce debt to levels more in line
with other utilities and the competitive environment. The CPUC also authorized
Edison an 11.0% return on common equity for 1994. Authorized return on common
equity was 11.8% for 1993 and 12.65% for 1992. This decision is expected to
reduce 1994 earnings by approximately 6 cents per share.
The CPUC is reviewing Edison's costs (approximately $90 million)
related to a 1985 steam-pipe rupture at the Mohave Generating Station. A
December 1993 proposed decision, issued by a CPUC administrative law judge,
recommended disallowance of all accident-related expenditures. A final CPUC
decision, expected in 1994, may accept or modify the proposed decision. If
accepted, a second phase of this proceeding will quantify the disallowance.
Edison maintains the accident was caused by a manufacturing defect in a seam
weld and filed comments on January 20, 1994, contesting the proposed decision.
The probable effect on net income cannot be determined at this time, but
SCEcorp believes it will not materially affect its financial position.
The CPUC is also reviewing extended outages at Palo Verde. The CPUC's
Division of Ratepayer Advocates (DRA) initially recommended a disallowance
valued at $169 million. In September 1993, Edison and the DRA agreed to settle
these disputes for $38 million, subject to CPUC approval. The effect of the
settlement has been fully reflected in the financial statements. A CPUC
decision is expected in early 1994.
In its 1995 general rate case filing, Edison requested a $117 million
revenue increase to recover the higher costs of operations (excluding fuel)
resulting from inflation and new capital investments. This increase, adjusted
for inflation, represents a 7.2% reduction from Edison's 1992 authorized
revenue. In addition, Edison filed a proposal for a performance-based
rate-making mechanism that would determine most of Edison's revenue (excluding
fuel) from 1995-2000 (see Competitive Environment). Hearings on both matters
will be conducted in 1994 with implementation, if approved, in January 1995.
Environmental Protection
Costs to protect the environment continue to grow due to increasingly
stringent laws and regulations.
SCEcorp has identified 46 sites for which it is, or may be, responsible
for remediation under environmental laws. SCEcorp is participating in
investigations and cleanups at a number of these sites and has recorded a $60
million liability for its estimated minimum costs to clean up several sites.
Additional costs may be incurred as progress is made in determining the
magnitude of required remedial actions, as SCEcorp's share of these costs in
proportion to other responsible parties is determined, and as additional
investigations and cleanups are performed. The CPUC currently allows Edison
rate recovery of environmental-cleanup costs after reasonableness reviews.
However, in a recent decision, the CPUC concluded that this procedure may not
be appropriate and requested interested parties to recommend alternatives. In
late 1993, the major California utilities, the DRA and others recommended an
incentive mechanism for these costs, where shareholders would fund 10% of
cleanup costs, with the opportunity to recover these costs through insurance.
Accordingly, Edison has recorded a regulatory asset representing 90% of the
estimated cleanup costs. A final CPUC decision is expected in early 1994.
The 1990 federal Clean Air Act requires power producers to have
emissions allowances to emit sulfur dioxide. Power companies receive emissions
allowances from the federal government and may bank or sell excess allowances.
Edison expects to have excess allowances under Phase II of the Clean Air Act
(2000 and later). The act also calls for a five-year study of regional haze in
the southwestern U.S. In addition, the U.S. Environmental Protection Agency is
conducting a study of the effect of air contaminant emissions on visibility in
Grand Canyon National Park. The potential effect of these studies on sulfur
dioxide emissions regulations for the Mohave Coal Generating Station is
unknown.
Edison's projected capital expenditures to protect the environment are
$1.2 billion for the 1994-1998 period, mainly for placing overhead distribution
lines underground and reducing nitrogen-oxides emissions from
<PAGE> 10
gas-fired electric generators. Local regulations may lower Edison's projected
capital expenditures (up to $330 million by 1998) to reduce nitrogen-oxides
emissions.
The possibility that exposure to electric and magnetic fields (EMF)
emanating from power lines, household appliances and other electric sources may
result in adverse health effects has received increased attention. The
scientific community has not yet reached a consensus on the nature of any
health effects of EMF. However, an administrative law judge's proposed decision
provides for a rate-recoverable research and public education program conducted
by California electric utilities, and authorizes these utilities to take
no-cost or low-cost steps to reduce EMF in new electric facilities. Edison is
unable to predict when or if the scientific com-
<PAGE> 11
29
SCEcorp and Subsidiaries
munity will be able to reach a consensus on any health effects of EMF,
or the effect that such a consensus, if reached, could have on future electric
operations.
The probable effect on net income of these environmental protection
matters cannot be determined at this time, but SCEcorp believes it will not
materially affect its financial position.
Competitive Environment
Electric utilities have historically operated in a highly regulated
environment that provides limited opportunities for direct competition in
providing electric service to their customers. This regulatory environment is
being challenged and Edison expects even greater competition in the generation
sector of its business in the next decade. The Energy Policy Act of 1992
assures that all power producers have access to transmission service for
wholesale transactions between utility and nonutility generators. Some parties
are seeking additional deregulation of power markets to obtain direct access to
utility customers who are the ultimate users of the energy. This is referred to
as "retail wheeling," which Edison opposes because it would adversely affect
most existing utility customers and would not contribute to economic
efficiency.
Due to this changing regulatory environment, Edison has requested a
performance-based rate-making mechanism (see Regulatory Matters). The filing
asks for a revenue-indexing formula that combines operating expenses and
capital-related costs into a single index. This is a departure from the
traditional utility model that links earnings with capital investment, and will
more efficiently utilize monetary resources and will allow for the sharing of
some cost savings between customers and shareholders. Edison will continue to
focus on increased productivity to further reduce its cost base.
Mission Energy Company, one of the nation's largest independent power
producers, is well positioned to take advantage of the changing regulatory
environment for electric power. Further, international markets present an even
greater opportunity for growth and earnings. Mission Energy currently owns
1,862 megawatts of generating capacity, enough power to serve a population of
over one million.
New Accounting Standards
In January 1993, SCEcorp adopted a new income tax accounting standard.
This standard requires the balance sheet method to account for income taxes,
where deferred taxes are recognized for all temporary differences between book
and tax income. Upon adoption, Edison recorded balance sheet adjustments of
$2.1 billion for previously unrecorded deferred taxes on temporary differences,
including the effect of the 1993 tax rate change. Substantially all of these
deferred taxes were offset by deferred charges representing amounts expected to
be recovered in future rates. The cumulative effect of adoption increased
SCEcorp's 1993 earnings by $16 million.
In January 1993, SCEcorp also adopted a new accounting standard for
postretirement benefits other than pensions, which requires the expected cost
of these benefits to be charged to expense during employees' years of service.
Previously, the costs of these benefits were recognized as expense when paid or
funded. SCEcorp will amortize its $728 million obligation related to prior
service over 20 years. The CPUC allows Edison to recover tax-deductible funding
for these benefits in rates. Any difference between expense determined under
the new standard and amounts authorized for rate recovery is not expected to be
material and will be charged to earnings.
<PAGE> 12
30
Notes to Consolidated Financial Statements SCEcorp and Subsidiaries
Note 1. Summary of Significant Accounting Policies
The consolidated financial statements include SCEcorp and its
subsidiaries: Southern California Edison Company, a rate-regulated electric
utility; and the Mission companies, SCEcorp's nonutility subsidiaries. SCEcorp
uses the equity method to account for significant investments in partnerships
and subsidiaries in which it owns 50% or less. Intercompany transactions have
been eliminated, except Mission Energy Company's profits from energy sales to
Edison, which are allowed in utility rates.
Edison's accounting policies conform with generally accepted accounting
principles for regulated enterprises and reflect the rate-making policies of
the California Public Utilities Commission (CPUC) and the Federal Energy
Regulatory Commission.
Certain prior-year reclassifications have been made to conform to the
December 31, 1993, financial statement presentation.
Cash Equivalents
Cash equivalents include temporary investments with original maturities
of three months or less. Due to their short maturities, reported amounts
approximate fair value.
Construction Financing Costs
Allowance for funds used during construction (AFUDC) represents the
estimated cost of debt and equity funds that finance utility-plant
construction. AFUDC is capitalized as a cost of utility plant and reported in
current earnings. AFUDC is recovered in rates through depreciation when
completed projects are placed into commercial operation.
Debt Issuance and Reacquisition Expense
Debt premium, discount and issuance expenses are amortized over the
life of each issue. Debt reacquisition expenses are amortized over the
remaining life of the reacquired debt or, if refinanced, the life of the new
debt.
Depreciation and Decommissioning
Depreciation of utility plant is computed on a straight-line,
remaining-life basis. Depreciation of nonutility properties is computed on a
straight-line basis over their estimated useful lives.
Decommissioning of Edison's nuclear generating facilities will cost an
estimated $1.0 billion in current-year dollars. Decommissioning costs are
accrued and recovered in rates over the life of the facility through charges to
depreciation expense ($141 million in 1993). The accumulated balance of these
costs ($797 million at December 31, 1993) approximates amounts funded, which
are held in trusts until decommissioning begins. Funded amounts are invested in
high-grade securities and reported at the lower of cost or market value. The
market value of the trusts was $853 million and $683 million at December 31,
1993, and 1992, respectively (based on quoted market prices). Earnings on these
funds are included in other income. Approximately 86% of the trust fund
contributions were tax-deductible.
Edison expects to decommission its facilities by prompt removal or
decontamination at the end of their useful lives. Decommissioning at Palo Verde
Nuclear Generating Station is scheduled to begin in 2024. Decommissioning at
San Onofre Nuclear Generating Station is scheduled to begin in 2013. San Onofre
Unit 1, which shut down in 1992, will be stored until decommissioning begins at
the other San Onofre units. The estimated current-dollar decommissioning costs
for Unit 1 have been recorded as a liability.
Under the Energy Policy Act of 1992, Edison is liable for its share of
the estimated costs to decommission three federal nuclear enrichment
facilities. Edison's share is based on the number of nuclear enrichment units
purchased, and will be paid over 15 years. These costs are fully recoverable
through rates. The fair value of this obligation was $59 million and $58
million at December 31, 1993, and 1992, respectively (estimated by discounting
future cash flows).
Nuclear Fuel
The cost of nuclear fuel, including disposal, is amortized to fuel
expense on the basis of generation. Under CPUC rate-making procedures,
nuclear-fuel financing costs are capitalized until the fuel is placed into
production.
<PAGE> 13
Rate Phase-In Plan
Collection of $200 million in revenue for each unit at Palo Verde was
deferred during the first four years of operation, under a CPUC-authorized rate
phase-in plan. The deferred revenue (including interest) is collected evenly
over the final six years of each unit's plan. The plans end in 1996 for Units 1
and 2, and in 1998 for Unit 3.
Regulatory Balancing Accounts
The differences between CPUC-authorized and actual kilowatt-hour sales
or energy costs are accumulated in balancing accounts until they are refunded
to, or recovered from, utility customers through authorized rate adjustments
(with interest). Income tax effects on balancing account changes are deferred.
CPUC-established target generation levels act as performance incentives
for Edison's nuclear generating stations. Fuel savings or costs above or below
these targets are shared equally by Edison and its customers through balancing
account adjustments.
Research, Development and Demonstration (RD&D)
Edison charges RD&D costs to expense unless they are expected to result
in plant construction. If construction does not result, any capitalized costs
are subsequently charged to expense. RD&D expenses are recorded in a balancing
account. At the end of the rate-case cycle, authorized but unspent RD&D funds
are refunded to customers. Edison's RD&D expenses were $49 million in 1993, $40
million in 1992 and $49 million in 1991.
Revenue
Electric revenue includes amounts for services rendered but unbilled at
the end of each year.
San Onofre Unit 1
In November 1992, Edison discontinued operation of San Onofre Unit 1.
Edison will recover its investment, plus an 8.98% rate of return, by mid-1996.
<PAGE> 14
31
Utility Plant
Plant additions, including replacements and betterments, are
capitalized. Such costs include direct material and labor, construction
overhead and AFUDC. Replaced or retired property and removal costs -- less
salvage -- are charged to the accumulated provision for depreciation.
Note 2. Regulatory Matters
Mohave Outage Review
In 1986, the CPUC began investigating a 1985 steam-pipe rupture at the
Mohave Generating Station. Edison, plant operator and 56% owner, incurred costs
of approximately $90 million, after insurance recoveries, to repair damage and
provide replacement power during the six-month outage. In 1991, the CPUC's
Division of Ratepayer Advocates (DRA) alleged that Edison contributed to the
piping failure by imprudently operating the plant and recommended the
disallowance of all accident-related expenditures. A December 1993 proposed
decision issued by a CPUC administrative law judge agreed with the DRA's
allegations. The final decision by the CPUC, expected in 1994, may accept or
modify the proposed decision. If accepted, a second phase of this proceeding
will quantify the disallowance.
Edison maintains the accident was caused by a manufacturing defect in a
seam weld and filed comments on January 20, 1994, contesting the proposed
decision. The probable effect on net income cannot be determined at this time,
but SCEcorp believes it will not materially affect its financial position.
Palo Verde Outage Review
In March 1989, Arizona Public Service Company, operating agent for Palo
Verde, removed Units 1 and 3 from service for modifications required by
regulatory agencies. As required by state law, the CPUC conducted an
investigation, and ordered the authorized revenue collected during the outages
be subject to refund. The units resumed operation in December 1989 and July
1990.
During 1992, the CPUC consolidated its reasonableness review of
replacement power costs from several Unit 2 outages in 1989 and 1990 with the
investigation of Units 1 and 3. The DRA initially recommended a disallowance
valued at $169 million, including: $63 million of revenue collected during the
outages (including interest); $5 million for capital projects deemed
unnecessary; $50 million in replacement power costs; and $51 million in
penalties for environmental effects of replacement power and the outages'
effect on the regional energy market. Edison filed testimony that its costs
were reasonably incurred.
In September 1993, Edison and the DRA agreed to settle these disputes
for $38 million (including $29 million for replacement power costs, $2 million
for capital projects and $7 million for interest), subject to CPUC approval.
The effect of the settlement has been fully reflected in the financial
statements. A CPUC decision is expected in early 1994.
RD&D Cost Review
In Edison's 1992 general rate case, the CPUC deferred a decision
(pending additional information from Edison) on the recovery of $56 million in
capitalized RD&D costs. Edison refiled, requesting that $35 million be included
in rate base and $17 million be classified as RD&D expense. Subsequently,
additional adjustments of $11 million were recorded. In August 1993, the DRA
filed its position on Edison's RD&D capital refiling, recommending further
disallowances of about $15 million. Edison is contesting the DRA's
recommendation. A CPUC decision is expected in early 1994. The probable effect
on net income cannot be determined at this time, but SCEcorp believes it will
not materially affect its results of operations or financial position.
Resale Rates
Resale revenue related to pending rate proceedings is subject to refund
with interest if subsequently disallowed by the Federal Energy Regulatory
Commission. SCEcorp believes any refunds from pending rate proceedings will not
materially affect its results of operations or financial position.
Note 3. Debt
Long-Term Debt
California law prohibits Edison from incurring or guaranteeing debt for
its nonutility affiliates.
Almost all Edison properties are subject to a trust indenture lien.
Edison has pledged first and refunding mortgage bonds as security for
borrowed funds obtained from pollution-control bonds issued by government
agencies. Edison uses these proceeds to finance construction of
<PAGE> 15
pollution-control facilities. Bondholders have limited discretion in
redeeming certain pollution-control bonds, and Edison has arranged with
securities dealers to remarket or purchase them in such cases.
SCEcorp had interest-rate swap and cap agreements to reduce the effect
of changes in interest rates on $959 million and $400 million of its debt at
December 31, 1993, and 1992, respectively. The fair value of the agreements
(the cost to terminate them) was estimated at $64 million and $28 million, at
December 31, 1993, and 1992, respectively (based on brokers' quotes). SCEcorp
has entered into foreign exchange contracts as a hedge against foreign currency
fluctuations. SCEcorp is exposed to credit loss from nonperformance by
counterparties to these agreements, but does not anticipate such
nonperformance.
A portion of commercial paper has been classified as long-term debt
based on the loan and credit agreement with the issuing bank. Commercial paper
that finances nuclear fuel scheduled to be used more than one year after the
balance sheet date is classified as long-term debt.
<PAGE> 16
32
Notes to Consolidated Financial Statements
Long-term debt maturities and sinking-fund requirements for the next
five years are: 1994 -- $336 million; 1995 -- $272 million; 1996 -- $297
million; 1997 -- $570 million; and 1998 -- $523 million.
Long-term debt consisted of:
<TABLE>
<CAPTION>
December 31,
--------------
In millions 1993 1992
- ----------- ---- ----
<S> <C> <C>
First and refunding mortgage bonds:
1994-1997 (5.55% to 6.125%) $ 700 $1,050
1998-2002 (5.45% to 7.5%) 725 650
2003-2026 (5.875% to 10%) 2,118 2,025
Pollution-control bonds:
1999-2027 (5.585% to 7.2% and variable) 1,208 1,209
Funds held by trustees (2) (2)
Debentures and notes:
1994-2017 (4.875% to 10.364% and variable) 1,758 1,259
Commercial paper 252 245
Spent nuclear fuel obligation -- 6
Capital lease obligation 128 153
Current portion of capital lease obligation (13) (19)
Long-term debt due within one year (336) (195)
Unamortized debt discount -- net (79) (61)
------ ------
Total $6,459 $6,320
====== ======
Fair value $6,915 $6,682
====== ======
</TABLE>
The fair value estimates were based on brokers' quotes.
Short-Term Debt
SCEcorp has lines of credit it can use at negotiated or bank index
rates. At December 31, 1993, such lines totaled $1.7 billion, with $1.2 billion
supporting commercial paper and other short-term debt. The remaining $500
million is available for the long-term refinancing of certain variable-rate
pollution-control debt.
Short-term debt consisted of:
<TABLE>
<CAPTION>
December 31,
--------------
In millions 1993 1992
- ----------- ---- ----
<S> <C> <C>
Commercial paper:
Balancing accounts $ 163 $ 247
Fuel 270 228
General purpose 434 466
Other short-term debt 42 64
Amount reclassified as long-term (252) (245)
Unamortized debt discount (2) (2)
----- -----
Total $ 655 $ 758
===== =====
</TABLE>
Due to these instruments' short maturities, reported amounts
approximate fair value.
Note 4. Equity
The CPUC regulates Edison's capital structure, limiting the dividends
Edison may pay SCEcorp. SCEcorp does not expect this restriction to affect its
ability to meet its cash obligations.
All share data have been restated to reflect the two-for-one common
stock split effective June 1, 1993.
Authorized common stock is 800 million shares with no par value.
SCEcorp issued 63,118 ($1 million), 7,830,014 ($160 million) and
2,957,176 ($67 million) shares of common stock in 1993, 1992 and 1991,
respectively.
Edison's authorized shares of preferred and preference stock are: $25
cumulative preferred -- 24 million; $100 cumulative preferred -- 12 million;
and preference -- 50 million. All cumulative preferred stocks are redeemable.
Mandatorily redeemable preferred stocks are subject to sinking-fund provisions.
When preferred shares are redeemed, the premiums paid are charged to common
equity. There are no preferred stock redemption requirements for the next five
years. The fair value estimates of Edison's preferred stock subject to
mandatory redemption were based on brokers' quotes.
<PAGE> 17
Edison's cumulative preferred stock consisted of:
<TABLE>
<CAPTION>
December 31,
------------
Dollars in millions, except per-share amounts 1993 1992
- --------------------------------------------- ---- ----
December 31, 1993
------------------------
Shares Redemption
Outstanding Price
----------- ----------
Not subject to mandatory redemption:
$25 par value:
<S> <C> <C> <C> <C>
4.08% Series 1,000,000 $25.50 $25 $25
4.24 1,200,000 25.80 30 30
4.32 1,653,429 28.75 41 41
4.78 1,296,769 25.80 33 33
5.80 2,200,000 25.25 55 55
7.36 4,000,000 25.00 100 100
$100 par value:
7.58% Series 750,000 101.00 75 75
---- ----
Total $359 $359
==== ====
Subject to mandatory redemption:
$100 par value:
6.05% Series 750,000 $100.00 $ 75 $ --
6.45 1,000,000 100.00 100 100
7.23 1,000,000 100.00 100 100
7.325 -- -- -- 42
7.80 -- -- -- 41
Preferred stock to be redeemed
within one year -- (5)
---- ----
Total $275 $278
==== ====
Fair value of preferred stock
subject to mandatory redemption $291 $288
==== ====
</TABLE>
<PAGE> 18
33
Changes in Edison's preferred stocks were:
<TABLE>
<CAPTION>
Year ended December 31,
---------------------------
In thousands of shares 1993 1992 1991
- ---------------------- ---- ---- ----
<S> <C> <C> <C>
Series:
6.05% 750 -- --
6.45 -- 1,000 --
7.23 -- 1,000 --
7.325 (427) (30) (30)
7.36 -- 4,000 --
7.80 (411) (18) (18)
8.54 -- (547) (22)
8.70 -- (500) --
8.70A -- (394) (13)
8.96 -- (500) --
12.31 -- (277) (34)
---- ----- ----
Net issuances (redemptions) (88) 3,734 (117)
==== ===== ====
</TABLE>
Note 5. Income Taxes
SCEcorp's subsidiaries will be included in its consolidated federal
income tax and combined state franchise tax returns. Under income tax allocation
agreements, each subsidiary calculates its own tax liability.
Change in Accounting Principle
In January 1993, SCEcorp adopted a new income tax accounting standard.
This standard requires the balance sheet method to account for income taxes,
where deferred taxes are recognized for all temporary differences between book
and tax income. Prior-year financial statements have not been restated; they
reflect income taxes accounted for under the income statement method.
Upon adoption of the standard, Edison recorded balance sheet adjustments
of $2.1 billion for previously unrecorded deferred taxes on temporary
differences, including the effects of the 1993 tax rate change. Substantially
all of these deferred taxes were offset by deferred charges representing amounts
expected to be recovered in future rates. The cumulative effect of adoption
increased SCEcorp's 1993 earnings by $16 million.
Current and Deferred Taxes
Income tax expense includes the current tax liability from operations
and the change in deferred income taxes during the year. Investment tax credits
are amortized over the lives of the related properties.
The components of the net accumulated deferred income tax liability
were:
<TABLE>
<CAPTION>
December 31, January 1,
In millions 1993 1993
- ----------- ------------ ----------
<S> <C> <C>
Deferred tax assets:
Depreciation $ 240 $ 61
Investment tax credits 317 297
Regulatory balancing accounts 171 89
Other 590 606
------ ------
Total $1,318 $1,053
------ ------
Deferred tax liabilities:
Depreciation $2,842 $2,731
Property-related 1,404 1,476
Leveraged leases 401 336
Other 636 495
------ ------
Total $5,283 $5,038
------ ------
Accumulated deferred income taxes -- net $3,965 $3,985
====== ======
Classification of accumulated deferred income taxes:
Included in deferred credits $4,169 $4,219
Included in current assets 204 234
====== ======
</TABLE>
<PAGE> 19
The current and deferred components of income tax expense were:
<TABLE>
<CAPTION>
Year ended December 31,
-----------------------
In millions 1993 1992 1991
- ----------- ---- ---- ----
<S> <C> <C> <C>
Current:
Federal $ 183 $ 324 $219
State 75 110 114
----- ----- ----
258 434 333
----- ----- ----
Deferred -- federal and state:
Accrued charges (38) (8) (82)
Deferred alternative minimum tax credit (46) -- --
Depreciation 78 150 163
Investment and energy tax credits -- net (31) (30) (33)
Leveraged leases 63 93 77
Nonutility special charges (49) (6) --
Rate phase-in plan (51) (50) (17)
Regulatory balancing accounts 118 (121) (27)
Resale revenue 26 34 22
Retirement of debt 33 (5) 3
Other (7) (25) (3)
----- ----- ----
96 32 103
----- ----- ----
Total income tax expense $ 354 $ 466 $436
===== ===== ====
Classification of income taxes:
Included in operating income $ 465 $ 544 $453
Included in other income (111) (78) (17)
===== ===== ====
</TABLE>
The composite federal and state statutory income tax rate was 41.045%
for 1993 and 40.138% for 1992 and 1991.
<PAGE> 20
34
Notes to Consolidated Financial Statements
A reconciliation of the federal statutory income tax rate to the
effective rate is presented below:
<TABLE>
<CAPTION>
Year ended December 31,
-----------------------
1993 1992 1991
---- ---- ----
<S> <C> <C> <C>
Federal statutory rate 35.0% 34.0% 34.0%
Depreciation and related timing differences not deferred 6.1 3.0 4.3
Capitalized software (2.0) 0.3 --
Housing credits (1.8) (0.7) (0.7)
Investment and energy tax credits (3.1) (2.5) (3.6)
Merger expenses -- -- (2.1)
New accounting standard (1.9) -- --
State tax -- net of federal deduction 5.4 4.3 5.7
Other (2.1) 0.3 0.7
---- ---- ----
Effective tax rate 35.6% 38.7% 38.3%
==== ==== ====
</TABLE>
Note 6. Employee Benefit Plans
Pension Plan
SCEcorp has a noncontributory, defined-benefit pension plan,
administered by a trustee, that covers employees meeting minimum service
requirements. Benefits are based on years of accredited service and average
base pay. SCEcorp funds the plan on a level-premium actuarial method. Annual
contributions meet minimum legal funding requirements and do not exceed the
maximum amounts deductible for income taxes. Prior service costs from pension
plan amendments are funded over 30 years. Plan assets are primarily common
stocks, corporate and government bonds, and short-term investments.
Net pension cost recognized is calculated under the actuarial method
used for ratemaking. The difference between pension costs calculated for
accounting and ratemaking is deferred.
The plan's funded status was:
<TABLE>
<CAPTION>
December 31,
----------------
In millions 1993 1992
- ----------- ---- ----
<S> <C> <C>
Actuarial present value of benefit obligations:
Vested benefits $1,343 $1,438
Nonvested benefits 166 38
------ ------
Accumulated benefit obligation 1,509 1,476
Value of projected future compensation levels 558 494
------ ------
Projected benefit obligation $2,067 $1,970
====== ======
Plan assets at fair value $2,205 $1,947
====== ======
Projected benefit obligation in excess of
(less than) plan assets $(138) $23
Unrecognized net gain 249 83
Unrecognized prior service cost (5) (6)
Unrecognized net obligation being amortized
over 17 years (62) (67)
------ ------
Accrued pension liability $ 44 $ 33
====== ======
Discount rate 7.25% 7.0%
Rate of increase in future compensation 5.0% 5.0%
Expected long-term rate of return on assets 8.0% 8.0%
</TABLE>
<PAGE> 21
The components of pension expense were:
<TABLE>
<CAPTION>
Year ended December 31,
-----------------------
In millions 1993 1992 1991
- ----------- ---- ---- ----
<S> <C> <C> <C>
Net pension expense:
Service cost for benefits earned $ 70 $ 55 $ 53
Interest cost on projected benefit obligation 139 127 126
Actual return on plan assets (291) (86) (375)
Net amortization and deferral 142 (62) 251
----- ---- -----
Pension expense under accounting standards 60 34 55
Regulatory adjustment (11) 14 (7)
----- ---- -----
Net pension expense recognized $ 49 $ 48 $ 48
===== ==== =====
</TABLE>
Postretirement Benefits Other Than Pensions
Employees retiring at or after age 55, who have at least 10 years of
service, are eligible for postretirement health care, dental, life insurance
and other benefits. Health care benefits are subject to deductibles, copayment
provisions and other limitations.
In January 1993, SCEcorp adopted a new accounting standard for
postretirement benefits other than pensions, which requires the expected cost
of these benefits to be charged to expense during employees' years of service.
SCEcorp will amortize its $728 million obligation related to prior service over
20 years.
Edison funds the plan up to tax-deductible limits, in accordance with
rate-making practices. Edison began funding its future liability for these
benefits in 1991. Amounts funded prior to 1993 are amortized to expense and
recovered in rates over 12 months. Total expense was $165 million in 1993, $85
million in 1992 and $26 million in 1991. Any difference between expense
determined under the new standard and amounts authorized for rate recovery is
not expected to be material and will be charged to earnings. Plan assets are
primarily common stocks, corporate and government bonds, and short-term
investments.
The components of postretirement benefits other than pensions expense
were:
<TABLE>
<CAPTION>
In millions Year ended December 31,
- ----------- -----------------------
1993
----
<S> <C>
Service cost for benefits earned $ 27
Interest cost on projected benefit obligation 66
Actual return on plan assets (12)
Amortization of transition obligation 36
----
Net expense 117
Amortization of prior funding 48
----
Total expense $165
====
</TABLE>
<PAGE> 22
35
A reconciliation of the plan's funded status with the recorded
liability is presented below:
<TABLE>
<CAPTION>
December 31, January 1,
In millions 1993 1993
- ----------- ------------ ---------
<S> <C> <C>
Actuarial present value of benefit obligation:
Retirees $ 512 $ 482
Employees eligible to retire 87 75
Other employees 363 287
----- -----
Accumulated benefit obligation $ 962 $ 844
===== =====
Plan assets at fair value $ 210 $ 116
===== =====
Accumulated benefit obligation in excess
of plan assets $ 752 $ 728
Unrecognized transition obligation (693) (728)
Unrecognized net loss (59) --
----- -----
Recorded liability -- --
====== =====
</TABLE>
The assumed rate of future increases in the per-capita cost of health
care benefits is 12% for 1994, gradually decreasing to 5% for 2004 and beyond.
Increasing the health care cost trend rate by one percentage point would
increase the accumulated obligation as of December 31, 1993, by $134 million and
annual aggregate service and interest costs by $19 million. The actuarial
assumptions used were discount rates of 7.75% and 8.0% at December 31, 1993, and
January 1, 1993, respectively, and an expected long-term rate of return on plan
assets of 8.5% at both dates.
Stock Plans
SCEcorp has two stock plans designed to supplement employees' retirement
income. The Employee Stock Ownership Plan was funded primarily by employees and
federal income tax benefits. This plan will be transferred to the Stock Savings
Plus Plan by the end of 1994. The Stock Savings Plus Plan received Edison
contributions of $21 million in 1993, $20 million in 1992 and $18 million in
1991.
Under SCEcorp's long-term incentive compensation plan, 8.0 million
shares and 8.1 million shares of SCEcorp common stock were reserved at December
31, 1993, and 1992, respectively, for issue to key employees in various forms,
including the exercise of stock options. There were 6.5 million shares and 7.0
million shares reserved for future grants at December 31, 1993, and 1992,
respectively. Under SCEcorp's stock option plan, share options accrue dividend
equivalents at the same rate as outstanding common stock. The dividend
equivalents may be applied against the grant price at the time of exercise.
Activity in the stock option plan was:
<TABLE>
<CAPTION>
Share Options Share Price
<S> <C> <C>
Outstanding, December 31, 1991 823,570 $16.00-$20.10
Granted 395,400 20.66- 23.28
Canceled (82,150) 18.75- 23.28
Exercised (41,416) 16.19- 19.85
--------- -------------
Outstanding, December 31, 1992 1,095,404 16.00- 23.28
Granted 402,600 21.94- 24.44
Canceled (44,252) 18.75- 23.28
Exercised (63,118) 16.19- 23.28
--------- -------------
Outstanding, December 31, 1993 1,390,634 16.00- 24.44
Exercisable, December 31, 1993 778,530 16.00- 24.44
</TABLE>
Note 7. Jointly Owned Utility Projects
Edison owns interests in several generating stations and transmission
systems for which each participant provides its own financing.
The proportionate share of expenses for each project is included in the
consolidated statements of income.
<PAGE> 23
The investment in each project, as included in the consolidated balance
sheet as of December 31, 1993, was:
<TABLE>
<CAPTION>
Plant in Accumulated Under Ownership
In millions Service Depreciation Construction Interest
- ----------- -------- ------------ ------------ -------
<S> <C> <C> <C> <C>
Eldorado Transmission System $ 27 $ 11 $ 1 60%
Four Corners Coal Generating Station--Units 4 and 5 448 217 5 48
Mohave Coal Generating Station 274 138 10 56
Pacific Intertie Transmission System 213 60 1 50
Palo Verde Nuclear Generating Station 1,541 279 27 16
San Onofre Nuclear Generating Station 4,047 1,269 74 75
------ ------ ---- ---
Total $6,550 $1,974 $118 --
====== ====== ==== ===
</TABLE>
<PAGE> 24
36
Notes to Consolidated Financial Statements
Note 8. Leases
Investments in Leveraged Leases
Mission First Financial is the lessor in several leveraged-lease
agreements with terms of 13 to 30 years. All operating, maintenance, insurance
and decommissioning costs are the responsibility of the lessees. The total cost
of these facilities was $1.5 billion and $1.4 billion at December 31, 1993, and
1992, respectively.
The equity investment in these facilities is 21% of the purchase price.
The remainder is nonrecourse debt secured by first liens on the leased
property. The lenders have accepted their security interests as their only
remedy if the lessee defaults.
The net investment in leveraged leases consisted of:
<TABLE>
<CAPTION>
December 31,
---------------
In millions 1993 1992
- ----------- ---- ----
<S> <C> <C>
Rentals receivable (net of principal and
interest on nonrecourse debt) $ 710 $ 687
Unearned income (256) (261)
----- -----
Investment in leveraged leases 454 426
Estimated residual value 44 36
Deferred income taxes (401) (338)
----- -----
Net investment in leveraged leases $ 97 $ 124
===== =====
</TABLE>
Lease Commitments
SCEcorp has operating leases, primarily for vehicles (with varying
terms, provisions and expiration dates), and a capital lease ($128 million) for
a nonutility power-production facility.
Estimated remaining commitments for noncancelable leases at December
31, 1993, were:
<TABLE>
<CAPTION>
Operating Capital
In millions Lease Lease
- ----------- --------- -------
<S> <C> <C>
Year ended December 31,
1994 $ 27 $ 24
1995 22 24
1996 18 24
1997 13 24
1998 11 24
Thereafter 20 58
---- ----
Total future commitments $111 $178
---- ----
Amount representing interest (9.65%) (50)
----
Net commitments $128
====
</TABLE>
Note 9. Commitments
Edison has fuel supply contracts which require payment only if the fuel
is made available for purchase.
Edison has power-purchase contracts with certain qualifying facilities
(cogenerators and small power producers). These contracts provide for capacity
payments subject to a facility meeting certain performance obligations and
energy payments based on actual power supplied to Edison. There are no
requirements to make debt-service payments.
Edison has unconditional purchase obligations for part of a power
plant's generating output, as well as firm transmission service from another
utility. Minimum payments are based, in part, on the debt-service requirements
of the provider, whether or not the plant or transmission line is operable. The
purchased-power contract is not expected to provide more than 5% of current or
estimated future operating capacity. Edison's minimum commitment under both
contracts is approximately $210 million through 2017.
<PAGE> 25
Certain commitments for the years 1994 through 1998 are estimated
below:
<TABLE>
<CAPTION>
In millions 1994 1995 1996 1997 1998
- ----------- ---- ---- ---- ---- ----
<S> <C> <C> <C> <C> <C>
Construction expenditures $1,305 $1,330 $1,155 $1,094 $1,349
Fuel supply contracts 315 217 197 172 173
Purchased power capacity payments 658 666 676 680 682
Unconditional purchase obligations 9 9 9 9 9
====== ====== ====== ====== ======
</TABLE>
Mission Energy Company has guaranteed equity obligations of its
subsidiaries related to the Loy Yang B and Gordonsville projects. Mission Energy
has issued debt supporting most of the Loy Yang B equity obligations; the
remaining obligation (approximately $80 million) is expected to terminate in
1996, when the project becomes fully operational. The Gordonsville obligation
(approximately $55 million) is expected to be funded in June 1994.
In connection with the sale of interests in affordable housing projects,
SCEcorp has certain continuing obligations to investors through 2008,
(approximately $40 million).
<PAGE> 26
37
Note 10. Contingencies
Environmental Protection
SCEcorp is subject to numerous legislative and regulatory
environmental-protection requirements. To meet these requirements, SCEcorp will
continue to incur substantial costs to operate existing facilities, construct
and operate new facilities, and mitigate or remove the effect of past
operations on the environment.
SCEcorp has identified 46 sites for which it is, or may be, responsible
for remediation under environmental laws. SCEcorp is participating in
investigations and cleanups at a number of these sites and has recorded a $60
million liability for its estimated minimum costs to clean up several sites.
Additional costs may be incurred as progress is made in determining the
magnitude of required remedial actions, as SCEcorp's share of these costs in
proportion to other responsible parties is determined, and as additional
investigations and cleanups are performed.
The CPUC currently allows Edison to recover environmental cleanup costs
through rates, subject to reasonableness reviews. Edison filed for a
reasonableness review of costs incurred through 1991 at two hazardous substance
sites. Hearings have been delayed due to a 1992 CPUC decision, involving
another California utility, which concluded that the current procedure may not
be appropriate for these costs, and requested interested parties to recommend
alternatives. In November 1993, the major California utilities, the DRA and
others filed a collaborative report recommending an incentive mechanism, which
would require shareholders to fund 10% of cleanup costs. Shareholders would
have the opportunity to recover these costs through insurance. Accordingly,
Edison has recorded a regulatory asset which represents 90% of the estimated
cleanup costs for sites covered by this proposed mechanism. The remaining
sites' cleanup costs are expected to be immaterial and would be recovered
through base rates. If approved by the CPUC, Edison would be allowed to recover
90% of cleanup costs incurred to date under the reasonableness review procedure
($11 million). A final CPUC decision is expected in early 1994.
The probable effect on net income of these environmental-protection
matters cannot be determined at this time, but SCEcorp believes it will not
materially affect its financial position.
Nuclear Insurance
Federal law limits public liability claims from a nuclear incident to
$9.4 billion. Edison and other owners of San Onofre and Palo Verde have
purchased the maximum private primary insurance available ($200 million). The
balance is covered by the industry's retrospective rating plan that uses
deferred premium charges. Federal regulations require this secondary level of
financial protection. The secondary level and other insurance for San Onofre
Unit 1 remains in effect pending Nuclear Regulatory Commission approval to
discontinue the coverage. The maximum deferred premium for each nuclear
incident is $79 million per reactor, but not more than $10 million per reactor
may be charged in any one year for each incident. Based on ownership interests,
Edison could be required to pay a maximum of $218 million per nuclear incident.
However, it would have to pay no more than $28 million per incident in any one
year. Such amounts include a 5% surcharge if additional funds are needed to
satisfy public liability claims and are subject to adjustment for inflation.
Property damage insurance covers losses up to $500 million, including
decontamination costs, at San Onofre and Palo Verde. Decontamination liability
and property damage coverage exceeding the primary $500 million also has been
purchased in amounts greater than federal requirements. Additional insurance
covers part of replacement power expenses during an accident-related nuclear
unit outage. These policies are issued primarily by mutual insurance companies
owned by utilities with nuclear facilities. If losses at any nuclear facility
covered by the arrangement were to exceed the accumulated funds for these
insurance programs, Edison could be assessed retrospective premium adjustments
of up to $34 million per year. Insurance premiums are charged to operating
expense.
Note 11. Investments in Partnerships
The Mission companies have equity interests in several energy
generation and real estate investment partnerships. Summarized financial
information of the partnerships was:
<PAGE> 27
Income statements:
<TABLE>
<CAPTION>
Year ended December 31,
-------------------------
In millions 1993 1992 1991
- ----------- ---- ---- ----
<S> <C> <C> <C>
Revenue $1,678 $1,369 $1,267
Expenses 1,323 1,040 959
------ ------ ------
Net income $ 355 $ 329 $ 308
====== ====== ======
</TABLE>
Balance sheets:
<TABLE>
<CAPTION>
In millions December 31, 1993 1992
------ ------
<S> <C> <C>
Current assets $ 947 $ 762
Other assets 3,882 3,258
------ ------
Total assets $4,829 $4,020
====== ======
Current liabilities $ 490 $ 350
Other liabilities 2,434 1,919
Equity 1,905 1,751
------ ------
Total liabilities and equity $4,829 $4,020
====== ======
</TABLE>
<PAGE> 28
38
Notes to Consolidated Financial Statements
Note 12. Business Segments
SCEcorp's business segments include rate-regulated electric utility
operations (Edison) and three nonutility segments: electric power generation
(Mission Energy), financial investments (Mission First Financial) and real
estate holdings (Mission Land Company). The nonutility segment operations are
not individually significant for reporting purposes, so they are combined as
"diversified operations" below.
SCEcorp's business segment information was:
<TABLE>
<CAPTION>
Year ended December 31,
--------------------------
In millions 1993 1992 1991
- ----------- ---- ---- ----
<S> <C> <C> <C>
Operating income:
Electric $ 1,670 $ 1,750 $ 1,547
Diversified operations 14 139 146
------- ------- -------
Total operating income before taxes 1,684 1,889 1,693
------- ------- -------
Income taxes (465) (544) (453)
Corporate items and eliminations (2) (2) (1)
------- ------- -------
Total operating income $ 1,217 $ 1,343 $ 1,239
======= ======= =======
Depreciation and decommissioning:
Electric $ 893 $ 797 $ 759
Diversified operations 29 10 8
------- ------- -------
Total depreciation and decommissioning $ 922 $ 807 $ 767
======= ======= =======
Assets:
Electric $18,092 $15,969 $15,961
Diversified operations 3,291 3,344 2,344
Corporate items and eliminations (4) (2) 38
------- ------- -------
Total assets $21,379 $19,311 $18,343
======= ======= =======
Additions to property and plant:
Electric $ 1,040 $ 787 $ 964
Diversified operations 219 454 69
------- ------- -------
Total additions to property and plant $ 1,259 $ 1,241 $ 1,033
======= ======= =======
</TABLE>
<PAGE> 29
Revenue by segment is shown in the Consolidated Statements of Income.
Quarterly Financial Data
Unaudited
<TABLE>
<CAPTION> 1993
In millions, ---------------------------------------------------------
except per-share amounts Total Fourth Third Second First
- ------------------------ ------ ------ ------ ------ ------
<S> <C> <C> <C> <C> <C>
Operating revenue $7,821 $1,844 $2,424 $1,768 $1,785
Operating income 1,217 282 349 293 293
Net income 639 138 211 141 149
Per share:
Earnings 1.43 .31 .47 .32 .33
Dividends declared 1.415 .355 .355 .355 .35
------ ------ ------ ------ ------
Common stock prices
High $25-3/4 $23-5/8 $25-3/4 $24-7/8 $24-13/16
Low 19-7/8 19-7/8 23-1/4 23-3/16 21-7/16
Close 20 20 23-3/8 24-1/4 23-5/8
======= ======= ======= ======= ========
</TABLE>
<TABLE>
<CAPTION>
1992
In millions, ---------------------------------------------------------
except per-share amounts Total Fourth Third Second First
- ------------------------ ----- ------ ----- ------ -------
<S> <C> <C> <C> <C> <C>
Operating revenue $7,984 $1,939 $2,555 $1,771 $1,719
Operating income 1,343 293 441 305 304
Net income 739 152 272 158 157
Per share:
Earnings 1.66 .34 .61 .35 .36
Dividends declared 1.39 .35 .35 .35 .34
--------- -------- -------- -------- ---------
Common stock prices
High $23-13/16 $23-3/8 $23-13/16 $23-1/16 $23-11/16
Low 20-1/8 21-3/16 22-1/16 20-1/8 20-1/4
Close 22 22 22-5/8 22-1/8 20-3/8
========== ======== ======== ======== =========
</TABLE>
<PAGE> 30
39
Responsibility for Financial Reporting SCEcorp and Subsidiaries
The management of SCEcorp is responsible for preparing the accompanying
financial statements. The statements were prepared in accordance with generally
accepted accounting principles and necessarily include amounts based on
management's estimates and judgment. Management believes other information in
the annual report is consistent with the financial statements.
Management maintains systems of internal control to provide reasonable
assurance that assets are safeguarded, transactions are properly executed in
accordance with management's authorization, and accounting records may be
relied upon for the preparation of financial statements and other financial
information. The design of internal control systems involves management's
judgment concerning the relative cost and expected benefits of specific control
measures. These systems are augmented by internal audit programs through which
the adequacy and effectiveness of internal controls, policies and procedures
are evaluated and reported to management.
In addition, Arthur Andersen & Co., as part of its independent audit of
SCEcorp's financial statements, is responsible under generally accepted
auditing standards to evaluate the internal control structures in order to
determine the scope of its auditing procedures for the purpose of expressing
its opinion on the financial statements.
Management believes SCEcorp's systems of internal control are adequate
to accomplish the objectives discussed herein. Management has implemented all
of the internal and external auditors' significant recommendations regarding
the systems of internal control.
The audit committee of the board of directors, which is composed
entirely of non-employee directors, meets periodically with both the external
and internal auditors, who have unrestricted access to the committee. This
committee recommends to the board of directors the annual appointment of a firm
of independent public accountants, considers the audit scope and independence
of the external auditor, discusses the adequacy of internal controls, reviews
financial reporting issues and is advised of management's actions regarding
these matters.
Management is responsible for fostering a climate in which SCEcorp's
affairs are conducted in accordance with the highest standards of personal and
corporate conduct, which are reflected in SCEcorp's Standards of Conduct.
Management maintains programs to encourage and assess compliance with these
standards.
Richard K. Bushey John E. Bryson
Vice President Chairman of the Board
and Controller and Chief Executive Officer
February 4, 1994
Report of Independent Public Accountants
To the Shareholders and the Board of Directors, SCEcorp:
We have audited the accompanying consolidated balance sheets of SCEcorp
(a California corporation) and its subsidiaries as of December 31, 1993 and
1992, and the related consolidated statements of income, retained earnings and
cash flows for each of the three years in the period ended December 31, 1993.
These financial statements are the responsibility of SCEcorp's management. Our
responsibility is to express an opinion on these financial statements based on
our audits.
We conducted our audits in accordance with generally accepted auditing
standards. Those standards require that we plan and perform the audit to obtain
reasonable assurance about whether the financial statements are free of
material misstatement. An audit includes examining, on a test basis, evidence
supporting the amounts and disclosures in the financial statements. An audit
also includes assessing the accounting principles used and significant
estimates made by management, as well as evaluating the overall financial
statement presentation. We believe that our audits provide a reasonable basis
for our opinion.
In our opinion, the financial statements referred to above present
fairly, in all material respects, the financial position of SCEcorp and its
subsidiaries as of December 31, 1993 and 1992, and the results of their
operations and their cash flows for each of the three years in the period ended
December 31, 1993, in conformity with generally accepted accounting principles.
As discussed in Notes 5 and 6 to the financial statements, and as
required by generally accepted accounting principles, SCEcorp changed its
methods of accounting for income taxes and postretirement benefits other than
pensions in 1993.
ARTHUR ANDERSEN & CO.
Los Angeles, California
February 4, 1994
<PAGE> 31
40
Selected Financial and Operating Data: 1989 -- 1993 SCEcorp and Subsidiaries
<TABLE>
<CAPTION>
Dollars in millions,
except per-share amounts* 1993 1992 1991 1990 1989
- ------------------------- ---- ---- ---- ---- ----
SCEcorp and Subsidiaries
<S> <C> <C> <C> <C> <C>
Operating revenue $ 7,821 $ 7,984 $ 7,556 $ 7,226 $ 6,904
Operating expenses $ 6,604 $ 6,641 $ 6,317 $ 5,960 $ 5,737
Net income $ 639 $ 739 $ 703 $ 786 $ 778
Weighted-average shares of
common stock outstanding
(in millions) 448 445 437 437 437
Per-share data:
Earnings $1.43 $1.66 $1.61 $1.80 $1.78
Dividends declared $1.415 $1.39 $1.35 $1.31 $1.27
Book value $13.30 $13.30 $12.91 $12.59 $12.10
Market value at
year-end $20 $22 $23-3/8 $18-15/16 $19-11/16
Dividend payout ratio 98.6% 83.1% 83.2% 72.2% 70.8%
Rate of return on common
equity 10.65% 12.54% 12.51% 14.51% 14.99%
Price/earnings ratio 14.0 13.3 14.6 10.5 11.1
Ratio of earnings to
fixed charges 2.28 2.68 2.53 2.69 2.79
Assets $21,379 $19,311 $18,343 $17,684 $16,495
Retained earnings $ 3,266 $ 3,263 $ 3,150 $ 3,038 $ 2,824
Common shareholders' equity $ 5,958 $ 5,954 $ 5,681 $ 5,503 $ 5,289
Preferred stock:
Not subject to mandatory
redemption $ 359 $ 359 $ 359 $ 359 $ 359
Subject to mandatory
redemption $ 275 $ 278 $ 199 $ 210 $ 224
Long-term debt $ 6,459 $6,320 $ 5,940 $ 5,488 $ 5,283
Southern California Edison
Company
Financial data:
Operating revenue $ 7,397 $ 7,722 $ 7,298 $ 6,986 $ 6,524
Earnings $ 637 $ 631 $ 587 $ 693 $ 679
Earnings per SCEcorp
common share $1.42 $1.42 $1.34 $1.58 $1.55
Rate of return on
common equity 13.2% 13.2% 12.6% 15.0% 14.7%
Internal generation of funds 78% 83% 70% 76% 88%
Operating data:
Peak demand in megawatts (MW) 16,475 18,413 16,709 17,647 15,632
Generation capacity at
peak (MW) 20,606 20,712 20,875 20,323 20,136
Kilowatt-hour sales
(in millions) 73,308 74,186 71,146 71,614 69,136
Customers (in millions) 4.12 4.11 4.08 4.03 3.94
Full-time employees 16,487 16,736 17,110 16,604 16,627
Mission Companies
Net income $3 $109 $116 $94 $100
Earnings per SCEcorp
common share $.01 $.24 $.27 $.22 $.23
Percent of SCEcorp's earnings
per share 0.7% 14.5% 16.8% 12.2% 12.9%
Common shareholder's equity $1,002 $1,169 $1,020 $904 $735
Rate of return on common
equity 0.3% 9.8% 12.2% 11.8% 17.2%
Full-time employees 706 523 401 321 383
</TABLE>
* Per-share figures reflect the two-for-one split of SCEcorp common
stock effective June 1, 1993.
<PAGE> 1
EXHIBIT 21
SCEcorp SUBSIDIARIES
--------------------
February 1994
HOLDING COMPANY
---------------
SCEcorp
- -------
UTILITY SUBSIDIARIES
--------------------
SOUTHERN CALIFORNIA EDISON COMPANY
- ----------------------------------
CALIFORNIA ELECTRIC POWER COMPANY
CONSERVATION FINANCING CORPORATION
ENERGY SERVICES, INC.
MONO POWER COMPANY
THE BEAR CREEK URANIUM COMPANY
SCE CAPITAL COMPANY
SOUTHERN STATES REALTY
NON-UTILITY SUBSIDIARIES
------------------------
THE MISSION GROUP
- -----------------
MISSION ENERGY COMPANY
- ----------------------
Aguila Energy Company (LP)
American Bituminous Power Partners, L.P. (Delaware limited partnership)
American Kiln Partners, L.P. (Delaware limited partnership)
Anacapa Energy Company (GP)
Salinas River Cogeneration Company (partnership)
Anacostia Energy Company (D.C. corporation) (inactive)
Arrowhead Energy Company
Crown Energy, L.P. (New Jersey partnership)
Crown Vista Urban Renewal Corporation (New Jersey corporation)
Balboa Energy Company (GP)
Smithtown Cogeneration, L.P. (Delaware partnership)
Bergen Point Energy Company (GP)
TEVCO/Mission Bayonne Partnership (Delaware general partnership)
Blue Ridge Energy Company (GP)
Bretton Woods Cogeneration, L.P. (Delaware limited partnership)
BN Geothermal, Inc. (Delaware corporation)
Vulcan/BN Geothermal Power Company (Nevada general partnership)
Bretton Woods Energy Company (GP & LP)
Bretton Woods Cogeneration, L.P. (Delaware limited partnership)
Camino Energy Company (GP)
Watson Cogeneration Company (general partnership)
Capistrano Cogeneration Company (GP)
James River Cogeneration Company (North Carolina partnership)
Capitol Energy Company (D.C. corporation) (inactive)
Centerport Energy Company (GP & LP)
Riverhead Cogeneration I, L.P. (Delaware partnership)
<PAGE> 2
Chesapeake Bay Energy Company (formerly Woodand Energy Company) (GP)
Delaware Clean Energy Project (Delaware general partnership)
Chester Energy Company
Clayville Energy Company
Oconee Energy, L.P. (Delaware limited partnership)
Colonial Energy Company (formerly Hentland Farm Energy Company) (inactive)
Conejo Energy Company (GP & LP)
Andy Hoch (Del Ranch), L.P. (partnership)
Coronado Energy Company
Oconee Energy, L.P. (Delaware limited partnership)
Crescent Valley Energy Company (GP)
Beowawe Geothermal Power Company (general partnership)
Crystal River Energy Company (GP & LP)
Glenwood Springs Salt Company, L.P. (partnership)
Del Mar Energy Company (GP)
Mid-Set Cogeneration Company (partnership)
Desert Sunrise Energy Company (Nevada corporation) (inactive)
Devereaux Energy Company (LP)
Auburndale Power Partners, Limited Partnership (Delaware limited partnership)
Eastern Sierra Energy Company (GP & LP)
Saguaro Power Company, A Limited Partnership (partnership)
East Maine Energy Company (inactive)
El Dorado Energy Company (GP)
Auburndale Power Partners, Limited Partnership (Delaware limited partnership)
EMP, Inc. (Oregon corporation) (GP & LP)
GEO East Mesa Limited Partnership (partnership)
GEO East Mesa Electric Co. (Nevada corporation)
Four Counties Gas Company (inactive)
Hanover Energy Company
Chickahominy River Energy Corp. (GP & LP)
Commonwealth Atlantic Limited Partnership (Delaware partnership)
Holtsville Energy Company (GP & LP)
Brookhaven Cogeneration, L.P. (Delaware partnership)
Indian Bay Energy Company (GP & LP)
Riverhead Cogeneration III, L.P. (Delaware partnership)
Jefferson Energy Company (GP & LP)
Gordonsville Energy, L.P. (Delaware partnership)
Kings Canyon Energy Company (inactive)
Kingspark Energy Company (GP & LP)
Smithtown Cogeneration, L.P. (Delaware partnership)
Laguna Energy Company (inactive)
La Jolla Energy Company (inactive)
Lake Grove Energy Company (inactive)
Lakeview Energy Company
Georgia Peakers, L.P. (Delaware limited partnership)
Lehigh River Energy Company (GP)
TEVCO/Mission Assets Partnership (Delaware general partnership) Continental
Energy Associates, Limited Partnership (Massachusetts partnership)
Longview Cogeneration Company (formerly Columbia River Cogeneration
Company, formerly Cabrillo Energy Company)
Madera Energy Company (GP)
Brookhaven Cogeneration, L.P. (Delaware partnership)
Madison Energy Company (formerly Sunshine Generators, Inc.) (LP)
Gordonsville Energy, L.P. (Delaware partnership)
MEC International B.V. (Netherlands corporation)
Hydro Energy B.V. (Netherlands Antilles company)
Compania Mediterranea de Energias, S.A. (Spain corporation)
Energias Hidraulicas, S.A. (Spain corporation)
2
<PAGE> 3
Iberica de Energias, S.A. (Spain corporation)
Iberian Hy-Power Amsterdam B.V. (Netherlands corporation)
Electra La Mella, S.A. (Spain corporation)
Electrometalurgica del Ebro, S.A. (Spain corporation)
Hidroelectrica del Cadagua, S.A. (Spain corporation)
Hidroelectrica de Casillas, S.A. (Spain corporation)
Hidroelectrica de Olvera, S.A. (Spain corporation)
Hidroelectrica de Posadas, S.A. (Spain corporation)
Hidroelectrica del Sossis, S.A. (Spain corporation)
Hydro Energy B.V. (Netherlands Antilles company)
Compania Mediterranea de Energias, S.A. (Spain corporation)
Energias Hidraulicas, S.A. (Spain corporation)
Iberica de Energias, S.A. (Spain corporation)
Latrobe Power Pty. Ltd. (Australian corporation)
Mission Victoria Partnership (Australian partnership)
Latrobe Power Partnership (Australian partnership)
Loy Yang B Joint Venture (Australian joint
venture)
Loy Yang Holdings Pty. Ltd. (Australian corporation)
Latrobe Power Pty. Ltd. (Australian corporation)
Mission Victoria Partnership (Australian partnership)
Latrobe Power Partnership (Australian partnership)
Loy Yang B Joint Venture (Australian joint venture)
Mission Energy Australia Pty. Ltd. (Australian public company)
Latrobe Power Partnership (Australian partnership)
Loy Yang B Joint Venture (Australian joint venture)
Mission Energy Ventures Australia Pty. Ltd. (Australian company)
Mission Victoria Partnership (Australian partnership)
Latrobe Power Partnership (Australian partnership)
Loy Yang B Joint Venture (Australian joint venture)
Traralgon Power Pty. Ltd. (Australian corporation)
Mission Victoria Partnership (Australian partnership)
Latrobe Power Partnership (Australian partnership)
Loy Yang B Joint Venture (Australian joint venture)
Mission Energy Asia Pte Ltd. (Singapore private limited company)
Mission Energy Company (UK) Limited (United Kingdom private limited company)
Derwent Cogeneration Limited (United Kingdom private limited company)
Mission Energy Limited (United Kingdom private limited company)
Mission Energy Services Limited (United Kingdom private limited
company) Mission (No. 2) Limited (United Kingdom private limited
company) (formerly Mowlem Power Ltd.)
Mission Energy Holdings Pty. Ltd. (Australian corporation)
Mission Energy Development Australia Pty. Ltd.(Australian corporation)
Mission Energy Management Australia Pty. Ltd. (Australian corporation)
Pride Hold Ltd. (United Kingdom corporation)
Lakeland Power Limited (United Kingdom private company)
Traralgon Power Pty. Ltd. (Australian corporation)
Mission Victoria Partnership (Australian partnership)
Latrobe Power Partnership (Australian partnership)
Loy Yang B Joint Venture (Australian joint venture)
Mission Energy Asia (formerly Cypress Energy Company)
Mission Energy Canada Corporation (British Columbia company)
B.C. Star Partners (partnership)
The Mission Interface Partnership (Province of Ontario general partnership)
Mission Energy Fuel Company
Mission Energy Methane Company
Mission Energy Oil and Gas Company
3
<PAGE> 4
Four Star Oil & Gas Company (partnership)
Mission Energy Petroleum Company
Pocono Fuels Company (inactive)
Southern Sierra Gas Company
TM Star Fuel Company (general partnership)
Mission Energy Indonesia (formerly Chula Energy Company)
Mission Energy Mexico (inactive)
Mission Energy New York, Inc. (formerly Allegheny Energy Company) (GP & LP)
Brooklyn Navy Yard Cogeneration Partners, L.P. (Delaware partnership)
Mission Energy Westside, Inc. (formerly Sun Coast Energy Company)
Mission Operation and Maintenance, Incorporated
Mission Triple Cycle Systems Company (GP)
Triple Cycle Partnership (Texas general partnership)
Niguel Energy Company (GP & LP)
Elmore, Ltd. (partnership)
Northern Sierra Energy Company (GP)
Sobel Cogeneration Company (general partnership)
Ortega Energy Company
Otter Point Energy Company (Maryland corporation) (inactive)
Panther Timber Company (GP)
American Kiln Partners, L.P. (Delaware limited partnership)
Patapsco Energy Company (inactive)
Pleasant Valley Energy Company (GP)
American Bituminous Power Partners, L.P. (Delaware limited partnership)
Prince George Energy Company (LP)
Hopewell Cogeneration Limited Partnership (Delaware limited partnership)
Hopewell Cogeneration Inc. (Delaware corporation)
Hopewell Cogeneration Limited Partnership (Delaware limited
partnership)
Quartz Peak Energy Company (LP)
Nevada Sun-Peak Limited Partnership (Nevada partnership)
Rapidan Energy Company (GP)
Gordonsville Energy, L.P. (Delaware partnership)
Reeves Bay Energy Company (GP & LP)
North Shore Energy, L.P. (Delaware partnership)
Northville Energy Corporation (New York corporation)
Ridgecrest Energy Company (GP)
Riverhead Cogeneration I, L.P. (Delaware partnership)
Rio Escondido Energy Company
Energia Del Norte, S.A. de C.V. (partnership)
Minera Carbonifera Rio Escondido, S.A. de C.V. (Mexico corporation)
Riverport Energy Company (GP & LP)
Riverhead Cogeneration II, L.P. (Delaware partnership)
San Felipe Energy Company (GP & LP)
Leathers, L.P. (partnership)
San Gabriel Energy Company (inactive)
San Jacinto Energy Company (inactive)
San Joaquin Energy Company (GP)
Midway-Sunset Cogeneration Company, L.P. (partnership)
San Juan Energy Company (GP)
March Point Cogeneration Company (partnership)
San Pedro Energy Company (GP)
Riverhead Cogeneration II, L.P. (Delaware partnership)
Santa Ana Energy Company (GP)
Riverhead Cogeneration III, L.P. (Delaware partnership)
Santa Clara Energy Company (GP)
North Shore Energy, L.P. (Delaware partnership)
Northville Energy Corporation (New York corporation)
4
<PAGE> 5
Silverado Energy Company (GP)
Coalinga Cogeneration Company (partnership)
Silver Springs Energy Company
Georgia Peakers, L.P. (Delaware limited partnership)
Sonoma Geothermal Company (GP & LP)
Geothermal Energy Partners Ltd. (partnership)
South Coast Energy Company (GP)
Harbor Cogeneration Company (partnership)
Southern Sierra Energy Company (GP)
Kern River Cogeneration Company (general partnership)
MH V (partnership)
Centennial Place L.P. (partnership)
Viejo Energy Company (GP)
Sargent Canyon Cogeneration Company (partnership)
Vista Energy Company (New Jersey corporation) (GP & LP)
Vista Energy, L.P. (New Jersey limited partnership)
Crown Vista Urban Renewal Corporation (New Jersey corporation)
Western Sierra Energy Company (GP)
Sycamore Cogeneration Company (general partnership)
Winters Run Energy Company (Maryland corporation) (inactive)
MISSION FIRST FINANCIAL
-----------------------
Mission Funding Company
Mission Funding Gamma
Mission Funding Epsilon
Mission Funding Delta
Mission Investments, Inc. (U.S. Virgin Islands corporation)
Mission Funding Alpha
Mission (Bermuda) Investments, Ltd. (Bermuda corporation)
GEM Energy Company (New York partnership)
Mission Funding Beta
Mission Funding Theta
Mission Funding Kappa
ABB Funding Partners, L.P. (partnership)
Mission Housing Investments
Abby Associates L.P. (Windmere) (partnership)
AE Associates L.P. (Avenida Espana) (partnership)
Argyle Redevelopment Partnership, Ltd. (Colorado partnership)
Bartlett Hill Associates L.P. (partnership)
Berry Avenue Associates L.P. (partnership)
Carlton Way Apartments L.P. (partnership)
Centertown Associates L.P. (partnership)
Centro Partners L.P. (partnership)
Corona Ely/Ranch Associates L.P. (partnership)
Coyote Springs Apartments Associates L.P. (partnership)
Crescent Arms L.P. (partnership)
Cypress Cove Associates (partnership)
Delta Plaza Associates (partnership)
EAH Larkspur Creekside Associates L.P. (partnership)
East Cotati Avenue Partners L.P. (partnership)
Edmundson Associates L.P. (partnership)
Farm (The) Associates L.P. (partnership)
Fell Street Housing Associates L.P. (partnership)
Gilroy Redwood Associates L.P. (Redwoods) (partnership)
Ginzton Associates L.P. (partnership)
Grossman Apartments Investors L.P. (partnership)
Heather Glen Associates L.P. (partnership)
Holy Family Associates L.P. (partnership)
Hope West Apartments L.P. (partnership)
Kennedy Lofts Associates L.P. (Massachusetts partnership)
5
<PAGE> 6
La Brea/Franklin L.P. (partnership)
Larkin Pine L.P. (partnership)
MH I (partnership)
California Park Apartments L.P. (partnership)
MH II (partnership)
5363 Dent Avenue Associates L.P. (partnership)
MH III (partnership)
DeRose Housing Associates L.P. (partnership)
MH IV (partnership)
MPT Apartments L.P. (MacArthur Park) (partnership)
MH V (partnership)
Centennial Place L.P. (partnership)
Mar Associates L.P. (partnership)
Mayacamas Village Associates L.P. (partnership)
Mid-Peninsula Sharmon Palms Associates L.P. (Sharmon Palms)
(partnership)
Mission Capp L.P. (partnership)
Mission Housing Alpha
Lee Park Investors L.P. (Pennsylvania partnership)
Mission Housing Beta
Richmond City Center Associates L.P. (partnership)
Mission Housing Gamma
Del Carlo Court Associates L.P. (partnership)
Mission Housing Delta
MH I (partnership)
California Park Apartments L.P. (partnership)
MH II (partnership)
5363 Dent Avenue Associates L.P. (partnership)
MH III (partnership)
DeRose Housing Associates L.P. (partnership)
MH IV (partnership)
MPT Apartments L.P. (MacArthur Park) (partnership)
MH V (partnership)
Centennial Place L.P. (partnership)
Mission Housing Epsilon
Mission Housing Zeta
Mission Housing Theta
Mission Housing Investors Partnership
Forest Winds Associates L.P. (partnership)
Glen Eden Associates L.P. (partnership)
Gray's Meadows Investors L.P. (partnership)
Prince Bozzuto L.P. (Maryland partnership)
Rancho Park Associates L.P. (partnership)
Rustic Gardens Associates L.P. (partnership)
Sea Ranch Apartments L.P. (partnership)
Springdale Kresson Associates, L.P. (New Jersey partnership)
1028 Howard Street Associates L.P. (partnership)
Morrone Gardens Associates L.P. (partnership)
Neary Lagoon Associates L.P. (partnership)
Open Doors Associates L.P. (partnership)
Pajaro Court Associates L.P. (partnership)
Palmer House L.P. (partnership)
Park Place Terrace L.P. (partnership)
Pilot Grove L.P. (Massachusetts partnership)
Pinole Grove Associates (partnership)
Post Office Plaza L.P. (Ohio partnership)
Rincon De Los Esteros Associates L.P. (partnership)
Riverside/Liebrandt Partners L.P. (partnership)
Rosebloom Associates L.P. (partnership)
Runsen Associates L.P. (partnership)
San Pablo Senior Housing Associates L.P. (partnership)
San Pedro Gardens Associates L.P. (partnership)
6
<PAGE> 7
Santa Paulan Senior Apartments Associates L.P.(partnership)
Second Street Center L.P. (partnership)
South Beach Housing Associates L.P. (partnership)
Stoney Creek Associates L.P. (partnership)
Studebaker Building L.P. (partnership)
Sultana Acres Associates L.P. (partnership)
Tabor Grand L.P. (Colorado partnership)
The Josephinum Associates L.P. (Washington partnership)
Tierra Linda Associates L.P. (partnership)
Tlaquepaque Housing Associates L.P. (partnership)
Tuscany Associates L.P. (partnership)
Washington Creek Associates L.P. (partnership)
Westport Village Homes Associates L.P. (partnership)
Wheeler Manor Associates L.P. (partnership)
Winfield Hill Associates L.P. (partnership)
YWCA Villa Nueva Partners L.P. (partnership)
16th & Church Street Associates L.P. (partnership)
1101 Howard Street Associates L.P. (partnership)
210 Washington Avenue Associates (Connecticut partnership)
Mission First Asset Investment
Mission Funding Zeta
Huntington L.P. (New York partnership)
Renewable Energy Capital Company
Burlington Apartments, Inc.
Burlington Arboretum L.P. (partnership)
MISSION LAND COMPANY
--------------------
Associated Southern Investment Company
Calabasas Park Company (partnership) (inactive)
Central Valley/Calabasas L.P. (partnership)
Calabasas Palatino, Inc. (inactive)
California Commerce Center--North, L.P. (partnership)
Carol Point Builders I (partnership)
Carol Point Builders II (partnership)
Carol Stream Developers (partnership)
Centrelake Partners, L.P. (partnership)
Corona Partners, L.P. (partnership)
Irwindale Land Company (inactive)
Lusk-Mission Industrial Partners I (partnership)
Mission Airport Park Development Co.
Ontario Airport Industrial Park (partnership)
Mission-CCH I, L.P. (partnership)
Mission-Comstock Crosser Hickey (partnership)
Mission-DAI I, L.P. (partnership) (inactive)
Mission-Dominion Partners I, L.P. (partnership)
Mission Industrial Constructors, Inc. (inactive)
Mission-Koll I, L.P. (partnership)
Mission-Messenger Vacaville (partnership)
Mission-Nexus I, L.P. (partnership)
Mission-Nexus II, L.P. (partnership)
Mission-Ontario, Inc. (inactive)
Mission-Shea I, L.P. (partnership)
Mission-701 Minnesota (partnership)
Mission South Bay Company (inactive)
Mission Texas Property Holdings, Inc.
Ontario Lakeshore Partners, L.P. (partnership)
Parkway Business Centre Partners, Ltd. (partnership) (inactive)
Realco Texas Master Limited Partnership (Texas partnership)
7
<PAGE> 1
EXHIBIT 23
CONSENT OF INDEPENDENT PUBLIC ACCOUNTANTS
As independent public accountants, we hereby consent to the
incorporation by reference of our report dated February 4, 1994, (the Report of
Independent Public Accountants) appearing on page 39 of the 1993 Annual Report
to Shareholders of SCEcorp (Exhibit 13 included herein) in this Annual Report
on Form 10-K for the year ended December 31, 1993 of SCEcorp. It should be
noted that we have not audited any financial statements of SCEcorp subsequent
to December 31, 1993 or performed any audit procedures subsequent to the date
of our report.
We further consent to the incorporation by reference of the
above-mentioned Report of Independent Public Accountants, incorporated by
reference in this Annual Report on Form 10-K, and to the incorporation by
reference of our report (the Report of Independent Public Accountants on
Supplemental Schedules), appearing on page 33 of this Annual Report on Form
10-K, in the SCEcorp Registration Statements which follow:
<TABLE>
<CAPTION>
REGISTRATION FORM FILE NO. EFFECTIVE DATE
----------------- -------- --------------
<S> <C> <C>
Form S-8 33-32302 June 2, 1993
Form S-8 33-46713 June 2, 1993
Form S-8 33-46714 June 2, 1993
Form S-3 33-47389 June 2, 1993
Form S-8 33-51225 November 30, 1993
Form S-3 33-44148 September 17, 1993
</TABLE>
ARTHUR ANDERSEN & CO.
Los Angeles, California
March 17, 1994
<PAGE> 1
EXHIBIT 24.1
SCEcorp
POWER OF ATTORNEY
The undersigned, SCEcorp, a California corporation, and certain of its
officers and/or directors do each hereby constitute and appoint JOHN E. BRYSON,
BRYANT C. DANNER, ALAN J. FOHRER, R. K. BUSHEY, KENNETH S. STEWART, C. ALEX
MILLER, PATRICIA N. GLAZIER, VICTORIA W. SCHWARTZ, W. J. SCILACCI L. C. CLARK,
DOROTHY J. FULCO, JOHN STADNIK, CHARLES COOKE and TERRY M. ADLHOCK, or any of
them, to act as attorney-in-fact, for and in their respective names, places,
and steads, to execute, sign, and file or cause to be filed an Annual Report on
Form 10-K for the fiscal year ended December 31, 1993, the quarterly reports on
Form 10-Q for each of the first three quarters of fiscal year 1994 and from
time to time during 1994 any current report on Form 8-K, and any and all
supplements and amendements thereto, to be filed by SCEcorp with the Securities
and Exchange Commission under the Securities Exchange Act of 1934, as amended,
for the purpose of complying with Sections 13 or 15(d) of the Securities
Exchange Act of 1934, granting unto said attorneys-in-fact, and each of them,
full power and authority to do and perform all and every act and thing
whatsoever requisite, necessary and appropriate to be done in and about the
premises as fully and to all intents and purposes as the undersigned or any of
them might or could do if personally present, hereby ratifying and approving
the acts of each of said attorneys-in-fact.
Executed at Rosemead, California, as of this 17th day of March, 1994.
SCEcorp
By John E. Bryson
-------------------------------
Chairman of the Board
and Chief Executive Officer
(Seal)
Attest
Kenneth S. Stewart
- ------------------
Secretary
<PAGE> 2
1994 SCECORP 10-K POWER OF ATTORNEY
PRINCIPAL EXECUTIVE OFFICER:
<TABLE>
<S> <C> <C>
John E. Bryson
- ---------------------------- Chairman of the Board,
John E. Bryson Chief Executive Officer and
Director
Principal Financial Officer:
Alan J. Fohrer
- ----------------------------- Senior Vice President
Alan J. Fohrer and Chief Financial Officer
Controller and Principal Accounting Officer:
R. K. Bushey
- ----------------------------- Vice President
R. K. Bushey and Controller
Directors:
Howard P. Allen
- ----------------------------- Director
Howard P. Allen
N. Barker, Jr.
- ----------------------------- Director
N. Barker, Jr.
Walter B. Gerken
- ----------------------------- Director
Walter B. Gerken
Joan C. Hanley
- ----------------------------- Director
Joan C. Hanley
Carl F. Huntsinger
- ----------------------------- Director
Carl F. Huntsinger
Luis G. Nogales
- ----------------------------- Director
Luis G. Nogales
</TABLE>
2
<PAGE> 3
<TABLE>
<S> <C>
J. J. Pinola
- ----------------------------- Director
J. J. Pinola
Henry T. Segerstrom
- ----------------------------- Director
Henry T. Segerstrom
E. L. Shannon, Jr.
- ----------------------------- Director
E. L. Shannon, Jr.
Daniel M. Tellep
- ----------------------------- Director
Daniel M. Tellep
James D. Watkins
- ----------------------------- Director
James D. Watkins
Edward Zapanta
- ----------------------------- Director
Edward Zapanta
</TABLE>
3
<PAGE> 1
EXHIBIT 24.2
RESOLUTION OF THE BOARD OF DIRECTORS OF
SCEcorp
Adopted: March 17, 1994
RE: Filing of Annual Report on Form 10-K
WHEREAS, the Securities Exchange Act of 1934, as amended, and regulations
thereunder, require that Annual, Quarterly and from time to time Current
Reports of this corporation be filed with the Securities and Exchange
Commission ("Commission");
WHEREAS, it is convenient and desirable to effect such filings over the
signatures of attorneys-in-fact and to authorize the same for such purpose;
NOW, THEREFORE, BE IT RESOLVED, that the Chairman of the Board and Chief
Executive Officer or any Vice President of this corporation be, and each of
them hereby is, authorized and directed to file or cause to be filed with the
Commission the Annual Report on Form 10-K of this corporation for the fiscal
year ended December 31, 1993, Quarterly Reports on Form 10-Q for each of the
first three quarters of fiscal year 1994 and from time to time during 1994
Current Reports on Form 8-K, in a form or forms which the officer acting or
counsel acting for this corporation may deem necessary or proper, such
determination to be conclusively evidenced by said officer's execution thereof;
BE IT FURTHER RESOLVED, that each of the officers of this corporation is
hereby authorized to prepare and file or cause to be prepared and filed with
the Commission any and all required or appropriate supplements or further
amendments to the Annual Report on Form 10-K, the Quarterly Reports on Form
10-Q for each of the first three quarters of fiscal year 1994, and from time to
time during 1994 any Current Reports on Form 8-K;
BE IT FURTHER RESOLVED, that each of the officers of this corporation is
hereby authorized to execute and deliver on behalf of this corporation and in
its name a power of attorney appointing John E. Bryson, Bryant C. Danner, Alan
J. Fohrer, R. K. Bushey, Kenneth S. Stewart, C. Alex Miller, Patricia N.
Glazier, Victoria W. Schwartz, W. J. Scilacci, L. C. Clark, Dorothy J. Fulco,
John Stadnik, Charles Cooke, and Terry M. Adlhock, and each of them, to act
severally as attorney-in-fact for this corporation for the purpose of executing
and filing with the Commission on behalf of this corporation and in its name
the Annual Report on Form 10-K, the Quarterly Reports on Form 10-Q, any Current
Reports on Form 8-K, and any and all amendments and supplements thereto.
<PAGE> 2
I, MOLLY K. BYRD, Assistant Secretary of SCEcorp, certify that the attached
is an accurate and complete copy of a resolution of the Board of Directors of
the corporation, duly adopted at a meeting of its Board of Directors held on
March 17, 1994.
Dated: March 17, 1994
Molly K. Byrd
----------------------
Assistant Secretary
SCEcorp
