1997 INFORMATION STATEMENT AND ANNUAL REPORT TO SHAREHOLDERS
UNLOCKING THE POWER 1997
NOTICE OF ANNUAL MEETING OF SHAREHOLDERS
Information Statement Table of Contents
Notice of Annual Meeting 2
Information Statement 3
Appendix: 1997 Annual Report to Shareholders a-1
To the Shareholders of Illinois Power:
Notice is Hereby Given that the Annual Meeting of Shareholders of Illinois Power
Company ("Illinois Power") will be at 10 a.m. Wednesday, April 8, 1998, at
Shilling Community Education Center, Richland Community College, One College
Park, Decatur, Illinois 62521, for the following purposes:
(1) To elect the Board of Directors for the ensuing year.
(2) To transact any other business which may properly come before the
meeting or any adjournment.
Shareholders of record at the close of business on February 9, 1998, will
be entitled to receive notice of and to vote at the Annual Meeting.
By Order of the Board of Directors,
Leah Manning Stetzner,
Vice President, General Counsel and Corporate Secretary
Decatur, Illinois
March 10, 1998
IMPORTANT
Only shareholders of Illinois Power are entitled to attend the Annual Meeting.
Shareholders will be admitted on verification of record share ownership at the
admission desk. Shareholders who own shares through banks, brokerage firms,
nominees or other account custodians must present proof of beneficial share
ownership (such as a brokerage account statement) at the admission desk.
<PAGE>
INFORMATION STATEMENT
March 10, 1998
(Date first sent or given to security holders)
We are not asking you for a proxy and you are requested not to send us a proxy.
This Information Statement is furnished in connection with the Annual Meeting of
Shareholders of Illinois Power. The Annual Meeting will be held at 10 a.m.
Wednesday, April 8, 1998, at Shilling Community Education Center, Richland
Community College, One College Park, Decatur, Illinois 62521, for the purposes
set forth in the accompanying Notice of Annual Meeting of Shareholders.
On February 9, 1998 ("Record Date"), Illinova Corporation ("Illinova")
beneficially owned all of the 66,215,292 shares of Illinois Power Common Stock
then outstanding and there were 1,139,110 shares of Illinois Power Preferred
Stock then outstanding, none of which was held by Illinova.
Voting Rights
Shareholders of record at the close of business on the Record Date will be
entitled to receive notice of and to vote at the Annual Meeting. Shareholders
who are present at the Annual Meeting will be entitled to one vote for each
share of Illinois Power Stock which they held of record at the close of business
on the Record Date.
When voting for candidates nominated to serve as directors, all
shareholders will be entitled to 11 votes (the number of directors to be
elected) for each of their shares and may cast all of their votes for any one
candidate whose name has been placed in nomination prior to the voting, or
distribute their votes among two or more such candidates in such proportions as
they determine. In voting on other matters presented for consideration at the
Annual Meeting, each shareholder will be entitled to one vote for each share of
Stock held of record at the close of business on the Record Date.
Annual Report
and Information Statement
Accompanying this Information Statement, which includes Consolidated Financial
Statements, is a Notice of Annual Meeting of Shareholders and the Summary Annual
Report to Shareholders covering operations of Illinova for the year 1997. This
Information Statement and accompanying documents are first being mailed to
shareholders on or about March 10, 1998.
<PAGE>
Board of Directors
Information Regarding the Board of Directors
The Board of Directors held 10 Board meetings in 1997. Other than Mr. Adorjan,
who joined the Board in August 1997, and Mr. Berry, who retired from the Board
December 1, 1997, all directors attended at least 75% of the aggregate meetings
of the Board and Committees of which they were members during 1997. The Board
has four standing committees: the Audit Committee, the Finance Committee, the
Compensation and Nominating Committee and the Nuclear Operations Committee.
The duties and members of the standing committees are:
Audit Committee
(1) Review with the Chairman, President and Chief Executive Officer and the
independent accountants the scope and adequacy of Illinois Power's system of
internal controls; (2) review the scope and results of the annual examination
performed by the independent accountants; (3) review the activities of Illinois
Power's internal auditors; (4) report its findings to the Board and provide a
line of communication between the Board and both the internal auditors and the
independent accountants; and (5) recommend to the Board the appointment of the
independent accountants and approval of the services performed by the
independent accountants, considering their independence with regard thereto.
The Audit Committee met three times during 1997.
This Committee consists of the following non-employee directors ("Outside
Directors"): Robert M. Powers, Chairman, Richard R. Berry, C. Steven McMillan,
Sheli Z. Rosenberg, Walter M. Vannoy, and Marilou von Ferstel.
Finance Committee
(1) Review management's cash flow forecasts, financial forecasts and financing
program, and make recommendations to the Board regarding the approval of such
plans; (2) review Illinois Power's banking relationships, short-term borrowing
arrangements, dividend policies, arrangements with the transfer agent and
registrar, investment objectives and the performance of Illinois Power's pension
and other trust funds, evaluate fund managers, and make recommendations to the
Board concerning such matters; (3) review Illinois Power's risk management
programs, including insurance coverage, and make recommendations to the Board;
and (4) act in an advisory capacity to management, the Board of Directors, and
the Chairman, President and Chief Executive Officer on other financial matters
as they may arise.
The Finance Committee met three times during 1997.
This Committee consists of the following members of the Board: Walter D.
Scott, Chairman, J. Joe Adorjan, Richard R. Berry, Larry D. Haab, C. Steven
McMillan, Sheli Z. Rosenberg, Marilou von Ferstel, and John D. Zeglis.
Compensation and Nominating Committee
(1) Review performance and recommend salaries plus other forms of compensation
of elected Illinois Power officers and the Board of Directors; (2) review
Illinois Power's benefit plans for elected Illinova officers and make
recommendations to the Board regarding any changes deemed necessary; (3) review
with the Chairman, President and Chief Executive Officer any organizational or
other personnel matters; and (4) recommend to the Board nominees to stand for
election as director to fill vacancies in the Board of Directors as they occur.
The Compensation and Nominating Committee will consider shareholders'
recommendations for nominees for director made pursuant to timely notice in
writing addressed to the Chairman of the Committee at the executive offices of
Illinois Power. The recommendation should include a full description of the
qualifications and business and professional experience of the proposed nominees
and a statement of the nominees' willingness to serve. To be timely, the notice
must be delivered to or mailed and received at the executive offices of Illinois
Power not less than 90 nor more than 120 days prior to the Annual Meeting.
The Compensation and Nominating Committee met four times during 1997.
This Committee consists of the following Outside Directors: Ronald L.
Thompson, Chairman, J. Joe Adorjan, C. Steven McMillan, Robert M. Powers, Walter
D. Scott, Marilou von Ferstel, and John D. Zeglis.
Nuclear Operations Committee
(1) Review the safety, reliability and quality of nuclear operations; (2) review
the effectiveness of the management of nuclear operations; (3) review the
strategic plan for nuclear operations; (4) review various nuclear reports; and
(5) report its findings to the Board.
The Nuclear Operations Committee met four times during 1997.
This Committee consists of the following members of the Board: Walter M.
Vannoy, Chairman, Richard R. Berry, Larry D. Haab, Robert M. Powers, Walter D.
Scott, and Ronald L. Thompson.
<PAGE>
Board Compensation
The Outside Directors of Illinois Power, all of whom also serve on the Board of
Illinova, receive a total retainer fee of $18,000 per year for their service on
these boards. Outside Directors who also chair Board Committees receive an
additional $2,000, increased in February 1998 to $2,500, per year retainer.
Outside Directors receive a grant of 650 shares of Illinova Common Stock on the
date of each Annual Shareholders Meeting, representing payment in lieu of
attendance-based fees for all Board and Committee meetings to be held during the
subsequent one-year period. Outside Directors elected to the Board between
Annual Shareholders Meetings are paid $850 for each Board and Committee meeting
attended prior to the first Annual Shareholders Meeting after their election to
the Board.
Illinova had a Retirement Plan for Outside Directors. Under this plan, each
Outside Director who attained age 65 and served on the Board for a period of 60
or more consecutive months was eligible for annual retirement benefits at the
rate of the annual retainer fee in effect when the director retired. In 1996,
the Board of Directors adopted a Comprehensive Deferred Stock Plan for Outside
Directors, replacing the Retirement Plan. Each former Outside Director whose
right to receive the retirement benefit had vested continues to receive such
benefits in accordance with the terms of the Retirement Plan. All Outside
Directors serving at the time this new plan was adopted were granted a lump sum
amount based on the net present value of these benefits to them, were they to
have retired under the Retirement Plan, based on the number of years they have
served on the Board but not to exceed 10. This dollar amount was converted into
stock units, based on the then market value of Illinova Common Stock, and placed
into an account. The value of these stock units is to be paid out to the
director in cash on termination of service, based on the then market value of
Illinova Common Stock, plus dividend equivalents, in a lump sum or installments.
In addition, each Outside Director receives an annual award of stock units
having a value of $6,000, to be paid to the Outside Director in cash on
retirement, at once or in installments as the Director may elect, with the
amount of such payment determined by multiplying the number of stock units in
the account times the then market value of Illinova Common Stock, and adding the
dividend equivalents attributable to such stock units.
Pursuant to Illinova's Deferred Compensation Plan for Certain Directors,
Outside Directors of Illinois Power may elect to defer all or any portion of
their fees and stock grants until termination of their services as directors.
Such deferred amounts are converted into stock units representing shares of
Illinova Common Stock with the value of each stock unit based on the last
reported sales price of such stock. Additional credits are made to the
participating director's account in dollar amounts equal to the dividends paid
on the Common Stock which the director would have received if the director had
been the record owner of the shares represented by stock units, and these
amounts are converted into additional stock units. On termination of the
participating directors' services as directors, payment of their deferred fees
and stock grants was made in shares of Illinova Common Stock in an amount equal
to the aggregate number of stock units credited to their accounts. The plan was
amended in 1997 to provide for a payout in cash instead of shares of Common
Stock. Deferred amounts are still converted into stock units representing shares
of Common Stock with the value of each stock unit based on the last reported
sales price of such stock. Payment is made in cash, in a lump sum or
installments, as soon as practical following a director's termination. The cash
paid on termination equals the number of stock units times the share price at
the close of market on the last business day of the month preceding termination.
No other payments are made after service on the Board ceases.
Election of Directors
Illinois Power's entire Board of Directors is elected at each Annual Meeting of
Shareholders. Directors hold office until the next Annual Meeting of
Shareholders or until their successors are elected and qualified. At the Annual
Meeting a vote will be taken on a proposal to elect the 11 directors nominated
by Illinois Power's Board of Directors. The names and certain additional
information concerning each of the director nominees is set forth on the
following pages. If any nominee should become unable to serve as a director,
another nominee may be selected by the current Board of Directors. Walter M.
Vannoy normally would have not been eligible for election as a director at the
Annual Meeting of Shareholders pursuant to a Bylaw provision which mandates
retirement from Board service at age 70. Because there is a current need for his
nuclear expertise, the Board of Directors has elected to waive this requirement
in Mr. Vannoy's case, and he has agreed to serve if elected.
<PAGE>
BOARD OF DIRECTORS
Name of Director Nominee, Age, Year in Which First
Business Experience and Elected a Director
Other Information of Illinois Power
J. Joe Adorjan, 59 1997
Chairman and Chief Executive Officer of Borg-Warner Security Corporation,
Chicago, Ill., a security systems services firm, since 1995. He was President of
Emerson Electric Company from 1993 to 1995. Prior to that, he was Chairman and
Chief Executive Officer of ESCO Electronics Corporation. He is a director of The
Earthgrains Company, ESCO Electronics Corporation and Goss Graphics Systems,
Inc.
Larry D. Haab, 60 1986
Chairman, President, and Chief Executive Officer of Illinova since December
1993, and of Illinois Power since June 1991, and an employee of Illinois Power
since 1965. He is a director of First Decatur Bancshares, Inc.; The First
National Bank of Decatur; and Firstech, Incorporated.
C. Steven McMillan, 52 1996
President, Chief Operating Officer, and Director of Sara Lee Corporation,
Chicago, Ill., a global packaged food and consumer products company, since 1997.
He was Executive Vice President of Sara Lee from 1993 to 1997 and Senior Vice
President-Strategy Development from 1986 to 1993. He is Chairman of the Board of
Electrolux Corporation.
Robert M. Powers, 66 1984
From 1980 until retirement in December 1988, Mr. Powers was President and Chief
Executive Officer of A. E. Staley Manufacturing Company, Decatur, Ill., a
processor of grain and oil seeds. He is a director of A. E. Staley Manufacturing
Company.
Sheli Z. Rosenberg, 56 1997
President and Chief Executive Officer since 1994 and General Counsel 1980 to
1994 of Equity Group Investments, Inc., Chicago, Ill., a privately held business
conglomerate holding controlling interests in nine publicly traded corporations
involved in basic manufacturing, radio stations, retail, insurance, and real
estate. She is a director of American Classic Voyages Company; Quality Food
Centers, Inc.; Jacor Communications, Inc.; Anixter International , Inc.; Equity
Office Properties Trust; Equity Residential Properties Trust; CVS Corporation;
and Manufactured Home Communities, Inc.
Walter D. Scott, 66 1990
Professor of Management and Senior Austin Fellow, J. L. Kellogg Graduate School
of Management, Northwestern University, Evanston, Ill., since 1988. He was
Chairman of GrandMet USA from 1984 to 1986 and President and Chief Executive
Officer of IDS Financial Services from 1980 to 1984. He is a director of Chicago
Title and Trust Company, Chicago Title Insurance Company, Neodesic Corporation,
Orval Kent Holding Company, Inc., and Intermatic Incorporated.
Joe J. Stewart, 59
President of BWX Technologies, Inc., formerly The Babcock & Wilcox Government
Group, Lynchburg, Va., a diversified energy equipment and services company, and
Executive Vice President of McDermott International, Inc. (parent of BWX
Technologies, Inc. and The Babcock & Wilcox Company), since 1995. He was
President and Chief Operating Officer of The Babcock & Wilcox Company and
Executive Vice President of McDermott International, Inc., from 1993 to 1995 and
Executive Vice President of the Power Generation Group of The Babcock & Wilcox
Company from 1987 to 1993.
<PAGE>
Ronald L. Thompson, 48 1991
Chairman and Chief Executive Officer of Midwest Stamping and Manufacturing Co.,
Bowling Green, Ohio, a manufacturer of automotive parts, since 1993. He was
President and Chief Executive Officer and a director of The GR Group, Inc., St.
Louis, Mo., from 1980 to 1993. He is a director of Teachers Insurance and
Annuity Association, and Ryerson Tull.
Walter M. Vannoy, 70 1990
Chairman until retirement in May 1995 and Chief Executive Officer from May 1994
until January 1995 of Figgie International, Inc., Willoughby, Ohio, a
diversified operating company serving consumer, industrial, technical, and
service markets world-wide. From 1980 to 1988 he was President and Chief
Operating Officer, The Babcock & Wilcox Company, and Vice Chairman of McDermott
International, Inc.
Marilou von Ferstel, 60 1990
Executive Vice President and General Manager of Ogilvy Adams & Rinehart, Inc., a
public relations firm in Chicago, Ill., from June 1990 until retirement in April
1997. She was Managing Director and Senior Vice President of Hill and Knowlton,
Chicago, Ill., from 1981 to 1990. She is a director of Walgreen Company.
John D. Zeglis, 50 1993
President of AT&T, Basking Ridge, N.J., a diversified communications company,
since October 1997. He was Vice Chairman from June 1997 to October 1997, Senior
Executive Vice President and General Counsel, from 1995 to June 1997 and Senior
Vice President - General Counsel and Government Affairs from 1989 to 1995. He is
a director of the Helmerich & Payne Corporation.
Security Ownership of Management
and Certain Beneficial Owners
The table below shows shares of Illinova Common Stock beneficially owned as of
January 31, 1998, by each director nominee and executive officers named in the
Summary Compensation Table. All of Illinois Power's Common Stock is owned by
Illinova. To the best of Illinois Power's knowledge, no owner holds more than 5
percent of Illinois Power Preferred Stock.
Number Number of Stock
of Shares Units in Deferred
Name of Beneficially Compensation Percent
Beneficial Owner Owned (1)(2) Plans of Class
J. Joe Adorjan 0 0 (3)
Larry D. Haab 68,250 0 (3)
C. Steven McMillan 1,300 289 (3)
Robert M. Powers 8,550 289 (3)
Sheli Z. Rosenberg 0 1,539 (3)
Walter D. Scott 5,150 289 (3)
Joe J. Stewart 0 0 (3)
Ronald L. Thompson 3,677 3,275 (3)
Walter M. Vannoy 5,010 289 (3)
Marilou von Ferstel 4,420 1,603 (3)
John D. Zeglis 2,626 1,603 (3)
Paul L. Lang 21,216 0 (3)
Larry F. Altenbaumer 13,092 0 (3)
John G. Cook 11,894 0 (3)
David W. Butts 8,817 0 (3)
(1) With sole voting and/or investment power.
(2) Includes the following shares issuable pursuant to stock options
exercisable March 31, 1998: Mr. Haab, 56,900; Mr. Lang, 17,800; Mr.
Altenbaumer, 17,800; Mr. Cook, 9,900; and Mr. Butts, 7,900.
(3) No director or executive officer owns any other equity securities of
Illinova or as much as 1% of the Common Stock. As a group, directors
and executive officers of Illinova and Illinois Power own 187,021
shares of Common Stock (less than 1%).
<PAGE>
Executive Compensation
The following table sets forth a summary of the compensation of the Chief
Executive Officer and the four other most highly compensated executive officers
of Illinois Power for the years indicated. The compensation shown includes all
compensation paid for service to Illinois Power, its parent and subsidiaries.
<TABLE>
Summary Compensation Table
Long-Term Compensation
Annual Compensation Awards
Other Restricted Securities All Other
Bonus Annual Stock Awards Underlying Compensation
Name and Principal Position Year Salary (1) Compensation (2) Options (3)
<S> <C> <C> <C> <C> <C> <C> <C>
Larry D. Haab 1997 $514,952 $ 41,840 $ 16,557 $ 41,840 20,000 shs. $ 2,614
Chairman, President and 1996 493,709 69,267 15,973 69,267 22,000 shs. 2,615
Chief Executive Officer of 1995 472,250 91,144 19,088 91,144 20,000 shs. 2,550
Illinova and Illinois Power
Paul L. Lang 1997 $242,325 $ 10,602 $ 8,305 $ 10,601 6,500 shs. $ 2,615
Senior Vice President 1996 233,450 19,747 8,863 19,747 6,500 shs. 2,595
of Illinois Power 1995 222,812 23,841 8,265 23,841 6,500 shs. 2,510
Larry F. Altenbaumer 1997 $232,048 $ 8,992 $ 9,521 $ 8,992 6,500 shs. $ 1,985
Chief Financial Officer, 1996 222,374 19,832 8,459 19,832 7,500 shs. 1,976
Treasurer and Controller 1995 204,937 20,391 7,686 20,391 6,500 shs. 2,378
of Illinova, and Senior
Vice President and Chief
Financial Officer of
Illinois Power
John G. Cook 1997 $203,413 $ - $ 7,642 $ - 6,000 shs. $ 2,575
Senior Vice President 1996 196,474 16,293 7,409 16,293 6,500 shs. 2,575
and former Chief Nuclear 1995 179,069 16,620 6,930 16,620 4,500 shs. 2,530
Officer of Illinois Power
David W. Butts 1997 $188,227 $ 7,529 $ 7,185 $ 7,529 6,000 shs. $ 2,595
President of Illinova 1996 181,402 17,314 7,350 17,314 6,500 shs. 2,595
Energy Partners, formerly 1995 153,333 18,132 6,990 18,132 5,000 shs. 2,540
Senior Vice President of
Illinois Power
</TABLE>
(1) The amounts shown in this column are the cash award portion of grants
made to these individuals under the Executive Incentive Compensation
Plan ("Compensation Plan") for 1997, including amounts deferred under
the Executive Deferred Compensation Plan. See the Compensation Plan
description in footnote (2) below.
(2) This table sets forth stock unit awards for 1997 under the
Compensation Plan. One-half of each year's award under this plan is
converted into stock units representing shares of Illinova Common
Stock based on the closing price of Common Stock on the last trading
day of the award year. The other one-half of the award is cash and is
included under Bonus in the Summary Compensation Table. Stock units
awarded in a given year, together with cash representing the
accumulated dividend equivalents on those stock units, become fully
vested after a three-year holding period. Stock units are converted
into cash based on the closing price of Common Stock on the first
trading day of the distribution year. Participants (or beneficiaries
of deceased participants) whose employment is terminated by retirement
on or after age 55, disability, or death receive the present value of
all unpaid awards on the date of such termination. Participants whose
employment is terminated for reasons other than retirement,
disability, or death forfeit all unvested awards. In the event of a
termination of employment within two years after a change in control
of Illinova, without good cause or by any participant with good
reason, all awards of the participant become fully vested and payable.
As of December 31, 1997, named executive officers were credited with
the following total aggregate number of unvested stock units under the
Compensation Plan since its inception, valued on the basis of the
closing price of Common Stock on December 31, 1997: Mr. Haab, 7,619
units valued at $205,241; Mr. Lang, 2,044 units valued at $55,071; Mr.
Altenbaumer, 1,862 units valued at $50,151; Mr. Cook, 1,250 units
valued at $33,685; Mr. Butts, 1,626 units valued at $43,787. Although
stock units have been rounded, valuation is based on total stock
units, including partial shares.
(3) The amounts shown in this column are Illinois Power's contributions
under the Incentive Savings Plan (including the market value of shares
of Illinova Common Stock at the time of allocation).
<PAGE>
The following tables summarize grants during 1997 of stock options under
Illinova's 1992 Long-Term Incentive Compensation Plan ("LTIC") and awards
outstanding at year end for the individuals named in the Summary Compensation
Table.
<TABLE>
<S> <C> <C> <C> <C> <C>
Option Grants In 1997
Individual Grants
Number of Securities % of Total Options
Underlying Options Granted to Employees Exercise or Base Grant Date
Granted (1) in 1997 Price Per Share (1) Expiration Date Present Value (2)
Larry D. Haab 20,000 24% $26.125 2/12/2007 $107,200
Paul L. Lang 6,500 8% 26.125 2/12/2007 34,840
Larry F. Altenbaumer 6,500 8% 26.125 2/12/2007 34,840
John G. Cook 6,000 7% 26.125 2/12/2007 32,160
David W. Butts 6,000 7% 26.125 2/12/2007 32,160
</TABLE>
(1) Each option becomes exercisable on February 12, 2000. In addition to
the specified expiration date, the grant expires on the first
anniversary of the recipient's death and/or five years following date
of retirement, and is not exercisable in the event a recipient's
employment terminates. In the event of certain change-in-control
circumstances, the Compensation and Nominating Committee may declare
the option immediately exercisable. The exercise price of each option
is equal to the fair market value of the Common Stock on the date of
the grant. Recipients shall also receive, on or shortly after February
12, 2000, a target performance award, determined by calculating the
difference between the return earned by Illinova on its invested
capital and its cost of capital (the "spread"), then comparing this
spread to that of a peer group and reducing or increasing the target
award depending on Illinova's relative performance, but not reducing
the payment below zero. The target award is equal to one-half of the
mid-point of compensation for each officer's salary grade (a
market-based number) times a percentage, determined by the
Compensation and Nominating Committee. In 1997 those percentages
ranged between 20 and 45 percent. At the discretion of the Board of
Directors, the foregoing payment may be made in the form of Illinova
Common Stock of equivalent value based on the average New York Stock
Exchange price of the stock during February 2000, or in cash.
(2) The Grant Date Present Value has been calculated using the
Black-Scholes option pricing model. Disclosure of the Grant Date
Present Value, or the potential realizable value of option grants
assuming 5% and 10% annualized growth rates, is mandated by
regulation; however, Illinova does not necessarily view the
Black-Scholes pricing methodology, or any other present methodology,
as a valid or accurate means of valuing stock option grants. The
calculation was based on the following assumptions: (i) As of the
grant date, Illinova's calculated Black-Scholes ratio was .2248. After
discounting for risk of forfeiture at 3 percent per year over
Illinova's three-year vesting schedule, the ratio is reduced to .2052;
(ii) An annual dividend yield on Illinova Common Stock of 4.11%; (iii)
A risk-free interest rate of 6.57%, based on the yield of a
zero-coupon government bond maturing at the end of the option term;
and (iv) Stock volatility of 19.54%.
<TABLE>
<S> <C> <C>
Aggregated Option and Fiscal Year-End Option Value Table
Number of Securities Underlying Unexercised Value of Unexercised In-the-Money
Options at Fiscal Year-End Options at Fiscal Year-End
Name Exercisable/Unexercisable Exercisable/Unexercisable
Larry D. Haab 56,900 shs./62,000 shs. $237,414/$57,400
Paul L. Lang 17,800 shs./19,500 shs. $75,148/$18,655
Larry F. Altenbaumer 17,800 shs./20,500 shs. $75,148/$18,655
John G. Cook 9,900 shs./17,000 shs. $43,634/$14,130
David W. Butts 7,900 shs./17,500 shs. $37,384/$13,100
</TABLE>
<PAGE>
Pension Benefits
Illinois Power maintains a Retirement Income Plan for Salaried Employees (the
"Retirement Plan") providing pension benefits for all eligible salaried
employees. In addition to the Retirement Plan, Illinois Power also maintains a
nonqualified Supplemental Retirement Income Plan for Salaried Employees (the
"Supplemental Plan") that covers certain officers eligible to participate in
the Retirement Plan and provides for payments from general funds of Illinois
Power of any monthly retirement income not payable under the Retirement Plan
because of benefit limits imposed by law or because of certain Retirement Plan
rules limiting the amount of credited service accrued by a participant.
The following table shows the estimated annual pension benefits on a
straight life annuity basis payable upon retirement based on specified annual
average earnings and years of credited service classifications, assuming
continuation of the Retirement Plan and Supplemental Plan and employment until
age 65. This table does not show, but any actual pension benefit payments would
be subject to, the Social Security offset.
Estimated Annual Benefits (rounded)
Annual 15 Yrs. 20 Yrs. 25 Yrs. 30 Yrs. 35 Yrs.
Average Credited Credited Credited Credited Credited
Earnings Service Service Service Service Service
$125,000 $37,500 $ 50,000 $62,500 $75,000 $87,500
150,000 45,000 60,000 75,000 90,000 105,000
175,000 52,500 70,000 87,500 105,000 122,500
200,000 60,000 80,000 100,000 120,000 140,000
250,000 75,000 100,000 125,000 150,000 175,000
300,000 90,000 120,000 150,000 180,000 210,000
350,000 105,000 140,000 175,000 210,000 245,000
400,000 120,000 160,000 200,000 240,000 280,000
450,000 135,000 180,000 225,000 270,000 315,000
500,000 150,000 200,000 250,000 300,000 350,000
550,000 165,000 220,000 275,000 330,000 385,000
600,000 180,000 240,000 300,000 360,000 420,000
650,000 195,000 260,000 325,000 390,000 455,000
700,000 210,000 280,000 350,000 420,000 490,000
The earnings used in determining pension benefits under the Retirement Plan
are the participants' regular base compensation, as set forth under Salary in
the Summary Compensation Table.
At December 31, 1997, for purposes of both the Retirement Plan and the
Supplemental Plan, Messrs. Haab, Lang, Altenbaumer, Cook and Butts had completed
32, 16, 25, 23 and 19 years of credited service, respectively.
<PAGE>
Employee Retention Agreements
Illinova has entered into Employee Retention Agreements with each of its
executive officers and with officers of its subsidiaries. Under each agreement,
the officer would be entitled to receive a lump sum cash payment if his or her
employment were terminated by Illinova without good cause or voluntarily by the
officer for good reason within two years following a change in control of
Illinova (as defined in the Agreement) or terminated prior to a change of
control at the request of a potential acquirer. The amount of the lump sum
payment would be equal to (1) 36 months' salary at the greater of the officer's
salary rate in effect on the date the change in control occurred or the salary
rate in effect on the date the officer's employment with Illinova terminated;
plus (2) three times the latest bonus earned by the officer during the three
calendar years preceding termination of employment. Under the agreement, the
officer would continue, after any such termination of employment, to participate
in and receive benefits under other benefit plans of Illinova and/or Illinois
Power. Such coverage would continue for 36 months following termination of
employment, or, if earlier, until the officer reached age 65 or was employed by
another employer; provided that, if the officer was 50 years of age or older at
the time of such termination, then coverage under health, life insurance and
similar welfare plans would continue until the officer became 55 years of age,
at which time he or she would be eligible to receive the benefits extended to
the employees of Illinova and its subsidiaries who elect early retirement.
Compensation and Nominating Committee
Report on Officer Compensation
The seven-member Compensation and Nominating Committee of the Board of Directors
(the "Committee") is composed entirely of Outside Directors. The Committee's
role includes an assessment of Illinova's and Illinois Power's Compensation
Strategy, a review of the performance of the elected officers and the
establishment of specific officer salaries subject to Board approval. The
Committee establishes performance goals for the officers under the Compensation
Plan, approves payments made pursuant to the Compensation Plan and recommends
grants under the Long-Term Incentive Compensation Plan approved by the
shareholders in 1992. The Committee also reviews other forms of compensation and
benefits making recommendations to the Board on changes whenever appropriate.
The Committee carries out these responsibilities with assistance from an
executive compensation consulting firm and with input from the Chief Executive
Officer and management as it deems appropriate.
Officer Compensation Philosophy
Illinova's compensation philosophy reflects a commitment to compensate officers
competitively with other companies while rewarding executives for achieving
levels of operational and financial excellence consistent with continuous
improvement. Illinova's current compensation policy is to provide a total
compensation opportunity targeted to the median of all utilities in the Edison
Electric Institute (EEI) database. All but one of the electric power companies
in the S&P Utilities Index are also in the EEI database. The S&P index covers
the industry broadly including electric and gas utilities. After careful
consideration, the Committee has decided to maintain a separate compensation
peer group limited to electric or combination electric and gas companies for
reference purposes. While the philosophy described above was used by Illinova in
1997 as an indicator of future utility pay practices, as the industry migrates
toward deregulation and diversification, it is anticipated that the company will
broaden its competitive reference beyond the regulated utility industry in order
to compete sufficiently for talent in the deregulated environment of the future.
<PAGE>
The compensation program for officers consists of base salary, annual
incentive and long-term incentive components. The combination of these three
elements balances short- and long-term business performance goals and aligns
officer financial rewards with those of Illinova's shareholders. The
compensation program is structured so that, depending on the salary level,
between 25 and 45 percent of an officer's total compensation target is composed
of incentive compensation.
Base Salary Plan
The Committee determines base salary ranges for executive officers based on
competitive pay practices of similarly sized utilities. Officer salaries
correspond to approximately the median of the companies in the compensation peer
group. Individual increases are based on several factors, including the
officer's performance during the year, the relationship of the officer's salary
to the market salary level for the position and competitive industry salary
increase practices.
Annual Incentive Compensation Plan
Annual incentive awards are earned based on the achievement of specific annual
financial and operational goals by the Illinois Power officer group as a whole
and consideration of the officer's individual contribution. If payment is earned
under this Plan, one-half of the bonus is payable in cash during the year
following the award year, and one-half is credited to the participants in the
form of Common Stock units, the number of which is determined by dividing half
of the earned bonus amount by the closing price of the Common Stock on the last
trading day of the award year. The officer's interest in the stock units vests
at the end of the three-year period, which begins the year after the award year.
The officer receives this award in cash equal to (1) the closing stock price on
the first trading day of the distribution year times the number of units held
plus (2) dividend equivalents that would have been received if the stock had
actually been issued. Maximum awards under the plan may be up to 150 percent of
target; threshold awards are 50 percent of target.
For Illinois Power officers, 1997 awards under the Compensation Plan are
based on achievement in the performance areas: earnings per share, customer
satisfaction, safety and employee teamwork, cost management and shareholder
value added. Up to 50 percent of the awarded amount is based on an assessment of
the individual officer's performance during the year.
Awards shown under Bonus in the Summary Compensation Table for performance
during 1997 were based on achievement of officers' individual goals. There were
no payouts for the identified performance areas.
<PAGE>
Long-Term Incentive Compensation (LTIC) Plan
Awards under the LTIC plan are based on corporate performance as well as
individual officers' contributions to corporate performance subject to the
review of this Committee. In 1997, it was determined that awards under the LTIC
plan be delivered in two components. One-half of each officer's LTIC plan award
is delivered in the form of stock options granted at fair market value. The
stock options granted to the officers for 1997 represent an award based on
Illinova, Illinois Power, and individual performance as evaluated by the
Chairman and reviewed by the Committee. The other half of the LTIC plan award is
distributed to officers in cash based upon Illinova's Shareholder Value-Added
(SVA) performance relative to a peer group of utility companies, as measured in
overlapping three-year periods. SVA measures Illinova's return on the Company's
weighted average cost of capital. SVA performance at the median of the peer
group will result in target award levels. Performance above the median will
result in payouts greater than target to a maximum of two times target;
performance significantly below the median results in no payouts. Since 1996
represented the first year of the SVA plan's first three-year measurement cycle,
no awards are due to be paid out under the plan until 1999.
CEO Compensation
Larry Haab became Chairman, President, and Chief Executive Officer ("CEO")
of Illinois Power on June 12, 1991, and Chairman, President and Chief Executive
Officer of Illinova in December 1993. Illinova based Mr. Haab's 1997
compensation on the policies and plans described above.
The Committee invokes the active participation of all non-management
directors in reviewing Mr. Haab's performance before it makes recommendations
regarding his compensation. The Committee is responsible for administering the
processes for completing this review. The process starts early in the year when
the Board of Directors works with Mr. Haab to establish his personal goals and
short- and long-term strategic goals for Illinova and Illinois Power. At the
conclusion of the year, Mr. Haab reviews his performance with the non-management
directors. The Committee oversees this review and recommends to the Board
appropriate adjustments to compensation. In setting the CEO's salary for 1997,
the Committee, with the participation of all Outside Directors determined that
Mr. Haab had provided very strong leadership in promoting electric deregulation
in the State of Illinois. The continuing outage at the Clinton Power Station was
a major setback. Significant progress was made in advancing other strategic
objectives of the Company.
The 1997 Annual Incentive Compensation Plan award for the Chief Executive
Officer was calculated consistent with the determination of awards for all other
Illinois Power officers. Under the terms of the plan, one-half of the award was
paid in cash and one-half was converted to 1,539 stock units which vest over a
three-year period as described above.
The 20,000 option shares granted to the CEO reflect the Committee's
recognition of this work in directing Illinova and Illinois Power towards its
long-term objectives.
Compensation and Nominating Committee
Ronald L. Thompson, Chairman
J. Joe Adorjan
C. Steven McMillan
Robert M. Powers
Walter D. Scott
Marilou von Ferstel
John D. Zeglis
<PAGE>
Independent Auditors
The Board of Directors of Illinois Power has selected Price Waterhouse LLP as
independent auditors for the Company for 1998. A representative of that firm
will be present at the Annual Meeting and available to make a statement and to
respond to questions.
Other Matters
Illinova's 1997 Summary Annual Report to Shareholders was mailed to Illinois
Power's shareholders commencing on or about March 10, 1998. Copies of Illinois
Power's Annual Report on Form 10-K will be available to shareholders after its
filing with the Securities and Exchange Commission on or before March 31, 1998.
Requests should be addressed to Investor Relations, G-21, Illinois Power
Company, 500 South 27th Street, Decatur, Illinois 62521-2200.
Any proposal by a shareholder to be presented at the next Annual Meeting
must be received at Illinois Power's executive offices not later than November
12, 1998.
Other Business
Management does not know of any matter which will be presented for consideration
at the Annual Meeting other than the matters described in the accompanying
Notice of Annual Meeting.
By Order of the Board of Directors,
Leah Manning Stetzner,
Vice President, General Counsel and Corporate Secretary
Decatur, Illinois
March 10, 1998
<PAGE>
APPENDIX: 1997 ANNUAL REPORT TO SHAREHOLDERS
Table of Contents
Management's Discussion and Analysis a-2
Responsibility for Information a-10
Report of Independent Accountants a-10
Consolidated Statements of Income a-11
Consolidated Balance Sheets a-12
Consolidated Statements of Cash Flows a-13
Consolidated Statements of Retained Earnings a-13
Notes to Consolidated Financial Statements a-14
Selected Consolidated Financial Data a-32
Selected Illinois Power Company Statistics a-33
Abbreviations Used Throughout this Report
AFUDC Allowance for Funds Used
During Construction
Baldwin Baldwin Power Station
Clinton Clinton Power Station
DOE Department of Energy
EITF Emerging Issues Task Force of the
Financial Accounting Standards Board
EMF Electric and Magnetic Fields
EPS Earnings Per Share
ESOP Employees' Stock Ownership Plan
FAS Statement of Financial
Accounting Standards
FASB Financial Accounting Standards Board
FERC Federal Energy Regulatory Commission
Fuel Company Illinois Power Fuel Company
HB 362 House Bill 362, An Act in Relation
to the Competitive Provision of
Utility Services
ICC Illinois Commerce Commission
Illinova Illinova Corporation
IP Illinois Power Company
IPFI Illinois Power Financing I
ISA Integrated Safety Assessment
kw Kilowatt
kwh Kilowatt-Hour
MGP Manufactured-Gas Plant
MIPS Monthly Income Preferred Securities
MW Megawatt
MWH Megawatt-Hour
NOPR Notice of Proposed Rulemaking
NOx Nitrogen Oxide
NRC Nuclear Regulatory Commission
PCA Power Coordination Agreement
PECO PECO Energy Company
S&P Standard & Poor's
SO2 Sulfur Dioxide
Soyland Soyland Power Cooperative, Inc.
TOPrS Trust Originated Preferred Securities
UFAC Uniform Fuel Adjustment Clause
UGAC Uniform Gas Adjustment Clause
U.S. EPA United States Environmental
Protection Agency
Vermilion Vermilion Power Station
Wood River Wood River Power Station
<PAGE>
MANAGEMENT'S DISCUSSION AND ANALYSIS
In this report, we refer to the Consolidated Financial Statements, related Notes
to Consolidated Financial Statements, Selected Consolidated Financial Data and
Selected Statistics for information concerning consolidated financial position
and results of operations. This report contains estimates, projections and other
forward-looking statements that involve risks and uncertainties. Actual results
or outcomes could differ materially as a result of such important factors as:
the outcome of state and federal regulatory proceedings affecting the
restructuring of the electric and gas utility industries; the impacts new laws
and regulations relating to restructuring, environmental, and other matters have
on IP; the effects of increased competition on the utility businesses; risks of
owning and operating a nuclear facility; changes in prices and cost of fuel;
construction and operation risks; and increases in financing costs. Below is
discussion of the factors having significant impact on consolidated financial
position and results of operations since January 1, 1995.
Illinois Power Company is a subsidiary of Illinova Corporation, a holding
company. Illinova Generating Company, Illinova Energy Partners, Inc. and
Illinova Insurance Company are wholly owned subsidiaries of Illinova. IP is
engaged in the generation, transmission, distribution and sale of electric
energy and the distribution, transportation and sale of natural gas in the State
of Illinois.
Open Access and Wheeling
On March 29, 1995, the FERC issued a NOPR initiating the process of mandating
non-discriminatory open access to public utility transmission facilities at
cost-based rates. Transmission of electricity for a reseller or redistributor of
energy is called wholesale wheeling. Transmission of electricity for end-use
customers is known as retail wheeling.
On April 24, 1996, FERC issued Orders 888 and 889 which established the
Final Rule resulting from the NOPR. The Orders became effective July 9, 1996.
The Rule requires all public utilities under FERC jurisdiction that own
transmission facilities to file transmission service tariffs that comply with
Pro Forma Tariffs attached to the Orders. FERC also requires that all wholesale
sales made by a utility provide for transmission of the power under the
prescribed terms and conditions. IP made a compliance filing as required on July
9, 1996, which has been accepted by FERC.
Public utilities serving customers at retail are not required, at this
time, to abide by FERC-mandated terms and conditions. FERC does not require
public utilities to give retail customers access to alternate energy suppliers
or direct transmission service.
The move to open access transmission service likely will increase
competition in the wholesale energy market, but this alone is not expected to
have a significant financial impact.
Competition
On December 16, 1997, Illinois Governor Edgar signed electric deregulation
legislation. HB 362 guarantees IP's residential customers a 15 percent decrease
in base electric rates beginning August 1, 1998, and an additional 5 percent
decrease effective on May 1, 2002. The rate decreases are expected to result in
revenue reductions of approximately $40 million in 1998, approximately $80
million in each of the years 1999 through 2001 and approximately $100 million in
2002, based on current consumption. Customers with demand greater than 4 MW at a
single site will be free to choose their electric generation suppliers ("direct
access") starting October 1999. Customers with at least 10 sites which aggregate
at least 9.5 MW in total demand also will have direct access starting October
1999. Direct access for the remaining non-residential customers will occur in
two phases: customers representing one-third of the remaining load in the
non-residential class in October 1999 and customers representing the entire
remaining non-residential load on December 31, 2000. Direct access will be
available to all residential customers in May 2002. IP remains obligated to
serve all customers who continue to take service from IP at tariff rates, and
remains obligated to provide delivery service to all at regulated rates.
Although the specified residential rate reductions and the introduction of
direct access will lead to lower electric service revenues, HB 362 is designed
to protect the financial integrity of electric utilities in three principal
ways:
1) Departing customers are obligated to pay transition charges, based on
the utility's lost revenue from that customer, adjusted to deduct: 1)
delivery charges the utility will continue to receive from the
customer, and 2) the market value of the freed-up energy net of a
mitigation factor, which is a percentage reduction of the transition
charge amount. The mitigation factor is designed to provide incentive
for management to continue cost reduction efforts and generate new
sources of revenue.
2) Utilities are provided the opportunity to lower their financing and
capital costs through the issuance of "securitized" bonds; and
3) Utilities are permitted to seek rate relief in the event that the
change in law leads to their return on equity falling below a
specified minimum based on a prescribed test.
<PAGE>
The extent to which revenues are lowered will depend on a number of factors
including future market prices for wholesale and retail energy, and load growth
and demand levels in the current IP service territory. The impact on net income
will depend on, among other things, the amount of revenues earned and the
ongoing costs of doing business.
In 1996, IP received approval from both the ICC and FERC to conduct an open
access experiment beginning in 1996 and ending on December 31, 1999. The
experiment allows certain industrial customers to purchase electricity and
related services from other sources. Currently, 17 customers are participating
in the experiment. Since inception, the experiment has cost IP approximately
$11.2 million in lost revenue net of avoided fuel cost and variable operating
expenses. This loss was partially offset by selling the surplus energy and
capacity on the open market and by $2.7 million in transmission service charges.
Accounting Matters
Prior to the passage of HB 362, IP prepared its consolidated financial
statements in accordance with FAS 71, "Accounting for the Effects of Certain
Types of Regulation." Reporting under FAS 71 allows companies whose service
obligations and prices are regulated to maintain on their balance sheets assets
representing costs they expect to recover from customers, through inclusion of
such costs in their future rates. In July 1997, the EITF concluded that
application of FAS 71 accounting should be discontinued at the date of enactment
of deregulation legislation for business segments for which a plan of
deregulation has been established. The EITF further concluded that regulatory
assets and liabilities that originated in the portion of the business being
deregulated should be written off unless their recovery is specifically provided
for through future cash flows from the regulated portion of the business.
Because HB 362 provides for market-based pricing of electric generation
services, IP discontinued application of FAS 71 for its generating segment. IP
evaluated its regulatory assets and liabilities associated with its generation
segment and determined that recovery of these costs was not probable through
rates charged to transmission and distribution customers, the regulated portion
of the business.
IP wrote off generation-related regulatory assets and liabilities of
approximately $195 million (net of income taxes) in December 1997. These net
assets related to previously incurred costs that were expected to be collected
through future revenues, including deferred costs for Clinton, unamortized
losses on reacquired debt, recoverable income taxes and other generation-related
regulatory assets. At December 31, 1997, IP's net investment in generation
facilities was $3.5 billion and was reflected in "Utility Plant, at Original
Cost" on IP's balance sheet.
In addition, IP evaluated its generation segment plant investments to
determine if they had been impaired as defined in FAS 121, "Accounting for the
Impairment of Long-Lived Assets and Long-Lived Assets to Be Disposed Of." This
evaluation determined that future revenues were expected to be sufficient to
recover the costs of its generation segment plant investments and as a result,
no plant write-downs were necessary. However, ultimate recovery depends on a
number of factors and variables including market conditions and IP's ability to
operate its generation assets efficiently.
The provisions of HB 362 allow an acceleration in the rate at which any
utility-owned assets are expensed without regulatory approval, provided such
charges are consistent with generally accepted accounting principles. Under this
legislation, up to an aggregate of $1.5 billion in additional expense for the
generation-related assets could be accelerated through the year 2008. This
reduction in the net book value of IP's generation-related assets should help
position IP to operate competitively and profitably in the changing business
environment. This accelerated charge would have a direct impact on earnings but
not on cash flows.
The FASB continues to review the accounting for liabilities related to
closure and removal of long-lived assets, including decommissioning. See "Note 3
- - Commitments and Contingencies" for a discussion of decommissioning.
See "Note 1 - Summary of Significant Accounting Policies" for a discussion
of other accounting issues.
Regulatory Matters
In September 1996, a leak in a recirculation pump seal caused IP operations
personnel to shut down Clinton. Clinton has not resumed operation.
In January and again in June 1997, the NRC named Clinton among plants
having a trend of declining performance. In June 1997, IP committed to conduct
an ISA to thoroughly assess Clinton's performance. The ISA was conducted by a
team of 30 individuals with extensive nuclear experience and no substantial
previous involvement at Clinton. Their report concluded that the underlying
reasons for the performance problems at Clinton were ineffective leadership
throughout the organization in providing standards of excellence, complacency
throughout the organization, barrier weaknesses and weaknesses in teamwork. In
late October, a team commissioned by the NRC performed an evaluation to validate
the ISA results. In December, this team concluded that the findings of the ISA
accurately characterized Clinton's performance deficiencies and their causes.
<PAGE>
On January 5, 1998, IP and PECO announced an agreement under which PECO
will provide management services for Clinton. Although a PECO team will help
manage the plant, IP will continue to maintain the operating license for Clinton
and retain ultimate oversight of the plant. PECO employees will assume senior
positions at Clinton, but the plant will remain primarily staffed by IP
employees. IP made this decision based on a belief that bringing in PECO's
experienced management team would be the most efficient way to get Clinton back
on line and operating at a superior level as quickly as possible.
On January 21, 1998, the NRC placed Clinton on its Watch List of nuclear
plants that require additional regulatory oversight because of declining
performance. Twice a year the NRC evaluates the performance of nuclear power
plants in the United States and identifies those which require additional
regulatory oversight. Once placed on the Watch List a plant must demonstrate
consistent improved performance before it is removed from the list. The NRC will
monitor Clinton more closely than plants not on the Watch List. This may include
increased inspections, additional required documentation, NRC-required approval
of processes and procedures, and higher-level NRC oversight.
The NRC has advised IP that it must submit a written report to the NRC at
least two weeks prior to restarting Clinton, giving the agency reasonable
assurance that IP's actions to correct recurring weaknesses in the corrective
action program have been effective. After the report is submitted, the NRC staff
plans to meet with IP's management to discuss the plant's readiness for restart.
In March 1997, the NRC issued an order approving transfer to IP of the
Clinton operating license related to Soyland's 13.2% ownership, in connection
with the transfer from Soyland to IP of all of Soyland's interest in Clinton.
Soyland's title to the plant and directly related assets such as nuclear fuel
was transferred to IP in May 1997. Soyland's nuclear decommissioning trust
assets were transferred to IP in May 1997, consistent with IP's assumption of
all of Soyland's ownership obligations including those related to
decommissioning.
The FERC approved an amended PCA between IP and Soyland in July 1997. The
amended PCA obligates Soyland to purchase all of its capacity and energy needs
from IP for at least 10 years. The amended PCA provides that a contract
cancellation fee will be paid by Soyland to IP in the event that a Soyland
Cooperative member terminates its membership from Soyland. On May 31, 1997,
three distribution cooperative members terminated membership by buying out of
their long-term wholesale power contracts with Soyland. This action resulted in
Soyland paying a fee of $20.8 million to IP in June 1997 to reduce its base
capacity charges. Fee proceeds of $2.9 million were used to offset the costs of
acquiring Soyland's share of Clinton with the remaining $17.9 million recorded
as interchange revenue. In December 1997, Soyland signed a letter of intent to
pay in advance the remainder of its base capacity charges in the PCA. The fee of
approximately $70 million will be deferred and recognized as interchange revenue
over the initial term of the PCA. The payment is contingent on Soyland obtaining
the necessary financing and regulatory approvals in 1998.
In September 1997, the ICC approved a petition filed by IP which stipulates
customers will not be charged for certain additional costs of energy incurred as
a result of Clinton being out of service. IP did not collect from its customers
$36.3 million for higher-cost replacement power in 1997. IP will forego recovery
of additional fuel costs as the Clinton outage continues into 1998. Under the
petition, fuel costs charged to customers will be no higher than average
1995-1996 levels until Clinton is back in service operating at least at a 65%
capacity factor for two consecutive months.
Under HB 362, IP may choose to eliminate application of the UFAC. IP's base
rates will still include a component for some level of recovery of fuel costs,
but IP would not be able to pass through to customers increased costs of
purchasing fuel, emission allowances, or replacement power. On elimination of
the UFAC, base rates will include a fixed fuel-cost factor equivalent to the
average 1995 - 1996 fuel cost levels. Future recovery of fuel costs is
uncertain, as IP will decrease base electric rates to residential customers
beginning in August 1998 and certain customers will be free to choose their
electric generation suppliers beginning in October 1999. The extent to which
fuel costs are recovered will depend on a number of factors including the future
market prices for wholesale and retail energy, when Clinton returns to service,
and whether IP elects to eliminate the UFAC.
Year 2000
In November 1996, IP deployed a project team to coordinate the identification,
evaluation, and implementation of changes to computer systems and applications
necessary to achieve a year 2000 date conversion with no effect on customers or
disruption to business operations.
These actions are necessary to ensure that systems and applications will
recognize and process coding for the year 2000 and beyond. Major areas of
potential business impact have been identified and initial conversion efforts
are underway. IP also is communicating with third parties with whom it does
business to ensure continued business operations. The cost of achieving year
2000 compliance is estimated to be at least $14 million through 1999.
Contingency plans for operating without year 2000 compliance have not been
developed. Such activity will depend on assessment of progress. Project
completion is planned for the fourth quarter of 1999.
<PAGE>
Enhanced Retirement
In December 1994, IP announced plans for voluntary enhanced retirement and
severance programs. During the fourth quarter of 1995, 727 employees accepted
enhanced retirement or severance under these programs. The combined enhanced
retirement and severance programs generated a pretax charge of $38 million
against fourth quarter 1995 earnings.
Consolidated Results of Operations
Overview
Earnings (loss) applicable to common stock were $(65) million for 1997, $206
million for 1996 and $156 million for 1995. The decrease in 1997 earnings
compared to 1996 was due primarily to the extraordinary item related to
discontinued application of FAS 71 for the generation segment, higher operation
and maintenance expenses due to Clinton, higher power purchased costs due to
Clinton and Wood River outages and an increase in uncollectible accounts
expense. The increase in 1996 net income over 1995 was due primarily to the
one-time charge in 1995 for the enhanced retirement and severance programs,
lower operations expense due to the employment decrease and lower financing
costs. The 1995 results include $(22.8) million net-of-tax for the enhanced
retirement and severance programs and $(3.5) million for the carrying amount
under consideration paid for preferred stock redeemed in December 1995.
Regulators historically have determined IP's rates for electric service,
the ICC at the retail level and the FERC at the wholesale level. The ICC
determines IP's rates for gas service. These rates have been designed to recover
the cost of service and allow shareholders the opportunity to earn a fair rate
of return. As described under "Competition" above, Illinois electric
deregulation legislation phases in a competitive marketplace for electric
generation while maintaining cost-based regulation for electric delivery
services and gas service, protecting the financial integrity of the company
during the transition period. Future electric and natural gas sales, including
interchange sales, will continue to be affected by an increasingly competitive
marketplace, changes in the regulatory environment, increased transmission
access, weather conditions, competing fuel sources, interchange market
conditions, plant availability, fuel cost recoveries, customer conservation
efforts and the overall economy.
Electric Operations For the years 1995 through 1997, electric revenues including
interchange increased 3.7% and the gross electric margin decreased 6.4% as
follows:
(Millions of dollars) 1997 1996 1995
Electric revenues $ 1,244.4 $ 1,202.9 $ 1,252.6
Interchange revenues 175.6 137.6 116.3
Fuel cost & power
purchased (450.3) (313.3) (333.4)
Electric margin $ 969.7 $ 1,027.2 $ 1,035.5
The components of annual changes in electric revenues were:
(Millions of dollars) 1997 1996 1995
Price $ (11.5) $ (7.2) $ 13.3
Volume and other 9.7 6.4 42.7
Fuel cost recoveries 43.3 (48.9) 19.1
Revenue increase
(decrease) $ 41.5 $ (49.7) $ 75.1
1997 Electric revenues excluding interchange sales increased 3.4%, primarily due
to an increase in revenues under the UFAC and increased wheeling revenues.
Interchange revenues increased 27.6% due to the receipt of an opt-out fee from
Soyland per the amended PCA and increased interchange activity. Electric margin
decreased primarily due to increased power purchased costs as a result of
outages at the nuclear and fossil facilities.
1996 Electric revenues excluding interchange sales decreased 4.0%, primarily due
to reduction in revenues under the UFAC. Volume changes by customer class were
insignificant, as kwh sales to ultimate consumers (excluding interchange sales
and wheeling) decreased .3%. Interchange revenues increased 18.3% as a result of
higher plant availability in the first half of the year.
<PAGE>
1995 The 6.4% increase in electric revenues was primarily due to a 1.9% increase
in kwh sales to ultimate consumers (excluding interchange sales and wheeling).
Volume increases resulted from higher residential sales (4.8%) and higher
commercial sales (8.2%) due to an improving economy and warmer summer
temperatures compared to 1994. Industrial sales remained essentially unchanged
from 1994. Interchange revenues increased $6.3 million (5.8%) as a result of
increased sales opportunities.
The cost of meeting IP's system requirements was reflected in fuel costs
for electric plants and power purchased. Changes in these costs are detailed
below:
(Millions of dollars) 1997 1996 1995
Fuel for electric plants
Volume and other $ (37.7) $ 15.4 $ 9.8
Price (8.5) (12.0) (35.5)
Emission allowances 12.3 .8 18.5
Fuel cost recoveries 18.2 (30.0) 14.5
(15.7) (25.8) 7.3
Power purchased 152.7 5.7 6.9
Total increase (decrease) $ 137.0 $ (20.1) $ 14.2
Weighted average system
generating fuel cost
($/MWH) $ 12.06 $ 11.01 $ 11.41
System load requirements, generating unit availability, fuel prices,
purchased power prices, resale of energy to other utilities, emission allowance
costs and fuel cost recovery through UFAC caused changes in these costs.
Changes in factors affecting the cost of fuel for electric generation are below:
1997 1996 1995
Increase (decrease)
in generation (25.4)% 5.4% .7%
Generation mix
Coal and other 100% 78% 73%
Nuclear 0% 22% 27%
1997 The cost of fuel decreased 6.3% and electric generation decreased 25.4%.
The decrease in fuel cost was primarily attributable to decreased generation and
a favorable price variance. These factors were partially offset by effects of
the UFAC and increased emission allowance costs. Power purchased increased
$152.7 million primarily due to Clinton and Wood River being out of service.
1996 The cost of fuel decreased 9.4% and electric generation increased 5.4%. The
decrease in fuel cost was primarily attributable to the effects of the UFAC, as
well as a favorable price variance. These factors were partially offset by an
increase in fuel cost due to the increase in generation. Power purchased
increased $5.7 million primarily due to the extended Clinton outage. Clinton's
equivalent availability and generation were lower than in 1995 due to that
outage.
1995 The cost of fuel increased 2.8% and electric generation increased .7%. The
increase in fuel cost was attributable to the effects of the UFAC, the increase
in higher-cost fossil generation and the cost of emission allowances. Clinton's
equivalent availability and generation were lower in 1995 as compared to 1994
due to the scheduled refueling and maintenance outage. Clinton returned to
service April 29, 1995, after completing its fifth refueling and maintenance
outage, which began March 12, 1995. Power purchased increased $6.9 million.
Gas Operations For the years 1995 through 1997, gas revenues including
transportation increased 29.9%, while the gross margin on gas revenues increased
9.3% as follows:
(Millions of dollars) 1997 1996 1995
Gas revenues $ 345.2 $ 341.4 $ 264.5
Gas cost (207.7) (202.6) (138.8)
Transportation revenues 8.7 6.8 8.0
Gas margin $ 146.2 $ 145.6 $ 133.7
(Millions of therms)
Therms sold 537 703 588
Therms transported 309 251 273
Total consumption 846 954 861
Changes in the cost of gas purchased for resale were:
(Millions of dollars) 1997 1996 1995
Gas purchased for resale
Cost $ 8.0 $ 49.0 $ (43.5)
Volume (30.0) 8.5 25.3
Gas cost recoveries 27.1 6.3 (15.4)
Total increase (decrease) $ 5.1 $ 63.8 $ (33.6)
Average cost per therm
delivered $ .28 $ .267 $ .201
<PAGE>
The 1997 increase in gas costs was due to slightly higher prices from
suppliers and effects of the UGAC, offset by a decrease in volume. The 1996
increase in gas costs was primarily due to higher prices from suppliers and the
effects of the UGAC. The 1995 decrease in the cost of gas purchased was due to
lower gas prices caused by unusually warm winter weather nationwide. Also
contributing to the higher gas margins in 1995 was the 6.1% increase in gas base
rates approved by the ICC in April 1994.
Other Expenses A comparison of significant increases (decreases) in other
operating expenses, maintenance and depreciation for the last three years is
presented in the following table:
(Millions of dollars) 1997 1996 1995
Other operating expenses $ 40.6 $ (9.8) $ (.3)
Maintenance 12.0 (.3) 10.4
Depreciation and
amortization 8.8 3.5 7.2
The increase in operating and maintenance expenses for 1997 is primarily
due to increased company and contractor labor at the nuclear and fossil plants.
An increase in uncollectible accounts expense and disposal of surplus inventory
also contributed to the increase.
The decrease in operating expenses for 1996 is due primarily to the savings
from the enhanced retirement and severance program, partially offset by the
costs of the extended Clinton outage and increased amortization of MGP site
expenses. The ICC approved tariff riders in March 1996 that resulted in the
current recognition of MGP site remediation costs in operating expenses. The
1996 increase amounted to $5.5 million. This increase is offset by increased
revenues collected under the riders.
The increase in maintenance expenses for 1995 is primarily due to the
refueling and maintenance outage at Clinton. The increases in depreciation and
amortization for each of the three years were due to increases in utility plant
balances.
Other Income and Deductions - Net The 1997 decrease of $2.1 million in Other
Income and Deductions, Net is due primarily to 1996 accruals recorded for the
planned disposition of property. The 1996 increase was due primarily to a
decrease in the credit for allocated income taxes. The 1995 change in Other
Income and Deductions, Net was negligible.
Interest Charges Interest charges, including AFUDC, decreased $2.8 million in
1997, decreased $15.5 million in 1996, and increased $3.6 million in 1995. The
1997 decrease is primarily due to the continued benefits of IP refinancing
efforts and capitalization reductions partially offset by increased IP
short-term borrowings and lower AFUDC. The 1996 decrease was due to lower
short-term interest rates and the impact of IP refinancing efforts and
capitalization reduction during 1996. The 1995 increase was due to increased
short-term borrowings at higher interest rates.
Inflation Inflation, as measured by the Consumer Price Index, was 2.3%, 3.3%,
and 2.5% in 1997, 1996, and 1995, respectively. IP recovers historical rather
than current plant costs in its regulated rates.
Liquidity and Capital Resources
Dividends
On December 10, 1997, IP declared the quarterly common stock dividend for the
first quarter of 1998. On December 11, 1996, IP increased the quarterly common
stock dividend by 11% declaring the common stock dividend for the first quarter
of 1997. On December 13, 1995, IP increased the quarterly common stock dividend
12%, declaring the common stock dividend for the first quarter of 1996.
Capital Resources and Requirements
IP needs cash for operating expenses, interest and dividend payments, debt and
certain preferred stock retirements and construction programs. To meet these
needs, IP has used internally generated funds and external financings, including
the issuance of debt and revolving lines of credit. The timing and amount of
external financings depend primarily on economic and financial market
conditions, cash needs and capitalization ratio objectives.
<PAGE>
IP cash flows from operations during 1997 provided sufficient working
capital to meet ongoing operating requirements, to service existing common and
IP preferred stock dividends and debt requirements and to meet all of IP's
construction requirements. Additionally, IP expects that future cash flows will
enable it to meet operating requirements and continue to service IP's existing
debt, preferred stock dividends, IP's sinking fund requirements and all of IP's
anticipated construction requirements. Continued sufficiency of cash flows for
these purposes will depend on a number of factors and variables, including
market conditions, business expenses and the ability to compete.
To a significant degree, the availability and cost of external financing
depend on the financial health of the company seeking those funds. Security
ratings are an indication of a company's financial position and may affect the
cost of securities, as well as the willingness of investors to invest in these
securities. The current ratings of IP's securities by three principal securities
rating agencies are as follows:
Standard Duff &
Moody's & Poor's Phelps
First/New mortgage bonds Baa1 BBB BBB+
Preferred stock baa2 BBB- BBB-
Commercial paper P-2 A-2 D-2
Under current market conditions, these ratings would afford IP the ability
to issue additional securities through external financing. IP has adequate
short-term and intermediate-term bank borrowing capacity.
Based on its 1993 revised standards for review of utility business and
financial risks, S&P placed IP, along with approximately one-third of the
industry, in a "somewhat below average" category. In April 1994, S&P lowered
IP's mortgage bond rating to BBB from BBB+. In August 1995, S&P revised its
ratings outlook from stable to positive. In February 1996, Moody's also revised
its ratings outlook from stable to positive.
Moody's upgraded IP's securities on July 1, 1996. The rating for mortgage
bonds was raised from Baa2 to Baa1, while preferred stock ratings went from baa3
to baa2. Duff & Phelps has indicated that it expects IP's ratings to remain
stable, reflecting a modestly strengthening financial profile characterized by
good cash flow and an average business risk profile.
For the years 1997, 1996 and 1995, changes in long-term debt and preferred
stock, including normal maturities and elective redemptions, were as follows:
(Millions of dollars) 1997 1996 1995
Long-term debt $ (11) $(154) $ (5)
Preferred stock (39) 71 (135)
Total decrease $ (50) $ (83) $(140)
The amounts shown in the preceding table for debt retirements do not
include all mortgage sinking fund requirements. IP generally has met these
requirements by pledging property additions as permitted under IP's 1943
Mortgage and Deed of Trust and the 1992 New Mortgage. For additional
information, see "Note 8 - Long-Term Debt" an d "Note 9 - Preferred Stock."
During 1997, IP redeemed $34.9 million (all of the remaining) Adjustable
Rate Series A serial preferred stock. IP also redeemed $4.2 million of various
issues of serial preferred stock. In addition, $10.5 million of medium-term
notes matured and were retired. During the year IP issued $150 million of
Adjustable Rate Pollution Control Revenue Bonds, due April 1, 2032. The proceeds
were used on June 2, 1997, to retire $150 million of IP's 7 5/8% Pollution
Control First Mortgage Bonds due 2016.
During 1996, IP redeemed $2.2 million of Adjustable Rate Series A serial
preferred stock, $20.5 million (all of the remaining) Adjustable Rate Series B
serial preferred stock and $6.7 million of 7.75% serial preferred stock. During
the year, IP also retired $62.9 million of 8.75% First Mortgage Bonds due 2021,
$6 million of 8% New Mortgage Bonds due 2023 and $23 million of 7.5% New
Mortgage Bonds due 2025. The $40 million of 5.85% First Mortgage Bonds matured
and were retired. In addition, $21.5 million of medium-term notes matured and
were retired.
In February 1995, IP redeemed $12 million of 8.00% mandatorily redeemable
serial preferred stock. In May 1995, IP redeemed the remaining $24 million of
8.00% mandatorily redeemable serial preferred stock. In March 1995, IP redeemed
$.2 million of 7.56% serial preferred stock and $3 million of 8.24% serial
preferred stock. In August 1995, IP redeemed $5 million of 8.75% First Mortgage
Bonds. In December 1995, IP redeemed $34.7 million of 8.00% serial preferred
stock, $33.6 million of 7.56% serial preferred stock and $27 million of 8.24%
serial preferred stock.
<PAGE>
IPFI is a statutory business trust in which IP serves as sponsor. IPFI
issued $100 million of TOPrS at 8% (4.8% after-tax rate) in January 1996. The
TOPrS were issued by IPFI, which invested the proceeds in an equivalent amount
of IP subordinated debentures due in 2045. The proceeds were used by IP to repay
short-term indebtedness on varying dates on or before March 1, 1996. IP incurred
the indebtedness in December 1995 to redeem $95.3 million (principal value) of
higher-cost outstanding preferred stock of IP.
In 1992, IP executed a general obligation mortgage (New Mortgage) to
replace, over time, IP's 1943 Mortgage and Deed of Trust (First Mortgage). Both
mortgages are secured by liens on substantially all of IP's properties. A
corresponding issue of First Mortgage bonds, under the First Mortgage, secures
any bonds issued under the New Mortgage. In October 1997, at a special
bondholders meeting, the 1943 First Mortgage was amended to be generally
consistent with the New Mortgage. The New Mortgage provides IP with increased
financial flexibility.
At December 31, 1997, based on the most restrictive earnings test contained
in the New Mortgage, IP could issue approximately $800 million of additional New
Mortgage bonds for other than refunding purposes. Also at December 31, 1997, the
unused portion of IP total bank lines of credit was $354 million. The amount of
available IP unsecured borrowing capacity totaled $168 million at December 31,
1997.
On February 12, 1997, the IP Board of Directors approved a change to the
Articles of Incorporation to remove the limitation on the amount of unsecured
debt that IP can issue. The change will be voted on by the preferred
stockholders at a special meeting planned to be held in 1998.
Under HB 362, IP may issue transitional funding instruments for up to 25%
of its December 31, 1996, capitalization on or after August 1, 1998. IP is
continuing to review its refinancing plans but could issue up to $864 million of
transitional funding instruments on or after August 1, 1998, under this
provision. In addition, IP would be eligible to issue up to an additional $864
million of transition funding instruments on or after August 1, 1999. Of the
proceeds from the issuance of transitional funding instruments, 80% or more must
be used to retire and repurchase IP debt and equity while 20% or less can be
used to fund certain other transition costs.
Construction expenditures for the years 1995 through 1997 were
approximately $620.5 million, including $17.5 million of AFUDC. IP estimates
that it will spend approximately $225 million for construction expenditures in
1998. IP construction expenditures for the period 1998-2002 are expected to
total about $1 billion. Additional expenditures may be required during this
period to accommodate transitional expenditures related to a competitive
environment, environmental compliance costs and system upgrades, which cannot be
determined at this time.
IP's capital expenditures for the years 1998 through 2002, in addition to
its construction expenditures, are expected to include $129 million for nuclear
fuel and $291 million for mandatory debt retirement.
See "Note 3 - Commitments and Contingencies" for additional information.
Internal cash generation will meet substantially all construction and capital
requirements.
Environmental Matters
See "Note 3 - Commitments and Contingencies" for a discussion of environmental
matters that impact or could potentially impact IP.
Tax Matters
See "Note 6 - Income Taxes" for a discussion of effective tax rates and other
tax issues.
<PAGE>
Illinois Power Company
RESPONSIBILITY FOR INFORMATION
The consolidated financial statements and all information in this annual report
are the responsibility of management. The consolidated financial statements have
been prepared in conformity with generally accepted accounting principles and
include amounts that are based on management's best estimates and judgments.
Management also prepared the other information in the annual report and is
responsible for its accuracy and consistency with the consolidated financial
statements. In the opinion of management, the consolidated financial statements
fairly reflect Illinois Power's financial position, results of operations and
cash flows.
Illinois Power believes that its accounting and internal accounting control
systems are maintained so that these systems provide reasonable assurance that
assets are safeguarded against loss from unauthorized use or disposition and
that the financial records are reliable for preparing the consolidated financial
statements. The consolidated financial statements have been audited by Illinois
Power's independent accountants, Price Waterhouse LLP, in accordance with
generally accepted auditing standards. Such standards include the evaluation of
internal accounting controls to establish a basis for developing the scope of
the examination of the consolidated financial statements. In addition to the use
of independent accountants, Illinois Power maintains a professional staff of
internal auditors who conduct financial, procedural and special audits. To
assure their independence, both Price Waterhouse LLP and the internal auditors
have direct access to the Audit Committee of the Board of Directors.
The Audit Committee is composed of members of the Board of Directors who are not
active or retired employees of Illinois Power. The Audit Committee meets with
Price Waterhouse LLP and the internal auditors and makes recommendations to the
Board of Directors concerning the appointment of the independent accountants and
services to be performed. Additionally, the Audit Committee meets with Price
Waterhouse LLP to discuss the results of their annual audit, Illinois Power's
internal accounting controls and financial reporting matters. The Audit
Committee meets with the internal auditors to assess the internal audit work
performed, including tests of internal accounting controls.
Larry D. Haab Chairman, President
and Chief Executive Officer
Larry F. Altenbaumer
Senior Vice President
and Chief Financial Officer
Illinois Power Company
REPORT OF INDEPENDENT ACCOUNTANTS
PRICE WATERHOUSE LLP
To the Board of Directors and Shareholders of Illinois Power Company
In our opinion, the consolidated financial statements of Illinois Power Company
and its subsidiaries appearing on pages a-11 through a-31 of this report present
fairly, in all material respects, the financial position of Illinois Power
Company and its subsidiaries at December 31, 1997 and 1996, and the results of
their operations and their cash flows for each of the three years in the period
ended December 31, 1997, in conformity with generally accepted accounting
principles. These financial statements are the responsibility of Illinois
Power's management; our responsibility is to express an opinion on these
financial statements based on our audits. We conducted our audits of these
statements in accordance with generally accepted auditing standards which
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, assessing the accounting principles
used and significant estimates made by management, and evaluating the overall
financial statement presentation. We believe that our audits provide a
reasonable basis for the opinion expressed above.
As discussed in Note 1 to the consolidated financial statements, Illinois Power
discontinued applying the provisions of Statement of Financial Accounting
Standards No. 71, "Accounting for the Effects of Certain Types of Regulations,"
for its generation segment of the business in December 1997.
Price Waterhouse LLP
St. Louis, Missouri
February 12, 1998
<PAGE>
Illinois Power Company
CONSOLIDATED STATEMENTS OF INCOME
<TABLE>
<S> <C> <C> <C>
(Millions of dollars)
For the Years Ended December 31, 1997 1996 1995
Operating Revenues
Electric $ 1,244.4 $ 1,202.9 $ 1,252.6
Electric interchange 175.6 137.6 116.3
Gas 353.9 348.2 272.5
Total 1,773.9 1,688.7 1,641.4
Operating Expenses and Taxes
Fuel for electric plants 232.4 248.1 273.9
Power purchased 217.9 65.2 59.5
Gas purchased for resale 207.7 202.6 138.8
Other operating expenses 290.5 249.9 259.7
Maintenance 111.7 99.7 100.0
Enhanced retirement and severance - - 37.8
Depreciation and amortization 198.8 190.0 186.5
General taxes 133.8 131.3 135.0
Income taxes 102.4 140.5 125.8
Total 1,495.2 1,327.3 1,317.0
Operating income 278.7 361.4 324.4
Other Income and Deductions, Net (4.2) (6.3) .3
Income before interest charges 274.5 355.1 324.7
Interest Charges
Interest expense 128.7 133.0 148.0
Allowance for borrowed funds used during construction (5.0) (6.5) (6.0)
Total 123.7 126.5 142.0
Net income before extraordinary item 150.8 228.6 182.7
Extraordinary item net of income tax benefit of $118.0 million (Note 1) (195.0) - -
Net income (loss) (44.2) 228.6 182.7
Less - Preferred dividend requirements 21.5 22.3 23.7
Plus - Carrying amount over (under) consideration paid for redeemed preferred stock .2 (.7) (3.5)
Net income (loss) applicable to common stock $ (65.5) $ 205.6 $ 155.5
</TABLE>
See notes to consolidated financial statements which are an integral part of
these statements.
<PAGE>
Illinois Power company
CONSOLIDATED BALANCE SHEETS
<TABLE>
(Millions of dollars)
December 31, 1997 1996
Assets
Utility Plant, at original cost
<S> <C> <C>
Electric (includes construction work in progress of $214.3 million and $212.5 million, respectively) $ 6,690.4 $ 6,335.4
Gas (includes construction work in progress of $10.7 million and $21.2 million, respectively) 663.0 646.1
7,353.4 6,981.5
Less - accumulated depreciation 2,808.1 2,419.7
4,545.3 4,561.8
Nuclear fuel in process 6.3 5.3
Nuclear fuel under capital lease 126.7 96.4
4,678.3 4,663.5
Investments and Other Assets 5.9 14.5
Current Assets
Cash and cash equivalents 17.8 12.5
Accounts receivable (less allowance for doubtful accounts of $5.5 million and $3.0 million, respectively)
Service 115.6 138.8
Other 16.6 51.1
Accrued unbilled revenue 86.3 106.0
Materials and supplies, at average cost
Fossil fuel 12.6 7.9
Gas in underground storage 29.3 27.2
Operating materials 75.4 77.1
Prepayments and other 61.2 23.7
414.8 444.3
Deferred Charges
Deferred Clinton costs - 103.9
Recoverable income taxes - 101.3
Other 192.5 241.0
192.5 446.2
$ 5,291.5 $ 5,568.5
Capital and Liabilities
Capitalization
Common stock - No par value, 100,000,000 shares authorized; 75,643,937 shares issued, stated at $ 1,424.6 $ 1,424.6
Retained earnings 89.5 245.9
Less - Capital stock expense 7.3 8.2
Less - 9,428,645 and 3,410,897 shares of common stock in treasury, respectively, at cost 207.7 86.2
Total common stock equity 1,299.1 1,576.1
Preferred stock 57.1 96.2
Mandatorily redeemable preferred stock 197.0 197.0
Long-term debt 1,617.5 1,636.4
Total capitalization 3,170.7 3,505.7
Current Liabilities
Accounts payable 102.7 149.7
Notes payable 376.8 310.0
Long-term debt and lease obligations maturing within one year 87.5 47.7
Dividends declared 22.9 24.7
Taxes accrued 27.5 46.0
Interest accrued 33.0 34.3
Other 78.7 43.1
729.1 655.5
Deferred Credits
Accumulated deferred income taxes 980.6 1,048.0
Accumulated deferred investment tax credits 208.3 215.5
Other 202.8 143.8
1,391.7 1,407.3
$ 5,291.5 $ 5,568.5
</TABLE>
(Commitments and Contingencies Note 3)
See notes to consolidated financial statements which are an integral part of
these statements.
<PAGE>
Illinois Power company
CONSOLIDATED STATEMENTS OF CASH FLOWS
<TABLE>
<S> <C> <C> <C>
(Millions of dollars)
For the Years Ended December 31, 1997 1996 1995
Cash Flows from Operating Activities
Net income (loss) $ (44.2) $ 228.6 $ 182.7
Items not requiring (providing) cash - 202.1 195.3 190.0
Depreciation and amortization (5.0) (6.5) (6.0)
Allowance for funds used during construction 29.4 64.2 42.0
Deferred income taxes - - 37.8
Enhanced retirement and severance 195.0 - -
Extraordinary item
Changes in assets and liabilities - 57.7 (35.2) 38.7
Accounts and notes receivable 19.7 (16.9) (10.2)
Accrued unbilled revenue (5.1) (1.2) 22.8
Materials and supplies (31.2) 29.8 (14.0)
Accounts payable .3 (14.8) (10.1)
Interest accrued and other, net 418.7 443.3 473.7
Net cash provided by operating activities
Cash Flows from Investing Activities (223.9) (187.3) (209.3)
Construction expenditures 5.0 6.5 6.0
Allowance for funds used during construction 27.8 5.0 (7.5)
Other investing activities (191.1) (175.8) (210.8)
Net cash used in investing activities
Cash Flows from Financing Activities (114.6) (107.9) (100.5)
Dividends on common stock and preferred stock (121.5) (18.9) (67.3)
Repurchase of common stock
Redemptions - (164.1) (355.8) (213.6)
Short-term debt (160.8) (153.7) (5.2)
Long-term debt (39.0) (29.5) (134.5)
Preferred stock
Issuances - 231.0 306.2 209.5
Short-term debt 150.0 - -
Long-term debt - 100.0 -
Preferred stock (3.3) .3 5.1
Other financing activities (222.3) (259.3) (306.5)
Net cash used in financing activities 5.3 8.2 (43.6)
Net change in cash and cash equivalents 12.5 4.3 47.9
Cash and cash equivalents at beginning of year $ 17.8 $ 12.5 $ 4.3
Cash and cash equivalents at end of year
</TABLE>
Illinois Power company
CONSOLIDATED STATEMENTS OF RETAINED EARNINGS
<TABLE>
<S> <C> <C> <C>
(Millions of dollars)
For the Years Ended December 31, 1997 1996 1995
Balance at beginning of year $ 245.9 $ 129.6 $ 51.1
Net income (loss) before dividends and carrying amount adjustment (44.2) 228.6 182.7
201.7 358.2 233.8
Less -
Dividends -
Preferred stock 21.7 22.6 23.6
Common stock 90.7 86.6 77.1
Investment transfer to Illinova - 2.4 -
Plus -
Carrying amount over (under) consideration paid for redeemed preferred stock .2 (.7) (3.5)
(112.2) (112.3) (104.2)
Balance at end of year $ 89.5 $ 245.9 $ 129.6
</TABLE>
See notes to consolidated financial statements which are an integral part of
these statements.
<PAGE>
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
Note 1 - Summary of Significant Accounting Policies
Principles of Consolidation IP is a subsidiary of Illinova, a holding company.
IP is engaged in the generation, transmission, distribution and sale of electric
energy and the distribution, transportation and sale of natural gas in the state
of Illinois. The consolidated financial statements include the accounts of IP, a
combination electric and gas utility, Illinois Power Capital, L.P. and IPFI. See
"Note 9 - Preferred Stock" for additional information.
All significant intercompany balances and transactions have been eliminated
from the consolidated financial statements. Preparation of financial statements
in conformity with generally accepted accounting principles requires the use of
management's estimates. Actual results could differ from those estimates.
Regulation IP is subject to regulation by the ICC and the FERC. Prior to the
passage of HB 362, IP prepared its consolidated financial statements in
accordance with FAS 71, "Accounting for the Effects of Certain Types of
Regulation." Reporting under FAS 71 allows companies whose service obligations
and prices are regulated to maintain on their balance sheets assets which
represent costs they expect to recover from customers through inclusion of such
costs in their future rates. In July 1997, the EITF concluded that application
of FAS 71 accounting should be discontinued at the date of enactment of
deregulation legislation for business segments for which a plan of deregulation
has been established. The EITF further concluded that regulatory assets and
liabilities that originated in the portion of the business being deregulated
should be written off unless their recovery is specifically provided for through
future cash flows from the regulated portion of the business.
Because HB 362 provides for market-based pricing of electric generation
services, IP discontinued application of FAS 71 for its generating segment in
December 1997 when HB 362 was signed by Illinois Governor Edgar. IP evaluated
its regulatory assets and liabilities associated with its generation segment and
determined that recovery of these costs was not probable through rates charged
to transmission and distribution customers, the regulated portion of its
business. Therefore, IP wrote off generation-related regulatory assets and
liabilities of approximately $195 million (net of income taxes) in December
1997. These net assets related to previously incurred costs that had been
expected to be collected through future revenues, including deferred Clinton
post construction costs, unamortized losses on reacquired debt, recoverable
income taxes and other generation-related regulatory assets. At December 31,
1997, IP's net investment in generation facilities was $3.5 billion and was
included in "Utility Plant, at Original Cost" on IP's Consolidated Balance
Sheets.
IP's principal accounting policies are:
Regulatory Assets Regulatory assets represent probable future revenues to IP
associated with certain costs that are expected to be recovered from customers
through the ratemaking process. Significant regulatory assets are as follows:
(Millions of dollars) 1997 1996
Deferred Clinton
post-construction costs $ - $ 103.9
Recoverable income taxes $ - $ 101.3
Unamortized losses on reacquired debt $ 32.3 $ 87.7
Manufactured-gas plant site cleanup costs $ 64.8 $ 69.1
DOE decontamination and
decommissioning fees $ 6.3 $ 5.4
Utility Plant The cost of additions to utility plant and replacements for
retired property units is capitalized. Cost includes labor, materials, and an
allocation of general and administrative costs, plus AFUDC as described below.
Maintenance and repairs, including replacement of minor items of property, are
charged to maintenance expense as incurred. When depreciable property units are
retired, the original cost and dismantling charges, less salvage value, are
charged to accumulated depreciation.
<PAGE>
Allowance for Funds Used During Construction The FERC Uniform System of Accounts
defines AFUDC as the net costs for the period of construction of borrowed funds
used for construction purposes and a reasonable rate on other funds when so
used. AFUDC is capitalized as a component of construction work in progress by
those business segments applying the provisions of FAS 71. In 1997, 1996 and
1995, the pre-tax rate used for all construction projects was 5.6%, 5.8% and
6.5%, respectively. Although cash is not currently realized from the allowance,
it is realized under the ratemaking process over the service life of the related
property through increased revenues resulting from a higher rate base and higher
depreciation expense. Non-regulated business segments capitalize interest under
the guidelines in FAS 34, "Capitalization of Interest Cost."
Depreciation For financial statement purposes, IP depreciates the various
classes of depreciable property over their estimated useful lives by applying
composite rates on a straight-line basis. In 1997, 1996 and 1995, provisions for
depreciation were 2.8%, 2.8% and 2.8%, respectively, of the average depreciable
cost for Clinton. Provisions for depreciation for all other electric plant were
2.8%, 2.6% and 2.6% in 1997, 1996 and 1995, respectively. Provisions for
depreciation of gas utility plant, as a percentage of the average depreciable
cost, were 3.3%, 3.9% and 3.9% in 1997, 1996 and 1995, respectively.
Amortization of Nuclear Fuel IP leases nuclear fuel from the Fuel Company under
a capital lease. Amortization of nuclear fuel (including related financing
costs) is determined on a unit of production basis. A provision for spent fuel
disposal costs is charged to fuel expense based on kwh generated. See "Note 3 -
Commitments and Contingencies" for discussion of decommissioning and nuclear
fuel disposal costs.
Unamortized Debt Discount, Premium and Expense Discount, premium and expense
associated with long-term debt are amortized over the lives of the related
issues. Costs related to refunded debt for business segments under the
provisions of FAS 71 are amortized over the lives of the related new debt issues
or the remaining life of the old debt if no new debt is issued. Costs related to
refunded debt for the generating segment are expensed when incurred.
Revenue and Energy Cost IP records revenue for services provided but not yet
billed to more closely match revenues with expenses. Unbilled revenues represent
the estimated amount customers will be billed for service delivered from the
time meters were last read to the end of the accounting period. Operating
revenues include related taxes that have been billed to customers in the amount
of $71 million in 1997, $68 million in 1996 and $66 million in 1995. The costs
of fuel for the generation of electricity, purchased power and gas purchased for
resale are recovered from customers pursuant to the electric fuel and purchased
gas adjustment clauses. Accordingly, allowable energy costs that are to be
passed on to customers in a subsequent accounting period are deferred. The
recovery of costs deferred under these clauses is subject to review and approval
by the ICC. In September 1997, IP filed a petition with the ICC that stipulated
customers will not be charged for certain additional costs of energy incurred as
a result of Clinton being out of service. During 1997, as a result of this
stipulation, IP did not collect $36.3 million of fuel costs. IP will also forego
recovery of additional fuel costs in 1998 for the duration of the Clinton
outage. Under the petition, fuel costs charged to customers will be no higher
than average 1995-1996 levels until Clinton is back in service operating at
least at a 65% capacity factor for two consecutive months.
Income Taxes Deferred income taxes result from temporary differences between
book income and taxable income, and the tax bases of assets and liabilities on
the balance sheet. The temporary differences relate principally to plant in
service and depreciation.
Investment tax credits used to reduce federal income taxes have been
deferred and are being amortized to income over the service life of the property
that gave rise to the credits.
IP is included in Illinova's consolidated federal income tax return. Income
taxes are allocated to the individual companies based on their respective
taxable income or loss. See "Note 6 - Income Taxes" for additional discussion.
<PAGE>
Preferred Dividend Requirements Preferred dividend requirements reflected in the
Consolidated Statements of Income are recorded on the accrual basis.
Consolidated Statements of Cash Flows Cash and cash equivalents include cash on
hand and temporary investments purchased with an initial maturity of three
months or less. Capital lease obligations not affecting cash flows increased by
$30 million, $31 million and $19 million during 1997, 1996 and 1995,
respectively. Income taxes and interest paid are as follows:
Years ended December 31,
(Millions of dollars) 1997 1996 1995
Income taxes $ 94.3 $ 65.9 $ 65.7
Interest $ 140.0 $ 147.4 $ 152.4
Interest Rate Cap Generally, premiums paid for purchased interest rate cap
agreements are being amortized to interest expense over the terms of the caps.
Unamortized premiums are included in Current Assets, "Prepayments and other," in
the Consolidated Balance Sheets. Amounts to be received under the cap agreements
are accrued and recognized as a reduction in interest expense.
Transactions with Illinova In addition to transfers of capital reflected in the
Consolidated Statements of Retained Earnings, IP provided approximately $122
million, $81 million and $34 million in funds to Illinova for operations and
investments during 1997, 1996 and 1995, respectively. Illinova is paying IP
interest on these funds at a rate equal to that which Illinova would have paid
had it used a currently outstanding line of credit. In addition, Illinova and IP
have recorded an intercompany payable and receivable, respectively, for
approximately $10.2 million, $14.3 million and $18.4 million in 1997, 1996 and
1995, respectively, in order to recognize the effect on the Employees' Stock
Ownership Plan of the conversion of IP common stock to Illinova common stock
concurrent with the formation of Illinova. This was a noncash transaction. See
"Note 10 - Common Stock and Retained Earnings" for additional information.
New Pronouncements The FASB issued FAS 128, "Earnings Per Share" in February
1997, effective for financial statements issued after December 15, 1997. FAS 128
establishes standards for computing and presenting EPS and replaces the
presentation of primary EPS and fully diluted EPS with a presentation of basic
EPS and diluted EPS, respectively. No new requirements are imposed on IP by FAS
128.
The FASB issued FAS 129, "Disclosure of Information about Capital
Structure" in February 1997, effective for financial statements for periods
ending after December 15, 1997. FAS 129 establishes standards for disclosing
information about an entity's capital structure and contains no change in
disclosure requirements for entities that were previously subject to the
requirements of Accounting Principles Board Opinions 10 and 15 and FAS 47. No
new requirements are imposed on IP by FAS 129.
The FASB issued FAS 130, "Reporting Comprehensive Income" in June 1997,
effective for fiscal years beginning after December 15, 1997. FAS 130
establishes standards for reporting and display of comprehensive income and its
components in a financial statement that is displayed with the same prominence
as other financial statements. IP continues to analyze FAS 130 and does not
expect it to have a significant impact on its financial statements presentation.
The FASB issued FAS 131, "Disclosures about Segments of an Enterprise and
Related Information" in June 1997, effective for periods beginning after
December 15, 1997. FAS 131 supersedes FAS 14, "Financial Reporting for Segments
of a Business Enterprise." FAS 131 establishes standards for the way public
business enterprises report financial and descriptive information about their
reportable operating segments in their financial statements. Generally,
financial information is required to be reported on the basis that is used
internally for evaluating segment performance and deciding how to allocate
resources to segments. IP continues to evaluate the provisions of FAS 131 and
determine the impact of the revised disclosure requirements on its 1998
financial statements.
<PAGE>
Note 2 - Clinton Power Station
Clinton Operations
In September 1996, a leak in a recirculation pump seal caused IP operations
personnel to shut down Clinton. Clinton has not resumed operation.
In January and again in June 1997, the NRC named Clinton among plants
having a trend of declining performance. In June 1997, IP committed to conduct
an ISA to thoroughly assess Clinton's performance. The ISA was conducted by a
team of 30 individuals with extensive nuclear experience and no substantial
previous involvement at Clinton. Their report concluded that the underlying
reasons for the performance problems at Clinton were ineffective leadership
throughout the organization in providing standards of excellence, complacency
throughout the organization, barrier weaknesses and weaknesses in teamwork. In
late October, a team commissioned by the NRC performed an evaluation to validate
the ISA results. In December, this team concluded that the findings of the ISA
accurately characterized Clinton's performance deficiencies and their causes.
In September 1997, the NRC advised IP that it must submit a written report
to the NRC at least two weeks prior to restarting Clinton, giving the agency
reasonable assurance that IP's actions to correct recurring weaknesses in the
corrective action program have been effective. After the report is submitted,
the NRC staff plans to meet with IP's management to discuss the plant's
readiness for restart.
In November 1997, Larry Haab, Chief Executive Officer of IP, publicly
pledged to address the findings of the ISA, to improve Clinton, and provide the
resources necessary to restart the plant. Further, in January 1998, IP and PECO
announced an agreement under which PECO will provide management services for
Clinton. The new management team initially will consist of nine people in key
positions, including chief nuclear officer and plant manager.
Although a PECO team will help manage the plant, IP will continue to
maintain the operating license for Clinton and retain ultimate oversight of the
plant. The plant will remain staffed primarily by IP employees.
PECO operates two stations, Limerick and Peach Bottom, each with two
boiling water reactors similar to the one at Clinton. Although PECO's Peach
Bottom Station was a troubled plant that experienced a two-year outage, it was
turned around, and both plants have set performance records for long operating
runs and short refueling outages, receiving excellent performance ratings from
the NRC and the Institute of Nuclear Power Operations.
On January 21, 1998, the NRC placed Clinton on its Watch List. Nuclear
plants are placed on the Watch List when the NRC believes additional regulatory
oversight is required because of declining performance. Clinton will remain on
the Watch List until consistent improved performance is demonstrated. During the
period Clinton remains on the Watch List, the NRC will monitor it more closely
than plants not on the Watch List. This may include increased inspections,
additional required documentation, NRC-required approval of processes and
procedures and higher-level NRC oversight.
<PAGE>
Transfer of Soyland's Ownership Share to IP
In March 1997, the NRC issued an order approving transfer to IP of the Clinton
operating license related to Soyland's 13.2% ownership in connection with the
transfer from Soyland to IP of all of Soyland's interest in Clinton. Soyland's
title to the plant and directly related assets such as nuclear fuel was
transferred to IP in May 1997. Soyland's nuclear decommissioning trust assets
were transferred to IP in May 1997, consistent with IP's assumption of all of
Soyland's ownership obligations, including those related to decommissioning.
The FERC approved an amended PCA in July 1997. The amended PCA obligates
Soyland to purchase all of its capacity and energy needs from IP for at least 10
years. The amended PCA provides that a contract cancellation fee be paid by
Soyland to IP in the event that a Soyland member terminates its membership from
Soyland. In May 1997, three distribution cooperative members terminated
membership by buying out of their long-term wholesale power contracts with
Soyland. As a result, Soyland paid a fee of $20.8 million to IP in June 1997.
Fee proceeds of $2.9 million were used to offset the costs of acquiring
Soyland's share of Clinton with the remaining $17.9 million recorded as
interchange revenue.
In December 1997, Soyland signed a letter of intent to pay in advance the
remainder of its base capacity charges in the PCA. The fee of approximately $70
million will be deferred and recognized as interchange revenue over the initial
term of the PCA. The payment is contingent on Soyland obtaining the necessary
financing and regulatory approvals in 1998.
Clinton Cost and Risks
Clinton was placed in service in 1987 and represents approximately 20.3% of IP's
installed generation capacity. The investment in Clinton represented
approximately 57% of IP's total assets at December 31, 1997. See "Note 1 -
Summary of Significant Accounting Policies" for additional information.
IP's Clinton-related costs represented 38% of its total 1997 other
operating, maintenance and depreciation expenses. Clinton's equivalent
availability was 0%, 66% and 76% for 1997, 1996 and 1995, respectively.
Ownership of an operating nuclear generating unit exposes IP to significant
risks, including increased and changing regulatory, safety and environmental
requirements and the uncertain future cost of closing and dismantling the unit.
IP expects to be allowed to continue to operate Clinton; however, if any
unforeseen or unexpected developments would prevent it from doing so, IP would
be materially adversely affected. See "Note 3 - Commitments and Contingencies"
for additional information.
Note 3 - Commitments and Contingencies
Commitments
IP estimates that it will spend approximately $225 million for construction
expenditures in 1998. IP construction expenditures for the period 1998-2002 are
expected to total about $1 billion. Additional expenditures may be required
during this period to accommodate transitional expenditures related to a
competitive environment, environmental compliance costs and system upgrades,
which cannot be determined at this time.
IP's capital expenditures for the years 1998 through 2002, in addition to
its construction expenditures, are expected to include $129 million for nuclear
fuel and $291 million for mandatory debt retirement.
In addition, IP has substantial commitments for the purchase of coal under
long-term contracts. Estimated coal contract commitments for 1998 through 2002
are $619 million (excluding price escalation provisions). Total coal purchases
for 1997, 1996 and 1995 were $181 million, $184 million and $168 million,
respectively. IP has contracts with various natural gas suppliers and interstate
pipelines to provide natural gas supply, transportation and leased storage.
Estimated committed natural gas, transportation and leased storage costs
(including pipeline transition costs) for 1998 through 2002 total $56 million.
Total natural gas purchased for 1997, 1996 and 1995 was $185 million, $207
million and $150 million, respectively.
<PAGE>
IP's estimated nuclear fuel commitments for Clinton are approximately $11
million for uranium concentrates through 2001, $3 million for conversion
services through 2002, $35 million for enrichment services through 1999 and $232
million for fabrication services through 2019. IP is committed to purchase
approximately $20 million of emission allowances through 1999. IP anticipates
that all gas-related costs will be recoverable under IP's UGAC. See the
subcaption "Fuel Cost Recovery" below for discussion of the UFAC.
Fuel Cost Recovery On September 29, 1997, the ICC approved an IP petition that
stipulates customers will not be charged for certain additional costs of energy
incurred as a result of Clinton being out of service. Under the petition, fuel
costs charged to customers will be no higher than average 1995 - 1996 levels
until Clinton is back in service operating at least at a 65% capacity factor for
two consecutive months. See "Note 2 - Clinton Power Station" for additional
information about Clinton.
As a result of Illinois deregulation legislation, IP may choose to
eliminate application of the UFAC. IP's base rates would still include a
component for some level of recovery of fuel costs, but IP would not be able to
pass through to customers increased costs of purchasing fuel, emission
allowances or replacement power. On elimination of the UFAC, base rates will
include a fixed fuel cost factor equivalent to the average 1995 - 1996 fuel cost
levels. Future recovery of fuel costs is uncertain, as IP will decrease base
electric rates to residential customers beginning August 1998 and certain
customers will be free to choose their electric generation suppliers beginning
in October 1999. The extent to which fuel costs are recovered will depend on a
number of factors including the future market prices for wholesale and retail
energy, when Clinton returns to service, and whether IP elects to eliminate the
UFAC.
Insurance IP maintains insurance for certain losses involving the operation of
Clinton. For physical damage to the plant, IP's insurance program has two
layers: 1) a primary layer of $500 million provided by nuclear insurance pools;
and 2) an excess coverage layer of $1.1 billion provided by an industry-owned
mutual insurance company for a total coverage of $1.6 billion. In the event of
an accident with an estimated cost of reactor stabilization and site
decontamination exceeding $100 million, NRC regulations require that insurance
proceeds be dedicated and used first to return the reactor to, and maintain it
in, a safe and stable condition, and second to decontaminate the reactor station
site. The insurers also provide coverage for the shortfall in the
Decommissioning Trust Fund caused by the premature decommissioning of the
reactor due to an accident. In the event insurance limits are not exhausted by
the above, the remaining coverage will be applied to property damage and a
portion of the value of the undamaged property. In addition, while IP has no
reason to anticipate a serious nuclear accident at Clinton, if such an incident
should occur, the claims for property damage and other costs could materially
exceed the limits of current or available insurance coverage. In the event of an
extended shutdown of Clinton due to accidental property damage, IP also
purchases approximately $1.5 million per week of business interruption insurance
coverage through an industry-owned mutual insurance company. This insurance does
not provide coverage until Clinton has been out of service for 21 weeks.
All United States nuclear reactor licensees are subject to the
Price-Anderson Act. This act currently limits public liability for a nuclear
incident to $8.9 billion. Private insurance covers the first $200 million.
Retrospective premium assessments against each licensed nuclear reactor in the
United States provide excess coverage. Currently, the liability to these nuclear
reactor licensees for such an assessment would be up to $79.3 million per
incident, not including premium taxes which may be applicable, payable in annual
installments of not more than $10 million.
A Master Worker Policy covers worker tort claims alleging bodily injury,
sickness or disease due to the nuclear energy hazard for workers whose initial
radiation exposure occurred on or after January 1, 1988. The policy has an
aggregate limit of $200 million that applies to the commercial nuclear industry
as a whole. A provision provides for automatic reinstatement of policy limits up
to an additional $200 million.
IP may be subject to other risks that may not be insurable, or the amount
of insurance carried to offset the various risks may not be sufficient to meet
potential liabilities and losses. There is also no assurance that IP will be
able to maintain insurance coverage at its present level. Under those
circumstances, such losses or liabilities may have a substantial adverse effect
on IP's financial position.
<PAGE>
Decommissioning and Nuclear Fuel Disposal IP is responsible for the costs of
decommissioning Clinton and for spent nuclear fuel disposal costs. In May 1997,
consistent with IP's assumption of all of Soyland's ownership obligations of
Clinton, Soyland's nuclear decommissioning trust assets were transferred to IP.
Future decommissioning costs related to Soyland's former share of Clinton will
be provided through the PCA between Soyland and IP. IP is collecting future
decommissioning costs for the remaining portion of Clinton through its electric
rates based on an ICC-approved formula that allows IP to adjust rates annually
for changes in decommissioning cost estimates. Illinois deregulation legislation
provides for the continued recovery of decommissioning costs from IP's delivery
customers.
IP concluded a site-specific study in 1996 to estimate the costs of
dismantlement, removal and disposal of Clinton. This study resulted in projected
decommissioning costs of $538 million (1996 dollars) or $969 million (2026
dollars, assuming a 2% inflation factor). Regulatory approval of this increased
decommissioning cost level was received in August 1997. This estimate is the
basis used for funding decommissioning costs through rates charged to IP's
customers and through the PCA with Soyland.
External decommissioning trusts, as prescribed under Illinois law and
authorized by the ICC, accumulate funds for the future decommissioning of
Clinton based on the expected service life of the plant. For the years 1997,
1996 and 1995, IP contributed $5.3 million, $3.9 million and $5.0 million,
respectively, to its external nuclear decommissioning trust funds. The balances
in these nuclear decommissioning funds at December 31, 1997 and 1996, were $62.5
million and $41.4 million, respectively. Decommissioning funds are recorded as
assets on the balance sheet. A decommissioning liability approximately
equivalent to trust assets is also recorded. IP recognizes earnings and expenses
from the trust fund as changes in its assets and liabilities relating to these
funds occur.
The FASB is reviewing the accounting for closure and removal costs of
long-lived assets. Changes to current electric utility industry accounting
practices for decommissioning may result in recording the estimated total cost
for decommissioning as a liability and an increase to plant balances,
depreciating the increased plant balances, and reporting trust fund income from
the external decommissioning trusts as investment income rather than as a
reduction to decommissioning expense. Based on current information, management
believes that these changes will not have an adverse effect on results of
operations due to existing and anticipated future ability to recover
decommissioning costs through rates.
Under the Nuclear Waste Policy Act of 1982, the DOE is responsible for the
permanent storage and disposal of spent nuclear fu el. The DOE currently charges
one mill ($0.001) per net kwh (one dollar per MWH) generated and sold for future
disposal of spent fuel. IP is recovering these charges through rates. In 1996,
the District of Columbia Circuit Court of Appeals issued an order, at the
request of nuclear-owning utilities and state regulatory agencies, confirming
DOE's unconditional obligation to take responsibility for spent nuclear fuel
commencing in 1998, even if it has no permanent repository at that time.
Notwithstanding this decision, which the DOE did not appeal, the DOE has
indicated to all nuclear utilities that it may experience delay in performance.
The impact of any such delay on IP will depend on many factors, including the
duration of such delay and the cost and feasibility of interim, on-site storage.
<PAGE>
Environmental Matters
Clean Air Act To comply with the SO2 emission reduction requirements of Phase I
(1995 - 1999) of the Acid Rain Program of the 1990 Clean Air Act Amendments, IP
continues to purchase emission allowances. An emission allowance is the
authorization by the U.S. EPA to emit one ton of SO2. The ICC approved IP's
Phase I Acid Rain Compliance Plan in September 1993, and IP is continuing to
implement that plan. IP has acquired sufficient emission allowances to meet most
of its anticipated needs for 1998 and 1999 and will purchase the remainder on
the spot market. In 1993, the Illinois General Assembly passed and the governor
signed legislation authorizing, but not requiring, the ICC to permit
expenditures and revenues from emission allowance purchases and sales to be
included in rates charged to customers as a cost of fuel. In December 1994, the
ICC approved the recovery of emission allowance costs through the UFAC. See the
subcaption "Fuel Cost Recovery" above for discussion of the UFAC. IP's
compliance plan will defer, until at least 2000, any need for scrubbers or other
capital projects associated with SO2 emission reductions. Phase II (2000 and
beyond) SO2 emission reduction requirements of the Acid Rain Program could
require additional actions and may result in capital expenditures and the
purchase of emission allowances.
To comply with the Phase I NOx emission reduction requirements of the acid
rain provisions of the Clean Air Act, IP installed low-NOx burners at Baldwin
Unit 3 and Vermilion Unit 2. On November 29, 1994, the Phase I NOx rules were
remanded to the U.S. EPA. On April 13, 1995, the U.S. EPA reinstated, with some
modifications, the Phase I NOx rules effective January 1, 1996. IP was
positioned to comply with these revised rules without additional modifications
to any of its generating plants.
The U.S. EPA issued revised Phase II NOx emission limits on December 10,
1996. IP has prepared a Phase II Compliance Plan. Litigation over the scope and
legality of these Phase II NOx limits precludes a precise quantification of
anticipated capital costs for compliance; however, capital expenditures for IP's
NOx Compliance Plan are expected to be $100 million prior to the year 2000. The
majority of this investment will be directed to Baldwin Units 1 and 2 and will
occur in conjunction with replacement of the air heaters on these units.
In addition, regulators are continuing to examine potential approaches for
compliance with current federal ozone air quality standards. On November 7,
1997, the U.S. EPA proposed air pollution rules which would require substantial
reductions of NOx emissions in Illinois and 21 other states. The proposal would
require the installation of NOx controls by September 2002. This proposal is
expected to be finalized by November 1998 with Illinois utility reduction
requirements specified in 1999. Preliminary cost estimates to comply with the
proposed NOx limitations are $130 to $150 million beyond what is already needed
to comply with the NOx requirements of Phase II of the Acid Rain Program. The
legality of this proposal along with its technical feasibility is expected to be
challenged by a number of utilities and utility groups, including IP.
Global Warming On December 11, 1997, international negotiations to reduce
greenhouse gas emissions concluded with the adoption of the Kyoto Protocol. This
Protocol requires the United States to reduce greenhouse gas emissions to 7%
below 1990 levels during the years 2008 through 2012 and to make further
reductions thereafter. This Protocol must be ratified by the United States
Senate. United States Senate Resolution 98 (passed 95-0) indicates the Senate
would not ratify an agreement that fails to involve all countries or would
damage the United States economy. Ratification will be a major political issue
as the Protocol does not contain key elements that Senate Resolution 98 said
would be necessary for ratification. It is anticipated that ratification will be
delayed until after 1998.
IP will face major changes in how it generates electricity if the Kyoto
Protocol is ratified, or if the Protocol's reduction goals are incorporated into
other environmental regulations. IP would have to repower some generating units
and change from coal to natural gas in other units to reduce greenhouse gas
emissions. IP estimates that compliance with these proposed regulations may
require significant capital outlays and annual operating expenses which could
have a material adverse impact on IP.
<PAGE>
Manufactured-Gas Plant IP's estimated liability for MGP site remediation is $65
million. This amount represents IP's current best estimate of the costs that it
will incur in remediation of the 24 MGP sites for which it is responsible.
Because of the unknown and unique characteristics at each site, IP cannot
presently determine its ultimate liability for remediation of the sites.
IP is currently recovering MGP site remediation through tariff riders
approved by the ICC. Accordingly, IP has recorded a regulatory asset on its
balance sheet totaling $65 million as of December 31, 1997. Management expects
that cleanup costs will be fully recovered from IP's customers.
To offset the burden imposed on its customers, IP has initiated litigation
against a number of insurance carriers. Any settlement proceeds or damages
recovered from the carriers will continue to be credited to IP's customers
through the tariff rider mechanism which the ICC previously approved.
Electric and Magnetic Fields The possibility that exposure to EMF emanating from
power lines, household appliances and other electric sources may result in
adverse health effects continues to be the subject of litigation and
governmental, medical and media attention. Litigants also have claimed that EMF
concerns justify recovery from utilities for the loss in value of real property
exposed to power lines, substations and other such sources of EMF. The number of
EMF cases has declined in the last few years as more national and international
science commissions have concluded that an EMF health risk has not been
established. Additional research is being conducted to attempt to resolve
continuing scientific uncertainties. On July 3, 1997, President Clinton signed
legislation extending the National EMF Research and Public Information
Dissemination Program through 1998. Research results, policy decisions and
public information developments will continue into 1999. It is too soon to tell
what, if any, impact these actions may have on IP's financial position. IP
continues its commitment to address customer and employee concerns related to
the EMF issue.
Other
Legal Proceedings IP is involved in legal or administrative proceedings before
various courts and agencies with respect to matters occurring in the ordinary
course of business, some of which involve substantial amounts of money.
Management believes that the final disposition of these proceedings will not
have a material adverse effect on the consolidated financial position or the
results of operations.
Accounts Receivable IP sells electric energy and natural gas to residential,
commercial and industrial customers throughout Illinois. At December 31, 1997,
72%, 17% and 11% of "Accounts receivable - Service" were from residential,
commercial and industrial customers, respectively. IP maintains reserves for
potential credit losses and such losses have been within management's
expectations. During 1997, IP increased its reserve for doubtful accounts from
$3.0 million to $5.5 million.
Contingencies
Soyland In March 1997, the NRC issued an order approving transfer to IP of the
Clinton operating license related to Soyland's 13.2% ownership in connection
with the transfer from Soyland to IP of all of Soyland's interest in Clinton.
The FERC approved an amended PCA in July 1997. The amended PCA obligates
Soyland to purchase all of its capacity and energy needs from IP for at least 10
years (the initial term of the PCA) and includes a provision that allows Soyland
to pay its base capacity charges in advance. The amended PCA also provides that
a contract cancellation fee will be paid by Soyland to IP in the event that a
Soyland Cooperative member terminates its membership from Soyland. In May 1997,
three distribution cooperative members terminated their membership by buying out
of their respective long-term wholesale power contracts with Soyland. As a
result, Soyland paid a fee of $20.8 million to IP in June 1997 to reduce its
future base capacity charges.
In December, 1997, Soyland signed a letter of intent to pay in advance the
remainder of its base capacity charges in the PCA. The fee of approximately $70
million will be deferred and recognized as interchange revenue over the initial
term of the PCA. The payment will be contingent on Soyland obtaining the
necessary financing and regulatory approvals in 1998.
Nuclear Fuel Lease See "Note 7 - Capital Leases" for discussion of contingencies
related to IP's nuclear fuel lease.
Internal Revenue Service Audit The Internal Revenue Service is currently
auditing IP's federal income tax returns for the years 1991 through 1993. At
this time, the outcome of the audit cannot be determined; however, management
does not expect that the results will have a material adverse effect on IP's
financial position or results of operations. For a detailed discussion of income
taxes, see "Note 6 - Income Taxes."
<PAGE>
Note 4 - Lines of Credit and Short-Term Loans
IP has total lines of credit represented by bank commitments amounting to $354
million, all of which were unused at December 31, 1997. These lines of credit
are renewable in May 1998, August 1998 and May 2002. These bank commitments
support the amount of commercial paper outstanding at any time, limited only by
the amount of unused bank commitments, and are available to support other IP
activities.
IP pays facility fees up to .10% per annum on $350 million of the total
lines of credit, regardless of usage. The interest rate on borrowings under
these agreements is, at IP's option, based upon the lending banks' reference
rate, their Certificate of Deposit rate, the borrowing rate of key banks in the
London interbank market or competitive bid.
IP has letters of credit totaling $206 million and pays fees up to .45% per
annum on the unused amount of credit.
In addition, IP and the Fuel Company each have a short-term financing
option to obtain funds not to exceed $30 million. IP and the Fuel Company pay no
fees for this uncommitted facility and funding is subject to availability upon
request.
For the years 1997, 1996 and 1995, IP had short-term borrowings consisting
of bank loans, commercial paper, extendible floating rate notes and other
short-term debt outstanding at various times as follows:
(Millions of dollars, except rates) 1997 1996 1995
Short-term borrowings
at December 31, $ 376.8 $ 310.0 $ 359.6
Weighted average interest
rate at December 31, 6.0% 5.7% 6.0%
Maximum amount
outstanding
at any month end $ 376.8 $ 310.0 $ 359.6
Average daily borrowings
outstanding during
the year $ 284.4 $ 261.9 $ 306.5
Weighted average interest
rate during the year 5.8% 5.6% 6.2%
Interest rate cap agreements are used to reduce the potential impact of
increases in interest rates on floating-rate debt. IP has two variable rate
interest rate cap agreements covering up to $114.6 million of commercial paper.
These agreements entitle IP to receive from a counterparty on a quarterly basis
the amount, if any, by which IP's interest payments on a nominal amount of
commercial paper exceed the interest rate set by the cap. On December 31, 1997,
the cap rates were set at 7.75% and 8.0% while the current market rate available
to IP was 5.8%.
IP also has a $50 million interest rate swap in effect through October 1998
where IP pays 5.92% and receives the LIBOR variable rate, payable quarterly.
Note 5 - Facilities Agreements
On March 13, 1997, the NRC issued an order approving transfer to IP of the
Clinton operating license related to Soyland's 13.2% ownership obligations in
connection with the transfer from Soyland to IP of all of Soyland's interest in
Clinton pursuant to an agreement reached in 1996. Soyland's title to the plant
and directly related assets such as nuclear fuel was transferred to IP on May 1,
1997. Soyland's nuclear decommissioning trust assets were transferred to IP on
May 19, 1997, consistent with IP's assumption of all of Soyland's ownership
obligations including those related to decommissioning.
The FERC approved an amended PCA between Soyland and IP in July 1997. The
amended PCA obligates Soyland to purchase all of its capacity and energy needs
from IP for at least 10 years. The amended PCA provides that a contract
cancellation fee will be paid by Soyland to IP in the event that a Soyland
member terminates its membership in Soyland. In May 1997, three distribution
cooperative members terminated their membership by buying out of their
respective long-term wholesale power contracts with Soyland. This action
resulted in Soyland paying a fee of $20.8 million to IP in June 1997 to reduce
its future base capacity charges. Fee proceeds of $2.9 million were used to
offset the costs of acquiring Soyland's share of Clinton with the remaining
$17.9 million recorded as interchange revenue. In December 1997, Soyland signed
a letter of intent to pay in advance the remainder of its base capacity charges
in the PCA. The fee of approximately $70 million will be deferred and recognized
as interchange revenue over the initial term of the PCA. The payment will be
contingent on Soyland obtaining the necessary financing and regulatory approvals
in 1998.
<PAGE>
Note 6 - Income Taxes
Deferred tax assets and liabilities were comprised of the following:
Balances as of December 31,
(Millions of dollars) 1997 1996
Deferred tax assets:
Current:
Misc. book/tax recognition differences $ 11.2 $ 7.7
Noncurrent:
Depreciation and other property related 46.2 42.0
Alternative minimum tax 156.8 198.5
Tax credit and net operating loss
carryforward - 32.8
Unamortized investment tax credit 116.9 120.9
Misc. book/tax recognition differences 40.3 65.8
360.2 460.0
Total deferred tax assets $ 371.4 $ 467.7
Deferred tax liabilities:
Current:
Misc. book/tax recognition differences $ .9 $ 11.3
Noncurrent:
Depreciation and other property related 1,348.0 1,350.1
Deferred Clinton costs - 58.2
Misc. book/tax recognition differences (7.1) 99.7
1,340.9 1,508.0
Total deferred tax liabilities $ 1,341.8 $ 1,519.3
Income taxes included in the Consolidated Statements of Income consist of the
following components:
Years Ended December 31,
(Millions of dollars) 1997 1996 1995
Current taxes-
Included in operating
expenses and taxes $ 72.7 $ 79.2 $ 98.6
Included in other income
and deductions (.7) (14.5) (20.3)
Total current taxes 72.0 64.7 78.3
Deferred taxes-
Included in operating
expenses and taxes
Property related differences 9.2 60.4 62.2
Alternative minimum tax 41.7 1.1 2.9
Gain/loss on reacquired debt .4 (1.6) (1.9)
Net operating loss
carryforward - - (.2)
Enhanced retirement
and severance .5 2.6 (15.0)
Misc. book/tax recognition
differences (16.7) 6.1 (13.9)
Included in other income
and deductions
Property related differences (.4) 10.2 9.7
Misc. book/tax recognition
differences 1.5 1.7 2.2
Total deferred taxes 36.2 80.5 46.0
Deferred investment
tax credit-net
Included in operating
expenses and taxes (7.3) (7.3) (6.9)
Total investment tax credit (7.3) (7.3) (6.9)
Total income taxes from
continuing operations $ 100.9 $ 137.9 $ 117.4
Income tax -
Extraordinary item
Current tax expense (17.8) - -
Deferred tax expense (100.2) - -
Total extraordinary item (118.0) - -
Total income taxes $ (17.1) $ 137.9 $ 117.4
<PAGE>
The reconciliations of income tax expense to amounts computed by applying
the statutory tax rate to reported pretax income from continuing operations for
the period are set below:
Years Ended December 31,
(Millions of dollars) 1997 1996 1995
Income tax expense at the
federal statutory tax rate $ 88.1 $ 128.3 $ 105.0
Increases/(decreases) in taxes resulting from-
State taxes,
net of federal effect 11.8 13.7 14.0
Investment tax credit
amortization (7.3) (7.3) (6.9)
Depreciation not normalized 11.3 9.4 7.4
Interest expense on
preferred securities (6.9) (6.9) (3.7)
Other-net 3.9 .7 1.6
Total income taxes from
continuing operations $ 100.9 $ 137.9 $ 117.4
Combined federal and state effective income tax rates were 40.1%, 37.6% and
39.1% for the years 1997, 1996 and 1995, respectively.
IP is subject to the provisions of the Alternative Minimum Tax System. As a
result, IP has an Alternative Minimum Tax credit carryforward at December 31,
1997, of approximately $156.8 million. This credit can be carried forward
indefinitely to offset future regular income tax liabilities in excess of the
tentative minimum tax.
The Internal Revenue Service is currently auditing IP's consolidated
federal income tax returns for the years 1991 through 1993. At this time, the
outcome of the audit cannot be determined; however, the results of the audit are
not expected to have a material adverse effect on IP's consolidated financial
position or results of operations.
Because of the passage of HB 362, IP's electric generation business no
longer meets the criteria for application of FAS 71. As required by FAS 101,
"Regulated Enterprises - Accounting for the Discontinuation of Application of
FASB Statement No. 71", the income tax effects of the write-off of regulatory
assets and liabilities related to electric generation are reflected in the
extraordinary item for the cumulative effect of a change in accounting
principle.
Note 7 - Capital Leases
The Fuel Company, which is 50% owned by IP, was formed in 1981 for the purpose
of leasing nuclear fuel to IP for Clinton. Lease payments are equal to the Fuel
Company's cost of fuel as consumed (including related financing and
administrative costs). Billings under the lease agreement during 1997, 1996 and
1995 were $4 million, $35 million and $41 million, respectively, including
financing costs of $4 million, $5 million and $7 million, respectively. IP is
required to pay financing costs whether or not fuel is consumed. IP is obligated
to make subordinated loans to the Fuel Company at any time the obligations of
the Fuel Company that are due and payable exceed the funds available to the Fuel
Company. Lease terms stipulate that in the event that Clinton is out of service
for 24 consecutive months, IP will be obligated to purchase Clinton's incore
nuclear fuel for $62 million from the Fuel Company. IP has an obligation for
nuclear fuel disposal costs of leased nuclear fuel. See "Note 3 - Commitments
and Contingencies" for discussion of decommissioning and nuclear fuel disposal
costs. Nuclear fuel lease payments are included with "Fuel for electric plants"
on IP's Consolidated Statements of Income.
At December 31, 1997 and 1996, current obligations under capital lease for
nuclear fuel are $18.7 million and $36.9 million, respectively.
Over the next five years estimated payments under capital leases are as
follows:
(Millions of dollars)
1998 $ 23.5
1999 44.3
2000 23.9
2001 21.5
2002 16.7
Thereafter 12.8
142.7
Less-Interest 16.0
Total $ 126.7
<PAGE>
Note 8 - Long-Term Debt
<TABLE>
<S> <C> <C>
(Millions of dollars)
December 31, 1997 1996
First mortgage bonds-
6 1/2% series due 1999 $ 72.0 $ 72.0
6.60% series due 2004 (Pollution Control Series A) 6.3 6.5
7.95% series due 2004 72.0 72.0
6% series due 2007 (Pollution Control Series B) 18.7 18.7
7 5/8% series due 2016 (Pollution Control Series F, G and H) - 150.0
8.30% series due 2017 (Pollution Control Series I) 33.8 33.8
7 3/8% series due 2021 (Pollution Control Series J) 84.7 84.7
8 3/4% series due 2021 57.1 57.1
5.70% series due 2024 (Pollution Control Series K) 35.6 35.6
7.40% series due 2024 (Pollution Control Series L) 84.1 84.1
Total first mortgage bonds 464.3 614.5
New mortgage bonds-
6 1/8% series due 2000 40.0 40.0
5 5/8% series due 2000 110.0 110.0
6 1/2% series due 2003 100.0 100.0
6 3/4% series due 2005 70.0 70.0
8% series due 2023 229.0 229.0
7 1/2% series due 2025 177.0 177.0
Adjustable rate series due 2028 (Pollution Control Series M, N and O) 111.8 111.8
Adjustable rate series due 2032 (Pollution Control Series P, Q and R) 150.0 -
Total new mortgage bonds 987.8 837.8
Total mortgage bonds 1,452.1 1,452.3
Medium-term notes, series A 68.0 78.5
Variable rate long-term debt due 2017 75.0 75.0
Total other long-term debt 143.0 153.5
1,595.1 1,605.8
Unamortized discount on debt (16.8) (18.1)
Total long-term debt excluding capital lease obligations 1,578.3 1,587.7
Obligations under capital leases 126.7 96.4
1,705.0 1,684.1
Long-term debt and lease obligations maturing within one year (87.5) (47.7)
Total long-term debt $ 1,617.5 $ 1,636.4
</TABLE>
In April 1997, IP refinanced $150 million of 7 5/8% First Mortgage Bonds due
2016 as Adjustable Rate New Mortgage Bonds due 2032.
In 1989 and 1991, IP issued a series of fixed rate medium-term notes. At
December 31, 1997, these notes had interest rates ranging from 9% to 9.31% and
will mature at various dates in 1998. Interest rates on variable rate long-term
debt due 2017 are adjusted weekly and ranged from 4.35% to 4.6% at December 31,
1997.
For the years 1998, 1999, 2000, 2001 and 2002, IP has long-term debt maturities
and cash sinking fund requirements in the aggregate of (in millions) $68.8,
$72.8, $150.8, $.8 and $.8, respectively. These amounts exclude capital lease
requirements. See "Note 7 - Capital Leases."
At December 31, 1997, the aggregate total of unamortized debt expense and
unamortized loss on reacquired debt was approximately $50.4 million.
In 1992, IP executed a new general obligation mortgage (New Mortgage) to
replace, over time, IP's 1943 Mortgage and Deed of Trust (First Mortgage). Both
mortgages are secured by liens on substantially all of IP's properties. A
corresponding issue of First Mortgage bonds, under the First Mortgage, secures
any bonds issued under the New Mortgage. In October 1997, at a special
bondholders meeting, the 1943 First Mortgage was amended to be generally
consistent with the New Mortgage. The remaining balance of net bondable
additions at December 31, 1997, was approximately $1.8 billion.
<PAGE>
Note 9 - Preferred Stock
<TABLE>
<S> <C> <C>
(Millions of dollars)
December 31, 1997 1996
Serial Preferred Stock, cumulative, $50 par value-
Authorized 5,000,000 shares; 1,139,110 and 1,221,700 shares outstanding, respectively
Series Shares Redemption Prices
4.08% 283,290 $ 51.50 $ 14.1 $ 15.0
4.26% 136,000 51.50 6.8 7.5
4.70% 176,000 51.50 8.8 10.0
4.42% 134,400 51.50 6.7 7.5
4.20% 167,720 52.00 8.4 9.0
7.75% 241,700 50.00 after July 1, 2003 12.1 12.1
Net premium on preferred stock .2 .2
Total Preferred Stock, $50 par value $ 57.1 $ 61.3
Serial Preferred Stock, cumulative, without par value-
Authorized 5,000,000 shares; 0 and 698,200 shares outstanding, respectively
Series Shares Redemption Prices
A - - $ - $ 34.9
Total Preferred Stock, without par value $ - $ 34.9
Preference Stock, cumulative, without par value-
Authorized 5,000,000 shares; none outstanding - -
Total Serial Preferred Stock, Preference Stock and Preferred Securities $ 57.1 $ 96.2
Company Obligated Mandatorily Redeemable Preferred Securities of:
Illinois Power Capital, L.P.
Monthly Income Preferred Securities, cumulative, $25 liquidation preference-
3,880,000 shares authorized and outstanding $ 97.0 $ 97.0
Illinois Power Financing I
Trust Originated Preferred Securities, cumulative, $25 liquidation preference-
4,000,000 shares authorized and outstanding 100.0 100.0
Total Mandatorily Redeemable Preferred Stock $ 197.0 $ 197.0
</TABLE>
Serial Preferred Stock ($50 par value) is redeemable at the option of IP in
whole or in part at any time with not less than 30 days and not more than 60
days notice by publication. The MIPS are redeemable at the option in whole or in
part on or after October 6, 1999 with not less than 30 days and not more than 60
days notice by publication. The TOPrS mature on January 31, 2045 and may be
redeemed in whole or in part at any time on or after January 31, 2001.
Quarterly dividend rates for Serial Preferred Stock, Series A, are determined
based on market interest rates of certain U.S. Treasury securities. Dividends
paid in 1997 and 1996 were $.75 per share per quarter.
Illinois Power Capital, L.P., is a limited partnership in which IP serves as a
general partner. Illinois Power Capital issued (1994) $97 million of
tax-advantaged MIPS at 9.45% (5.67% after-tax rate) with a liquidation
preference of $25 per share. IP consolidates the accounts of Illinois Power
Capital.
Illinois Power Financing I is a statutory business trust in which IP serves as
sponsor. IPFI issued (1996) $100 million of TOPrS at 8% (4.8% after-tax rate).
IP consolidates the accounts of IPFI.
On September 29, 1997, IP issued a notice of redemption to all holders of its
Adjustable Rate Series A Preferred Stock. All 698,200 shares outstanding were
redeemed on November 1, 1997, at the price of $50 per share. In 1997, IP
redeemed $4.2 million of various issues of Serial Preferred Stock. The carrying
amount was $.2 million over consideration paid and was recorded in equity and
included in Net income applicable to common stock.
<PAGE>
Note 10 - Common Stock
and Retained Earnings
On May 31, 1994, common shares of IP began trading as common shares of Illinova.
Illinova is the sole shareholder of IP common stock.
In 1997, IP repurchased 6,017,748 shares of its common stock from Illinova.
In 1996 and 1995, IP repurchased 714,811 shares and 2,696,086 shares,
respectively, of its common stock from Illinova. Under Illinois law, such shares
may be held as treasury stock and treated as authorized but unissued, or may be
canceled by resolution of the Board of Directors. IP holds the common stock as
treasury stock and deducts it from common equity at the cost of the shares.
IP employees participate in an ESOP that includes an incentive compensation
feature which is tied to achievement of specified corporate performance goals.
This arrangement began in 1991 when IP loaned $35 million to the Trustee of the
Plans, which used the loan proceeds to purchase 2,031,445 shares of IP's common
stock on the open market. The loan and common shares were converted to Illinova
instruments with the formation of Illinova in May 1994. These shares are held in
a suspense account under the Plans and are being distributed to the accounts of
participating employees as the loan is repaid by the Trustee with funds
contributed by IP, together with dividends on the shares acquired with the loan
proceeds. IP financed the loan with funds borrowed under its bank credit
agreements.
For the year ended December 31, 1997, 91,282 common shares were allocated
to salaried employees and 83,418 shares to employees covered under the
Collective Bargaining Agreement through the matching contribution feature of the
ESOP arrangement. Under the incentive compensation feature, 70,720 common shares
were allocated to employees for the year ended December 31, 1997. During 1997,
IP contributed $5.0 million to the ESOP and, using the shares allocated method,
recognized $3.3 million of expense. Interest paid on the ESOP debt was
approximately $1.3 million in 1997 and dividends used for debt service were
approximately $2.3 million.
In 1992, the Board of Directors adopted and the shareholders approved a
Long-Term Incentive Compensation Plan (the Plan) for officers or employee
members of the Board, but excluding directors who are not officers or employees.
The types of awards that may be granted under the Plan are restricted stock,
incentive stock options, non-qualified stock options, stock appreciation rights,
dividend equivalents and other stock-based awards. The Plan provides that any
one or more types of awards may be granted for up to 1,500,000 shares of
Illinova's common stock. The following table outlines the activity under this
plan at December 31, 1997. Of the options granted in 1992, 1993, 1994 and 1995
in the table below, 7,500, 10,500, 4,400 and 6,500 options, respectively, have
been forfeited and are not exercisable. An additional 20,000 options were
exercised in January 1998.
Year Options Grant Year Expiration Options
Granted Granted Price Exercisable Date Exercised
1992 62,000 $ 23 3/8 1996 6/10/01 38,000
1993 73,500 $ 24 1/4 1997 6/09/02 -
1994 82,650 $ 20 7/8 1997 6/08/03 -
1995 69,300 $ 24 7/8 1998 6/14/04 -
1996 80,500 $ 29 3/4 1999 2/07/05 -
1997 82,000 $ 26 1/8 2000 2/12/07 -
In October 1995, the FASB issued FAS 123, "Accounting for Stock-Based
Compensation" effective for fiscal years beginning after December 15, 1995.
Based on the current and anticipated use of stock options, the impact of FAS 123
is not material on the current period and is not envisioned to be material in
any future period. IP continues to account for its stock options in accordance
with Accounting Principle Board Opinion No. 25.
The provisions of Supplemental Indentures to IP's General Mortgage
Indenture and Deed of Trust contain certain restrictions with respect to the
declaration and payment of dividends. IP was not limited by any of these
restrictions at December 31, 1997. Under the Restated Articles of Incorporation,
common stock dividends are subject to the preferential rights of the holders of
preferre d and preference stock.
Note 11 -Pension and Other Benefit Costs
Illinova offers certain benefit plans to the employees of all of its
subsidiaries. IP is sponsor and administrator of all of the benefit plans. IP is
reimbursed by the other Illinova subsidiaries for their share of the expenses of
the benefit plans. The discussion and amounts below represent the plans in
total, including the amounts attributable to the other subsidiaries.
IP has defined-benefit pension plans covering all officers and employees.
Benefits are based on years of service and compensation. IP's funding policy is
to contribute annually at least the minimum amount required by government
funding standards, but not more than can be deducted for federal income tax
purposes.
<PAGE>
Pension costs, a portion of which have been capitalized for 1997, 1996 and
1995, include the following components:
Years Ended December 31,
(Million of dollars) 1997 1996 1995
Service cost on benefits
earned during the year $ 10.1 $ 10.2 $ 10.4
Interest cost on projected
benefit obligation 27.9 26.8 23.6
Return on plan assets (95.6) (42.2) (58.3)
Net amortization and deferral 61.5 9.4 29.6
Effect of enhanced retirement
program - - 15.7
Net periodic pension cost $ 3.9 $ 4.2 $ 21.0
The estimated funded status of the plans at December 31, 1997 and 1996,
using discount rates of 7.5% and 8.0%, respectively, and future compensation
increases of 4.5% was as follows:
Balances as of December 31,
(Millions of dollars) 1997 1996
Actuarial present value of:
Vested benefit obligation $ (329.7) $ (291.7)
Accumulated benefit obligation (350.6) (312.5)
Projected benefit obligation (412.8) (361.5)
Plan assets at fair value 432.1 357.2
Funded status 19.3 (4.3)
Unrecognized net (gain)/loss (39.1) (13.8)
Unrecognized net asset at transition (26.1) (30.3)
Unrecognized prior service cost 17.4 19.3
Accrued pension cost included in
deferred credits $ (28.5) $ (29.1)
The plans' assets consist primarily of common stocks, fixed income
securities, cash equivalents, alternative investments and real estate. The
actuarial present values of accumulated plan benefits at January 1, 1997 and
1996, were $375 million and $361 million, respectively, including vested
benefits of $353 million and $337 million, respectively. The pension cost for
1997, 1996 and 1995 was calculated using a discount rate of 8.0%, 7.75% and
8.75%, respectively; future compensation increases of 4.5% for 1997, 1996 and
1995; and a return on assets of 9.5% for 1997 and 1996, and 9.0% for 1995. The
unrecognized net asset at transition and the unrecognized prior service cost are
amortized on a straight-line basis over the average remaining service period of
employees who are expected to receive benefits under the plan. IP made cash
contributions of $5 million in 1997, $6 million in 1996 and $2 million in 1995.
IP provides health care and life insurance benefits to certain retired
employees, including their eligible dependents, who attain specified ages and
years of service under the terms of the defined-benefit plans. Postretirement
benefits, a portion of which have been capitalized, for 1997 and 1996 included
the following components:
Years Ended December 31,
(Millions of dollars) 1997 1996
Service cost on benefits earned
during the year $ 1.9 $ 2.2
Interest cost on projected
benefit obligation 5.9 6.1
Return on plan assets (8.0) (5.9)
Amortization of unrecognized
transition obligation 7.4 6.4
Net periodic postretirement
benefit cost $ 7.2 $ 8.8
The net periodic postretirement benefit cost in the preceding table
includes amortization of the previously unrecognized accumulated postretirement
benefit obligation, which was $41.4 million and $44.2 million as of January 1,
1997 and 1996, respectively, over 20 years on a straight-line basis.
IP has established two separate trusts for those retirees who were subject
to a collectively bargained agreement and all other retirees to fund retiree
health care and life insurance benefits. IP's funding policy is to contribute
annually an amount at least equal to the revenues collected for the amount of
postretirement benefit costs allowed in rates. The plan assets consist of common
stocks and fixed income securities at December 31, 1997 and 1996. The estimated
funded status of the plans at December 31, 1997 and 1996, using weighted average
discount rates of 7.0% and 8.0%, respectively, and a return on assets of 9.0%,
was as follows:
Balances as of December 31,
(Millions of dollars) 1997 1996
Accumulated postretirement
benefit obligation
Current retirees $ (51.1) $ (49.6)
Current employees - fully eligible (5.5) (3.5)
Current employees - not fully eligible (32.8) (28.6)
Total benefit obligation (89.4) (81.7)
Plan assets at fair value 49.7 34.4
Funded status (39.7) (47.3)
Unrecognized transition obligation 38.7 41.4
Unrecognized net (gain)/loss (6.3) (7.1)
Accrued postretirement benefit cost
included in deferred credits $ (7.3) $ (13.0)
The pre-65 health-care-cost trend rate decreases from 7.1% to 5.5% over
nine years and the post-65 health-care-cost trend rate is level at 1.5%. A 1.0%
increase in each future year's assumed health-care-cost trend rates increases
the service and interest cost from $7.8 million to $8.7 million and the
accumulated postretirement benefit obligation from $89.4 million to $99.9
million.
<PAGE>
Note 12 - Segments of Business
Illinois Power Company is a public utility engaged in the generation,
transmission, distribution and sale of electric energy, and the distribution,
transportation and sale of natural gas. The following is a summary of
operations:
<TABLE>
<S> <C> <C> <C> <C> <C> <C> <C> <C> <C>
(Millions of dollars)
1997 1996 1995
Total Total Total
Electric Gas Company Electric Gas Company Electric Gas Company
Operation information -
Operating revenues $ 1,420.0 $ 353.9 $ 1,773.9 $ 1,340.5 $ 348.2 $ 1,688.7 $ 1,368.9 $ 272.5 $ 1,641.4
Operating expenses,
excluding provision
for income taxes 1,081.3 311.5 1,392.8 886.2 300.5 1,186.7 946.2 245.0 1,191.2
Pre-tax operating income 338.7 42.4 381.1 454.3 47.7 502.0 422.7 27.5 450.2
AFUDC 4.9 .1 5.0 6.3 .2 6.5 5.5 .5 6.0
Pre-tax operating income,
including AFUDC $ 343.6 $ 42.5 $ 386.1 $ 460.6 $ 47.9 $ 508.5 $ 428.2 $ 28.0 $ 456.2
Other deductions, net 5.7 9.0 8.1
Interest charges 128.7 133.0 148.0
Provision for
income taxes 100.9 137.9 117.4
Net income 150.8 228.6 182.7
Extraordinary item
(net of taxes) (195.0) - -
Preferred dividend
requirements (21.5) (22.3) (23.7)
Carrying value over
(under) consideration
paid for redeemed
preferred stock .2 (.7) (3.5)
Net income (loss) applicable
to common stock $(65.5) $205.6 $155.5
Other information -
Depreciation 171.5 $ 24.1 $ 195.6 $ 164.0 $ 22.5 $ 186.5 $ 161.4 $ 21.6 $183.0
Capital expenditures $ 201.3 $ 22.6 $ 223.9 $ 164.0 $ 23.3 $ 187.3 $ 185.7 $ 23.6 $209.3
Investment information -
Identifiable assets* $4,508.1 $ 453.8 4,961.9 $ 4,577.1 $ 481.9 $ 5,059.0 $ 4,580.4 $ 446.3 $5,026.7
Nonutility plant and
other investments 5.7 14.3 16.2
Assets utilized for
overall operations 323.9 495.2 524.3
Total assets $5,291.5 $5,568.5 $5,567.2
</TABLE>
<PAGE>
Note 13 - Fair Value of Financial Instruments
1997 1996
Carrying Fair Carrying Fair
(Millions of dollars) Value Value Value Value
Nuclear decommissioning
trust funds $ 62.5 $ 62.5 $ 41.4 $ 41.4
Cash and cash equivalents 17.8 17.8 12.5 12.5
Mandatorily redeemable
preferred stock 197.0 202.7 197.0 199.3
Long-term debt 1,578.3 1,627.6 1,587.7 1,629.3
Notes payable 376.8 376.8 310.0 310.0
The following methods and assumptions were used to estimate the fair value
of each class of financial instruments listed in the table above:
Nuclear Decommissioning Trust Funds The fair values of available-for-sale
marketable debt securities and equity investments held by the Nuclear
Decommissioning Trust are based on quoted market prices at the reporting date
for those or similar investments.
Cash and Cash Equivalents The carrying amount of cash and cash equivalents
approximates fair value due to the short maturity of these instruments.
Mandatorily Redeemable Preferred Stock and Long-Term Debt The fair value of
mandatorily redeemable preferred stock and long-term debt is estimated based on
the quoted market prices for similar issues or by discounting expected cash
flows at the rates currently offered for debt of the same remaining maturities,
as advised by IP's bankers.
Notes Payable The carrying amount of notes payable approximates fair value due
to the short maturity of these instruments.
Note 14 - Quarterly Consolidated Financial Information and Common Stock Data
(unaudited)
<TABLE>
<S> <C> <C> <C> <C>
(Millions of dollars)
First Quarter Second Quarter Third Quarter Fourth Quarter
1997 1997 1997 1997
Operating revenues $ 472.8 $ 415.3 $ 497.1 $ 388.7
Operating income 88.9 82.6 101.8 5.4
Net income (loss) before extraordinary item 55.0 51.4 71.9 (27.5)
Net income (loss) after extraordinary item 55.0 51.4 71.9 (222.5)
Net income (loss) applicable to common stock 49.5 46.0 67.5 (228.5)
Cash dividends declared on common stock 23.5 23.2 22.2 22.2
Cash dividends paid on common stock 23.5 23.5 23.2 22.2
First Quarter Second Quarter Third Quarter Fourth Quarter
1996 1996 1996 1996
Operating revenues $ 446.7 $ 365.7 $ 458.4 $ 417.9
Operating income 88.1 74.9 133.3 65.1
Net income 49.1 48.7 100.6 30.2
Net income applicable to common stock 43.5 42.5 94.8 24.8
Cash dividends declared on common stock 21.2 21.2 21.2 23.5
Cash dividends paid on common stock 21.2 21.2 21.2 21.2
</TABLE>
<PAGE>
Illinois Power Company
SELECTED CONSOLIDATED FINANCIAL DATA
<TABLE>
<S> <C> <C> <C> <C> <C> <C>
(Millions of dollars)
1997 1996 1995 1994 1993 1987
Operating revenues
Electric $ 1,244.4 $ 1,202.9 $ 1,252.6 $ 1,177.5 $ 1,135.6 $ 910.8
Electric interchange 175.6 137.6 116.3 110.0 130.8 92.4
Gas 353.9 348.2 272.5 302.0 314.8 308.7
Total operating revenues $1,773.9 $1,688.7 $ 1,641.4 $ 1,589.5 $ 1,581.2 $ 1,311.9
Extraordinary item net of income tax benefit $ (195.0) $ - $ - $ - $ - $ -
Net income (loss) after extraordinary item $ (44.2) $ 228.6 $ 182.7 $ 180.3 $ (56.1) $ 289.6
Effective income tax rate 40.1% 37.6% 39.1% 38.4% (72.4)% 19.1%
Net income (loss) applicable to common stock $ (65.5) $ 205.6 $ 155.5 $ 161.8 $ (82.2) $ 251.9
Cash dividends declared on common stock $ 91.1 $ 87.1 $ 77.9 $ 49.1 $ 30.2 $ 178.5
Cash dividends paid on common stock 92.4 84.8 75.3 60.5 60.5 176.2
Total assets $ 5,291.5 $ 5,568.5 $ 5,567.2 $ 5,595.8 $ 5,445.1 $ 5,922.7
Capitalization
Common stock equity $ 1,299.1 $ 1,576.1 $ 1,478.1 $ 1,466.0 $ 1,342.8 $ 1,841.4
Preferred stock 57.1 96.2 125.6 224.7 303.7 315.2
Mandatorily redeemable
preferred stock 197.0 197.0 97.0 133.0 48.0 160.0
Long-term debt 1,617.5 1,636.4 1,739.3 1,946.1 1,926.3 2,279.2
Total capitalization $3,170.7 $3,505.7 $ 3,440.0 $ 3,769.8 $ 3,620.8 $ 4,595.8
Retained earnings (deficit) $ 89.5 $ 245.9 $ 129.6 $ 51.1 $ (71.0) $ 554.8
Capital expenditures $ 223.9 $ 187.3 $ 209.3 $ 193.7 $ 277.7 $ 263.5
Cash flows from operations $ 418.7 $ 443.3 $ 473.7 $ 280.2 $ 396.6 $ 232.3
AFUDC as a percent of earnings
applicable to common stock (7.6)% 3.2% 3.9% 5.7% N/A 80.2%
Ratio of earnings to fixed charges 1.24 3.40 2.77 2.73 .80 2.51
</TABLE>
<PAGE>
Illinois Power Company
SELECTED STATISTICS
<TABLE>
<S> <C> <C> <C> <C> <C> <C>
1997 1996 1995 1994 1993 1987
Electric Sales in KWH (Millions)
Residential 4,734 4,782 4,754 4,537 4,546 4,241
Commercial 3,943 3,894 3,804 3,517 3,246 2,862
Industrial 8,403 8,493 8,670 8,685 8,120 7,323
Other 426 367 367 536 337 910
Sales to ultimate consumers 17,506 17,536 17,595 17,275 16,249 15,336
Interchange 7,230 5,454 4,444 4,837 6,015 3,682
Wheeling 3,253 928 642 622 569 -
Total electric sales 27,989 23,918 22,681 22,734 22,833 19,018
Electric Revenues (Millions)
Residential 489 $ 483 $ 500 $ 471 $ 463 $ 352
Commercial 325 318 321 295 269 209
Industrial 376 360 392 378 360 325
Other 40 38 37 30 40 25
Revenues from ultimate consumers 1,230 1,199 1,250 1,174 1,132 911
Interchange 176 138 116 110 131 92
Wheeling 14 4 3 3 3 -
Total electric revenues $1,420 $ 1,341 $ 1,369 $ 1,287 $ 1,266 $ 1,003
Gas Sales in Therms (Millions)
Residential $ 343 427 356 359 371 332
Commercial 147 177 144 144 148 137
Industrial 47 99 88 81 78 96
Sales to ultimate consumers 537 703 588 584 597 565
Transportation of customer-owned gas 309 251 273 262 229 327
Total gas sold and transported 846 954 861 846 826 892
Interdepartmental sales 19 9 21 5 7 5
Total gas delivered 865 963 882 851 833 897
Gas Revenues (Millions)
Residential $ 238 $ 216 $ 173 $ 192 $ 200 $ 192
Commercial 77 79 60 66 68 66
Industrial 20 40 24 31 34 34
Revenues from ultimate consumers 335 335 257 289 302 292
Transportation of customer-owned gas 9 7 8 9 8 15
Miscellaneous 10 6 7 4 5 2
Total gas revenues $ 354 $ 348 $ 272 $ 302 $ 315 $ 309
System peak demand (native load) in kw (thousands) 3,532 3,492 3,667 3,395 3,415 3,083
Firm peak demand (native load) in kw (thousands) 3,469 3,381 3,576 3,232 3,254 2,923
Net generating capability in kw (thousands) 3,289 4,148 3,862 4,121 4,045 3,400
Electric customers (end of year) 580,257 549,957 529,966 553,869 554,270 542,848
Gas customers (end of year) 405,710 389,223 374,299 388,170 394,379 384,091
Employees (end of year) 3,655 3,635 3,559 4,350 4,540 4,616
</TABLE>
500 south 27th street, decatur, illinois 62521 n http://www.illinova.com
unlocking the power 1997
This entire report is printed on recycled paper
