<PAGE>
SECURITIES AND EXCHANGE COMMISSION
Washington, D.C. 20549
Form 8-K
CURRENT REPORT
Pursuant to Section 13 or 15(d) of
the Securities Exchange Act of 1934
Date of Report (Date of earliest event reported): February 19, 1999
Commonwealth Edison Company
(Exact name of registrant as specified in its charter)
Illinois 1-1839 36-0938600
(State or other (Commission File Number) (IRS Employer
jurisdiction of Identification No.)
incorporation)
37th Floor, 10 South Dearborn Street, 60690-0767
Post Office Box 767, Chicago, Illinois (Zip Code)
(Address of principal executive
offices)
Registrant's telephone number, including area code: (312) 394-4321
<PAGE>
Item 5. Other Events
The purpose of this Current Report is to file certain financial information
regarding the Registrant (Commonwealth Edison Company) and its subsidiaries.
Such financial information is set forth in the exhibits to this Current
Report.
Exhibits
<TABLE>
<C> <S>
(23) Consent of Independent Public Accountants
(27) Financial Data Schedule of Commonwealth Edison Company
(99) Commonwealth Edison Company and Subsidiary Companies--Certain
Financial Information as of and for the Year Ended December 31,
1998:
--Summary of Selected Consolidated Financial Data
--Cash Dividends Paid per Share of Common Stock
--1998 Consolidated Revenues and Sales
--Management's Discussion and Analysis of Financial Condition and
Results of Operations
--Report of Independent Public Accountants
--Statements of Consolidated Operations for the years 1998, 1997 and
1996
--Consolidated Balance Sheets as of December 31, 1998 and 1997
--Statements of Consolidated Capitalization as of December 31, 1998
and 1997
--Statements of Consolidated Retained Earnings (Deficit) for the
years 1998, 1997 and 1996
--Statements of Consolidated Cash Flows for the years 1998, 1997 and
1996
--Notes to Financial Statements
</TABLE>
2
<PAGE>
SIGNATURE
Pursuant to the requirements of the Securities Exchange Act of 1934, the
registrant has duly caused this report to be signed on its behalf by the
undersigned thereunto duly authorized.
Commonwealth Edison Company
(Registrant)
By: Robert E. Berdelle
----------------------------------
Robert E. Berdelle
Vice President and
Comptroller
Date: February 24, 1999
3
<PAGE>
EXHIBIT INDEX
<TABLE>
<CAPTION>
Exhibit
Number Description of Exhibit
------- ----------------------
<C> <S>
(23) Consent of Independent Public Accountants
(27) Financial Data Schedule of Commonwealth Edison Company
(99) Commonwealth Edison Company and Subsidiary Companies--Certain
Financial Information as of and for the Year Ended December 31,
1998:
--Summary of Selected Consolidated Financial Data
--Cash Dividends Paid per Share of Common Stock
--1998 Consolidated Revenues and Sales
--Management's Discussion and Analysis of Financial Condition
and Results of Operations
--Report of Independent Public Accountants
--Statements of Consolidated Operations for the years 1998, 1997
and 1996
--Consolidated Balance Sheets as of December 31, 1998 and 1997
--Statements of Consolidated Capitalization as of December 31,
1998 and 1997
--Statements of Consolidated Retained Earnings (Deficit) for the
years 1998, 1997 and 1996
--Statements of Consolidated Cash Flows for the years 1998, 1997
and 1996
--Notes to Financial Statements
</TABLE>
<PAGE>
Exhibit (23)
Commonwealth Edison Company
Form 8-K File No. 1-1839
CONSENT OF INDEPENDENT PUBLIC ACCOUNTANTS
As independent public accountants, we hereby consent to the incorporation by
reference of our report dated February 19, 1999 on Commonwealth Edison Company
and Subsidiary Companies' consolidated financial statements as of and for the
year ended December 31, 1998, included as an Exhibit to this Form 8-K Current
Report of Commonwealth Edison Company, into Commonwealth Edison Company's
previously filed prospectuses as follows: (1) prospectus dated August 21,
1986, constituting part of Form S-3 Registration Statement File No. 33-6879,
as amended (relating to the Company's Debt Securities and Common Stock); (2)
prospectus dated January 7, 1994, constituting part of Form S-3 Registration
Statement File No. 33-51379 (relating to the Company's Debt Securities and
Cumulative Preference Stock); (3) prospectus dated September 19, 1995,
constituting part of Amendment No. 1 to Form S-3 Registration Statement File
No. 33-61343, as amended (relating to Company-Obligated Mandatorily Redeemable
Preferred Securities of ComEd Financing I); (4) prospectus dated June 13, 1997
constituting part of Form S-4 Registration Statement File No. 333-28369
(relating to Company-Obligated Mandatorily Redeemable Preferred Securities of
ComEd Financing II); and (5) Form S-8 Registration Statement File No. 333-
33847 (relating to the Commonwealth Edison Company Excess Benefit Savings
Plan). We also consent to the application of our report to the ratios of
earnings to fixed charges and the ratios of earnings to fixed charges and
preferred and preference stock dividend requirements for each of the years
ended December 31, 1998, 1997 and 1996 appearing in Exhibit 99 of this Form 8-
K.
ARTHUR ANDERSEN LLP
Chicago, Illinois
February 24, 1999
<TABLE> <S> <C>
<PAGE>
<ARTICLE> UT
<LEGEND> This schedule contains summary financial information extracted from the
Consolidated Balance Sheet and Statement of Consolidated Capitalization as of
December 31, 1998 and the related Statements of Consolidated Operations,
Retained Earnings (Deficit) and Cash Flows for the twelve months ended December
31, 1998 and is qualified in its entirety by reference to such financial
statements.
</LEGEND>
<CIK> 0000022606
<NAME> Commonwealth Edison Company
<MULTIPLIER> 1,000
<S> <C>
<PERIOD-TYPE> 12-MOS
<FISCAL-YEAR-END> DEC-31-1998
<PERIOD-START> JAN-01-1998
<PERIOD-END> DEC-31-1998
<BOOK-VALUE> PER-BOOK
<TOTAL-NET-UTILITY-PLANT> 13,441,905
<OTHER-PROPERTY-AND-INVEST> 2,373,477
<TOTAL-CURRENT-ASSETS> 4,954,807
<TOTAL-DEFERRED-CHARGES> 0<F1>
<OTHER-ASSETS> 4,663,380
<TOTAL-ASSETS> 25,433,569
<COMMON> 2,677,952
<CAPITAL-SURPLUS-PAID-IN> 2,208,042
<RETAINED-EARNINGS> 176,643
<TOTAL-COMMON-STOCKHOLDERS-EQ> 5,055,837<F2>
69,475
74,488
<LONG-TERM-DEBT-NET> 7,677,219<F3>
<SHORT-TERM-NOTES> 0<F1>
<LONG-TERM-NOTES-PAYABLE> 0<F3>
<COMMERCIAL-PAPER-OBLIGATIONS> 0<F1>
<LONG-TERM-DEBT-CURRENT-PORT> 1,497,706
534,193
<CAPITAL-LEASE-OBLIGATIONS> 333,653
<LEASES-CURRENT> 194,969
<OTHER-ITEMS-CAPITAL-AND-LIAB> 9,996,029<F4>
<TOT-CAPITALIZATION-AND-LIAB> 25,433,569
<GROSS-OPERATING-REVENUE> 7,135,880
<INCOME-TAX-EXPENSE> 351,202<F5>
<OTHER-OPERATING-EXPENSES> 5,769,967
<TOTAL-OPERATING-EXPENSES> 6,125,634
<OPERATING-INCOME-LOSS> 1,010,246
<OTHER-INCOME-NET> 29,657<F5><F6>
<INCOME-BEFORE-INTEREST-EXPEN> 1,044,368
<TOTAL-INTEREST-EXPENSE> 450,162
<NET-INCOME> 594,206
56,884
<EARNINGS-AVAILABLE-FOR-COMM> 537,322
<COMMON-STOCK-DIVIDENDS> 342,776
<TOTAL-INTEREST-ON-BONDS> 0<F7>
<CASH-FLOW-OPERATIONS> 1,449,446
<EPS-PRIMARY> 0<F7>
<EPS-DILUTED> 0<F7>
<FN>
<F1> This item is not disclosed as a separate line item on the Consolidated
Balance Sheet.
<F2> Includes a deduction of $6,800 thousand for treasury stock.
<F3> $3,965,620 thousand of notes and transitional trust notes are included in
LONG-TERM-DEBT-NET.
<F4> Includes $350,000 thousand of Company-obligated mandatorily redeemable
preferred securities of subsidiary trusts holding solely the Company's
subordinated debt securities.
<F5> A tax benefit of $4,465 thousand related to nonoperating activities is
included in INCOME-TAX-EXPENSE.
<F6> Includes $29,710 thousand of provision for preferred securities dividends
of subsidiary trusts holding solely the Company's subordinated debt
securities.
<F7> This item is not disclosed as a separate line item on the Statement of
Consolidated Operations.
</FN>
</TABLE>
<PAGE>
Exhibit (99)
Commonwealth Edison Company
Form 8-K File No. 1-1839
COMMONWEALTH EDISON COMPANY AND SUBSIDIARY COMPANIES
CONSOLIDATED FINANCIAL STATEMENTS
AS OF DECEMBER 31, 1998 AND 1997
<PAGE>
Commonwealth Edison Company and Subsidiary Companies
Forward-Looking Information
Except for historical data, the information contained herein constitutes
forward-looking statements. Forward-looking statements are inherently
uncertain and subject to risks. Such statements should be viewed with caution.
Actual results or experience could differ materially from the forward-looking
statements as a result of many factors. Forward-looking statements in this
report include, but are not limited to: (1) statements regarding expectations
of revenue reductions and collections of future CTC revenues as a result of
the 1997 Act in "Management's Discussion and Analysis of Financial Condition
and Results of Operations," subcaption "Changes in the Electric Utility
Industry--The 1997 Act," and in Note 2 of Notes to Financial Statements, (2)
statements regarding estimated capital expenditures in "Management's
Discussion and Analysis of Financial Condition and Results of Operations,"
subcaptions "Liquidity and Capital Resources--Construction Program" and
"Changes in the Electric Utility Industry--Response to Regulatory Changes,"
(3) statements regarding the estimated return to service of certain nuclear
generating units in "Management's Discussion and Analysis of Financial
Condition and Results of Operations," subcaption "Regulation--Nuclear
Matters," (4) statements regarding the costs of decommissioning nuclear
generating stations in "Management's Discussion and Analysis of Financial
Condition and Results of Operations," subcaption "Regulation--Nuclear
Matters," and in Note 1 of Notes to Financial Statements, under "Depreciation,
Amortization of Regulatory Assets and Decommissioning," (5) statements
regarding cleanup costs associated with MGPs and other remediation sites in
Note 22 of Notes to Financial Statements, (6) statements regarding the
estimated fair value of forward energy contracts in "Management's Discussion
and Analysis of Financial Condition and Results of Operations," subcaption
"Liquidity and Capital Resources--Market Price Exposure," and (7) statements
regarding the risks and uncertainties relating to Year 2000 issues set forth
in "Management's Discussion and Analysis of Financial Condition and Results of
Operations," subcaption "Liquidity and Capital Resources--Year 2000
Conversion," including the projected completion dates in each of Unicom's four
critical business areas, Unicom's dependence upon the Year 2000 readiness of
third parties with whom it has significant business relationships, the
estimated costs of remediating or upgrading embedded systems and software that
would not otherwise be replaced in accordance with Unicom's business plans,
and Unicom's Year 2000 contingency planning process. Management cannot predict
the course of future events or anticipate the interaction of multiple factors
beyond management's control and their effect on revenues, project timing and
costs. The statements regarding revenue reductions and collections of future
CTC revenues are subject to unforeseen developments in the market for
electricity in Illinois resulting from regulatory changes. The statements
regarding estimated capital expenditures, estimated return to service of
nuclear generation units, decommissioning costs, cleanup costs and Year 2000
conversion costs are subject to changes in the scope of work and manner in
which the work is performed and consequent changes in the timing and level of
the projected expenditure, and are also subject to changes in laws and
regulations or their interpretation or enforcement. The statements regarding
expectations for Year 2000 readiness and Unicom's Year 2000 contingency
planning process are subject to the risk that Year 2000 remediation efforts of
Unicom and other parties with whom it has significant business relationships
are not successful. The statements regarding the estimated return to service
of nuclear generating units are subject to the concurrence of the NRC with
proceeding to power operations. The statements regarding the fair value of
forward energy contracts are subject to changes in generating capability and a
reduction in the demand for electricity. Unicom and ComEd make no commitment
to disclose any revisions to the forward-looking statements, or any facts,
events or circumstances after the date hereof that may bear upon forward-
looking statements.
1
<PAGE>
INDEX
<TABLE>
<CAPTION>
Page
-----
<S> <C>
Definitions.............................................................. 3
Summary of Selected Consolidated Financial Data.......................... 4
Cash Dividends Paid per Share of Common Stock............................ 4
1998 Consolidated Revenues and Sales..................................... 4
Management's Discussion and Analysis of Financial Condition and Results
of Operations........................................................... 5-22
Report of Independent Public Accountants................................. 23
Consolidated Financial Statements--
Statements of Consolidated Operations for the years 1998, 1997 and
1996.................................................................. 24
Consolidated Balance Sheets as of December 31, 1998 and 1997........... 25-26
Statements of Consolidated Capitalization as of December 31, 1998 and
1997.................................................................. 27
Statements of Consolidated Retained Earnings (Deficit) for the years
1998, 1997 and 1996................................................... 28
Statements of Consolidated Cash Flows for the years 1998, 1997 and
1996.................................................................. 29
Notes to Financial Statements.......................................... 30-57
</TABLE>
2
<PAGE>
DEFINITIONS
The following terms are used in this document with the following meanings:
<TABLE>
<CAPTION>
Term Meaning
- ------------------- ------------------------------------------------------------------
<S> <C>
1997 Act Illinois Electric Service Customer Choice and Rate Relief Law of
1997
AFUDC Allowance for funds used during construction
APB Accounting Principles Board
CERCLA Comprehensive Environmental Response, Compensation and Liability
Act of 1980, as amended
ComEd Commonwealth Edison Company
ComEd Funding ComEd Funding, LLC, a ComEd subsidiary
ComEd Funding Trust ComEd Transitional Funding Trust, a ComEd Funding subsidiary
Congress U.S. Congress
Cotter Cotter Corporation, a ComEd subsidiary
CTC Non-bypassable "competitive transition charge"
DOE U.S. Department of Energy
EEI Edison Electric Institute
EPRI Electric Power Research Institute
ESPP Employee Stock Purchase Plan
FAC Fuel adjustment clause
FASB Financial Accounting Standards Board
FERC Federal Energy Regulatory Commission
FERC Order FERC Open Access Order No. 888 issued in April 1996
GAAP Generally Accepted Accounting Principles
ICC Illinois Commerce Commission
IDR Illinois Department of Revenue
Indiana Company Commonwealth Edison Company of Indiana, Inc., a ComEd subsidiary
INPO Institute of Nuclear Power Operations
ISO Independent System Operator
MAIN Mid-America Interconnected Network
MGP Manufactured gas plant
NEI Nuclear Electric Institute
NEIL Nuclear Electric Insurance Limited
NERC North American Electric Reliability Council
NML Nuclear Mutual Limited
NRC Nuclear Regulatory Commission
O&M Operation and maintenance
SEC Securities and Exchange Commission
SFAS Statement of Financial Accounting Standards
SPEs Special purpose entities
S&P Standard & Poor's
Trusts ComEd Financing I and ComEd Financing II, ComEd subsidiaries
Trust Securities Company-obligated mandatorily redeemable preferred securities of
subsidiary trusts holding solely the Company's subordinated debt
securities
Unicom Unicom Corporation
Unicom Enterprises Unicom Enterprises Inc., a Unicom subsidiary
U.S. EPA U.S. Environmental Protection Agency
</TABLE>
3
<PAGE>
COMMONWEALTH EDISON COMPANY AND SUBSIDIARY COMPANIES
Summary of Selected Consolidated Financial Data
<TABLE>
<CAPTION>
1998 1997 1996 1995 1994
------- ------- ------- ------- -------
(Millions Except per Share Data)
<S> <C> <C> <C> <C> <C>
Electric operating revenues.. $ 7,136 $ 7,073 $ 6,935 $ 6,910 $ 6,278
Net income (loss)............ $ 594 $ (774)(1) $ 743 $ 717(2) $ 424
Net income (loss) on common
stock....................... $ 537 $ (834)(1) $ 679 $ 647(2) $ 359
Cash dividends declared per
common share................ $ 1.60 $ 1.60 $ 1.60 $ 1.60 $ 1.60(3)
Total assets (at end of
year)....................... $25,434 $22,458 $23,217 $23,119 $23,076
Long-term obligations at end
of year excluding current
portion:
Long-term debt, preference
stock and preferred
securities subject to
mandatory redemption
requirements............... $ 8,097 $ 6,087 $ 6,376 $ 6,950 $ 7,745
Accrued spent nuclear fuel
disposal fee and related
interest................... $ 728 $ 693 $ 657 $ 624 $ 590
Capital lease obligations... $ 334 $ 438 $ 475 $ 374 $ 431
Other long-term obligations. $ 2,953 $ 3,177 $ 1,983 $ 1,819 $ 1,754
</TABLE>
- --------
(1) Includes an extraordinary loss for the write-off of generation-related net
regulatory assets of $810 million (after-tax), the loss on the early
retirement of Zion nuclear generating station of $523 million (after-tax)
and the positive impact of a one-time cumulative effect for a change in
accounting principle for revenue recognition of $197 million (after-tax).
(2) Includes an extraordinary loss related to the early redemption of long-term
debt of $20 million (after-tax).
(3) Excludes a special dividend (consisting of $40 million cash and the common
stock of Unicom Enterprises) effected on September 1, 1994 in connection
with the holding company corporate restructuring.
Cash Dividends Paid per Share of Common Stock
<TABLE>
<CAPTION>
1998 (by quarters) 1997 (by quarters)
------------------------- -------------------------
Fourth Third Second First Fourth Third Second First
------ ----- ------ ----- ------ ----- ------ -----
<S> <C> <C> <C> <C> <C> <C> <C> <C>
Cash dividends paid......... 40c 40c 40c 40c 40c 40c 40c 40c
</TABLE>
1998 Consolidated Revenues and Sales
<TABLE>
<CAPTION>
Electric % Increase/ %
Operating (Decrease) Kilowatthour Increase/ %
Revenues Over Sales (Decrease) Increase
(Thousands) 1997 (Millions) Over 1997 Customers Over 1997
----------- ----------- ------------ ---------- --------- ---------
<S> <C> <C> <C> <C> <C> <C>
Residential............. $2,551,741 -- % 23,942 8.1% 3,134,490 0.4%
Small commercial and
industrial............. 2,187,532 1.6 27,005 4.4 304,208 4.5
Large commercial and
industrial............. 1,406,720 (4.1) 24,043 (0.1) 1,794 14.6
Public authorities...... 510,185 0.8 7,472 2.0 14,049 15.4
Electric railroads...... 31,022 4.2 433 3.6 3 50.0
---------- ------ ---------
Ultimate consumers..... $6,687,200 (0.3) 82,895 3.8 3,454,544 0.8
Provision for revenue
refunds................ (21,848) (52.1) -- -- -- --
---------- ------ ---------
Net ultimate consumers. $6,665,352 -- 82,895 3.8 3,454,544 0.8
Sales for resale........ 397,157 18.0 14,744 (6.0) 62 21.6
Other revenues.......... 73,371 0.6 -- -- -- --
---------- ------ ---------
Total.................. $7,135,880 0.9 97,639 2.2 3,454,606 0.8
========== ====== =========
</TABLE>
4
<PAGE>
MANAGEMENT'S DISCUSSION AND ANALYSIS OF
FINANCIAL CONDITION AND RESULTS OF OPERATIONS
Changes in the Electric Utility Industry
Unicom and its predominant business, electric energy generation,
transmission and distribution, are in a period of fundamental change. These
changes are attributable to changes in technology and regulation. Federal law
and regulations have been amended to provide for open transmission system
access, and various states, including Illinois, are considering, or have
adopted, new regulatory structures to allow access by some or all customers to
energy suppliers, in addition to the local utility.
Electric Utility Industry. The electric utility industry historically has
consisted of vertically integrated companies which combine generation,
transmission and distribution assets; serve customers within relatively
defined service territories; and operate under extensive regulation with
respect to rates, operations and other matters. Utilities have operated under
a regulatory compact with the state, with a statutory obligation to serve all
of the electricity needs within their service territory in a nondiscriminatory
manner. Historically, investment and operating decisions have been made based
upon the utilities' respective assessment of the current and projected needs
of their customers. In view of this obligation, regulation has focused on
investment and operating costs, and rates have been based on a recovery of
some or all of such prudently incurred costs plus a return on invested
capital. Such rate regulation, and the ability of utilities to recover
investment and other costs through rates, have provided the basis for
recording certain costs as regulatory assets. These assets represent costs
which are allocated over future periods reflecting related regulatory
treatment, rather than expensed in the current period.
Federal Regulation. The Federal Energy Policy Act of 1992, among other
things, empowered FERC to introduce a greater level of competition into the
wholesale marketplace for electric energy. Under the FERC Order, utilities are
required to file open access tariffs with regard to their transmission
systems. These tariffs set forth the terms, including prices, under which
other parties and the utility's wholesale marketing function may use the
utility's transmission system. ComEd has an approved open access tariff with
the FERC. The FERC Order requires the separation of the transmission
operations and wholesale marketing functions so as to ensure that unaffiliated
third parties have access to the same information as to system availability
and other requirements. The FERC Order further requires utilities to operate
an electronic bulletin board to make transmission price and access data
available to all potential users. A key feature of the FERC Order is that it
contemplates full recovery of a utility's costs "stranded" by competition.
These costs are "stranded" or "strandable" to the extent market-based rates
would be insufficient to allow for their full recovery. To recover stranded
costs, the utility must show that it had a reasonable expectation that it
would continue to serve the customer in question under its regulatory compact.
In addition, some governmental entities, such as cities, may elect to
"municipalize" a utility's distribution facilities through condemnation
proceedings. Such municipalities would then be able to purchase electric power
on a wholesale basis and resell it to customers over the newly acquired
facilities. The FERC Order provides for the recovery of a utility's investment
stranded by municipalization.
The 1997 Act. In December 1997, the Governor of Illinois signed into law the
1997 Act, which established a phased process to introduce competition into the
electric industry in Illinois under a less regulated structure. Major
provisions of the 1997 Act applicable to ComEd include a 15% residential base
rate reduction which became effective August 1, 1998, an additional 5%
residential base rate reduction commencing on May 1, 2002 and gradual customer
access to other electric suppliers. Access for commercial and industrial
customers will occur over a period from October 1999 to December 2000, and
access for residential customers will occur after May 1, 2002. ComEd's
operating revenues were reduced by approximately $170 million in 1998 due to
the rate reduction. ComEd is engaged in certain pricing experiments
contemplated by the 1997 Act, which reduced ComEd's
5
<PAGE>
operating revenues by approximately $30 million in 1998 and are expected to
reduce operating revenues by $55 million in 1999, compared to 1997 rate
levels; however, such reductions are expected to be offset by the effects of
customer growth. ComEd expects that the 15% residential base rate reduction
will reduce ComEd's operating revenues by approximately $380 million in 1999,
compared to 1997 rate levels.
The 1997 Act also provides for the collection of a CTC from customers who
choose another electric service provider during a transition period that
extends through 2006, and can be extended through 2008 with ICC approval. The
CTC will be established in accordance with a formula defined in the 1997 Act.
The CTC, which will be applied on a cents per kilowatthour basis, considers
the revenue which would have been collected from a customer under tariffed
rates, reduced by the revenue the utility will receive for providing delivery
services to the customer, the market price for electricity and a defined
mitigation factor, which represents the utility's opportunity to develop new
revenue sources and achieve cost savings.
Notwithstanding these rate reductions, and subject to certain earnings
tests, a rate freeze will generally be in effect until at least January 1,
2005. During this period, utilities may reorganize, sell or assign assets,
retire or remove plants from service, and accelerate depreciation or
amortization of assets with limited ICC regulatory review. A utility may
request a rate increase during the rate freeze period only when necessary to
ensure the utility's financial viability, but not before January 1, 2000.
Under the earnings provision of the 1997 Act, if the earned return on common
equity of a utility during this period exceeds an established threshold, one-
half of the excess earnings must be refunded to customers. The threshold rate
of return on common equity is based on the 30-Year Treasury Bond rate, plus
5.5% in the years 1998 through 1999 and plus 6.5% in the years 2000 through
2004. The utility's earned return on common equity and the threshold return on
common equity are each calculated on a two year average basis. The earnings
sharing provision is applicable only to utility earnings. Increased
amortization of regulatory assets may be recorded, thereby reducing the earned
return on common equity, if earnings otherwise would have exceeded the maximum
allowable rate of return. The potential for earnings sharing or increased
amortization of regulatory assets could limit earnings in future periods.
Under the 1997 Act, utilities are required to continue to offer delivery
services, including the transmission and distribution of electric energy, such
that customers who select an alternative energy supplier can receive electric
energy from that supplier using existing transmission and distribution
facilities. Such services will continue to be offered under cost-based,
regulated rates. The 1997 Act also requires utilities to establish or join an
ISO that will independently manage and control utility transmission systems.
Additionally, the 1997 Act includes the leveling of certain regulatory
requirements to permit operational flexibility, the leveling of certain
regulatory and tax provisions as applied to various electric suppliers and a
new, more stringent, liability standard applicable to ComEd in the event of a
major outage. See "Response to Regulatory Changes" below for additional
information.
The 1997 Act also allows a portion of ComEd's future revenues to be
segregated and used to support the issuance of securities by ComEd or a SPE.
The proceeds from such securities issuances must be used to refinance
outstanding debt and equity or for certain other limited purposes. The total
amount of such securities that may be issued is approximately $6.8 billion;
approximately one-half of that amount can be issued in the twelve-month period
which commenced on August 1, 1998. In December 1998, ComEd initiated the
issuance of $3.4 billion of transitional trust notes through its SPEs, ComEd
Funding and ComEd Funding Trust. See "Liquidity and Capital Resources,"
subcaption "Capital Resources" below, and Notes 2, 7 and 24 of Notes to
Financial Statements, for additional information regarding the issuance of
transitional trust notes and the planned use of the proceeds.
6
<PAGE>
As a result of the 1997 Act, prices for the supply of electric energy are
expected to change from cost-based, regulated rates to rates determined by
competitive market forces. The CTC allows ComEd to recover some of its costs
which might otherwise be unrecoverable under market-based rates. Nonetheless,
ComEd will need to take steps to address the portion of such costs which are
not recoverable through the CTC. Such steps may include cost control efforts,
developing new sources of revenue and potential asset dispositions. See
"Response to Regulatory Changes" below for additional information.
See Note 2 of Notes to Financial Statements for the accounting effects
related to the 1997 Act.
Response to Regulatory Changes. Unicom has announced several business and
operational objectives designed to focus efforts in responding to the energy
market changes that are expected to develop from the 1997 Act. These objectives
contemplate that ComEd will seek additional improvements in its transmission
and distribution operations in order to meet customers' expectations for
reliable delivery and will seek to refocus its generation activities, with a
concentration on improved nuclear generation, and that Unicom and ComEd will
seek to expand their offerings of energy-related products and services. See
Unicom and ComEd's Current Report on Form 8-K dated July 6, 1998 for more
information regarding the objectives announced by Unicom.
Under the 1997 Act, the role of electric utilities in the supply and delivery
of energy is expected to change. Utilities, such as ComEd, traditionally have
been responsible for providing both adequate supply and reliable delivery of
electricity to customers within their service areas. In the future, ComEd will
continue to be obligated to provide a reliable delivery system. However, ComEd
will be obligated to supply electricity only to those customers that it
continues to serve under tariffs for electricity, but not to those customers
who choose to rely on the marketplace. Nonetheless, during the transition
period to a competitive supply marketplace, ComEd must provide both an adequate
supply and reliable delivery of electricity. Given the tight capacity situation
in ComEd's market, ComEd will continue working to restore and maintain its
available capacity, as well as working to assist in the development of a
competitive supply marketplace in Illinois.
ComEd has a significant commitment to, and investment in, nuclear generating
capacity. ComEd has installed a new management team responsible for improving
nuclear operations. Such improvements are aimed at increasing levels of energy
generation, or capacity factors, at ComEd's nuclear generating units while
simultaneously improving ComEd's record of meeting NRC requirements and INPO
performance standards. Increased capacity factors generally result in lower
unit production costs and an improved opportunity to generate and sell
electricity in a competitive marketplace. Efforts are also being made to
control capital and operating costs through increased efficiencies, such as the
reduction of downtime and expense associated with generating unit maintenance
and refueling outages.
ComEd also evaluated the recoverability of its generating plant investment as
a result of the 1997 Act. This evaluation, based upon interpretative guidance
issued by the SEC, resulted in a conclusion that the investment was impaired
and should be reduced. See Note 2 of Notes to Financial Statements for
additional information. Notwithstanding these efforts, there continues to be an
ongoing analysis of the ability of ComEd's various nuclear plants to generate
and deliver electric energy safely at competitive prices in the competitive
market for energy. Although short-term system reliability and capacity
constraints are likely to support the continued operation of ComEd's nuclear
units in the near term, expected longer term developments are likely to make
decision-making a function of economic considerations. In the absence of short-
term reliability and capacity constraints, if a generating plant cannot produce
power safely at a cost below the competitive market price, it will be disposed
of or closed. Plant impairment adjustments have reduced the carrying value of
nuclear plants, and depreciation rates reflecting shortened estimated useful
lives for certain stations will reduce the
7
<PAGE>
carrying value further during the next several years. However, closure of a
plant could involve additional charges associated with the write-off of its
then-current carrying value. In January 1998, ComEd announced its decision to
permanently cease nuclear generating operations at its Zion Station. The
related retirement resulted in a charge in 1997 of $523 million (after-tax)
reflecting both a write down of the plant's carrying value and a liability for
future closing costs. A portion of Zion Station is used to provide voltage
support in the transmission system that serves ComEd's northern region. See
Note 5 of Notes to Financial Statements for additional information.
ComEd is also undertaking steps to offer for sale approximately 9,700
megawatts of fossil generating capacity, representing seven fossil-fired
generating stations, and the oil and gas peaking units located in Illinois.
Such plants have an aggregate book value of approximately $1.3 billion. As a
part of such sales, ComEd expects to enter into transitional power purchase
agreements with the purchasers in order to assure the availability of power
during the period that the competitive market for electric generation is
developing in Illinois. Non-binding proposals from prospective qualified
buyers were received in late 1998, with final, binding proposals due in the
first quarter of 1999. The closing of the sale is anticipated for the fourth
quarter of 1999. Any net gain on the sale of the stations will be offset in
large part by increased amortization of the regulatory asset for impaired
production plant and therefore is not expected to have a material impact on
results of operations. In addition, ComEd continues to examine its other
operations and assets with a view to rationalizing their investment and
operating costs against their ability to contribute to the revenues and
profits of ComEd. As a result of such evaluation, additional asset sales may
be undertaken.
In response to customer expectations and more stringent reliability
standards provided for by the 1997 Act, ComEd's Board of Directors approved a
$307 million increase in capital expenditures on its transmission and
distribution systems over the next three years. See "Liquidity and Capital
Resources," subcaption "Construction Program" below, for additional
information regarding capital spending for the transmission and distribution
systems.
ComEd joined with other Midwestern utilities in the formation of a regional
Midwest ISO in January 1998. Presently, a number of these utilities have
agreed to place their transmission systems under the control of the Midwest
ISO. The Midwest ISO is a key element in accommodating the restructuring of
the electric industry and will promote enhanced reliability of the
transmission system, equal access to the transmission system and increased
competition. The Midwest ISO has established an independent body that will
ultimately direct the planning and operation of the transmission system for
the utilities involved. The Midwest ISO will have operational control over the
transmission system and will have authority to require modification in the
operation of generators connected to that system during system emergencies.
ComEd will retain ownership of its transmission system. The formation of the
Midwest ISO was approved by FERC in September 1998, subject to certain
conditions. The ISO members elected the Midwest ISO Board of Directors in
December 1998.
Liquidity and Capital Resources
Construction Program. ComEd has a construction program for the years 1999-
2001, which consists principally of improvements to its existing nuclear and
other electric production, transmission and distribution facilities. The
program, as currently approved by ComEd, includes the following estimated
expenditures (excluding nuclear fuel expenditures of approximately $676
million):
<TABLE>
<CAPTION>
1999 2000 2001
------ ---- ----
(Millions of Dollars)
<S> <C> <C> <C>
Production.............................................. $ 420 $264 $233
Transmission and Distribution........................... 515 527 529
General................................................. 109 83 80
------ ---- ----
$1,044 $874 $842
====== ==== ====
</TABLE>
8
<PAGE>
This program includes an increase in capital expenditures on transmission
and distribution systems of approximately $307 million over the next three
years, in addition to the estimated $1.3 billion previously planned to be
spent on these systems over the same time period. A significant portion of
such additional expenditures is intended to increase the reliability of
ComEd's distribution system by replacing certain equipment and increasing
automation to identify distribution problems faster and more quickly restore
power to customers.
ComEd's forecasts of peak load indicate a need for additional resources to
meet demand, either through generating capacity, equivalent purchased power
and/or the development of additional demand-side management resources, in 1999
and each year thereafter for the foreseeable future. However, ComEd believes
that adequate resources, including cost-effective, demand-side management
resources, non-utility generation resources and other-utility power purchases,
can be obtained in sufficient quantities to meet such forecasted needs.
Purchase commitments for ComEd, principally related to construction and
nuclear fuel, approximated $335 million at December 31, 1998. In addition,
ComEd's estimated commitments for the purchase of coal are as follows:
<TABLE>
<CAPTION>
Contract Period Commitment (1)
-------------- --------- --------------
<S> <C> <C>
Black Butte Coal Co................................ 1999-2000 $434
Decker Coal Co..................................... 1999-2014 478
Other commitments.................................. 1999-2000 38
----
$950
====
</TABLE>
--------
(1) In millions of dollars, excluding transportation costs. No estimate of
future cost escalation has been made.
For additional information concerning these coal contracts, see Note 22 of
Notes to Financial Statements. See "Changes in the Electric Utility Industry,"
subcaption "Response to Regulatory Changes" above, for additional information.
Capital Resources. In December 1998, ComEd initiated the issuance of $3.4
billion of transitional trust notes through its SPEs, ComEd Funding and ComEd
Funding Trust. The proceeds from the transitional trust notes, net of
transaction costs, must be used to redeem or repurchase debt and equity to
lower ComEd's overall cost of capital. Accordingly, in early 1999 ComEd
redeemed $788 million of long-term debt and $534 million of preference stock,
and reacquired $229 million of outstanding long-term debt through a tender
offer. In addition, $500 million of the proceeds, of which approximately $300
million has been utilized, is being used to reduce ComEd's outstanding short-
term debt. As more fully described below, Unicom has announced plans to
repurchase approximately $750 million of Unicom common stock using the
proceeds it receives from ComEd's repurchase of its common stock held by
Unicom. The remaining proceeds will be used for the payment of fees and
additional debt and equity redemptions and repurchases.
ComEd has entered into a prepaid forward purchase arrangement with Unicom
for the repurchase of approximately 15 million shares of ComEd common stock.
The repurchase arrangement provides for final settlement no later than
February 2000, on either a physical (share) basis, or a net cash basis. The
terms of the repurchase agreements between ComEd and Unicom are identical to
the terms of Unicom's repurchase agreements with the financial institutions.
The repurchase agreements between ComEd and Unicom are expected to be settled
on the same basis Unicom settles its repurchase agreements with the financial
institutions. The amount at which the arrangement can be settled is dependent
principally upon the average market price at which Unicom's common shares have
been repurchased under its repurchase agreements, compared to the forward
price per share. The share repurchases will not reduce shares outstanding or
reduce common stock equity and resulting return on common equity calculations
until the date of physical settlement. ComEd currently does not anticipate
that settlement will occur in 1999. The repurchase arrangement will initially
be recorded as a receivable on ComEd's Consolidated Balance Sheets and will be
adjusted at the end of each
9
<PAGE>
reporting period to reflect the aggregate market value of the shares
deliverable under the arrangement. Consequently, the arrangement could increase
earnings volatility in 1999.
This arrangement supplements a previously announced program to repurchase up
to $200 million of ComEd common stock. Shares repurchased under that program
will also be outstanding for financial statement purposes until the time of
physical settlement, which is currently expected to extend to February 2000, on
either a physical (share) basis, or a net cash basis, at the option of ComEd.
As of December 31, 1998, this arrangement has been accounted for as an equity
instrument. If this arrangement had been settled on a physical (share) basis at
December 31, 1998, ComEd would have received approximately 5.1 million shares
of its common stock.
See Note 24 of Notes to Financial Statements for additional information
regarding the redemptions and repurchases of debt and equity.
ComEd forecasts that internal sources will provide approximately three-
fourths of the funds required for ComEd's 1999 construction program and other
capital requirements, including nuclear fuel expenditures, contributions to
nuclear decommissioning funds, sinking fund obligations and scheduled debt
maturities. See Notes 10 and 12 of Notes to Financial Statements for the
summaries of the annual sinking fund requirements and scheduled maturities for
ComEd preference stock and long-term debt, respectively. The forecast takes
into consideration the effects of the 1997 Act and the issuance by ComEd
Funding Trust of $3.4 billion of transitional trust notes in 1998 to refinance
debt and equity, as discussed above.
The type and amount of external financing will depend on financial market
conditions and the needs and capital structure of ComEd at the time of such
financing. A portion of ComEd's financing may be provided through the continued
sale and leaseback of nuclear fuel through ComEd's existing nuclear fuel lease
facility. During 1998, ComEd sold and leased back $101 million of nuclear fuel
through its existing nuclear fuel lease facility. See Note 20 of Notes to
Financial Statements for additional information concerning ComEd's nuclear fuel
lease facility. In July 1998, ComEd issued $225 million principal amount of
6.95% Notes due July 15, 2018, the proceeds of which were used for general
corporate purposes, including the refinancing of existing debt. ComEd has $1
billion of unused bank lines of credit at December 31, 1998, which may be
borrowed at various interest rates. The interest rate is set at the time of a
borrowing and is based on floating rate bank indices plus a spread, which is
dependent upon the credit ratings of ComEd's outstanding first mortgage bonds
or on a prime interest rate. See Note 13 of Notes to Financial Statements for
information concerning lines of credit. See the Statements of Consolidated Cash
Flows for the construction expenditures and cash flow from operating activities
for the years 1998, 1997 and 1996. Cash flow from operating activities
decreased temporarily for the year 1998, compared to the previous two years, as
a result of an increase in customer receivables due to the transition to a new
customer information and billing system in the latter part of 1998.
As of February 19, 1999, ComEd has an effective "shelf" registration
statement with the SEC for the future sale of up to an additional $280 million
of debt securities and cumulative preference stock for general corporate
purposes of ComEd, including the discharge or refund of other outstanding
securities.
ComEd's securities and other securities guaranteed by ComEd are currently
rated by three principal securities rating agencies as follows:
<TABLE>
<CAPTION>
Standard Duff &
Moody's & Poor's Phelps
------- -------- ------
<S> <C> <C> <C>
First mortgage and secured pollution control
bonds........................................... Baa2 BBB BBB
Publicly-held debentures and unsecured pollution
control obligations............................. Baa3 BBB- BBB-
Convertible preferred stock...................... baa3 BB+ BBB-
Preference stock................................. baa3 BB+ BBB-
Trust Securities................................. baa3 BB+ BBB-
Commercial paper................................. P-2 A-2 D-2
</TABLE>
10
<PAGE>
ComEd Funding Trust's securities are currently rated by three principal
securities rating agencies as follows:
<TABLE>
<CAPTION>
Standard Duff &
Moody's & Poors Phelps
------- -------- ------
<S> <C> <C> <C>
Transitional trust notes.......................... Aaa AAA AAA
</TABLE>
As of January 1999, Moody's rating outlook on ComEd's securities is "Stable"
and S&P's rating outlook is "Positive." Duff & Phelps removed ComEd's
securities from "Rating Watch-Down" in September 1998.
In February 1999, S&P revised the general ratings scale for evaluating
preferred and preference stock issues of corporations. As a result of this
change in scale, ratings on ComEd's preferred and preference stocks, and Trust
Securities were lowered in February 1999.
Capital Structure. The ratio of long-term debt to total capitalization
increased to 58.0% at December 31, 1998 from 48.5% at December 31, 1997. The
increase is primarily due to the issuance of $3.4 billion of transitional
trust notes in late December, which had not been applied to redeem long-term
debt and equity as of December 31, 1998. Excluding the effect of the
transitional trust notes, ComEd's ratio of long-term debt to total
capitalization was 45.5% at December 31, 1998. ComEd does not expect the
issuance of the transitional trust notes to adversely affect security ratings
of other outstanding securities. ComEd's retained earnings account had a
positive balance of $177 million at December 31, 1998 and a deficit balance of
$19 million at December 31, 1997. As of December 31, 1998 and 1997, $580
million and $384 million, respectively, of retained earnings had been
appropriated for future dividend payments.
Year 2000 Conversion. Unicom, including ComEd, uses various software
applications and embedded systems throughout its businesses that will be
affected by so-called "Year 2000 issues." These issues may prevent an
application or system from correctly processing dates up to the year 2000 and
beyond. A failure to correct any critical Year 2000 processing problems prior
to January 1, 2000 could have material adverse operational and financial
consequences if the affected systems either cease to function or produce
erroneous data. At this time, Unicom believes the major risks associated with
the inability of systems and software to process Year 2000 data correctly are
a system failure or miscalculation causing disruption of operations, including
among other things, an inability to operate ComEd's nuclear or fossil
generating plants, disruption in the operation of its transmission and
distribution systems or an inability to access interconnections with the
systems of neighboring utilities. Such failures could materially and adversely
affect Unicom's results of operations, financial position and cash flows.
Unicom management established a Year 2000 project team to address Year 2000
issues. The Year 2000 project team is currently composed of over 300 members,
including members of Unicom's senior management. The team is focused on three
elements that are integral to the project: business continuity, project
management and risk management. Business continuity involves the continuation
of reliable electric supply and service in a safe, cost-effective manner.
Project management involves defining and meeting the project scope, schedule
and budget. Risk management involves customer communications, contingency
planning and legal issues.
In addition to its internal efforts, Unicom is working with various industry
groups, including NERC, EPRI and EEI to coordinate electric utility industry
Year 2000 efforts with the Clinton Administration's Year 2000 Conversion
Council, the DOE and Congress. The DOE has asked NERC to report on the
integrity of the transmission system for North America and to coordinate and
assess the preparation of the electric systems in North America for the Year
2000. NERC submitted its initial status report and coordination plan to the
DOE in September 1998 and a second report in January 1999; a full status
report is due by July 1999.
Since July 1996, Unicom has been working to identify and address Year 2000
issues. Unicom's approach to identifying and addressing noncompliant software
applications and embedded systems consists of the following stages: inventory,
analysis, renovation, testing and deployment. The first stage
11
<PAGE>
is to inventory all applications and systems. The analysis stage involves
assessing whether software applications and embedded systems are Year 2000
compliant. The renovation stage involves remediating or upgrading applications
and systems to make them Year 2000 ready. The testing stage determines whether
the renovated applications and systems are Year 2000 ready. The deployment
stage is when the tested applications and systems are implemented. In
addition, Unicom is engaged in contingency planning for Year 2000 problems.
Unicom is developing contingency plans to address the possibility that the
applications and systems may not be Year 2000 ready at the end of this
process. An independent consultant has been engaged to assist Unicom in the
assessment of the process being used to address the Year 2000 issue.
Unicom's Year 2000 project focuses on those facets of its business that are
required to deliver reliable electric service. The project encompasses the
computer systems that support core business functions such as customer
information and billing, finance, procurement, supply and personnel as well as
the components of metering, transmission, distribution and generation support.
The project also focuses on embedded systems, instrumentation and control
systems in facilities and plants. In accordance with business plans, Unicom
has replaced certain of its financial, human resources and customer service
and billing software, and is in the process of replacing its payroll system,
with new software that is Year 2000 compliant, and that addresses Unicom's
strategic needs as it enters a less regulated environment.
The following table summarizes the status as of February 5, 1999 of Unicom's
progress toward achieving Year 2000 readiness. The figures set forth in the
table represent the estimated extent to which Unicom has completed each phase
of the Year 2000 project for software applications and embedded systems.
<TABLE>
<CAPTION>
Software Embedded
Applications Systems
------------ --------
<S> <C> <C>
Inventory........................................... 100% 100%
Analysis............................................ 93% 96%
Renovation.......................................... 87% 74%
Testing............................................. 79% 46%
Deployment.......................................... 78% 91%
</TABLE>
The renovation and testing phases include only those software applications
and embedded systems which are not Year 2000 compliant, and require renovation
and testing. The deployment phase includes all inventoried applications and
systems, including those applications and systems that are Year 2000 compliant
and required no renovation or testing. Accordingly, the percentage of
completion for testing and renovation may be lower than the percentage of
completion for deployment.
The following is a brief summary of estimates of the progress of the Year
2000 project and certain projected completion dates in each of Unicom's four
critical business areas--nuclear generation, fossil generation, transmission
and distribution, and corporate information services:
. Nuclear Generation--Software applications analysis is 65% complete and
embedded systems analysis is 98% complete. Testing of software
applications is 36% complete and 55% complete for embedded systems.
Deployment of software applications is 23% complete and embedded systems
are 85% complete. All ten operating nuclear units are expected to be Year
2000 ready by June 30, 1999.
. Fossil Generation--Analysis is 100% complete for software applications
and 96% complete for embedded systems. Testing of software applications
is 63% complete and 4% complete for embedded systems. Deployment of
software applications is 80% complete and embedded systems are 97%
complete and both are expected to be completed by June 30, 1999.
. Transmission and Distribution--Analysis is 100% complete for software
applications and 98% complete for embedded systems. Testing of software
applications is 89% complete and 97% complete for embedded systems.
Deployment of software applications is 89% complete and 97% complete for
embedded systems. Deployment of software applications and embedded
systems is expected to be completed by June 30, 1999.
12
<PAGE>
. Corporate Information Services--Inventory and analysis are 100% complete.
Renovation, testing and deployment are 99% complete. Enterprise-wide
mainframe applications and systems are 100% complete.
Unicom's current schedule is subject to change, depending on developments
that may arise through unforeseen business circumstances, and through the
remediation and testing phases of its compliance effort. Unicom also depends
upon third parties, including customers, suppliers, government agencies and
financial institutions, to reliably deliver its products and services. Unicom
has implemented additional initiatives to assess the degree to which third
parties with whom it has business relationships are addressing Year 2000
issues. These initiatives include analysis of the Year 2000 compliance
programs of Unicom's critical vendors and obtaining Year 2000 warranties in
certain new contracts and licenses. Unicom also has introduced protocols for
assuring that software and embedded systems remain Year 2000 compliant on a
continuing basis. Unicom's contingency planning is addressing mechanisms for
preventing or mitigating interruption caused by its suppliers. Unicom also has
an outreach program in place for communicating Year 2000 project information
to residential and business customers.
Unicom estimates that the total cost of remediating or upgrading software
which would not otherwise be replaced in accordance with its business plans is
approximately $20 million, and the total cost of remediating or upgrading
embedded systems is approximately $20-$40 million. Approximately $26 million
has been expended as of December 31, 1998 for external labor, hardware and
software costs, and for the costs of Unicom employees who are dedicated full-
time to the Year 2000 project. All of such costs are expensed as incurred. The
foregoing amounts do not include the cost of new software applications
installed as a result of strategic replacement projects described earlier.
Such replacement projects were not accelerated because of Year 2000 issues.
The cost of the project and the dates on which Unicom plans to complete its
Year 2000 modifications are based on management's best estimates, which were
derived utilizing numerous assumptions of future events, including the
continued availability of certain resources, third parties' Year 2000
readiness and other factors. Further, Unicom expects to incur additional costs
after 1999 to remediate and replace less critical software applications and
embedded systems.
Unicom has existing contingency plans in place for events such as extreme
heat, storms, equipment failures and accidents. Unicom is preparing Year 2000
contingency plans based on the framework of existing emergency management
system preparation and scenario development.
Unicom has begun the process of developing contingency plans to address the
most reasonably likely worst case scenarios that could occur in the event that
various Year 2000 issues are not resolved in a timely manner. Unicom submitted
the first draft of contingency plans to NERC prior to December 31, 1998, as
NERC requested. In addition, the first draft contingency plans were also
submitted to MAIN. Final plans are due to be submitted to NERC by June 30,
1999. Contingency planning is an ongoing process and will continue through the
fourth quarter of 1999.
Unicom is using an approach in its contingency planning process that has
been recognized by NERC and NEI. The phases of the process include: business
impact analysis, contingency planning and testing. Unicom's business impact
analysis requires business unit personnel to evaluate the impact of mission-
critical systems failures on Unicom's core business operations, focusing on
specific failure scenarios and how they can be mitigated. The necessary
conditions for enacting the plans will be documented along with the
appropriate personnel responsible in each of the business units should a Year
2000 failure occur. Additionally, Unicom will participate in the NERC
industry-wide readiness drills scheduled for the spring and fall of 1999.
Based on Unicom's current schedule for completion of Year 2000 tasks, it
believes that its planning is adequate to secure Year 2000 readiness of its
critical systems. Nevertheless, achieving Year 2000 readiness is subject to
various risks and uncertainties, many of which are described above.
13
<PAGE>
Unicom is not able to predict all the factors that could cause actual results
to differ materially from its current expectations as to its Year 2000
readiness. However, if Unicom or third parties with whom it has significant
business relationships fail to achieve Year 2000 readiness with respect to
critical systems, there could be a material adverse effect on Unicom's results
of operations, financial position and cash flows.
Market Risks. ComEd is exposed to market risk due to changes in interest
rates and the market price for electricity. Exposure for interest rate changes
relates to its long-term debt and preferred equity obligations. Exposure to
electricity market price risk relates to forward activities taken to manage
effectively the supply of, and demand for, the electric generation capability
of ComEd's generating plants. ComEd has implemented an integrated risk
management framework to manage such risks. A corporate Risk Management
Committee defines the Company's risk tolerance and establishes appropriate
position limits, and corporate policies and procedures have been implemented
to minimize the exposure to market risk. ComEd does not currently utilize
derivative commodity or financial instruments for trading or speculative
purposes. See "Energy Risk Management Contracts" in Note 1 of Notes to
Financial Statements regarding the accounting for energy risk management
contracts.
Interest Rate Exposure. The table below provides the fair value and average
interest or fixed dividend rates of ComEd's outstanding debt and preferred
stock equity instruments as of December 31, 1998, excluding the January and
February redemptions of long-term debt and preference stock. See Note 24 of
Notes to Financial Statements for additional information on the redemptions.
<TABLE>
<CAPTION>
Expected Maturity Date Fair Value
ComEd and Subsidiary ---------------------------------------- as of
Companies (millions) 1999 2000 2001 2002 2003 Thereafter Total 12/31/98
- -------------------- ---- ---- ---- ---- ---- ---------- ------ ----------
<S> <C> <C> <C> <C> <C> <C> <C> <C>
Long-Term Debt--
Fixed Rate............. $151 $460 $ 6 $305 $105 $3,931 $4,958 $5,332
Average Interest Rate.. 8.7% 7.2% 4.3% 7.9% 6.5% 7.8%
Variable Rate.......... $ 92 $ 92 $ 92
Average Interest Rate.. 4.1%
Transitional Trust
Notes................. $330 $350 $340 $340 $340 $1,700 $3,400 $3,450
Average Interest Rate.. 5.4% 5.3% 5.3% 5.4% 5.4% 5.6%
Preferred and Preference
Stock--
Subject to Mandatory
Redemption............ $ 69 $ 69 $ 71
Average Dividend Rate.. 6.9%
Not Subject to Manda-
tory Redemption....... $ 75 $ 75 $ 77
Average Dividend Rate.. 9.9%
Trust Securities........ $ 350 $ 350 $ 371
Average Dividend Rate.. 8.5%
</TABLE>
Market Price Exposure. ComEd's energy purchases from other suppliers have
increased as a result of reductions in owned generating capability and system
load growth. The market price of energy is subject to price volatility
associated with changes in supply and demand in the electric supply markets.
In the normal course of business, ComEd utilizes contracts for the forward
sale and purchase of energy to assure system reliability and manage
effectively the utilization of its available generating capability. ComEd also
utilizes put and call option contracts and energy swap arrangements to limit
the market price risk associated with the forward commodity contracts. The
estimated fair value of the forward energy contracts, including options at
December 31, 1998, was approximately $22 million. The estimated fair value is
based on the estimated net settlement value of the contracts derived from
forward price curves and market quotes, discounted at a 10% rate. A
sensitivity analysis has been performed which indicates that the market price
risk exposure of these financial instruments is not material. Notwithstanding
these price risk management activities, an unexpected loss of generating
capability or reduction in demand could increase ComEd's exposure to market
price risks and could have a material adverse effect on operating results.
14
<PAGE>
Regulation
ComEd and the Indiana Company are subject to federal and state regulation in
the conduct of their respective businesses, including the operations of Cotter.
Such regulation includes rates, securities issuance, nuclear operations,
environmental and other matters. Particularly in the cases of nuclear
operations and environmental matters, such regulation can and does affect
operational and capital expenditures.
Rate Matters. See "Changes in the Electric Utility Industry," subcaption "The
1997 Act" above, for information regarding the effects of the 1997 Act on rate
matters. See "Nuclear Matters" below for information regarding fuel
reconciliation proceedings for the years 1994 and 1996.
Nuclear Matters. Nuclear operations have been, and remain, an important focus
of ComEd--given the impact of such operations on overall O&M expenses and the
ability of nuclear power plants to produce electric energy at a relatively low
marginal cost. ComEd operates five nuclear power plants, ranging from the older
Dresden and Quad Cities Stations to the more recently completed LaSalle, Byron
and Braidwood Stations, and is intent upon safe, reliable and efficient
operation. See "Changes in the Electric Utility Industry," subcaption "Response
to Regulatory Changes" above, for information regarding ComEd's permanent
cessation of nuclear generation operations at its Zion Station.
ComEd's LaSalle Station is currently on the NRC's list of plants that require
increased regulatory scrutiny. Dresden Station had been included on the list
since 1992 and LaSalle and Zion Stations were added in January 1997. In July
1998, the NRC removed Dresden Station from the list because of improved
performance at the station, and also administratively removed Zion Station from
the list because of ComEd's decision to permanently cease further nuclear
operations at that plant. The listing of LaSalle Station does not prevent ComEd
from operating the generating units; however, it does mean that the NRC will
devote additional resources to monitoring ComEd's operating performance and
that ComEd will need to work to demonstrate to the NRC the sustainability of
improvements which it believes it has undertaken and is continuing to
implement. In January 1998, the NRC noted a declining performance trend at Quad
Cities Station. In March 1998, the NRC stated that weaknesses were observed
with respect to certain operations, maintenance and engineering activities at
Quad Cities Station. In July 1998, the NRC stated that there has not been
sufficient operational data to enable it to assess Quad Cities Station's
performance. The NRC indicated that it is monitoring ComEd's ability to manage
its nuclear operations in their entirety and that the performance at any one
facility will be viewed by the NRC in context with the performance of ComEd's
nuclear generating fleet as a whole. The NRC and representatives of ComEd's
management have met, and will continue to meet periodically in the future, to
discuss the status of recovery and restart efforts and overall performance of
the ComEd nuclear program.
ComEd has devoted, and intends to continue to devote, significant resources
to the management and operations of its nuclear generating stations. In recent
years, it has increased and reinforced the Nuclear Generation Group executive
leadership and station management with executives and managers drawn from other
utilities that have resolved similar operational and performance issues. These
efforts include the appointment of a new Chief Nuclear Officer in late 1997.
ComEd has also sought to identify, anticipate and address operating and
performance issues in a safe, cost-effective manner, while seeking to improve
the availability and capacity factors of its nuclear generating units.
ComEd's activities, with respect to its nuclear generating stations, have
included improvements in operating and personnel procedures and repair and
replacement of equipment. Although performing such improvements can result in
longer unit outages, the improvements are expected to result in improved
operational performance when completed. LaSalle Units 1 and 2 were shut down
for extensive improvement work in September 1996. LaSalle Unit 1 was returned
to service in August 1998 after the NRC determined that ComEd had made
sufficient improvements at LaSalle Unit 1 for
15
<PAGE>
the unit to resume operations. LaSalle Unit 2 is expected to restart during
the second quarter of 1999. The restart of LaSalle Unit 2 requires the
resolution of material condition issues similar to those of LaSalle Unit 1.
The NERC forecasted the possibility of electric energy shortages in the
summer of 1998 in light of continued outages at nuclear plants operated by
ComEd and other utilities in the Midwest power grid. ComEd took numerous steps
to support the reliability of its system during the summer of 1998. Such steps
included maximizing available on-system generating capacity during periods of
peak demand, arrangements to purchase power from other utilities,
reinforcements to the transmission systems of ComEd and neighboring utilities
to increase capacity and to provide voltage support, and working with
customers to manage the use of and demand for power. As a result of a unique
combination of heat, storms and equipment problems affecting utilities
throughout the Midwest region, on June 25, 1998, ComEd declared a NERC
generation deficiency alert Level 3, which is a statement that firm load loss
is possible. No firm load losses were experienced in 1998. See "Results of
Operations," subcaption "Purchased Power" below, regarding the increased
purchased power expense in 1998.
Generating station availability and performance during a year have been
issues in fuel reconciliation proceedings in assessing the prudence of fuel
and purchased power costs during such year. Final ICC orders have been issued
in fuel reconciliation proceedings related to ComEd's FAC collections for all
years except for 1994. On November 5, 1998, the ICC issued an order in the
proceeding for the year 1994 providing for a refund of approximately $3
million related to nuclear station performance. On February 9, 1999, an
intervenor moved to dismiss its appeal of the 1994 ICC order. On December 29,
1998, the ICC issued an order for the 1996 fuel reconciliation proceeding
requiring ComEd to refund approximately $19 million related to nuclear station
performance. The 1997 Act provides that, because ComEd eliminated its FAC
effective January 1, 1997, the ICC shall not conduct a fuel reconciliation
proceeding for the year 1997 and subsequent years.
Based on ComEd's most recent study approved by the ICC, decommissioning
costs, including the cost of decontamination and dismantling, are estimated to
aggregate to $4.6 billion in current-year (1999) dollars, including a
contingency allowance. ComEd estimates that it will expend approximately $11.6
billion, including a contingency allowance, for decommissioning costs
primarily during the period from 2007 through 2034. Additionally, ComEd
estimates that it will expend an aggregate of approximately $226 million in
current-year (1999) dollars during the period 2000 through 2014 to maintain
Zion Station in a secured mode until decommissioning begins. All such costs
are expected to be funded by external decommissioning trusts, which ComEd
established in compliance with Illinois law and into which ComEd has been
making annual contributions. Future decommissioning cost estimates may be
significantly affected by the adoption of or changes to NRC regulations, as
well as changes in the assumptions used in making such estimates, including
changes in technology, available alternatives for the disposal of nuclear
waste and inflation. See Note 1 of Notes to Financial Statements, under
"Depreciation, Amortization of Regulatory Assets and Decommissioning," for
additional information regarding decommissioning costs.
Environmental Matters. ComEd is involved in administrative and legal
proceedings concerning air quality, water quality and other matters. The
outcome of these proceedings may require increases in future construction
expenditures and operating expenses, and changes in operating procedures. See
Note 22 of Notes to Financial Statements for additional information.
Results of Operations
ComEd's operating results for 1998, 1997 and 1996 were as follows:
<TABLE>
<CAPTION>
1998 1997 1996
-------- --------- --------
(Thousands of Dollars)
<S> <C> <C> <C>
Net Income (Loss) before Extraordinary Item and
Cumulative Effect of Change in Accounting
Principle..................................... $594,206 $(160,138) $743,368
======== ========= ========
Net Income (Loss) on Common Stock.............. $537,322 $(834,259) $678,944
======== ========= ========
</TABLE>
16
<PAGE>
Net Income on Common Stock for the Year 1998. The increase in earnings for
1998 was primarily due to increased kilowatthour sales, which increased both
operating revenues and energy costs, reduced O&M expenses, lower depreciation
and amortization expenses, lower than expected Zion Station closing costs and
gains on the sales of certain assets. In December 1997, ComEd discontinued
regulatory accounting practices for the generation portion of its business and
recorded other non-recurring accounting charges as a result of the 1997 Act,
which are primarily attributable to the loss for 1997. The 1997 operating
results also include the write-off for the closure of Zion nuclear generating
station, partially offset by a cumulative one-time positive impact of $197
million (after-tax) for a change in accounting method for revenue recognition
to record ComEd's revenues associated with service which has been provided to
customers but has not yet been billed at the end of each accounting period,
retroactive to January 1, 1997.
Kilowatthour sales increased 2% for the year 1998, compared to 1997, driven
largely by increased sales to retail customers due to warmer weather
experienced during the recent year, as well as continued economic growth in
ComEd's service territory. Operating revenues increased 1% during 1998,
compared to 1997. See "Operating Revenues" below for additional information.
Fuel and purchased power costs increased 15% in 1998, compared to the year
1997, reflecting increased demand for electricity, as well as the effects of
higher purchased power prices. See "Purchased Power" below for additional
information.
O&M expenses decreased 7% for the year 1998, compared to the year 1997, as
discussed in "Operation and Maintenance Expenses" below.
The year 1998 includes a 6% decrease in depreciation and amortization
expenses, as discussed in "Depreciation and Amortization" below, and a $15
million (after-tax) reduction in the estimated liability for closing costs
related to the Zion nuclear generating station, both of which increased
operating results.
Also, 1998 operating results reflect realized gains on the sales of certain
assets of $31 million (after-tax). The sold assets consisted principally of
surplus inventory of emission allowances.
Net Loss on Common Stock for the Year 1997. ComEd's kilowatthour sales,
including sales to wholesale customers, increased 5% during 1997, compared to
1996, as discussed below. In 1997, O&M expenses increased 12%, as discussed
below.
Also, 1997 operating results were reduced by $336 million for increased fuel
and purchased power costs, as discussed below. In addition, a 4% increase in
depreciation expense, primarily due to an increase in certain nuclear plant
depreciation, resulted in a charge of $23 million (after-tax).
ComEd discontinued regulatory accounting practices for the generation
portion of its business in the fourth quarter of 1997 due to the expected
transition of electric generation services to market-based pricing as a result
of the 1997 Act. Accordingly, ComEd's generation-related net regulatory
assets, which represent assets and liabilities properly recorded under
regulatory accounting practices but which would not be recorded under GAAP for
non-regulated entities, were written off, resulting in an extraordinary charge
in 1997 of $810 million (after-tax).
In addition, as permitted under the 1997 Act, ComEd elected to eliminate its
FAC in December 1997, which resulted in a charge in the fourth quarter of 1997
of $44 million (after-tax). The reduction includes $25 million (after-tax) in
net FAC charges billed to its customers in 1997, which were refunded to
customers during the first six months of 1998. The reduction also includes a
write-off of $19 million (after-tax) in underrecovered energy costs that ComEd
would have been entitled to recover if the FAC had remained in effect.
17
<PAGE>
Also, 1997 operating results included the write down of ComEd's investment
in uranium-related properties to reflect costs which are not expected to be
recovered in a competitive market. The write down resulted in a charge in 1997
of $60 million (after-tax).
Partially offsetting the charges to operations for 1997 was a change in the
accounting method for revenue recognition to record ComEd's revenues
associated with service which has been provided to customers but has not yet
been billed at the end of each accounting period, retroactive to January 1,
1997. This change in accounting method had a one-time cumulative positive
impact for years prior to 1997 of $197 million (after-tax).
The year 1997 also included a charge of $523 million (after-tax) reflecting
the write-off of the unrecoverable portion of the cost of ComEd's Zion Station
plant and inventories, and a liability for future closing costs, resulting
from the decision in January 1998 to permanently cease nuclear generation
operations at Zion Station.
Net Income on Common Stock for the Year 1996. The 1996 operating results
reflect, among other factors, a 1% decrease in overall O&M expenses, compared
to 1995, the positive effects of an income tax refund related to prior years
with an increase in operating results of $26 million (after-tax), and a
reduction in real estate taxes with an increase in operating results of $28
million (after-tax). Approximately half of the reduction in real estate taxes
in 1996 is related to the year 1995. The 1996 results also reflect a 9%
reduction in the total interest expense on debt and dividend requirements on
preferred and preference stocks, compared to 1995, largely due to the early
retirement of debt at the end of 1995. In September 1996, the ICC approved
ComEd's request to increase depreciation charges on its nuclear generating
units by $30 million for the year 1996, resulting in a charge of $20 million
(after-tax).
Operating Revenues. ComEd's electric operating revenues reflect revenues
from sales to ultimate consumers (including residential, commercial and
industrial customers within its service territory), revenues from sales for
resale (i.e., sales to wholesale customers, principally other electric
utilities), and revenues from collections under its FAC for years prior to
1997, which were intended to recover variations in ComEd's fuel cost for
generating electric energy and the energy portion of purchased power cost in
relation to the amount included in ComEd's base rates. Operating revenues are
affected by kilowatthour sales and rate levels, kilowatthour sales, in turn,
are affected by weather, the level of economic activity within ComEd's service
area, and off-system or wholesale sales to other utilities. Off-system sales
are affected by a number of factors, including nuclear generating availability
and performance.
In 1998, operating revenues increased $63 million and kilowatthour sales
increased 2%, compared to the year 1997, primarily due to warmer summer
weather experienced in 1998 and continued economic growth in ComEd's service
territory, partially offset by a 15% residential rate reduction and reserves
for various federal and state litigation matters. Operating revenues for 1998
also were reduced by approximately $95 million due to a change in presentation
for certain state and municipal taxes. During 1997, electric operating
revenues increased $139 million, primarily due to a 29% increase in
kilowatthour sales to wholesale customers. Kilowatthour sales to ultimate
consumers during 1997 increased 1%, compared to 1996, reflecting continued
economic growth in ComEd's service territory. Operating revenues in 1997 were
reduced by the provision for revenue refunds of $45 million, including revenue
taxes, related to the elimination of the FAC. Operating revenues increased $25
million in the year 1996, compared to the year 1995, principally reflecting
increased sales to other utilities and increased energy cost recoveries under
ComEd's then effective FAC, although kilowatthour sales to ultimate consumers
were down 1% from the prior year due to the cooler summer weather, compared to
the exceptionally hot summer in the year 1995.
Fuel Costs. Changes in fuel expense for the years 1998, 1997 and 1996
primarily resulted from changes in the average cost of fuel consumed, changes
in the mix of fuel sources of electric energy
18
<PAGE>
generated and changes in net generation of electric energy. Fuel mix is
determined primarily by system load, the costs of fuel consumed and the
availability of nuclear generating units. The cost of fuel consumed, net
generation of electric energy and fuel sources of kilowatthour generation were
as follows:
<TABLE>
<CAPTION>
1998 1997 1996
------ ------ ------
<S> <C> <C> <C>
Cost of fuel consumed (per million Btu):
Nuclear........................................... $0.57 $0.57 $0.53
Coal.............................................. $2.38 $2.28 $2.41
Oil............................................... $3.49 $3.90 $3.41
Natural gas....................................... $2.39 $2.69 $2.75
Average all fuels................................. $1.23 $1.33 $1.17
Net generation of electric energy (millions of
kilowatthours).................................... 83,302 85,861 93,048
Fuel sources of kilowatthour generation:
Nuclear........................................... 65% 57% 67%
Coal.............................................. 30 39 30
Oil............................................... -- -- 1
Natural gas....................................... 5 4 2
------ ------ ------
100% 100% 100%
====== ====== ======
</TABLE>
The decreases in the net generation of electric energy for 1998 and 1997,
compared to the prior years, are primarily due to the sales of State Line and
Kincaid Stations in December 1997 and February 1998, respectively, and lower
nuclear plant availability in 1997. See "Regulation," subcaption "Nuclear
Matters" above, for information regarding outages at certain of ComEd's
nuclear generating stations.
Fuel Supply. Compared to other utilities, ComEd has relatively low average
fuel costs as a result of its reliance predominantly on lower cost nuclear
generation. ComEd's coal costs, however, are high compared to those of other
utilities. ComEd's western coal contracts and its rail contracts for delivery
of the western coal provide for the purchase of certain coal at prices
substantially above currently prevailing market prices, and ComEd has
significant purchase commitments under its contracts. For additional
information concerning ComEd's coal purchase commitments, see "Liquidity and
Capital Resources" above and Note 22 of Notes to Financial Statements. For
additional information concerning ComEd's FAC, see Notes 2 and 4 of Notes to
Financial Statements.
Purchased Power. Amounts of purchased power are primarily affected by system
load, the availability of ComEd's generating units, and the availability and
cost of power from other utilities. Purchased power costs increased $395
million and $255 million in 1998 and 1997, compared to 1997 and 1996,
respectively. The increase in 1998 includes $161 million for the agreements
entered into in connection with the sales of State Line and Kincaid Stations
in December 1997 and February 1998, respectively. The increase in purchased
power costs in 1998 also reflects the effects of an extraordinary combination
of heat, storms and equipment problems experienced throughout the Midwest in
late June 1998 which resulted in unprecedented purchased power price levels.
The increase in 1997 is primarily due to outages at certain of ComEd's nuclear
generating stations. See "Regulation," subcaption "Nuclear Matters" above, for
information regarding outages at certain of ComEd's nuclear generating
stations.
The number and average cost of kilowatthours purchased were as follows:
<TABLE>
<CAPTION>
1998 1997 1996
------ ------ -----
<S> <C> <C> <C>
Kilowatthours (millions).............................. 20,704 16,672 6,129
Cost per kilowatthour................................. 3.84c 2.40c 2.37c
</TABLE>
The market price for electricity is subject to price volatility associated
with changes in supply and demand in the electric supply markets. ComEd
utilizes energy put and call option contracts and energy swap arrangements to
limit market price risk associated with forward commodity contracts.
19
<PAGE>
Operation and Maintenance Expenses. O&M expenses include the expenses
associated with operating and maintaining ComEd's generation, transmission and
distribution assets, as well as administrative overhead and support. Given the
variety of expense categories covered, there are a number of factors which
affect the level of such expenses within any given year. Two major components
of such expenses; however, are the costs associated with operating and
maintaining ComEd's nuclear and fossil generating facilities. Generating
station expenses are affected by the cost of materials, regulatory
requirements and expectations, the age of facilities, as well as cost control
efforts.
During the three years presented in the financial statements, the aggregate
level of O&M expenses decreased 7% in 1998 compared to 1997, increased 12% in
1997 compared to 1996, and decreased 1% in 1996 compared to 1995. The year to
year variations reflect increasing efforts in 1997 and 1996 to improve nuclear
generating station availability, as well as to meet regulatory requirements
and expectations. Additional factors in each year also affected the level of
O&M expenses.
O&M expenses associated with nuclear generating stations decreased $172
million and increased $122 million and $88 million for the years 1998, 1997
and 1996, respectively. The decrease in 1998 is principally due to the
permanent cessation of nuclear generation operations at Zion Station. The
increases in 1997 and 1996 were a result of increased levels of activities
associated with the repair, replacement and improvement of nuclear generating
facility equipment. Since 1995, ComEd has increased the number and scope of
maintenance activities associated with its nuclear generating stations. Such
efforts are the result of station performance evaluations performed to
identify the sources and causes of unplanned equipment repairs. The goal of
such efforts is to design and implement cost effective repairs and
improvements to increase station availability. See "Changes in the Electric
Utility Industry," subcaption "Response to Regulatory Changes" above,
regarding the permanent cessation of nuclear operations at Zion Station.
O&M expenses associated with nuclear generating stations have been driven by
ComEd's objective to improve station availability, as well as to meet
regulatory requirements and expectations. ComEd is pursuing a program to
improve the quality of nuclear operations, including safety and efficiency,
which is also expected to achieve a longer term goal of improved availability
and to be positioned to take advantage of opportunities in a more competitive
market. Over the past several years, ComEd has increased and reinforced
station management with managers drawn from other utilities which have
resolved similar operating issues. It has also sought to identify, anticipate
and address nuclear station operation and performance issues in a safe, cost-
effective manner, while seeking to improve the availability and capacity
factors of its nuclear generating units. Such activities have included
improvements in operating and personnel procedures and repair and replacement
of equipment, and can result in longer unit outages. Such activities have
involved increased maintenance and repair expenses in recent years.
O&M expenses associated with fossil generating stations decreased $5 million
and increased $31 million and $4 million for the years 1998, 1997 and 1996,
respectively. The decrease related to fossil generating stations in 1998,
compared to 1997, is primarily due to the sales of State Line and Kincaid
Stations in December 1997 and February 1998, respectively, partially offset by
plant refurbishment costs. The increase related to fossil generating stations
in 1997 is primarily due to an increase in the repair and improvement of
fossil generating facility equipment in order to increase their general
availability, and to ensure their availability during the summer of 1997. That
increase was partially offset by a reduction in personnel.
O&M expenses associated with ComEd's transmission and distribution systems
increased $32 million, $15 million and $11 million for the years 1998, 1997
and 1996, respectively. The 1998 and 1997 increases are primarily due to
increased emergency restoration of electric service, higher maintenance
expenses and tree trimming costs. The 1996 increase reflects higher
maintenance
20
<PAGE>
expenses. O&M expenses associated with customer-related activities increased
$19 million, $11 million and $17 million for the years 1998, 1997 and 1996,
respectively. The increase in 1998 is primarily due to increased marketing
initiatives, uncollectible accounts and customer service personnel costs. The
increase in 1997 is primarily due to an increase in uncollectible accounts.
O&M expenses also include employee benefits expenses. Since 1995, ComEd has
reduced the size of its workforce by offering incentives for employees to
leave the company voluntarily. Such incentives included both current payments
and earlier eligibility for post-retirement health care benefits, in addition
to certain one-time, employee-related costs, resulting in charges of $48
million, $39 million and $12 million for the years 1998, 1997 and 1996,
respectively.
Other employee-related expenses, excluding the effects of employee
separation plans and certain other one-time, employee-related costs, increased
$41 million and decreased $11 million and $47 million for the years 1998, 1997
and 1996, respectively. The increase for the year 1998 is primarily due to
accruals for estimated incentive compensation recorded in 1998. The decrease
in 1997 is primarily due to a reduction in medical costs for active employees.
The decrease in 1996 is primarily related to a reduction in post-retirement
health care benefit costs, primarily due to a plan amendment effected in mid-
1995 which required retired employee contributions to the plan for the first
time. Favorable experience also allowed the use of lower health care cost
trend rates, producing a lower charge in 1996.
O&M expenses in 1998 reflect a reduction of $34 million in certain nuclear
maintenance costs due to technological improvements, compared to 1997. O&M
expenses in 1997 include $25 million for the additional write-off of obsolete
materials and supplies. O&M expenses associated with certain administrative
and general costs decreased $22 million and increased $35 million for the
years 1998 and 1997, respectively. The 1997 increase was due to a variety of
reasons including an increase in the provision for vacation pay liability. The
effects of inflation have also increased O&M expenses during the years and are
also reflected in the increases and decreases discussed herein.
Depreciation and Amortization. Depreciation expense decreased in 1998 and
increased for the years 1997 and 1996. The decrease in 1998 reflects the
retirement of Zion Station and the plant impairment recorded by ComEd in the
second quarter of 1998, partially offset by plant additions and shortened
depreciable lives for certain nuclear stations. The decrease also reflects the
sales of State Line and Kincaid Stations in December 1997 and February 1998,
respectively. The increases in 1997 and 1996 are a result of additional
nuclear plant depreciation and additions to plant in service. Depreciation
expense for 1998 and 1997 includes depreciation related to the replacement of
the steam generators at Byron Unit 1 and Braidwood Unit 1 of $34 million and
$59 million for the years 1998 and 1997, respectively. The 1996 increase
includes the additional depreciation initiative of $30 million. See Note 1 of
Notes to Financial Statements, under "Depreciation, Amortization of Regulatory
Assets and Decommissioning," for additional information.
The amortization of the regulatory asset, related to impaired production
plant recorded by ComEd in the second quarter of 1998, partially offset the
reductions in depreciation expense. Such amortization was $65 million for the
year 1998. See Note 1 of Notes to Financial Statements, under "Depreciation,
Amortization of Regulatory Assets and Decommissioning," for additional
information.
Interest on Debt. Changes in interest on long-term debt and notes payable
for the years 1998, 1997 and 1996 were due to changes in average interest
rates and in the amounts of long-term debt and notes payable outstanding.
Changes in interest on long-term debt also reflected new issues of debt, the
retirement and early redemption of debt, and the retirement and redemption of
issues which
21
<PAGE>
were refinanced at generally lower rates of interest. The average amounts of
long-term debt and notes payable outstanding and average interest rates
thereon were as follows:
<TABLE>
<CAPTION>
1998 1997 1996
------ ------ ------
<S> <C> <C> <C>
Long-term debt outstanding:
Average amount (millions).......................... $6,099 $6,256 $6,644
Average interest rate.............................. 7.06% 7.65% 7.67%
Notes payable outstanding:
Average amount (millions).......................... $ 344 $ 153 $ 230
Average interest rate.............................. 5.68% 5.95% 5.79%
</TABLE>
Decommissioning. The staff of the SEC has questioned certain of the current
accounting practices of the electric utility industry, including ComEd,
regarding the recognition, measurement and classification of decommissioning
costs for nuclear generating stations in the financial statements of electric
utilities. In response to these questions, the FASB is reviewing the
accounting for nuclear decommissioning costs. If current electric utility
industry accounting practices for such decommissioning costs are changed,
annual provisions for decommissioning could increase and the estimated cost
for decommissioning could be recorded as a liability rather than as
accumulated depreciation. Decommissioning costs of currently retired nuclear
plants are recorded as a liability. ComEd does not believe that such changes,
if required, would have an adverse effect on results of operations due to its
ability to recover decommissioning costs through rates.
Other Items. The amounts of AFUDC reflect changes in the average levels of
investment subject to AFUDC and changes in the average annual capitalization
rates as discussed in Note 1 of Notes to Financial Statements, under "AFUDC
and Interest Capitalized." ComEd discontinued SFAS No. 71 regulatory
accounting practices in December 1997 for the generation portion of its
business. As a result, beginning in 1998, ComEd capitalized $28 million in
interest costs on its generation-related construction work in progress and
nuclear fuel in process. AFUDC and interest capitalized do not contribute to
the current cash flow of ComEd.
The ratios of earnings to fixed charges for the years 1998, 1997 and 1996
were 2.67, 0.58 and 2.90, respectively. The ratios of earnings to fixed
charges and preferred and preference stock dividend requirements for the years
1998, 1997 and 1996 were 2.29, 0.49 and 2.48, respectively. Earnings for 1997
were inadequate to cover fixed charges by approximately $259 million and fixed
charges and preferred and preference stock dividend requirements by
approximately $359 million. The deficiency is principally attributable to the
earnings impact of the closure of Zion Station.
Business corporations, in general, have been adversely affected by inflation
because amounts retained after the payment of all costs have been inadequate
to replace, at increased costs, the productive assets consumed. Electric
utilities, in particular, have been especially affected as a result of their
capital intensive nature and regulation which limits capital recovery and
prescribes installation or modification of facilities to comply with
increasingly stringent safety and environmental requirements. Because the
regulatory process limits the amount of depreciation expense included in
ComEd's revenue allowance to the original cost of utility plant investment,
the resulting cash flows are inadequate to provide for replacement of that
investment in future years or preserve the purchasing power of common equity
capital previously invested.
22
<PAGE>
REPORT OF INDEPENDENT PUBLIC ACCOUNTANTS
To the Shareholders of Commonwealth Edison Company:
We have audited the accompanying consolidated balance sheets and statements
of consolidated capitalization of Commonwealth Edison Company (an Illinois
corporation) and subsidiary companies as of December 31, 1998 and 1997, and
the related statements of consolidated operations, retained earnings (deficit)
and cash flows for each of the three years in the period ended December 31,
1998. These financial statements are the responsibility of the Company'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 Commonwealth Edison
Company and subsidiary companies as ofDecember 31, 1998 and 1997, and the
results of their operations and their cash flows for each of the three years
in the period ended December 31, 1998, in conformity with generally accepted
accounting principles.
As discussed in Note 3, effective January 1, 1997, the Company changed its
method of accounting for revenue recognition.
Arthur Andersen LLP
Chicago, Illinois
February 19, 1999
23
<PAGE>
COMMONWEALTH EDISON COMPANY AND SUBSIDIARY COMPANIES
STATEMENTS OF CONSOLIDATED OPERATIONS
The following Statements of Consolidated Operations for the years 1998, 1997
and 1996 reflect the results of past operations and are not intended as any
representation as to results of operations for any future period. Future
operations will necessarily be affected by various and diverse factors and
developments, including changes in electric prices, regulation, population,
business activity, competition, taxes, environmental control, energy use,
fuel, cost of labor, purchased power and other matters, the nature and effect
of which cannot now be determined.
<TABLE>
<CAPTION>
1998 1997 1996
---------- ----------- ----------
(Thousands of Dollars)
<S> <C> <C> <C>
Electric Operating Revenues............... $7,135,880 $ 7,073,088 $6,934,547
---------- ----------- ----------
Electric Operating Expenses and Taxes:
Fuel.................................... $1,093,264 $ 1,239,438 $1,157,855
Purchased power......................... 795,355 400,055 145,299
Operation............................... 1,457,331 1,715,016 1,496,562
Maintenance............................. 789,262 689,729 652,495
Depreciation and amortization........... 937,604 1,001,149 967,137
Taxes (except income)................... 697,151 799,167 782,668
Income taxes--
Current--Federal...................... 287,865 214,168 265,199
--State................................ 52,233 65,248 74,165
Deferred--Federal--net................ 30,761 56,111 140,122
--State--net........................... 12,538 2,544 16,139
Investment tax credits deferred--net.... (27,730) (31,015) (33,378)
---------- ----------- ----------
$6,125,634 $ 6,151,610 $5,664,263
---------- ----------- ----------
Electric Operating Income................. $1,010,246 $ 921,478 $1,270,284
---------- ----------- ----------
Other Income and (Deductions):
Interest on long-term debt, net of
interest capitalized................... $ (430,602) $ (478,530) $ (509,898)
Interest on notes payable............... (19,560) (9,134) (13,308)
Allowance for funds used during
construction........................... 16,464 42,325 40,202
Income taxes applicable to nonoperating
activities............................. 4,974 11,010 7,659
Provision for dividends on company-
obligated mandatorily redeemable
preferred securities of subsidiary
trusts holding solely the Company's
subordinated debt securities........... (29,710) (28,860) (16,960)
Loss of nuclear plant closure........... -- (885,611) --
Income tax effect of nuclear plant
closure................................ -- 362,952 --
Miscellaneous--net...................... 42,394 (95,768) (34,611)
---------- ----------- ----------
$ (416,040) $(1,081,616) $ (526,916)
---------- ----------- ----------
Net Income (Loss) before Extraordinary
Item and Cumulative Effect of Change in
Accounting Principle..................... $ 594,206 $ (160,138) $ 743,368
Extraordinary Loss, less Applicable Income
Taxes.................................... -- (810,335) --
Cumulative Effect of Change in Accounting
Principle................................ -- 196,700 --
---------- ----------- ----------
Net Income (Loss)......................... $ 594,206 $ (773,773) $ 743,368
Provision for Dividends on Preferred and
Preference Stocks........................ 56,884 60,486 64,424
---------- ----------- ----------
Net Income (Loss) on Common Stock......... $ 537,322 $ (834,259) $ 678,944
========== =========== ==========
</TABLE>
The accompanying Notes to Financial Statements are an integral part of the
above statements.
24
<PAGE>
COMMONWEALTH EDISON COMPANY AND SUBSIDIARY COMPANIES
CONSOLIDATED BALANCE SHEETS
<TABLE>
<CAPTION>
December 31
------------------------
ASSETS 1998 1997
------ ----------- -----------
(Thousands of Dollars)
<S> <C> <C>
Utility Plant:
Plant and equipment, at original cost (includes
construction work in progress of $858 million and
$1,131 million, respectively)..................... $27,801,246 $27,518,690
Less--Accumulated provision for depreciation....... 15,234,320 11,646,445
----------- -----------
$12,566,926 $15,872,245
Nuclear fuel, at amortized cost.................... 874,979 906,043
----------- -----------
$13,441,905 $16,778,288
----------- -----------
Investments:
Nuclear decommissioning funds...................... $ 2,267,317 $ 1,855,697
Subsidiary companies............................... 49,129 48,605
Other investments, at cost......................... 57,031 39,002
----------- -----------
$ 2,373,477 $ 1,943,304
----------- -----------
Current Assets:
Cash............................................... $ 69 $ --
Temporary cash investments......................... 26,935 72,634
Cash held for redemption of securities............. 3,062,816 --
Special deposits................................... 271 271
Receivables--
Customers........................................ 1,364,760 873,418
Other............................................ 138,594 130,537
Provisions for uncollectible accounts............ (48,008) (17,544)
Coal and fuel oil, at average cost................. 134,965 120,664
Materials and supplies, at average cost............ 229,532 255,338
Deferred income taxes related to current assets and
liabilities....................................... 26,486 179,493
Prepayments and other.............................. 18,387 38,622
----------- -----------
$ 4,954,807 $ 1,653,433
----------- -----------
Deferred Charges and Other Noncurrent Assets:
Regulatory assets.................................. $ 4,578,427 $ 1,966,889
Other.............................................. 84,953 116,489
----------- -----------
$ 4,663,380 $ 2,083,378
----------- -----------
$25,433,569 $22,458,403
=========== ===========
</TABLE>
The accompanying Notes to Financial Statements are an integral part of the
above statements.
25
<PAGE>
COMMONWEALTH EDISON COMPANY AND SUBSIDIARY COMPANIES
CONSOLIDATED BALANCE SHEETS
<TABLE>
<CAPTION>
December 31
-----------------------
CAPITALIZATION AND LIABILITIES 1998 1997
------------------------------ ----------- -----------
(Thousands of Dollars)
<S> <C> <C>
Capitalization (see accompanying statements):
Common stock equity.................................. $ 5,055,837 $ 4,866,438
Preferred and preference stocks without mandatory
redemption requirements............................. 74,488 507,053
Preference stock subject to mandatory redemption re-
quirements.......................................... 69,475 174,328
Company-obligated mandatorily redeemable preferred
securities of subsidiary trusts holding solely the
Company's subordinated debt securities*............. 350,000 350,000
Long-term debt....................................... 7,677,219 5,562,883
----------- -----------
$13,227,019 $11,460,702
----------- -----------
Current Liabilities:
Notes payable........................................ $ 276,356 $ 158,150
Current portion of long-term debt, redeemable prefer-
ence stock and capitalized lease obligations........ 2,226,868 772,831
Accounts payable..................................... 605,712 490,124
Accrued interest..................................... 178,238 167,807
Accrued taxes........................................ 165,466 198,556
Dividends payable.................................... 104,022 106,083
Customer deposits.................................... 56,954 55,214
Accrued plant closing costs.......................... 78,430 135,000
Other................................................ 149,304 164,897
----------- -----------
$ 3,841,350 $ 2,248,662
----------- -----------
Deferred Credits and Other Noncurrent Liabilities:
Deferred income taxes................................ $ 3,787,978 $ 3,839,607
Nuclear decommissioning liability for retired plants. 1,215,400 1,301,000
Accumulated deferred investment tax credits.......... 562,285 602,122
Accrued spent nuclear fuel disposal fee and related
interest............................................ 728,413 692,673
Obligations under capital leases..................... 333,653 437,950
Regulatory liabilities............................... 595,005 698,750
Other................................................ 1,142,466 1,176,937
----------- -----------
$ 8,365,200 $ 8,749,039
----------- -----------
Commitments and Contingent Liabilities (Note 22)
$25,433,569 $22,458,403
=========== ===========
</TABLE>
*As described in Note 11 of Notes to Financial Statements, the sole asset of
ComEd Financing I, a subsidiary trust of ComEd, is $206.2 million principal
amount of ComEd's 8.48% subordinated deferrable interest notes due September
30, 2035. The sole asset of ComEd Financing II, also a subsidiary trust of
ComEd, is $154.6 million principal amount of ComEd's 8.50% subordinated
deferrable interest debentures due January 15, 2027.
The accompanying Notes to Financial Statements are an integral part of the
above statements.
26
<PAGE>
COMMONWEALTH EDISON COMPANY AND SUBSIDIARY COMPANIES
STATEMENTS OF CONSOLIDATED CAPITALIZATION
<TABLE>
<CAPTION>
December 31
------------------------
1998 1997
----------- -----------
(Thousands of Dollars)
<S> <C> <C>
Common Stock Equity:
Common stock, $12.50 par value per share--
Outstanding--214,236,153 shares and
214,228,077 shares, respectively......... $ 2,677,952 $ 2,677,851
Premium on common stock and other paid-in
capital................................... 2,223,706 2,223,564
Capital stock and warrant expense.......... (15,664) (15,805)
Retained earnings (deficit)................ 176,643 (19,172)
Treasury stock--178,982 shares............. (6,800) --
----------- -----------
$ 5,055,837 $ 4,866,438
----------- -----------
Preferred and Preference Stocks Without
Mandatory Redemption Requirements:
Preference stock, cumulative, without par
value--
Outstanding--13,499,549 shares............ $ 504,957 $ 504,957
Current redemption requirements for
preference stock included in current
liabilities............................... (432,320) --
$1.425 convertible preferred stock,
cumulative, without par value--
Outstanding--58,211 shares and 65,912
shares, respectively..................... 1,851 2,096
Prior preferred stock, cumulative, $100 par
value per share--
No shares outstanding..................... -- --
----------- -----------
$ 74,488 $ 507,053
----------- -----------
Preference Stock Subject to Mandatory Redemption
Requirements:
Preference stock, cumulative, without par
value--
Outstanding--1,720,345 shares and
2,058,560 shares, respectively........... $ 171,348 $ 205,016
Current redemption requirements for
preference stock included in current
liabilities............................... (101,873) (30,688)
----------- -----------
$ 69,475 $ 174,328
----------- -----------
Company-Obligated Mandatorily Redeemable
Preferred Securities of Subsidiary Trusts
Holding Solely the Company's Subordinated
Debt Securities............................. $ 350,000 $ 350,000
----------- -----------
Long-Term Debt:
First mortgage bonds:
Maturing 1998 through 2003--6.00% to
9 3/8%.................................. $ 1,080,000 $ 1,385,000
Maturing 2004 through 2013--3.70% to
8 3/8%.................................. 1,485,400 1,485,400
Maturing 2014 through 2023--5.85% to
9 7/8%.................................. 1,981,000 1,981,000
----------- -----------
$ 4,546,400 $ 4,851,400
Transitional trust notes, due 2000 through
2008--5.29% to 5.74%...................... 3,400,000 --
Sinking fund debentures, due 1999 through
2011--2 3/4% to 7 5/8%.................... 94,159 100,298
Pollution control obligations, due 2007
through 2014--3.70% to 5 7/8%............. 140,700 142,200
Other long-term debt....................... 1,056,346 1,016,889
Current maturities of long-term debt
included in current liabilities........... (1,497,706) (501,445)
Unamortized net debt discount and premium.. (62,680) (46,459)
----------- -----------
$ 7,677,219 $ 5,562,883
----------- -----------
$13,227,019 $11,460,702
=========== ===========
</TABLE>
The accompanying Notes to Financial Statements are an integral part of the
above statements.
27
<PAGE>
COMMONWEALTH EDISON COMPANY AND SUBSIDIARY COMPANIES
STATEMENTS OF CONSOLIDATED RETAINED EARNINGS (DEFICIT)
<TABLE>
<CAPTION>
1998 1997 1996
-------- ---------- ----------
(Thousands of Dollars)
<S> <C> <C> <C>
Balance at Beginning of Year.................. $(19,172) $1,157,956 $ 821,848
Add--Net income (loss)........................ 594,206 (773,773) 743,368
-------- ---------- ----------
$575,034 $ 384,183 $1,565,216
-------- ---------- ----------
Deduct--
Dividends declared on--
Common stock.............................. $342,776 $ 342,763 $ 342,732
Preferred and preference stocks........... 55,320 60,159 64,095
Other capital stock transactions--net....... 295 433 433
-------- ---------- ----------
$398,391 $ 403,355 $ 407,260
-------- ---------- ----------
Balance at End of Year (Includes $580 million
and $384 million of appropriated retained
earnings at December 31, 1998 and 1997, re-
spectively).................................. $176,643 $ (19,172) $1,157,956
======== ========== ==========
</TABLE>
The accompanying Notes to Financial Statements are an integral part of the
above statements.
28
<PAGE>
COMMONWEALTH EDISON COMPANY AND SUBSIDIARY COMPANIES
STATEMENTS OF CONSOLIDATED CASH FLOWS
<TABLE>
<CAPTION>
1998 1997 1996
----------- ----------- -----------
(Thousands of Dollars)
<S> <C> <C> <C>
Cash Flow from Operating Activities:
Net income (loss)...................... $ 594,206 $ (773,773) $ 743,368
Adjustments to reconcile net income
(loss) to net cash provided by
operating activities:
Depreciation and amortization........ 989,147 1,047,603 1,004,216
Deferred income taxes and investment
tax credits--net.................... 62,775 (348,889) 124,857
Extraordinary loss related to write-
off of certain net regulatory as-
sets................................ -- 810,335 --
Cumulative effect of change in ac-
counting principle.................. -- (196,700) --
Loss on nuclear plant closure........ -- 885,611 --
Provisions/(payments) for revenue re-
funds--net.......................... (23,622) 45,470 --
Equity component of allowance for
funds used during construction...... (6,959) (23,770) (20,776)
Provisions/(payments) for liability
for separation costs--net........... 9,757 15,986 (29,888)
Net effect on cash flows of changes
in:
Receivables........................ (468,935) 21,194 67,888
Coal and fuel oil.................. (14,301) 19,698 (11,186)
Materials and supplies............. 22,519 41,659 9,053
Accounts payable excluding nuclear
fuel lease principal payments and
separation costs--net............. 111,981 233,360 110,437
Accrued interest and taxes......... (22,659) (6,465) (37,021)
Other changes in certain current
assets and liabilities............ 141,942 38,873 13,765
Other--net........................... 53,595 177,918 105,543
----------- ----------- -----------
$ 1,449,446 $ 1,988,110 $ 2,080,256
----------- ----------- -----------
Cash Flow from Investing Activities:
Construction expenditures.............. $ (912,215) $ (969,626) $ (949,871)
Nuclear fuel expenditures.............. (166,168) (185,373) (281,833)
Sales of generating plants............. 177,454 60,791 --
Equity component of allowance for
funds used during construction........ 6,959 23,770 20,776
Contributions to nuclear
decommissioning funds................. (136,771) (114,825) (119,281)
Other investments and special depos-
its................................... (1,174) (4,703) (52)
----------- ----------- -----------
$(1,031,915) $(1,189,966) $(1,330,261)
----------- ----------- -----------
Cash Flow from Financing Activities:
Issuance of securities--
Transitional trust notes............. $ 3,382,629 $ -- $ --
Other long-term debt................. 222,068 297,663 198,902
Company-obligated mandatorily redeem-
able preferred securities of
subsidiary trusts holding solely the
Company's subordinated debt
securities.......................... -- 150,000 --
Capital stock........................ 244 288 669
Retirement and redemption of securi-
ties--
Long-term debt....................... (498,192) (734,768) (431,985)
Capital stock........................ (34,066) (44,111) (44,513)
Repurchase of common stock............. (6,800) -- --
Premium paid on early redemption of
long-term debt........................ -- (9,500) --
Cash dividends paid on capital stock... (429,867) (426,916) (424,764)
Proceeds from sale/leaseback of nu-
clear fuel............................ 101,038 149,955 316,617
Nuclear fuel lease principal payments.. (255,605) (166,411) (211,741)
Increase/(decrease) in short-term
borrowings............................ 118,206 29,400 (139,400)
----------- ----------- -----------
$ 2,599,655 $ (754,400) $ (736,215)
----------- ----------- -----------
Change in Net Cash Balance.............. $ 3,017,186 $ 43,744 $ 13,780
Cash, Temporary Cash Investments and
Cash Held for Redemption of
Securities:
Balance at Beginning of Year........... 72,634 28,890 15,110
----------- ----------- -----------
Balance at End of Year................. $ 3,089,820 $ 72,634 $ 28,890
=========== =========== ===========
</TABLE>
The accompanying Notes to Financial Statements are an integral part of the
above statements.
29
<PAGE>
COMMONWEALTH EDISON COMPANY AND SUBSIDIARY COMPANIES
NOTES TO FINANCIAL STATEMENTS
(1) Summary of Significant Accounting Policies
Corporate Structure and Basis of Presentation. Unicom is the parent holding
company of ComEd and other unregulated subsidiaries. ComEd, a regulated
electric utility, is the principal subsidiary of Unicom.
The consolidated financial statements include the accounts of ComEd, the
Indiana Company, the Trusts, ComEd Funding and ComEd Funding Trust. All
significant intercompany transactions have been eliminated. Although the
accounts of ComEd Funding and ComEd Funding Trust, which are SPEs, are
included in the consolidated financial statements, as required by GAAP, ComEd
Funding and ComEd Funding Trust are legally separated from Unicom and ComEd.
The assets of the SPEs are not available to creditors of Unicom or ComEd and
the transitional property held by the SPEs are not assets of Unicom or ComEd.
Use of Estimates. The preparation of financial statements in conformity with
GAAP requires management to make estimates and assumptions that affect the
reported amounts of assets and liabilities, and disclosure of contingent
assets and liabilities at the date of the financial statements and the
reported amounts of revenues and expenses during the reporting period. Actual
results could differ from those estimates. Due to the transition to a new
customer information and billing system, a larger portion of customer revenues
and receivables were based on estimates in 1998 than in previous years.
Regulation. ComEd is subject to regulation as to accounting and ratemaking
policies and practices by the ICC and FERC. ComEd's accounting policies and
the accompanying consolidated financial statements conform to GAAP applicable
to rate-regulated enterprises for the non-generation portion of its business,
including the effects of the ratemaking process in accordance with SFAS No.
71, Accounting for the Effects of Certain Types of Regulation. Such effects on
the non-generation portion of its business concern mainly the time at which
various items enter into the determination of operating results in order to
follow the principle of matching costs with the applicable revenues collected
from or returned to customers through future rates. See Note 2 for information
regarding the write-off of generation-related regulatory assets and
liabilities in December 1997.
ComEd's investment in generation-related, net utility plant, including
construction work in progress and nuclear fuel, and excluding the
decommissioning costs included in the accumulated provision for depreciation,
not subject to cost-based rate regulation, was $9.2 billion and $12.4 billion
at December 31, 1998 and 1997, respectively. See Note 2 regarding the plant
impairment recorded by ComEd in the second quarter of 1998.
30
<PAGE>
COMMONWEALTH EDISON COMPANY AND SUBSIDIARY COMPANIES
NOTES TO FINANCIAL STATEMENTS--Continued
Regulatory Assets and Liabilities. Regulatory assets are incurred costs
which have been deferred and are amortized for ratemaking and accounting
purposes. Regulatory liabilities represent amounts to be settled with
customers through future rates. Regulatory assets and liabilities reflected on
the Consolidated Balance Sheets at December 31, 1998 and 1997 were as follows:
<TABLE>
<CAPTION>
December 31
---------------------
1998 1997
---------- ----------
(Thousands of
Dollars)
<S> <C> <C>
Regulatory assets:
Impaired production plant (1)........................... $2,955,154 $ --
Deferred income taxes (2)............................... 680,356 785,354
Nuclear decommissioning costs--Dresden Unit 1 (3)....... 255,031 268,369
Nuclear decommissioning costs--Zion Units 1 and 2 (4)... 443,130 579,777
Coal reserves (5)....................................... 197,975 281,654
Unamortized loss on reacquired debt (6)................. 46,781 51,735
---------- ----------
$4,578,427 $1,966,889
========== ==========
Regulatory liabilities:
Deferred income taxes (2)............................... $ 595,005 $ 698,750
========== ==========
</TABLE>
- --------
(1) Amortized over a transition period which is expected to end by 2006, but
may be extended to 2008 with ICC approval. See Note 2 for additional
information.
(2) Recorded in compliance with SFAS No. 109, Accounting for Income Taxes, for
non-generation related temporary differences.
(3) Amortized over the period 1999 to 2011. See "Depreciation, Amortization of
Regulatory Assets and Decommissioning" below for additional information.
(4) Amortized over the period 1999 to 2013. See "Depreciation, Amortization of
Regulatory Assets and Decommissioning" below for additional information.
(5) Amortized through regulated cash flows as coal is used for the generation
of electricity. See "Depreciation, Amortization of Regulatory Assets and
Decommissioning" below for additional information.
(6) Amortized over the remaining lives of the non-generation related long-term
debt issued to finance the reacquisition. See "Loss on Reacquired Debt"
below for additional information.
Nuclear Fuel. The cost of nuclear fuel is amortized to fuel expense based on
the quantity of heat produced using the unit of production method. As
authorized by the ICC, provisions for spent nuclear fuel disposal costs have
been recorded at a level required to recover the fee payable on current
nuclear-generated and sold electricity and the current interest accrual on the
one-time fee payable to the DOE for nuclear generation prior to April 7, 1983.
The one-time fee and interest thereon have been recovered and the current fee
and interest on the one-time fee are presently being recovered through base
rates. See Note 14 for additional information concerning the disposal of spent
nuclear fuel, one-time fee and interest accrual on the one-time fee. Nuclear
fuel expenses, including leased fuel costs and provisions for spent nuclear
fuel disposal costs, were $325 million, $298 million and $354 million for the
years 1998, 1997 and 1996, respectively.
Customer Receivables and Revenues. ComEd is engaged principally in the
production, purchase, transmission, distribution and sale of electricity to a
diverse base of residential, commercial, industrial and wholesale customers.
ComEd's electric service territory has an area of approximately 11,300 square
miles and an estimated population of approximately eight million as of
December 31, 1998. It includes the city of Chicago, an area of about 225
square miles with an estimated population of approximately three million from
which ComEd derived approximately one-third of its ultimate consumer revenues
in 1998. ComEd had 3.5 million electric customers at December 31, 1998. See
Notes 3, 4 and 19 for additional information.
31
<PAGE>
COMMONWEALTH EDISON COMPANY AND SUBSIDIARY COMPANIES
NOTES TO FINANCIAL STATEMENTS--Continued
Depreciation, Amortization of Regulatory Assets and Decommissioning.
Depreciation, decommissioning and amortization of regulatory assets for the
years 1998, 1997 and 1996 were as follows:
<TABLE>
<CAPTION>
1998 1997 1996
-------- ---------- --------
(Thousands of Dollars)
<S> <C> <C> <C>
Depreciation expense.............................. $782,373 $ 877,256 $841,681
Decommissioning expense........................... 90,020 108,621 110,184
Amortization of regulatory assets................. 65,211 15,272 15,272
-------- ---------- --------
$937,604 $1,001,149 $967,137
======== ========== ========
</TABLE>
Depreciation is provided on a straight-line basis by amortizing the cost of
depreciable plant and equipment over estimated service lives for each class of
plant. Provisions for depreciation, including nuclear plant, were at average
annual rates of 3.02%, 3.36% and 3.25% for the years 1998, 1997 and 1996,
respectively, of average depreciable utility plant and equipment. The decrease
for the year 1998, compared to 1997, in the average depreciation rates relates
primarily to a reduction in nuclear depreciation rates due to the partial
impairment of production plant, which was recorded as a component of
accumulated depreciation, partially offset by shortened depreciable lives for
certain nuclear stations. The annual rate for nuclear plant and equipment,
excluding separately collected decommissioning costs and depreciation related
to the replacement of the steam generators, was 2.88% for periods ending prior
to July 1, 1998. The nuclear depreciation rate applied to gross depreciable
nuclear plant, beginning July 1, 1998, is 2.16% reflecting the partial
impairment of production plant and shortened depreciable lives for certain
nuclear stations. See Note 2 for additional information on the partial
impairment of production plant.
The regulatory assets for impaired production plant and coal reserves are
being amortized as they are recovered through regulated cash flows over a
transition period which is expected to end by 2006, but may be extended to
2008 with ICC approval. Recovery of these regulatory assets will be realized
through future regulatory revenues, including CTC revenues, and potential
gains on generation asset sales, and will vary from year to year. The
amortization of coal reserves is included in fuel expense on the Statements of
Consolidated Operations.
Nuclear plant decommissioning costs are accrued over the current NRC license
lives of the related nuclear generating units. The accrual is based on an
annual levelized cost of the unrecovered portion
of estimated decommissioning costs, which are escalated for expected inflation
to the expected time of decommissioning and are net of expected earnings on
the trust funds. See "Management's Discussion and Analysis of Financial
Condition and Results of Operations," subcaption "Results of Operations--
Decommissioning," for a discussion of questions raised by the staff of the SEC
and a FASB review regarding the electric utility industry's method of
accounting for decommissioning costs. Dismantling is expected to occur
relatively soon after the end of the current NRC license life of each
generating station currently operating. The accrual for decommissioning is
based on the prompt removal method authorized by NRC guidelines. ComEd's ten
operating units have remaining current NRC license lives ranging from 7 to 29
years. ComEd's Zion Station and its first nuclear unit, Dresden Unit 1, are
retired and expected to be dismantled beginning in the years 2014 and 2012,
respectively, which is consistent with the regulatory treatment for the
related decommissioning costs.
Based on ComEd's most recent study approved by the ICC, decommissioning
costs, including the cost of decontamination and dismantling, are estimated to
aggregate to $4.6 billion in current-year (1999) dollars, including a
contingency allowance. ComEd estimates that it will expend approximately $11.6
billion, including a contingency allowance, for decommissioning costs
primarily during the period
32
<PAGE>
COMMONWEALTH EDISON COMPANY AND SUBSIDIARY COMPANIES
NOTES TO FINANCIAL STATEMENTS--Continued
from 2007 through 2034. Additionally, ComEd estimates that it will expend an
aggregate of approximately $226 million in current-year (1999) dollars during
the period 2000 through 2014 to maintain Zion Station in a secured mode until
decommissioning begins. All such costs are expected to be funded by the
external decommissioning trusts, which ComEd established in compliance with
Illinois law and into which ComEd has been making annual contributions. Future
decommissioning cost estimates may be significantly affected by the adoption
of or changes to NRC regulations, as well as changes in the assumptions used
in making such estimates, including changes in technology, available
alternatives for the disposal of nuclear waste and inflation.
Since 1995, ComEd has collected decommissioning costs from its ratepayers in
conjunction with a rider to its tariffs. The rider allows annual adjustments
to decommissioning cost collections outside the context of a traditional rate
proceeding and will continue under the 1997 Act. The current estimated
decommissioning costs include a contingency allowance, but, except at Dresden
Unit 1, exclude amounts for spent fuel storage installations, which may be
necessary to store spent fuel during the period beginning at the end of the
NRC license life of the plants to the date when the DOE accepts the spent fuel
for permanent storage. Contingency allowances used in decommissioning cost
estimates provide for currently unspecifiable costs that are likely to occur
after decommissioning begins and generally range from 20% to 25% of the
currently specifiable costs.
In February 1998, the ICC authorized a reduction in the annual
decommissioning cost accrual from $109 million to $84 million. The reduction
primarily reflects stronger than expected after-tax returns on the external
trust funds in 1996 and lower than expected escalation in low-level waste
disposal costs, partially offset by the higher current-year cost estimates,
including a contingency allowance.
The approved annual decommissioning cost accrual of $84 million was
determined using the following assumptions: the decommissioning cost estimate
of $4.6 billion in current-year (1999) dollars, after-tax earnings on the tax-
qualified and nontax-qualified decommissioning funds of 7.30% and 6.26%,
respectively, and an escalation rate for future decommissioning costs of 4.1%.
The annual accrual of $84 million provided over the current NRC license lives
of the nuclear plants, coupled with the expected fund earnings and amounts
previously recovered in rates, is expected to aggregate to approximately $11.6
billion.
For the ten operating nuclear units, decommissioning cost accruals are
recorded as portions of depreciation expense and accumulated provision for
depreciation on the Statements of Consolidated Operations and the Consolidated
Balance Sheets, respectively, as such costs are recovered through rates. As of
December 31, 1998, the total decommissioning costs included in the accumulated
provision for depreciation were $1,870 million.
For ComEd's retired nuclear units, the total estimated liability for nuclear
decommissioning in current-year (1999) dollars is recorded as a liability. The
unrecovered portion of the liability was also recorded as a regulatory asset.
The nuclear decommissioning liability for retired plants as of December 31,
1998 was as follows:
<TABLE>
<CAPTION>
Zion
Dresden Units
Unit 1 1 and 2 Total
-------- -------- ----------
(Thousands of Dollars)
<S> <C> <C> <C>
Amounts recovered through rates and investment
fund earnings.................................... $101,469 $415,770 $ 517,239
Unrecovered portion of the liability.............. 255,031 443,130 698,161
-------- -------- ----------
Nuclear decommissioning liability for retired
plants.......................................... $356,500 $858,900 $1,215,400
======== ======== ==========
</TABLE>
33
<PAGE>
COMMONWEALTH EDISON COMPANY AND SUBSIDIARY COMPANIES
NOTES TO FINANCIAL STATEMENTS--Continued
The total estimated liability related to Zion Units 1 and 2, and the
unrecovered portion of that liability, decreased from December 31, 1997 to
December 31, 1998 due to the exclusion of estimated dry cask storage costs.
Under Illinois law, decommissioning cost collections are required to be
deposited into external trusts. Consequently, such collections do not add to
the cash flows available for general corporate purposes. The ICC has approved
ComEd's funding plan, which provides for annual contributions of current
accruals and ratable contributions of past accruals over the remaining current
NRC license lives of the nuclear plants. The fair value of funds accumulated
in the external trusts at December 31, 1998 was $2,267 million, which includes
pre-tax unrealized appreciation of $620 million. The earnings on the external
trusts for operating plants accumulate in the fund balance and accumulated
provision for depreciation. Nuclear decommissioning funding as of December 31,
1998 was as follows:
<TABLE>
<CAPTION>
(Thousands of Dollars)
<S> <C>
Amounts recovered through rates and investment fund
earnings for operating plants (included in the accumu-
lated provision for depreciation)...................... $1,870,213
Amounts recovered through rates and investment fund
earnings for retired plants............................ 517,239
Less past accruals not yet contributed to the trusts.... 120,135
----------
Fair value of external trust funds..................... $2,267,317
==========
</TABLE>
Income Taxes. ComEd is included in the consolidated federal and state income
tax returns filed by Unicom. Current and deferred income taxes of the
consolidated group are allocated to ComEd as if ComEd filed separate tax
returns. Deferred income taxes are provided for income and expense items
recognized for financial accounting purposes in periods that differ from those
for income tax purposes. Income taxes deferred in prior years are charged or
credited to income as the book/tax temporary differences reverse. Prior years'
deferred investment tax credits are amortized through credits to income
generally over the lives of the related property. Income tax credits resulting
from interest charges applicable to nonoperating activities, principally
construction, are classified as other income.
AFUDC and Interest Capitalized. In accordance with the uniform systems of
accounts prescribed by regulatory authorities, ComEd capitalizes AFUDC,
compounded semiannually, which represents the estimated cost of funds used to
finance its construction program for the non-generation portion of its
business. The equity component of AFUDC is recorded on an after-tax basis and
the borrowed funds component of AFUDC is recorded on a pre-tax basis. The
average annual capitalization rates were 8.34%, 9.39% and 9.02% for the years
1998, 1997 and 1996, respectively. ComEd discontinued SFAS No. 71 regulatory
accounting practices in December 1997 for the generation portion of its
business. As a result, beginning in 1998, ComEd capitalized $28 million in
interest costs on its generation-related construction work in progress and
nuclear fuel in process. AFUDC and interest capitalized do not contribute to
the current cash flow of ComEd.
Interest. Total interest costs incurred on debt, leases and other
obligations were $527 million, $588 million and $620 million for the years
1998, 1997 and 1996, respectively.
Debt Discount, Premium and Expense. Discount, premium and expense on long-
term debt are being amortized over the lives of the respective issues.
Loss on Reacquired Debt. Consistent with regulatory treatment, the net loss
from reacquisition, in connection with the refinancing of first mortgage
bonds, sinking fund debentures and pollution control obligations prior to
their scheduled maturity dates, is deferred and amortized over the lives of
the long-term debt issued to finance the reacquisition for non-generation
related financings. See "Regulatory Assets and Liabilities" above and Note 2
for additional information.
34
<PAGE>
COMMONWEALTH EDISON COMPANY AND SUBSIDIARY COMPANIES
NOTES TO FINANCIAL STATEMENTS--Continued
Stock Option Awards/Employee Stock Purchase Plan. ComEd has elected to adopt
SFAS No. 123, Accounting for Stock-Based Compensation, for disclosure purposes
only. ComEd accounts for its stock option awards and ESPP under APB Opinion
No. 25, Accounting for Stock Issued to Employees. See Note 8 for additional
information.
Energy Risk Management Contracts. In the normal course of business, ComEd
utilizes contracts for the forward sale and purchase of energy to manage
effectively the utilization of its available generating capability. ComEd also
utilizes put and call option contracts and energy swap arrangements to limit
the market price risk associated with the forward commodity contracts. As
ComEd does not currently utilize financial or commodity instruments for
trading or speculative purposes, any gains or losses on forward commodity
contracts are recognized when the underlying transactions affect earnings.
Revenues and expenses associated with market price risk management contracts
are amortized over the terms of such contracts.
In June 1998, the FASB issued SFAS No. 133, Accounting for Derivative
Instruments and Hedging Activities. SFAS No. 133 establishes accounting and
reporting standards requiring that every derivative instrument, including
certain derivative instruments embedded in other contracts, be recorded on the
Consolidated Balance Sheets as either an asset or liability measured at its
fair value. SFAS No. 133 requires that changes in the derivative's fair value
be recognized currently in earnings, unless specific hedge accounting criteria
are met. Special accounting for qualifying hedges allows a derivative's gains
and losses to offset related results on the hedged item on the Statements of
Consolidated Operations, and requires ComEd to formally document, designate,
and assess the effectiveness of transactions that receive hedge accounting.
SFAS No. 133 is effective for fiscal years beginning after June 15, 1999.
SFAS No. 133 may be implemented prior to June 15, 1999, but such
implementation cannot be applied retroactively. SFAS No. 133 must be applied
to (i) derivative instruments and (ii) certain derivative instruments embedded
in hybrid contracts that were issued, acquired, or substantively modified
after December 31, 1997 (and, at the company's election, before January 1,
1998).
ComEd has not yet quantified the effects on its financial statements of
adopting SFAS No. 133 and has not determined the timing or method of adopting
SFAS No. 133. However, adoption of SFAS No. 133 could increase volatility in
earnings and other comprehensive income.
Reclassifications. Certain prior year amounts have been reclassified to
conform with current period presentation. These reclassifications had no
effect on operating results.
Statements of Consolidated Cash Flows. For purposes of the Statements of
Consolidated Cash Flows, temporary cash investments, generally investments
maturing within three months at the time of purchase, are considered to be
cash equivalents. Supplemental cash flow information for the years 1998, 1997
and 1996 was as follows:
<TABLE>
<CAPTION>
1998 1997 1996
-------- -------- --------
(Thousands of Dollars)
<S> <C> <C> <C>
Supplemental Cash Flow Information:
Cash paid during the year for:
Interest (net of amount capitalized)............ $439,706 $502,260 $533,498
Income taxes (net of refunds)................... $302,289 $280,368 $238,920
Supplemental Schedule of Non-Cash Investing and Fi-
nancing Activities:
Capital lease obligations incurred................ $106,370 $158,412 $320,975
</TABLE>
35
<PAGE>
COMMONWEALTH EDISON COMPANY AND SUBSIDIARY COMPANIES
NOTES TO FINANCIAL STATEMENTS--Continued
(2) Accounting Effects Related to the 1997 Act
In December 1997, the Governor of Illinois signed into law the 1997 Act,
which established a phased process to introduce competition into the electric
industry in Illinois under a less regulated structure. Major provisions of the
1997 Act applicable to ComEd include a 15% residential base rate reduction
which became effective August 1, 1998, an additional 5% residential base rate
reduction commencing on May 1, 2002 and gradual customer access to other
electric suppliers. Access for commercial and industrial customers will occur
over a period from October 1999 to December 2000, and access for residential
customers will occur after May 1, 2002. ComEd's operating revenues were
reduced by approximately $170 million in 1998 due to the rate reduction. ComEd
is engaged in certain pricing experiments contemplated by the 1997 Act, which
reduced ComEd's operating revenues by approximately $30 million in 1998 and
are expected to reduce operating revenues by $55 million in 1999, compared to
1997 rate levels; however, such reductions are expected to be offset by the
effects of customer growth. ComEd expects that the 15% residential base rate
reduction will reduce ComEd's operating revenues by approximately $380 million
in 1999, compared to 1997 rate levels.
The 1997 Act also provides for the collection of a CTC from customers who
choose another electric service provider during a transition period that
extends through 2006, and can be extended through 2008 with ICC approval. The
CTC will be established in accordance with a formula defined in the 1997 Act.
The CTC, which will be applied on a cents per kilowatthour basis, considers
the revenue which would have been collected from a customer under tariffed
rates, reduced by the revenue the utility will receive for providing delivery
services to the customer, the market price for electricity and a defined
mitigation factor, which represents the utility's opportunity to develop new
revenue sources and achieve cost savings.
Notwithstanding these rate reductions, and subject to certain earnings
tests, a rate freeze will generally be in effect until at least January 1,
2005. During this period, utilities may reorganize, sell or assign assets,
retire or remove plants from service, and accelerate depreciation or
amortization of assets with limited ICC regulatory review. A utility may
request a rate increase during the rate freeze period only when necessary to
ensure the utility's financial viability, but not before January 1, 2000.
Under the earnings provision of the 1997 Act, if the earned return on common
equity of a utility during this period exceeds an established threshold, one-
half of the excess earnings must be refunded to customers. The threshold rate
of return on common equity is based on the 30-Year Treasury Bond rate, plus
5.5% in the years 1998 through 1999 and plus 6.5% in the years 2000 through
2004. The utility's earned return on common equity and the threshold return on
common equity are each calculated on a two year average basis. The earnings
sharing provision is applicable only to utility earnings. Increased
amortization of regulatory assets may be recorded, thereby reducing the earned
return on common equity, if earnings otherwise would have exceeded the maximum
allowable rate of return. The potential for earnings sharing or increased
amortization of regulatory assets could limit earnings in future periods.
Under the 1997 Act, utilities are required to continue to offer delivery
services, including the transmission and distribution of electric energy, such
that customers who select an alternative energy supplier can receive electric
energy from that supplier using existing transmission and distribution
facilities. Such services will continue to be offered under cost-based,
regulated rates. The 1997 Act also requires utilities to establish or join an
ISO that will independently manage and control utility transmission systems.
Additionally, the 1997 Act includes the leveling of certain regulatory
requirements to permit operational flexibility, the leveling of certain
regulatory and tax provisions as applied to various electric suppliers and a
new, more stringent, liability standard applicable to ComEd in the event of a
major outage.
36
<PAGE>
COMMONWEALTH EDISON COMPANY AND SUBSIDIARY COMPANIES
NOTES TO FINANCIAL STATEMENTS--Continued
The 1997 Act also allows a portion of ComEd's future revenues to be
segregated and used to support the issuance of securities by ComEd or a SPE.
The proceeds from such securities issuances must be used to refinance
outstanding debt and equity or for certain other limited purposes. The total
amount of such securities that may be issued is approximately $6.8 billion;
approximately one-half of that amount can be issued in the twelve-month period
which commenced on August 1, 1998. In December 1998, ComEd initiated the
issuance of $3.4 billion of transitional trust notes through its SPEs, ComEd
Funding and ComEd Funding Trust. The proceeds from the transitional trust
notes, net of transaction costs, must be used to redeem or repurchase debt and
equity to lower ComEd's overall cost of capital. Accordingly, in early 1999
ComEd redeemed $788 million of long-term debt and $534 million of preference
stock, and reacquired $229 million of outstanding long-term debt through a
tender offer. In addition, $500 million of the proceeds, of which
approximately $300 million has been utilized, is being used to reduce ComEd's
outstanding short-term debt. Unicom has announced plans to repurchase
approximately $750 million of Unicom common stock using the proceeds it
receives from ComEd's repurchase of its common stock held by Unicom. The
remaining proceeds will be used for the payment of fees and additional debt
and equity redemptions. See Notes 7 and 24 for additional information
regarding Unicom's share repurchase plans.
As a result of the 1997 Act, prices for the supply of electric energy are
expected to change from cost-based, regulated rates to rates determined by
competitive market forces. The CTC allows ComEd to recover some of its costs
which might otherwise be unrecoverable under market-based rates. Nonetheless,
ComEd will need to take steps to address the portion of such costs which are
not recoverable through the CTC. Such steps may include cost control efforts,
developing new sources of revenue and potential asset dispositions.
Because the 1997 Act is expected ultimately to lead to market-based pricing
of electric generation services, ComEd discontinued SFAS No. 71 regulatory
accounting practices for the generation portion of its business in December
1997. ComEd evaluated the regulatory assets and liabilities related to the
generation portion of its business and determined that it was not probable
that such costs would be recovered through the cash flows from the regulated
portion of its business. Accordingly, the generation-related regulatory assets
and liabilities were written off in the fourth quarter of 1997, resulting in
an extraordinary charge of $810 million (after-tax). These write-offs related
principally to previously incurred costs originally expected to be collected
through future revenues, including income tax benefits previously flowed
through to customers, deferred carrying charges on the Byron Unit 2 and
Braidwood Units 1 and 2 nuclear generating plants, generation-related
unamortized loss on reacquired debt and other miscellaneous generation-related
costs. The regulatory asset for the unrecovered nuclear decommissioning costs
of currently retired nuclear plants was not written off, as the 1997 Act
provides for the ongoing recovery of decommissioning costs through regulated
rates. See "Regulatory Assets and Liabilities" and "Depreciation, Amortization
of Regulatory Assets and Decommissioning" in Note 1 for additional
information.
Pursuant to an option contained in the 1997 Act, ComEd filed a tariff in
December 1997 to eliminate its FAC as of January 1, 1997. Under ComEd's
regulated rates, the FAC provided for the recovery of changes in fossil and
nuclear fuel costs and the energy portion of purchased power costs, compared
to the fuel and purchased energy costs included in ComEd's base rates. The
elimination of the FAC required ComEd to refund to customers the net FAC
charges billed during the calendar year 1997 of $25 million (after-tax). These
costs, as well as deferred underrecovered energy costs of $19 million (after-
tax) which ComEd would have been entitled to recover if the FAC had remained
in effect, were recorded as a charge to operating results in the fourth
quarter of 1997.
37
<PAGE>
COMMONWEALTH EDISON COMPANY AND SUBSIDIARY COMPANIES
NOTES TO FINANCIAL STATEMENTS--Continued
Additionally, the elimination of the FAC and a transition to market-based
pricing for generation-related costs required ComEd to write down its
investment in uranium-related properties. Projections of the market price for
uranium indicated that the expected incremental costs of mining and milling
uranium at such properties would exceed the expected market price for uranium.
Such costs are not expected to be recoverable in a competitive market. A write
down of ComEd's investment in uranium-related properties to realizable value
resulted in a charge of $60 million (after-tax) in December 1997.
The staff of the SEC issued interpretive guidance in the second quarter of
1998 regarding the application of SFAS No. 121, Accounting for the Impairment
of Long-Lived Assets and for Long-Lived Assets to Be Disposed Of, when a
regulated enterprise such as an electric utility discontinues regulatory
accounting practices for separable portions of its operations and assets.
Under SFAS No. 121, an asset is considered impaired, and should be written
down to fair value, if its future cash flows are insufficient to recover the
carrying value of the asset. The interpretive guidance concludes that for
purposes of applying SFAS No. 121, supplemental regulated cash flows, such as
a CTC, should be excluded from the cash flows of assets in the portion of the
business not subject to regulatory accounting practices. If such assets are
determined to be impaired, a regulatory asset should be established if such
costs are recoverable through regulated cash flows. The guidance also
addresses the extent to which assets should be grouped to determine
impairment.
ComEd discontinued the application of regulatory accounting principles in
December 1997 for the generation portion of its business and performed a SFAS
No. 121 impairment analysis that concluded that future revenues, including the
collection of the CTC, expected to be recovered from electric supply services
would be sufficient to cover the costs of its generating assets. However,
reflecting the SEC's interpretive guidance, ComEd's revised impairment
evaluation resulted in a plant impairment of $3 billion. Because future CTC
revenues collected through regulated cash flows are expected to provide
recovery of the impaired plant assets, a regulatory asset was recorded for the
same amount. Accordingly, the impairment, recorded in the second quarter of
1998, had no effect on results of operations. The regulatory asset is being
amortized as it is recovered through regulated cash flows over a transition
period that ends in 2006, but may be extended to 2008 with ICC approval.
Recovery of the regulatory asset will be realized through future regulatory
revenues, including CTC revenues, and potential gains on generation asset
sales, and will vary from year to year.
(3) Cumulative Effect of a Change in Accounting Principle
In the fourth quarter of 1997, ComEd changed its accounting method for
revenue recognition to record revenues associated with service which has been
provided to customers but has not yet been billed at the end of each
accounting period, retroactive to January 1, 1997. This change in accounting
method increased operating results for the year 1997 to reflect the one-time
cumulative effect of the change for years prior to 1997 by $197 million
(after-tax). If the new accounting method had been in effect for the years
1997 and 1996, the pro forma unaudited net income (loss) on common stock would
have been $(1,030,959,000) and $711,073,000, respectively, excluding the one-
time cumulative effect of a change in accounting principle.
(4) Rate Matters
Final ICC orders have been issued in fuel reconciliation proceedings related
to ComEd's FAC collections for all years except for 1994. On November 5, 1998,
the ICC issued an order in the proceeding for the year 1994 providing for a
refund of approximately $3 million related to nuclear station performance. On
February 9, 1999, an intervenor moved to dismiss its appeal of the 1994 ICC
38
<PAGE>
COMMONWEALTH EDISON COMPANY AND SUBSIDIARY COMPANIES
NOTES TO FINANCIAL STATEMENTS--Continued
order. On December 29, 1998, the ICC issued an order for the 1996 fuel
reconciliation proceeding requiring ComEd to refund approximately $19 million
related to nuclear station performance. The 1997 Act provides that, because
ComEd eliminated its FAC effective January 1, 1997, the ICC shall not conduct a
fuel reconciliation proceeding for the year 1997 and subsequent years. See Note
2 for information regarding the 1997 Act and the elimination of ComEd's FAC.
Three of ComEd's wholesale municipal customers filed a complaint and request
for refund with the FERC alleging that ComEd failed to properly adjust their
rates, as provided for under the terms of their electric service contracts, to
track certain refunds made to ComEd's retail customers in the years 1992
through 1994. In the third quarter of 1998, the FERC granted the complaint and
directed that refunds be made, with interest. ComEd filed and was granted a
request for rehearing for purposes of reconsideration with the FERC. If the
order is upheld, ComEd must make refunds within 15 days of the resolution for
rehearing.
ComEd's management believes adequate reserves have been established in
connection with the cases discussed above.
(5) Closure and Sale of Plants
In January 1998, the Boards of Directors of Unicom and ComEd authorized the
permanent cessation of nuclear generation operations and retirement of
facilities at ComEd's 2,080 megawatt Zion nuclear generating station. Such
retirement resulted in a charge for 1997 of $523 million (after-tax). The
decision to close Zion Station was a result of ComEd's ongoing analysis of the
economic value of its generating assets in light of the expected changes in the
manner in which electric energy is marketed and sold. The passage of the 1997
Act provided a clearer basis for evaluating the costs and benefits of
alternative courses of action. In reaching the decision to cease nuclear
generation operations at Zion Station, the Boards also considered the
significant uncertainty associated with continued operation of the station due
to the degradation of the steam generators and the expected operating costs
associated with continued station operation.
ComEd's fourth quarter 1997 financial results reflected a charge of $406
million (after-tax), representing the undepreciated costs of Zion Station
(excluding the portion which will remain in use to provide voltage support),
materials and supplies inventories, and nuclear fuel inventories. In addition,
as required by GAAP, a liability for future closing costs associated with the
retirement of Zion Station, excluding severance costs, was recorded resulting
in a charge of $117 million (after-tax) in the fourth quarter of 1997. ComEd
recorded a reduction to the liability for future closing costs of $15 million
(after-tax) in the year 1998 to reflect lower than expected closing costs due
to employees being reassigned or removed from payroll sooner than expected, and
lower than anticipated support costs and use of contractors. See Note 17 for
information regarding costs of voluntary employee separation plans.
ComEd completed the sale of two of its coal-fired generating stations,
representing 1,598 megawatts of generating capacity, and has exclusive 15-year
purchased power agreements for the output of the stations. The sales of State
Line and Kincaid Stations were completed in December 1997 and February 1998,
respectively. The net proceeds of the sales, after income tax effects and
closing costs, were approximately $190 million. The proceeds were used to
retire or redeem existing debt in the first quarter of 1998. See "Management's
Discussion and Analysis of Financial Condition and Results of Operations,"
subcaption "Response to Regulatory Changes," for information regarding ComEd's
fossil generating plants, and oil and gas peaking units being offered for sale.
39
<PAGE>
COMMONWEALTH EDISON COMPANY AND SUBSIDIARY COMPANIES
NOTES TO FINANCIAL STATEMENTS--Continued
(6) Authorized Shares and Voting Rights of Capital Stock
At December 31, 1998, the authorized shares of capital stock were: common
stock--250,000,000 shares; preference stock--22,030,345 shares; $1.425
convertible preferred stock--58,211 shares; and prior preferred stock--850,000
shares. The preference and prior preferred stocks are issuable in series and
may be issued with or without mandatory redemption requirements. Holders of
shares at any time outstanding, regardless of class, are entitled to one vote
for each share held on each matter submitted to a vote at a meeting of
shareholders, with the right to cumulate votes in all elections for directors.
(7) Common Equity
ComEd has entered into a prepaid forward purchase arrangement with Unicom
for the repurchase of approximately 15 million shares of ComEd common stock.
The repurchase arrangement provides for final settlement no later than
February 2000, on either a physical (share) basis, or a net cash basis. The
terms of the repurchase agreements between ComEd and Unicom are identical to
the terms of Unicom's repurchase agreements with the financial institutions.
The repurchase agreements between ComEd and Unicom are expected to be settled
on the same basis Unicom settles its repurchase agreements with the financial
institutions. The amount at which the arrangement can be settled is dependent
principally upon the average market price at which Unicom's common shares have
been repurchased under its repurchase agreements, compared to the forward
price per share. The share repurchases will not reduce shares outstanding or
reduce common stock equity and resulting return on common equity calculations
until the date of physical settlement. ComEd currently does not anticipate
that settlement will occur in 1999. The repurchase arrangement will initially
be recorded as a receivable on ComEd's Consolidated Balance Sheets and will be
adjusted at the end of each reporting period to reflect the aggregate market
value of the shares deliverable under the arrangement. Consequently, the
arrangement could increase earnings volatility in 1999.
This arrangement supplements a previously announced program to repurchase up
to $200 million of ComEd common stock. Shares repurchased under that program
will also be outstanding for financial statement purposes until the time of
physical settlement, which is currently expected to extend to February 2000,
on either a physical (share) basis, or a net cash basis, at the option of
ComEd. As of December 31, 1998, this arrangement has been accounted for as an
equity instrument. If this arrangement had been settled on a physical (share)
basis at December 31, 1998, ComEd would have received approximately 5.1
million shares of its common stock.
See Note 24 for additional information regarding the redemptions and
repurchases of debt and equity.
At December 31, 1998, shares of common stock were reserved for the following
purposes:
<TABLE>
<S> <C>
Conversion of $1.425 convertible preferred stock................... 59,375
Conversion of warrants............................................. 25,359
------
84,734
======
</TABLE>
Shares of common stock issued for the years 1998, 1997 and 1996 were as
follows:
<TABLE>
<CAPTION>
1998 1997 1996
----- ----- ------
<S> <C> <C> <C>
Conversion of $1.425 convertible preferred stock............. 7,848 9,261 22,146
Conversion of warrants....................................... 228 362 1,358
----- ----- ------
8,076 9,623 23,504
===== ===== ======
</TABLE>
In December 1998, 178,982 shares of ComEd common stock were reacquired and
held as treasury stock at a cost of $6.8 million.
40
<PAGE>
COMMONWEALTH EDISON COMPANY AND SUBSIDIARY COMPANIES
NOTES TO FINANCIAL STATEMENTS--Continued
At December 31, 1998 and 1997, 76,079 and 76,868, respectively, of common
stock purchase warrants were outstanding. The warrants entitle the holders to
convert such warrants into common stock at a conversion rate of one share of
common stock for three warrants.
ComEd's retained earnings had a positive balance of $177 million at December
31, 1998 and a deficit balance of $19 million at December 31, 1997. As of
December 31, 1998 and 1997, $580 million and $384 million, respectively, of
retained earnings had been appropriated for future dividend payments.
(8) Stock Option Awards/Employee Stock Purchase Plan
Unicom has a nonqualified stock option awards program under its Long-Term
Incentive Plan. The stock option awards program was adopted by Unicom in July
1996 to reward valued employees responsible for, or contributing to, the
management, growth and profitability of Unicom and its subsidiaries. The stock
options granted expire ten years from their grant date. One-third of the shares
subject to the options vest on each of the first three anniversaries of the
option grant date. In addition, the stock options become fully vested
immediately if the holder dies, retires, is terminated by the Company, other
than for cause, or qualifies for long-term disability and will also vest in
full upon a change in control.
Stock option transactions for the years 1998, 1997 and 1996 are summarized as
follows:
<TABLE>
<CAPTION>
Weighted
Average
Number of Exercise
Options Price
--------- --------
<S> <C> <C>
Outstanding at the beginning of 1996.................. -- $ --
Granted during the year............................... 1,205,500 25.500
Expired/cancelled during the year..................... (17,500) 25.500
---------
Outstanding as of December 31, 1996................... 1,188,000 25.500
Granted during the year............................... 1,339,350 22.313
Exercised during the year............................. (23,423) 25.500
Expired/cancelled during the year..................... (212,549) 23.632
---------
Outstanding as of December 31, 1997................... 2,291,378 23.810
Granted during the year............................... 1,379,525 35.234
Exercised during the year............................. (404,082) 24.244
Expired/cancelled during the year..................... (124,594) 25.714
---------
Outstanding as of December 31, 1998................... 3,142,227 28.694
=========
</TABLE>
Of the stock options outstanding at December 31, 1998, 943,851 have vested
with a weighted average exercise price of $24.234.
The fair value of each stock option is estimated on the date of grant using
the Black-Scholes option-pricing model with the following weighted average
assumptions:
<TABLE>
<CAPTION>
Stock Option Grant Date
-----------------------
1998 1997 1996
------- ------- -------
<S> <C> <C> <C>
Expected option life.............................. 7 years 7 years 7 years
Dividend yield.................................... 4.54% 7.20% 6.30%
Expected volatility............................... 21.95% 22.29% 20.98%
Risk-free interest rate........................... 5.58% 6.25% 6.64%
</TABLE>
The estimated weighted average fair value for each stock option granted for
the years 1998, 1997 and 1996 was $6.62, $2.79 and $3.74, respectively.
41
<PAGE>
COMMONWEALTH EDISON COMPANY AND SUBSIDIARY COMPANIES
NOTES TO FINANCIAL STATEMENTS--Continued
The ESPP allows employees to purchase Unicom common stock at a 10% discount
from market value. Substantially all of the employees of Unicom, ComEd and
certain subsidiaries are eligible to participate in the ESPP. Unicom issued
94,270, 196,003 and 196,513 shares of common stock for the years 1998, 1997 and
1996, respectively, under the ESPP at a weighted average annual purchase price
of $33.11, $19.15 and $23.52, respectively.
ComEd has adopted the disclosure-only provisions of SFAS No. 123. For
financial reporting purposes, ComEd has adopted APB No. 25 and thus no
compensation cost has been recognized for the stock option awards program or
ESPP. If ComEd had recorded compensation expense for the stock options granted
and the shares of common stock issued under the ESPP in accordance with SFAS
No. 123 using the fair value based method of accounting, the additional charge
to operations would have been $2 million (after-tax), $2 million (after-tax)
and $1 million (after-tax) for the years 1998, 1997 and 1996, respectively.
(9) Preferred and Preference Stocks Without Mandatory Redemption Requirements
No shares of preferred or preference stocks without mandatory redemption
requirements were issued or redeemed during 1998, 1997 and 1996. The series of
preference stock without mandatory redemption requirements outstanding at
December 31, 1998 are summarized as follows:
<TABLE>
<CAPTION>
Involuntary
Shares Aggregate Redemption Liquidation
Series Outstanding Stated Value Price(1) Price(1)
------- ----------- ------------ ---------- -----------
(Thousands
of Dollars)
<S> <C> <C> <C> <C>
$1.90 4,249,549 $106,239 $ 25.25 $25.00
$2.00 2,000,000 51,560 $ 26.04 $25.00
$1.96 2,000,000 52,440 $ 27.11 $25.00
$7.24 750,000 74,340 $101.00 $99.12
$8.40 750,000 74,175 $101.00 $98.90
$8.38 750,000 73,566 $100.16 $98.09
$2.425 3,000,000 72,637 $ 25.00 $25.00
---------- --------
13,499,549 $504,957
========== ========
</TABLE>
--------
(1) Per share plus accrued and unpaid dividends, if any.
The outstanding shares of $1.425 convertible preferred stock are convertible
at the option of the holders thereof, at any time, into common stock at the
rate of 1.02 shares of common stock for each share of convertible preferred
stock, subject to future adjustment. The convertible preferred stock may be
redeemed by ComEd at $42 per share, plus accrued and unpaid dividends, if any.
The involuntary liquidation price of the $1.425 convertible preferred stock is
$31.80 per share, plus accrued and unpaid dividends, if any.
ComEd redeemed $432 million of preference stock without mandatory redemption
requirements on January 19, 1999. The redemption retires all series other than
Series $2.425 and $1.425. See Note 24 for additional information regarding the
redemption of ComEd preference stocks.
42
<PAGE>
COMMONWEALTH EDISON COMPANY AND SUBSIDIARY COMPANIES
NOTES TO FINANCIAL STATEMENTS--Continued
(10) Preference Stock Subject to Mandatory Redemption Requirements
During 1998, 1997 and 1996, no shares of preference stock subject to
mandatory redemption requirements were issued. The series of preference stock
subject to mandatory redemption requirements outstanding at December 31, 1998
are summarized as follows:
<TABLE>
<CAPTION>
Shares Aggregate
Series Outstanding Stated Value Optional Redemption Price(1)
- -------------- ----------- ------------ -----------------------------------------------
(Thousands
of Dollars)
<S> <C> <C> <C>
$8.20 142,845 $ 14,285 $101
$8.40 Series B 240,000 23,838 $101
$8.85 187,500 18,750 $101
$9.25 450,000 45,000 $103 through July 31, 1999; and $101 thereafter
$6.875 700,000 69,475 Non-callable
--------- --------
1,720,345 $171,348
========= ========
</TABLE>
- --------
(1) Per share plus accrued and unpaid dividends, if any.
ComEd redeemed $102 million of preference stock with mandatory redemption
requirements on January 19, 1999. The redemption retires all series other than
Series $6.875, all of which is required to be redeemed on May 1, 2000. The
sinking fund price for Series $6.875 is $100 and the involuntary liquidation
price is $99.25 per share plus accrued and unpaid dividends, if any. See Note
24 for additional information regarding the redemption of ComEd preference
stocks.
After reflecting the redemption, the remaining sinking fund requirement is
$69 million in the year 2000. During 1998, 338,215 shares and in each of the
years 1997 and 1996, 438,215 shares of preference stock subject to mandatory
redemption requirements were reacquired to meet sinking fund requirements plus
any optional additional sinking fund payments.
Sinking fund requirements and the redemption due within one year are included
in current liabilities.
(11) Company-Obligated Mandatorily Redeemable Preferred Securities of
Subsidiary Trusts Holding Solely the Company's Subordinated Debt Securities
In September 1995, ComEd Financing I, a wholly-owned subsidiary trust of
ComEd, issued 8,000,000 of its 8.48% company-obligated mandatorily redeemable
preferred securities. The sole asset of ComEd Financing I is $206.2 million
principal amount of ComEd's 8.48% subordinated deferrable interest notes due
September 30, 2035. In January 1997, ComEd Financing II, a wholly-owned
subsidiary trust of ComEd, issued 150,000 of its 8.50% company-obligated
mandatorily redeemable capital securities. The sole asset of ComEd Financing II
is $154.6 million principal amount of ComEd's 8.50% subordinated deferrable
interest debentures due January 15, 2027. There is a full and unconditional
guarantee by ComEd of the Trusts' obligations under the securities issued by
the Trusts. However, ComEd's obligations are subordinate and junior in right of
payment to certain other indebtedness of ComEd. ComEd has the right to defer
payments of interest on the subordinated deferrable interest notes by extending
the interest payment period, at any time, for up to 20 consecutive quarters.
Similarly, ComEd has the right to defer payments of interest on the
subordinated deferrable interest debentures by extending the interest payment
period, at any time, for up to ten consecutive semi-annual periods. If interest
payments on the subordinated deferrable interest notes or
43
<PAGE>
COMMONWEALTH EDISON COMPANY AND SUBSIDIARY COMPANIES
NOTES TO FINANCIAL STATEMENTS--Continued
debentures are so deferred, distributions on the preferred securities will also
be deferred. During any deferral, distributions will continue to accrue with
interest thereon. In addition, during any such deferral, ComEd may not declare
or pay any dividend or other distribution on, or redeem or purchase, any of its
capital stock.
The subordinated deferrable interest notes are redeemable by ComEd, in whole
or in part, from time to time, on or after September 30, 2000, and with respect
to the subordinate deferrable interest debentures, on or after January 15,
2007, or at any time in the event of certain income tax circumstances. If the
subordinated deferrable interest notes or debentures are redeemed, the Trusts
must redeem preferred securities having an aggregate liquidation amount equal
to the aggregate principal amount of the subordinated deferrable interest notes
or debentures so redeemed. In the event of the dissolution, winding up or
termination of the Trusts, the holders of the preferred securities will be
entitled to receive, for each preferred security, a liquidation amount of $25
for the securities of ComEd Financing I and $1,000 for the securities of ComEd
Financing II, plus accrued and unpaid distributions thereon, including interest
thereon, to the date of payment, unless in connection with the dissolution, the
subordinated deferrable interest notes or debentures are distributed to the
holders of the preferred securities.
(12) Long-Term Debt
ComEd initiated the issuance of $3.4 billion of transitional trust notes
through its SPEs, ComEd Funding and ComEd Funding Trust, in the fourth quarter
of 1998, as follows:
<TABLE>
<CAPTION>
Interest Principal
Rate Class and Scheduled Maturity Dates Amount
-------- ---------------------------------- ----------
(Thousands
of
Dollars)
<C> <S> <C>
5.38% A-1 due March 25, 2000............................... $ 424,967
5.29% A-2 due June 25, 2001................................ 425,033
5.34% A-3 due March 25, 2002............................... 258,861
5.39% A-4 due June 25, 2003................................ 421,139
5.44% A-5 due March 25, 2005............................... 598,511
5.63% A-6 due June 25, 2007................................ 761,489
5.74% A-7 due December 25, 2008............................ 510,000
----------
$3,400,000
==========
</TABLE>
The proceeds, net of transaction costs, from the transitional trust notes
must be used to redeem debt and equity. On January 27, 1999, ComEd redeemed
$730 million of first mortgage bonds. On February 16, 1999, ComEd redeemed $58
million of sinking fund debentures. In response to a tender offer, ComEd
reacquired $229 million of first mortgage bonds in early February 1999. See
Note 24 for additional information regarding the redemptions of first mortgage
bonds and sinking fund debentures, and the reacquired first mortgage bonds.
For accounting purposes, the liabilities of ComEd Funding Trust for the
transitional trust notes are reflected as long-term debt on the Consolidated
Balance Sheets of ComEd.
Sinking fund requirements and scheduled maturities remaining through 2003,
after reflecting the redemptions, for first mortgage bonds, transitional trust
notes, sinking fund debentures and other long-term debt outstanding at December
31, 1998, are summarized as follows: 1999--$481 million; 2000--$727 million;
2001--$346 million; 2002--$645 million; and 2003--$445 million.
44
<PAGE>
COMMONWEALTH EDISON COMPANY AND SUBSIDIARY COMPANIES
NOTES TO FINANCIAL STATEMENTS--Continued
After reflecting the redemptions of first mortgage bonds, outstanding first
mortgage bonds maturing through 2003 were as follows:
<TABLE>
<CAPTION>
Series Principal Amount
------ ----------------------
(Thousands of Dollars)
<S> <C>
9 3/8% due February 15, 2000...................... $ 42,345
6 1/2% due April 15, 2000......................... 230,000
6 3/8% due July 15, 2000.......................... 100,000
7 3/8% due September 15, 2002..................... 200,000
6 5/8% due July 15, 2003.......................... 100,000
--------
$672,345
========
</TABLE>
Other long-term debt outstanding at December 31, 1998 is summarized as
follows:
<TABLE>
<CAPTION>
Principal
Debt Security Amount Interest Rate
- ------------------------ ---------- ------------------------------------------
(Thousands
of
Dollars)
<S> <C> <C>
Notes:
Medium Term Notes, Se-
ries 3N due various
dates through October
15, 2004 $ 296,000 Interest rates ranging from 9.00% to 9.20%
Notes due January 15, 150,000 Interest rate of 7.375%
2004
Notes due October 15, 235,000 Interest rate of 6.40%
2005
Notes due January 15, 150,000 Interest rate of 7.625%
2007
Notes due July 15, 2018 225,000 Interest rate of 6.95%
----------
$1,056,000
----------
Purchase Contract Obli-
gation
due April 30, 2005 $ 346 Interest rate of 3.00%
----------
$1,056,346
==========
</TABLE>
Long-term debt maturing within one year, including long-term debt redeemed in
January and February of 1999, have been included in current liabilities.
The outstanding first mortgage bonds are secured by a lien on substantially
all property and franchises, other than expressly excepted property, owned by
ComEd.
(13) Lines of Credit
ComEd had total unused bank lines of credit of $1 billion at December 31,
1998. Of that amount, $500 million expires on October 7, 1999 and $500 million
expires on October 8, 2003. The interest rate is set at the time of a borrowing
and is based on several floating rate bank indices plus a spread, which is
dependent upon the credit rating of ComEd's outstanding first mortgage bonds or
on a prime interest rate. ComEd is obligated to pay commitment fees with
respect to the unused portion of such lines of credit.
(14) Disposal of Spent Nuclear Fuel
Under the Nuclear Waste Policy Act of 1982, the DOE is responsible for the
selection and development of repositories for, and the disposal of, spent
nuclear fuel and high-level radioactive waste. ComEd, as required by that Act,
has signed a contract with the DOE to provide for the disposal of spent nuclear
fuel and high-level radioactive waste from ComEd's nuclear generating stations.
That
45
<PAGE>
COMMONWEALTH EDISON COMPANY AND SUBSIDIARY COMPANIES
NOTES TO FINANCIAL STATEMENTS--Continued
contract provided for acceptance by the DOE of such materials to begin in
January 1998; however, that date was not met by the DOE and is expected to be
delayed significantly. The DOE's current estimate for opening a facility to
accept such waste is 2010. This extended delay in spent nuclear fuel acceptance
by the DOE has led to ComEd's consideration of additional dry storage
alternatives. On July 30, 1998, ComEd filed a complaint against the United
States in the United States Court of Federal Claims seeking to recover damages
caused by the DOE's failure to honor its contractual obligation to begin
disposing of spent nuclear fuel in January 1998. The contract with the DOE
requires ComEd to pay the DOE a one-time fee applicable to nuclear generation
through April 6, 1983 of $277 million, with interest to date of payment, and a
fee payable quarterly equal to one mill per kilowatthour of nuclear-generated
and sold electricity after April 6, 1983. Pursuant to the contract, ComEd has
elected to pay the one-time fee, with interest, just prior to the first
delivery of spent nuclear fuel to the DOE. The liability for the one-time fee
and related interest is reflected on the Consolidated Balance Sheets.
(15) Fair Value of Financial Instruments
The following methods and assumptions were used to estimate the fair value of
financial instruments either held or issued and outstanding. The disclosure of
such information does not purport to be a market valuation of ComEd and
subsidiary companies as a whole. The impact of any realized or unrealized gains
or losses related to such financial instruments on the financial position or
results of operations of ComEd and subsidiary companies is primarily dependent
on the treatment authorized under future ratemaking proceedings.
Investments. Securities included in the nuclear decommissioning funds have
been classified
and accounted for as "available for sale" securities. The estimated fair value
of the nuclear decommissioning funds, as determined by the trustee and based on
published market data, as of December 31, 1998 and 1997 was as follows:
<TABLE>
<CAPTION>
December 31, 1998 December 31, 1997
-------------------------------- --------------------------------
Unrealized Cost Unrealized Fair
Cost Basis Gains Fair Value Basis Gains Value
---------- ---------- ---------- ---------- ---------- ----------
(Thousands of Dollars)
<S> <C> <C> <C> <C> <C> <C>
Short-term investments.. $ 40,907 $ 42 $ 40,949 $ 33,524 $ 2 $ 33,526
U.S. Government and
Agency issues.......... 197,240 20,213 217,453 170,240 15,882 186,122
Municipal bonds......... 416,121 24,124 440,245 306,104 20,598 326,702
Corporate bonds......... 241,111 8,790 249,901 231,738 4,293 236,031
Common stock............ 740,956 565,630 1,306,586 667,657 385,851 1,053,508
Other................... 11,345 838 12,183 17,300 2,508 19,808
---------- -------- ---------- ---------- -------- ----------
$1,647,680 $619,637 $2,267,317 $1,426,563 $429,134 $1,855,697
========== ======== ========== ========== ======== ==========
</TABLE>
At December 31, 1998, the debt securities held by the nuclear decommissioning
funds had the following maturities:
<TABLE>
<CAPTION>
Cost Basis Fair Value
---------- ----------
(Thousands of
Dollars)
<S> <C> <C>
Within 1 year....................................... $ 29,421 $ 29,431
1 through 5 years................................... 185,810 192,159
5 through 10 years.................................. 254,024 273,255
Over 10 years....................................... 411,607 439,643
</TABLE>
46
<PAGE>
COMMONWEALTH EDISON COMPANY AND SUBSIDIARY COMPANIES
NOTES TO FINANCIAL STATEMENTS--Continued
The net earnings of the nuclear decommissioning funds, which are recorded as
increases to the accumulated provision for depreciation, for the years 1998,
1997 and 1996 were as follows:
<TABLE>
<CAPTION>
1998 1997 1996
---------- ---------- ----------
(Thousands of Dollars)
<S> <C> <C> <C>
Gross proceeds from sales of securities....... $1,795,484 $2,163,522 $2,335,974
Less cost based on specific identification.... 1,728,092 2,088,300 2,300,038
---------- ---------- ----------
Realized gains on sales of securities......... $ 67,392 $ 75,222 $ 35,936
Other realized fund earnings net of expenses.. 40,374 39,123 33,008
---------- ---------- ----------
Total realized net earnings of the funds...... $ 107,766 $ 114,345 $ 68,944
Unrealized gains.............................. 190,503 198,741 65,516
---------- ---------- ----------
Total net earnings of the funds.............. $ 298,269 $ 313,086 $ 134,460
========== ========== ==========
</TABLE>
Current Assets. Cash, temporary cash investments, cash held for redemption
of securities and other cash investments, which include U.S. Government
obligations and other short-term marketable securities, and special deposits,
which primarily includes cash deposited for the redemption, refund or
discharge of debt securities, are stated at cost, which approximates their
fair value because of the short maturity of these instruments. The securities
included in these categories have been classified as "available for sale"
securities.
Capitalization. The estimated fair values of preferred and preference
stocks, company-obligated mandatorily redeemable preferred securities of
subsidiary trusts holding solely the Company's subordinated debt securities,
transitional trust notes, and long-term debt were obtained from an independent
consultant. The estimated fair values, which include the current portions of
redeemable preference stock and long-term debt but exclude accrued interest
and dividends, as of December 31, 1998 and 1997 were as follows:
<TABLE>
<CAPTION>
December 31, 1998 December 31, 1997
-------------------------------- --------------------------------
Carrying Unrealized Fair Carrying Unrealized Fair
Value Losses Value Value Losses Value
---------- ---------- ---------- ---------- ---------- ----------
(Thousands of Dollars)
<S> <C> <C> <C> <C> <C> <C>
Preferred and preference
stocks................. $ 678,156 $ 11,500 $ 689,656 $ 712,069 $ 11,970 $ 724,039
Company-obligated
mandatorily redeemable
preferred securities of
subsidiary trusts
holding solely the
Company's subordinated
debt securities........ $ 350,000 $ 20,678 $ 370,678 $ 350,000 $ 21,701 $ 371,701
Transitional trust
notes.................. $3,382,821 $ 67,168 $3,449,989 $ -- $ -- $ --
Long-term debt.......... $5,791,757 $442,077 $6,233,834 $5,913,942 $380,890 $6,294,832
</TABLE>
A long-term note payable, which is not included in the above table, amounted
to $150 million at December 31, 1997. Such note, for which interest is paid at
fixed and prevailing rates, is included in the consolidated financial
statements at cost, which approximates its fair value.
Current Liabilities. The carrying value of notes payable, which consists of
commercial paper and bank loans maturing within one year, approximates the
fair value because of the short maturity of these instruments. See
"Capitalization" above for a discussion of the fair value of the current
portions of long-term debt and redeemable preference stock.
Other Noncurrent Liabilities. The carrying value of accrued spent nuclear
fuel disposal fee and related interest represents the settlement value as of
December 31, 1998 and 1997; therefore, the carrying value is equal to the fair
value.
47
<PAGE>
COMMONWEALTH EDISON COMPANY AND SUBSIDIARY COMPANIES
NOTES TO FINANCIAL STATEMENTS--Continued
(16) Pension and Postretirement Benefits
As of December 31, 1998, ComEd had a qualified non-contributory defined
benefit pension plan which covers all regular employees. Benefits under this
plan reflect each employee's compensation, years of service and age at
retirement. Funding is based upon actuarially determined contributions that
take into account the amount deductible for income tax purposes and the
minimum contribution required under the Employee Retirement Income Security
Act of 1974, as amended. The December 31, 1998 and 1997 pension liabilities
and related data were determined using the January 1, 1998 actuarial
valuation. Additionally, ComEd maintains a nonqualified supplemental
retirement plan which covers any excess pension benefits that would be payable
to management employees under the qualified plan but which are limited by the
Internal Revenue Code. On January 19, 1998, Indiana Company's qualified
defined benefit pension plan was merged into the ComEd pension plan as a
result of the sale of Indiana Company's State Line Station and the transfer of
its remaining employees to ComEd.
ComEd and the Indiana Company provide certain postretirement medical, dental
and vision care, and life insurance for retirees and their dependents and for
the surviving dependents of eligible employees and retirees. The employees
become eligible for postretirement benefits when they reach age 55 with ten
years of service. The liability for postretirement benefits is funded through
trust funds based upon actuarially determined contributions that take into
account the amount deductible for income tax purposes. The health care plans
are contributory, funded jointly by the companies and the participating
retirees. The December 31, 1998 and 1997 postretirement benefit liabilities
and related data were determined using the January 1, 1998 actuarial
valuations.
48
<PAGE>
COMMONWEALTH EDISON COMPANY AND SUBSIDIARY COMPANIES
NOTES TO FINANCIAL STATEMENTS--Continued
Reconciliations of the beginning and ending balances of the projected
pension benefit obligation and the accumulated postretirement benefit
obligation and the funded status of these plans for the years 1998 and 1997
are as follows:
<TABLE>
<CAPTION>
Twelve Months Ended Twelve Months Ended
December 31, 1998 December 31, 1997
-------------------------- --------------------------
Other Other
Pension Postretirement Pension Postretirement
Benefits Benefits Benefits Benefits
---------- -------------- ---------- --------------
(Thousands of Dollars)
Change in benefit
obligation
- -----------------
<S> <C> <C> <C> <C>
Benefit obligation at
beginning of period.... $4,010,000 $1,139,000 $3,579,000 $1,035,000
Service cost............ 115,000 38,000 100,000 34,000
Interest cost........... 273,000 78,000 261,000 76,000
Plan participants' con-
tributions............. -- 3,000 -- 3,000
Curtailment gain........ -- -- (5,000) --
Actuarial loss.......... 165,000 37,000 282,000 32,000
Benefits paid........... (236,000) (46,000) (207,000) (41,000)
---------- ---------- ---------- ----------
Benefit obligation at
end of period......... $4,327,000 $1,249,000 $4,010,000 $1,139,000
---------- ---------- ---------- ----------
<CAPTION>
Change in plan assets
- ---------------------
<S> <C> <C> <C> <C>
Fair value of plan as-
sets at beginning of
period................. $3,706,000 $ 767,000 $3,281,000 $ 665,000
Actual return on plan
assets................. 534,000 108,000 631,000 128,000
Employer contribution... 11,000 20,000 1,000 12,000
Plan participants' con-
tributions............. -- 3,000 -- 3,000
Benefits paid........... (236,000) (46,000) (207,000) (41,000)
---------- ---------- ---------- ----------
Fair value of plan as-
sets at end of period. $4,015,000 $ 852,000 $3,706,000 $ 767,000
---------- ---------- ---------- ----------
Plan assets less than
benefit obligation..... $ (312,000) $ (397,000) $ (304,000) $ (372,000)
Unrecognized net actuar-
ial loss (gain)........ 37,000 (345,000) 68,000 (350,000)
Unrecognized prior serv-
ice cost (asset)....... (60,000) 48,000 (64,000) 52,000
Unrecognized transition
obligation (asset)..... (101,000) 323,000 (114,000) 345,000
---------- ---------- ---------- ----------
Accrued liability for
benefits.............. $ (436,000) $ (371,000) $ (414,000) $ (325,000)
========== ========== ========== ==========
</TABLE>
The assumed discount rate used to determine the benefit obligation as of
December 31, 1998 and 1997 was 6.75% and 7.00%, respectively. The fair value
of pension plan assets excludes $21 million and $17 million held in grantor
trust as of December 31, 1998 and 1997, respectively, for the payment of
benefits under the supplemental plan.
49
<PAGE>
COMMONWEALTH EDISON COMPANY AND SUBSIDIARY COMPANIES
NOTES TO FINANCIAL STATEMENTS--Continued
The components of pension and other postretirement benefit costs, portions of
which were recorded as components of construction costs, for the years 1998,
1997 and 1996 were as follows:
<TABLE>
<CAPTION>
1998 1997 1996
-------- -------- --------
Pension Benefit Costs (Thousands of Dollars)
- ---------------------
<S> <C> <C> <C>
Service cost............ $115,000 $100,000 $ 93,000
Interest cost on
projected benefit
obligation............. 273,000 261,000 247,000
Expected return on plan
assets................. (342,000) (310,000) (289,000)
Amortization of
transition asset....... (12,000) (13,000) (13,000)
Amortization of prior
service asset.......... (4,000) (4,000) (4,000)
Recognized loss......... 2,000 2,000 2,000
Curtailment gain........ -- (5,000) --
-------- -------- --------
Net periodic benefit
cost.................. $ 32,000 $ 31,000 $ 36,000
======== ======== ========
<CAPTION>
Other Postretirement
Benefit Costs
- --------------------
<S> <C> <C> <C>
Service cost............ $ 38,000 $ 34,000 $ 32,000
Interest cost on
accumulated benefit
obligation............. 78,000 76,000 73,000
Expected return on plan
assets................. (69,000) (61,000) (55,000)
Amortization of
transition obligation.. 22,000 22,000 22,000
Amortization of prior
service cost........... 4,000 4,000 3,000
Recognized gain......... (14,000) (13,000) (9,000)
Severance plan cost..... 6,000 8,000 4,000
-------- -------- --------
Net periodic benefit
cost.................. $ 65,000 $ 70,000 $ 70,000
======== ======== ========
</TABLE>
In accounting for the pension costs and other postretirement benefit costs
under the plans, the following weighted average actuarial assumptions were used
for the years 1998, 1997 and 1996:
<TABLE>
<CAPTION>
Other
Pension Benefits Postretirement Benefits
----------------- -----------------------
1998 1997 1996 1998 1997 1996
----- ----- ----- ------- ------- -------
<S> <C> <C> <C> <C> <C> <C>
Annual discount rate................. 7.00% 7.50% 7.50% 7.00% 7.50% 7.50%
Annual long-term rate of return on
plan assets......................... 9.50% 9.75% 9.75% 9.20% 9.40% 9.38%
Annual rate of increase in future
compensation levels................. 4.00% 4.00% 4.00% -- -- --
</TABLE>
The pension curtailment gain in December 1997 represents the recognition of
prior service costs, the transition asset and the decrease in the projected
benefit obligation related to the reduction in the number of employees due to
the sale of State Line Station by the Indiana Company.
Postretirement health care costs for the years 1998, 1997 and 1996 included
$6 million, $8 million and $4 million, respectively, related to voluntary
separation offers to certain employees of ComEd and the Indiana Company.
The health care cost trend rates used to measure the expected cost of the
postretirement medical benefits are assumed to be 8.5% for pre-Medicare
recipients and 6.5% for Medicare recipients for 1998. Those rates are assumed
to decrease in 0.5% annual increments to 5% for the years 2005 and 2001,
respectively, and to remain level thereafter. The health care cost trend rates,
used to measure the expected cost of postretirement dental and vision benefits,
are a level 3.5% and 2.0% per year, respectively. Assumed health care cost
trend rates have a significant effect on the amounts reported
50
<PAGE>
COMMONWEALTH EDISON COMPANY AND SUBSIDIARY COMPANIES
NOTES TO FINANCIAL STATEMENTS--Continued
for the health care plans. A one percentage point change in the assumed health
care cost trend rates would have the following effects:
<TABLE>
<CAPTION>
1 Percentage 1 Percentage
Point Increase Point Decrease
-------------- --------------
(Thousands of Dollars)
<S> <C> <C>
Effect on total annual service and interest cost
components...................................... $ 24,000 $ (18,000)
Effect on postretirement benefit obligation...... 225,000 (176,000)
</TABLE>
In addition, an employee savings and investment plan is available to
eligible employees of ComEd and certain of its subsidiaries. Under the plan,
each participating employee may contribute up to 20% of such employee's base
pay. The participating companies match the first 6% of such contribution equal
to 100% of the first 2% of contributed base salary, 70% of the next 3% of
contributed base salary and 25% of the next 1% of contributed base salary. The
participating companies' contributions were $32 million, $33 million and
$30 million for the years 1998, 1997 and 1996, respectively.
(17) Separation Plan Costs
O&M expenses included $48 million, $39 million and $12 million for the years
1998, 1997 and 1996, respectively, for costs related to voluntary separation
offers to certain employees of ComEd and the Indiana Company, as well as
certain one-time, employee-related costs. Such costs resulted in charges of
$29 million (after-tax), $24 million (after-tax) and $7 million (after-tax)
for the years 1998, 1997 and 1996, respectively.
(18) Income Taxes
The components of the net deferred income tax liability at December 31, 1998
and 1997 were as follows:
<TABLE>
<CAPTION>
December 31
----------------------
1998 1997
---------- ----------
(Thousands of
Dollars)
<S> <C> <C>
Deferred income tax liabilities:
Accelerated cost recovery and liberalized deprecia-
tion, net of removal costs........................... $4,007,681 $4,051,191
Overheads capitalized................................. 140,922 131,509
Repair allowance...................................... 233,861 231,697
Regulatory assets recoverable through future rates.... 680,356 785,354
Deferred income tax assets:
Postretirement benefits............................... (331,566) (305,220)
Unamortized investment tax credits.................... (191,135) (206,112)
Regulatory liabilities to be settled through future
rates................................................ (595,005) (698,750)
Nuclear plant closure................................. (38,354) (194,244)
Other--net............................................ (145,268) (135,311)
---------- ----------
Net deferred income tax liability...................... $3,761,492 $3,660,114
========== ==========
</TABLE>
The $101 million increase in the net deferred income tax liability from
December 31, 1997 to December 31, 1998 is comprised of $102 million of
deferred income tax expense and a $1 million decrease in regulatory assets net
of regulatory liabilities pertaining to income taxes for the year. The amount
of accelerated cost recovery and liberalized depreciation included in deferred
income tax liabilities as of December 31, 1998 includes amounts related to the
regulatory asset for impaired production plant. The amount of regulatory
assets included in deferred income tax liabilities primarily relates to the
equity component of AFUDC which is recorded on an after-tax basis, the
borrowed funds component of AFUDC which was previously recorded net of tax and
other temporary differences for
51
<PAGE>
COMMONWEALTH EDISON COMPANY AND SUBSIDIARY COMPANIES
NOTES TO FINANCIAL STATEMENTS--Continued
which the related tax effects were not previously recorded. The amount of
other regulatory liabilities included in deferred income tax assets primarily
relates to deferred income taxes provided at rates in excess of the current
statutory rate.
The components of net income tax expense charged (credited) to continuing
operations for the years 1998, 1997 and 1996 were as follows:
<TABLE>
<CAPTION>
1998 1997 1996
-------- --------- --------
(Thousands of Dollars)
<S> <C> <C> <C>
Electric operating income:
Current income taxes.......................... $340,098 $279,416 $339,364
Deferred income taxes......................... 43,299 58,655 156,261
Investment tax credits deferred--net.......... (27,730) (31,015) (33,378)
Other (income) and deductions:
Current income taxes.......................... (51,816) 1,116 (12,348)
Deferred income taxes......................... 59,458 (385,994) 5,118
Investment tax credits........................ (12,107) (22,526) --
-------- --------- --------
Net income taxes charged (credited) to continu-
ing operations................................ $351,202 $(100,348) $455,017
======== ========= ========
</TABLE>
Provisions for current and deferred federal and state income taxes and
amortization of investment tax credits resulted in the following effective
income tax rates for the years 1998, 1997 and 1996:
<TABLE>
<CAPTION>
1998 1997 1996
-------- --------- ----------
<S> <C> <C> <C>
Pre-tax book income (loss) (thousands)......... $945,408 $(260,486) $1,198,385
Effective income tax rate...................... 37.1% 38.5% 38.0%
</TABLE>
The principal differences between net income taxes charged (credited) to
continuing operations and the amounts computed at the federal statutory rate
of 35% for the years 1998, 1997 and 1996 were as follows:
<TABLE>
<CAPTION>
1998 1997 1996
-------- --------- --------
(Thousands of Dollars)
<S> <C> <C> <C>
Federal income taxes computed at statutory rate. $330,893 $ (91,170) $419,435
Equity component of AFUDC which was excluded
from taxable income............................ (390) (8,320) (7,272)
Amortization of investment tax credits, net of
deferred income taxes.......................... (25,503) (53,541) (33,378)
State income taxes, net of federal income taxes. 43,699 3,470 58,381
Differences between book and tax accounting,
primarily property-related deductions.......... 2,503 49,213 17,851
-------- --------- --------
Net income taxes charged (credited) to continu-
ing operations................................. $351,202 $(100,348) $455,017
======== ========= ========
</TABLE>
The effects of an income tax refund related to prior years were recorded in
1996, resulting in a positive impact of $26 million (after-tax).
(19) Taxes, Except Income Taxes
Provisions for taxes, except income taxes, for the years 1998, 1997 and 1996
were as follows:
<TABLE>
<CAPTION>
1998 1997 1996
-------- -------- --------
(Thousands of Dollars)
<S> <C> <C> <C>
Illinois electricity excise tax............... $126,481 $228,350 $227,062
Illinois invested capital..................... -- 99,503 104,663
Illinois electricity distribution tax......... 110,025 -- --
Municipal utility gross receipts.............. 152,879 168,094 168,715
Real estate................................... 124,131 150,179 129,985
Municipal compensation........................ 78,010 78,286 78,544
Other--net.................................... 105,625 74,755 73,699
-------- -------- --------
$697,151 $799,167 $782,668
======== ======== ========
</TABLE>
52
<PAGE>
COMMONWEALTH EDISON COMPANY AND SUBSIDIARY COMPANIES
NOTES TO FINANCIAL STATEMENTS--Continued
Effective January 1, 1998, the Illinois invested capital tax was repealed
and the Illinois electricity distribution tax was enacted as a replacement.
The new tax is based on the kilowatthours delivered to ultimate consumers.
Effective August 1, 1998, as provided for by the 1997 Act, the Illinois
electricity excise tax and certain municipal utility taxes are recorded as
liabilities. Previously, similar taxes were presented on the Statements of
Consolidated Operations as revenue and expense. The reduction in operating
revenues and taxes, except income taxes, due to the change in presentation for
such taxes was approximately $95 million for 1998. This change in the
presentation for such taxes did not have an effect on results of operations.
ComEd's real estate taxes in 1996 reflect a credit of $23 million which
related to the year 1995.
See Note 22 for additional information regarding Illinois invested capital
taxes.
(20) Lease Obligations
Under its nuclear fuel lease arrangement, ComEd may sell and lease back
nuclear fuel from a lessor who may borrow an aggregate of $700 million,
consisting of $300 million of commercial paper/bank borrowings and $400
million of intermediate term notes, to finance the transactions. With respect
to the commercial paper/bank borrowings portion, $300 million will expire on
November 23, 1999. With respect to the intermediate term notes, $60 million
expires on November 23, 1999, and an additional portion each November 23
thereafter through November 23, 2003. At December 31, 1998, ComEd's obligation
to the lessor for leased nuclear fuel amounted to approximately $529 million.
As a result of the permanent cessation of nuclear generation operations at
Zion Station, ComEd repurchased approximately $100 million of nuclear fuel
assemblies held under the nuclear fuel lease arrangements at Zion Station in
June 1998. See Note 5 for additional information regarding the permanent
cessation of nuclear generation operations at Zion Station. ComEd has agreed
to make lease payments which cover the amortization of the nuclear fuel used
in ComEd's reactors plus the lessor's related financing costs. ComEd has an
obligation for spent nuclear fuel disposal costs of leased nuclear fuel.
As of December 31, 1998, future minimum rental payments, net of executory
costs, for capital leases are estimated to aggregate to $589 million,
including $217 million in 1999, $164 million in 2000, $99 million in 2001, $60
million in 2002, $33 million in 2003 and $16 million in 2004-2005. The
estimated interest component of such rental payments aggregates $64 million.
The estimated portions of obligations due within one year under capital leases
of $195 million and $241 million at December 31, 1998 and 1997, respectively,
were included in current liabilities on the Consolidated Balance Sheets.
Future minimum rental payments at December 31, 1998 for operating leases are
estimated to aggregate to $286 million, including $37 million in 1999, $34
million in 2000, $28 million in 2001, $26 million in 2002, $24 million in 2003
and $137 million in 2004-2024.
(21) Joint Plant Ownership
ComEd has a 75% undivided ownership interest in the Quad Cities nuclear
generating station. Further, ComEd is responsible for 75% of all costs which
are charged to appropriate investment and O&M accounts, and provides its own
financing. ComEd's net plant investment, including construction work in
progress, in Quad Cities Station on the Consolidated Balance Sheets was $5
million at December 31, 1998, after reflecting the accounting impairment
recorded in the second quarter of 1998. See Note 2 for additional information.
53
<PAGE>
COMMONWEALTH EDISON COMPANY AND SUBSIDIARY COMPANIES
NOTES TO FINANCIAL STATEMENTS--Continued
(22) Commitments and Contingent Liabilities
Purchase commitments, principally related to construction and nuclear fuel,
approximated $335 million at December 31, 1998. In addition, ComEd has
substantial commitments for the purchase of coal. ComEd's coal costs are high
compared to those of other utilities. ComEd's western coal contracts and its
rail contracts for delivery of the western coal provide for the purchase of
certain coal at prices substantially above currently prevailing market prices.
See "Management's Discussion and Analysis of Financial Condition and Results
of Operations," subcaption "Liquidity and Capital Resources--Construction
Program," for additional information regarding ComEd's purchase commitments.
ComEd is a member of NEIL which provides insurance coverage against property
damage and associated replacement power costs occurring at members' nuclear
generating facilities. All companies insured with NEIL are subject to
retrospective premium adjustments if losses exceed accumulated reserve funds.
Capital has been accumulated in the reserve funds such that ComEd would not be
liable for any single incident. However, ComEd could be subject to assessments
in any policy year for each of three types of coverage provided. The maximum
assessments are approximately $53 million for primary property damage, $73
million for excess property damage and $22 million for replacement power.
Prior to January 1, 1998, the primary property damage coverage described was
provided by NML, another mutual insurance company which merged into NEIL. The
merger did not affect ComEd's obligations or coverage.
The NRC's indemnity for public liability coverage under the Price-Anderson
Act is supported by a mandatory industry-wide program under which owners of
nuclear generating facilities could be assessed in the event of nuclear
incidents. Based on the number of nuclear reactors with operating licenses,
ComEd would currently be subject to a maximum assessment of $1,145 million in
the event of an incident, limited to a maximum of $130 million in any calendar
year.
In addition, ComEd participates in the American Nuclear Insurers Master
Worker Program, which provides coverage for worker tort claims filed for
bodily injury caused by the nuclear energy hazard. This program was modified,
effective January 1, 1998, to provide coverage to all workers whose "nuclear-
related employment" began on or after the commencement date of reactor
operations. ComEd will not be liable for a retrospective assessment under this
new policy. However, ComEd is still subject to a maximum retroactive
assessment of up to $36 million in the event losses incurred under the small
number of policies in the old program exceed accumulated reserves.
During 1989 and 1991, actions were brought in federal and state courts in
Colorado against ComEd and Cotter seeking unspecified damages and injunctive
relief based on allegations that Cotter has permitted radioactive and other
hazardous material to be released from its mill into areas owned or occupied
by the plaintiffs resulting in property damage and potential adverse health
effects. With respect to Cotter, in 1994 a federal jury returned nominal
dollar verdicts against Cotter on eight bellwether plaintiffs' claims in the
1989 cases, which verdicts were upheld on appeal. The remaining claims in the
1989 actions have been settled and dismissed. On July 15, 1998, a jury verdict
was rendered in Dodge v. Cotter (United States District Court for the District
of Colorado, Civil Action No. 91-Z-1861), a case relating to 14 of the
plaintiffs in the 1991 cases. The verdict against Cotter included compensatory
and punitive damages totaling approximately $3 million (not including
prejudgment interest, which has not yet been calculated, and which Cotter
anticipates may bring the total award to under $6 million), together with
medical monitoring. The matter is currently on appeal. Although the other 1991
cases will necessarily involve the resolution of numerous contested issues of
fact and law, ComEd's determination is that these actions will not have a
material impact on its financial position or results of operations.
54
<PAGE>
COMMONWEALTH EDISON COMPANY AND SUBSIDIARY COMPANIES
NOTES TO FINANCIAL STATEMENTS--Continued
ComEd is involved in administrative and legal proceedings concerning air
quality, water quality and other matters. The outcome of these proceedings may
require increases in future construction expenditures and operating expenses
and changes in operating procedures. ComEd and its subsidiaries are or are
likely to become parties to proceedings initiated by the U.S. EPA, state
agencies and/or other responsible parties under CERCLA with respect to a
number of sites, including MGP sites, or may voluntarily undertake to
investigate and remediate sites for which they may be liable under CERCLA.
ComEd generally did not operate MGPs as a corporate entity but did, however,
acquire MGP sites as part of the absorption of smaller utilities.
Approximately half of these sites were transferred to Northern Illinois Gas
Company as part of a general conveyance in 1954. ComEd also acquired former
MGP sites as vacant real estate on which ComEd facilities have been
constructed. To date, ComEd has identified 44 former MGP sites for which it
may be liable for remediation. ComEd presently estimates that its costs of
former MGP site investigation and remediation will aggregate from $25 million
to $150 million in current-year (1999) dollars. It is expected that the costs
associated with investigation and remediation of former MGP sites will be
incurred over a period not to exceed 30 years. Because ComEd is not able to
determine the most probable liability for such MGP costs, in accordance with
accounting standards, a reserve of $25 million has been included in other
noncurrent liabilities on the Consolidated Balance Sheets as of December 31,
1998 and 1997, which reflects the low end of the range of ComEd's estimate of
the liability associated with former MGP sites. In addition, as of December
31, 1998 and 1997, a reserve of $8 million has been included in other
noncurrent liabilities on the Consolidated Balance Sheets, representing
ComEd's estimate of the liability associated with cleanup costs of remediation
sites other than former MGP sites. Approximately half of this reserve relates
to anticipated cleanup costs associated with a property formerly used as a
tannery which was purchased by ComEd in 1973. ComEd presently estimates that
its costs of investigating and remediating the former MGP and other
remediation sites, pursuant to CERCLA and state environmental laws, will not
have a material impact on the financial position or results of operations of
ComEd. These cost estimates are based on currently available information
regarding the responsible parties likely to share in the costs of responding
to site contamination, the extent of contamination at sites for which the
investigation has not yet been completed and the cleanup levels to which sites
are expected to have to be remediated.
The IDR has issued Notices of Tax Liability to ComEd alleging deficiencies
in Illinois invested capital tax payments for the years 1988 through 1996. The
alleged deficiencies including interest and penalties totaled approximately
$45 million as of December 31, 1998. ComEd has protested the notices, and the
matter is currently pending before the IDR's Office of Administrative
Hearings. Interest will continue to accrue on the alleged tax deficiencies.
55
<PAGE>
COMMONWEALTH EDISON COMPANY AND SUBSIDIARY COMPANIES
NOTES TO FINANCIAL STATEMENTS--Continued
(23) Quarterly Financial Information
<TABLE>
<CAPTION>
Net Income/
Electric Electric (Loss) on
Operating Operating Net Common
Three Months Ended (a) Revenues Income Income/(Loss) Stock
- ----------------------- ---------- --------- ------------- -----------
(Thousands of Dollars)
<S> <C> <C> <C> <C>
March 31, 1998.......... $1,709,613 $190,681 $ 71,833 $ 57,286
June 30, 1998........... $1,776,972 $214,982 $ 104,453 $ 89,991
September 30, 1998...... $2,089,547 $395,434 $ 286,071 $ 272,018
December 31, 1998....... $1,559,748 $209,149 $ 131,849 $ 118,027
March 31, 1997.......... $1,669,495 $214,310 $ 277,928 $ 262,401
June 30, 1997........... $1,685,196 $154,769 $ 25,063 $ 9,578
September 30, 1997...... $2,068,087 $390,345 $ 260,985 $ 246,083
December 31, 1997....... $1,650,310 $162,054 $(1,337,749) $(1,352,321)
</TABLE>
(a) The March 31, 1997 Net Income/(Loss) and Net Income/(Loss) on Common Stock
include $197 million (after-tax) for the cumulative effect of a change in
accounting principle.
(24) Subsequent Events
ComEd redeemed the following preference stock, first mortgage bonds and
sinking fund debentures on January 19, 1999, January 27, 1999 and February 16,
1999, respectively.
<TABLE>
<CAPTION>
Preference Stock
--------------------------------------------------------------------------
Shares
Series Outstanding Principal Amount
------ ----------- ----------------------
(Thousands of Dollars)
<S> <C> <C>
$8.40.................................. 750,000 $ 74,175
$8.38.................................. 750,000 73,566
$2.00.................................. 2,000,000 51,560
$1.96.................................. 2,000,000 52,440
$1.90.................................. 4,249,549 106,239
$7.24.................................. 750,000 74,340
$9.25.................................. 450,000 45,000
$8.85.................................. 187,500 18,750
$8.40 Series B......................... 240,000 23,838
$8.20.................................. 142,845 14,285
---------- --------
11,519,894 $534,193
========== ========
</TABLE>
<TABLE>
<CAPTION>
First Mortgage Bonds
--------------------------------------------------------------------------
Series Principal Amount
------ ----------------------
(Thousands of Dollars)
<S> <C>
9 1/8% due October 15, 2021.................... $125,000
8 7/8% due October 1, 2021..................... 100,000
8 1/8% due January 15, 2007.................... 180,000
8% due October 15, 2003........................ 125,000
7 5/8% due June 1, 2003........................ 100,000
7 1/2% due January 1, 2001..................... 100,000
--------
$730,000
========
</TABLE>
56
<PAGE>
COMMONWEALTH EDISON COMPANY AND SUBSIDIARY COMPANIES
NOTES TO FINANCIAL STATEMENTS--Concluded
<TABLE>
<CAPTION>
Sinking Fund Debentures
----------------------------------------------------------------------
Principal Amount
Series ----------------------
-----------------------------
(Thousands of Dollars)
<S> <C>
7 5/8% due February 15, 2003................... $56,000(1)
7 5/8% due February 15, 2003................... 2,000
-------
$58,000
=======
</TABLE>
--------
(1)Optional Redemption
In response to a tender offer, ComEd reacquired $229 million of the
following first mortgage bonds in early February 1999.
<TABLE>
<CAPTION>
Series Principal Amount
------------------------------ ---------------------
(Thousands of Dollars)
<S> <C>
9 3/8% due February 15, 2000................... $ 82,655
9 3/4% due February 15, 2020................... 146,547
--------
$229,202
========
</TABLE>
In the first quarter of 1999, ComEd expects to record losses and premiums
related to the early redemptions and the tender offer of the above-mentioned
first mortgage bonds, preference stock and sinking fund debentures, which will
reduce net income on common stock by approximately $38 million (after-tax).
In addition to the debt and preference stock redemptions and the tender
offer discussed above, Unicom also has announced plans to repurchase
approximately $750 million of Unicom common stock using the proceeds it
receives from ComEd's repurchase of its common stock held by Unicom. The
remaining proceeds will be used for the payment of fees and additional debt
and equity redemptions. See Note 7 for additional information.
57
