UNITED STATES

SECURITIES AND EXCHANGE COMMISSION

WASHINGTON, D.C. 20549

 

SCHEDULE 14A

 

Proxy Statement Pursuant to Section 14(a) of the Securities Exchange Act of 1934 (Amendment No.     )

 

Filed by the Registrant  x

 

Filed by a Party other than the Registrant  ¨

 

Check the appropriate box:

 

¨ Preliminary Proxy Statement

 

¨ Confidential, for use of the Commission Only (as permitted by Rule 14a-6(e)(2))

 

x Definitive Proxy Statement

 

¨ Definitive Additional Materials

 

¨ Soliciting Material Pursuant to (S) 240.14a-11(c) or (S) 240.14a-12

 

Wisconsin Power and Light Company

(Name of Registrant as Specified In Its Charter)

 

 

(Name of Person(s) Filing Proxy Statement, if other than the Registrant)

 

Payment of Filing Fee (Check the appropriate box):

 

x No fee required.

 

¨ Fee computed on table below per Exchange Act Rules 14a-6(i)(4) and 0-11.

 

 (1) Title of each class of securities to which transaction applies:

 

 (2) Aggregate number of securities to which transaction applies:

 

 (3) Per unit price or other underlying value of transaction computed pursuant to Exchange Act Rule 0-11 (set forth the amount on which the filing fee is calculated and state how it was determined):

 

 (4) Proposed maximum aggregate value of transaction:

 

 (5) Total fee paid:

 

¨ Fee paid previously with preliminary materials.

 

¨ Check box if any part of the fee is offset as provided by Exchange Act Rule 0-11(a)(2) and identify the filing for which the offsetting fee was paid previously. Identify the previous filing by registration statement number, or the Form or Schedule and the date of its filing.

 

 (1) Amount Previously Paid:

 

 (2) Form, Schedule or Registration Statement No.:

 

 (3) Filing Party:

 

 (4) Date Filed:

 

Notes:

 

Reg. (S) 240.14a-101.

SEC 1913 (3-99)




YOUR VOTE IS IMPORTANT

Wisconsin

Power and Light

Company

NOTICEOF 2003 ANNUAL MEETING

PROXY STATEMENTAND

2002 ANNUAL REPORT




 

WISCONSIN POWER AND LIGHT COMPANY

 

ANNUAL MEETING OF SHAREOWNERS

 

DATE:

 

June 5, 2003Wednesday, May 25, 2005

TIME:

 

1:2:00 PM,p.m., Central Daylight Savings Time

LOCATION:

 

Wisconsin Power and Light Company

Seine ConferenceNile Meeting Room (1R 440)

4902 North Biltmore Lane

Madison, Wis.

 

SHAREOWNER INFORMATION NUMBERS

 

LOCAL CALLS (Madison, Wis., Area)area)

 

608-458-3110(608) 458-3110

TOLL FREE NUMBER

 

800-356-5343(800) 356-5343

 

 


 

Wisconsin Power and Light Company

4902 North Biltmore Lane

P. O. Box 2568

Madison, WI 53701-2568

Phone: 608.458.3110

 

NOTICE OF ANNUAL MEETING AND PROXY STATEMENT

 

Dear Wisconsin Power and Light Company Shareowner:

 

On Thursday, June 5, 2003,Wednesday, May 25, 2005, Wisconsin Power and Light Company (the “Company”) will hold its 20032005 Annual Meeting of Shareowners at the officeoffices of Alliant Energy Corporation, 4902 North Biltmore Lane, SeineNile Meeting Room, Madison, Wis. The meeting will begin at 1:2:00 p.m. Central Daylight Savings Time.

 

Only the sole common stock shareowner, Alliant Energy Corporation, and preferred shareowners who owned stock at the close of business on April 15, 2003,5, 2005, may vote at this meeting. All shareowners are requested to be present at the meeting in person or by proxy so that a quorum may be ensured. At the meeting, the Company’s shareowners will:

 

 1.Elect three Directorsdirectors for terms expiring at the 20062008 Annual Meeting of Shareowners; and

 

 2.Attend to any other business properly presented at the meeting.

 

The Board of Directors of the Company presently knows of no other business to come before the meeting.

 

Please sign and return the enclosed proxy card as soon as possible.

 

The Company’s 20022004 Annual Report appears as Appendix BA to this proxy statement. The proxy statement and Annual Report have been combined into a single document to improve the effectiveness of our financial communication and to reduce costs, although the Annual Report does not constitute a part of the proxy statement.

 

Any Wisconsin Power and Light Company preferred shareowner who desires to receive a copy of the Alliant Energy Corporation 20022004 Annual Report, to ShareownersNotice of Annual Meeting and Proxy Statement may do so by calling the Company’s Shareowner Services Department at the Shareowner Information Numbersshareowner information numbers shown at the front of this proxy statement or writing to the Company at the address shown above.

 

By Order of the Board of Directors,

By Order of the Board of Directors,

LOGO

F. J. Buri

Corporate Secretary

 

Dated and mailed on or about April 22, 200313, 2005.


 

TABLE OF CONTENTS

 

Questions and Answers

 

  1

Election of Directors

 

4

  3

Meetings and Committees of the Board

 

7

  5

Corporate Governance

  7

Compensation of Directors

 

8

Ownership of Voting Securities

 

9

Compensation of Executive Officers

 

10

Stock Options

 

11

Long-Term Incentive Awards

 

12

13

Certain Agreements

 

13

Retirement and Employee Benefit Plans

 

14

Report of the Compensation and Personnel Committee on Executive Compensation

 

17

Report of the Audit Committee

 

20

21

Section 16(a) Beneficial Ownership Reporting Compliance

 

21

22

Appendix A – Audit Committee Charter

A-1

Appendix B – Wisconsin Power and Light Company Annual Report

 

B-1

 


QUESTIONS AND ANSWERS

 

1.  Q:Q:Why am I receiving these materials?
A:The Board of Directors of Wisconsin Power and Light Company (the “Company”) is providing these proxy materials to you in connection with the Company’s Annual Meeting of Shareowners (the “Annual Meeting”), which will take place on Thursday, June 5, 2003.Wednesday, May 25, 2005. As a shareowner, you are invited to attend the Annual Meeting and are entitled to and requested to vote on the mattersproposal described in this proxy statement.

 

2.  Q:Q:What is Wisconsin Power and Light Company and how does it relate to Alliant Energy Corporation?
A:The Company is a subsidiary of Alliant Energy Corporation (“AEC”), a public utility holding company whose other primary first tier subsidiaries includeare Interstate Power and Light Company (“IP&L”), Alliant Energy Resources, Inc. (“AER”Resources”) and Alliant Energy Corporate Services, Inc. (“Alliant Energy Corporate Services”).

 

3.  Q:Q:Who is entitled to vote at the Annual Meeting?
A:Only shareowners of record at the close of business on April 15, 2003,5, 2005 are entitled to vote at the Annual Meeting. As of the record date, 13,236,601 shares of common stock (owned solely by AEC) and 1,049,225 shares of preferred stock, in seven series (representing 599,630 votes), were issued and outstanding. Each share of Company common stock and Company preferred stock, with the exception of the 6.50% Series, is entitled to one vote per share. The 6.50% Seriesseries of Company preferred stock is entitled to ¼ vote per share.

 

4.  Q:Q:What may I vote on at the Annual Meeting?
A:You may vote on the election of three nominees to serve on the Company’s Board of Directors for terms expiring at the 2008 Annual Meeting of Shareowners in the year 2006.Shareowners.

 

5.  Q:Q:How does the Board of Directors recommend I vote?
A:The Board of Directors recommends that you vote your shares FOR each of the listed Directordirector nominees.

 

6.  Q:Q:How can I vote my shares?
A:You may vote either in person at the Annual Meeting or by appointing a proxy. If you desire to appoint a proxy, then sign and date each proxy card you receive and return it in the envelope provided. Appointing a proxy will not affect your right to vote your shares if you attend the Annual Meeting and desire to vote in person.

 

7.  Q:Q:How are votes counted?
A:In the election of Directors,directors, you may vote FOR all of the Directordirector nominees or you may WITHHOLD your vote may be WITHHELD with respect to one or more nominees. If you return your signed proxy card but do not mark the boxes showing how you wish to vote, your shares will be voted FOR all listed Directordirector nominees.

 

8.  Q:Q:Can I change my vote?
A:You have the right to revoke your proxy at any time before the Annual Meeting by:

 

·Providing written notice to the Corporate Secretary of the Company and voting in person at the Annual Meeting; or
·Appointing a new proxy prior to the start of the Annual Meeting.
Providing written notice to the Corporate Secretary of the Company and voting in person at the Annual Meeting; or
Appointing a new proxy prior to the start of the Annual Meeting.

 

Attendance at the Annual Meeting will not cause your previously appointed proxy to be revoked unless you specifically so request in writing.

 

9.  Q:Q:What does it mean if I get more than one proxy card?
A:If your shares are registered differently and are in more than one account, then you will receive more than one proxy card. Be sure to vote all of your accounts to ensure that all of your shares are voted. The Company encourages you to have all accounts registered in the same name and address (whenever possible). You can accomplish this by contacting the Company’s Shareowner Services Department at the Shareowner Information Numbersshareowner information numbers shown at the front of this proxy statement.

 

10.  Q:Q:Who may attend the Annual Meeting?
A:All shareowners who owned shares of the Company’s common and preferred stock on April 15, 2003,5, 2005, may attend the Annual Meeting. You may indicate on the enclosed proxy card your intention to attend the Annual Meeting and return it with your signed proxy.

 

11.  Q:Q:How will voting on any other business be conducted?
A:The Board of Directors of the Company does not know of any business to be considered at the 2003 Annual Meeting other than the election of three Directors.directors. If any other business is properly presented at the Annual Meeting, your signed proxy card gives authority to William D. Harvey,Barbara J. Swan, the Company’s President, and F. J. Buri, the Company’s Corporate Secretary, authority to vote on such matters inat their discretion.

 

12.  Q:Q:Where and when will I be able to find the results of the voting?
A:The results of the voting will be announced at the Annual Meeting. You may also call ourthe Company’s Shareowner Services Department at the Shareowner Information Numbersshareowner information numbers shown at the front of this proxy statement for the results. The Company will also publish the final results in its Quarterly Report on Form 10-Q for the second quarter of 20032005 to be filed with the Securities and Exchange Commission (“SEC”).

13.  Q:Q:When are shareowner proposals for the 20032006 Annual Meeting due?
A:All shareowner proposals to be considered for inclusion in the Company’s proxy statement for the 20042006 Annual Meeting must be received at the principal office of the Company by Dec. 23, 2003.14, 2005. In addition, any shareowner who intends to present a proposal from the floor at the 20042006 Annual Meeting must submit the proposal in writing to the Corporate Secretary of the Company no later than March 8, 2004.Feb. 27, 2006.

 

14.  Q:Q:Who are the independent auditors of the Company and how are they appointed?
A:Deloitte & Touche LLP audited the financial statements of the Company for the year ended Dec. 31, 2002, and re-audited the financial statements of the Company for the years ended Dec. 31, 2001, and Dec 31, 2000.2004. Representatives of Deloitte & Touche LLP are not expected to be present at the meeting. The Audit Committee of the Board of Directors expects to appoint the Company’s independent auditors for 20032005 later in the year.

 

On June 12, 2002, the Board of Directors of the Company, upon the recommendation of the Audit Committee, dismissed Arthur Andersen LLP as the Company’s independent auditors and contracted with Deloitte & Touche LLP to serve as its independent auditors for 2002. Arthur Andersen’s reports on the Company’s consolidated financial statements for the years ended Dec. 31, 2002, and Dec. 31, 2000, did not contain an adverse opinion, disclaimer of opinion or qualification or modification as to uncertainty, audit scope or accounting principles. During the years ended Dec. 31, 2001, and Dec. 31, 2000, and the subsequent interim period, there were no disagreements between the Company and Arthur Andersen on any matter of accounting principles or practices, financial statement disclosure or auditing scope or procedures, which disagreements, if not resolved to the satisfaction of the accounting firm, would have caused it to make a reference to the subject matter of such disagreements in connection with its reports.

15.  Q:Q:Who will bear the cost of soliciting proxies for the Annual Meeting?Meeting and how will these proxies be solicited?
A:The Company will pay the cost of preparing, assembling, printing, mailing and distributing these proxy materials. In addition to the mailing of these proxy materials, the solicitation of proxies or votes may be made in person, by telephone or by electronic communication by the Company’s officers and employees who will not receive any additional compensation for these solicitation activities. The Company will pay to banks, brokers, nominees and other fiduciaries their reasonable charges and expenses incurred in forwarding the proxy materials to their principals.

 

16.  Q.Q:How can I obtain a copy of the Company’s Annual Report on Form 10-K?
A:The Company will furnish without charge, to each shareowner who is entitled to vote at the Annual Meeting and who makes a written request, a copy of the Company’s Annual Report on Form 10-K (without exhibits) as filed with the SEC. Written requests for the Form 10-K should be mailed to the Corporate Secretary of the Company at the address on the first page of this proxy statement.

 

17.  Q:Q:If more than one shareowner lives in my household, how can I obtain an extra copy of thisthe Company’s 2004 Annual Report and proxy statement and Annual Report?statement?
A:Pursuant to the rules of the SEC, services that deliver the Company’s communications to shareowners that hold their stock through a bank, broker or other holder of record may deliver to multiple shareowners sharing the same address a single copy of the Company’s 20022004 Annual Report and proxy statement. Upon written or oral request, the Company will delivermail a separate copy of the 20022004 Annual Report and proxy statement to any shareowner at a shared address to which a single copy of eachthe document was delivered. You may notify the Company of your request by calling or writing the Company’s Shareowner Services Department at the Shareowner Information Numbersshareowner information numbers shown at the front of this proxy statement or at the address of the Company.Company shown on the Notice of Annual Meeting.

ELECTION OF DIRECTORS

 

Three DirectorsAt the Annual Meeting, three directors will be elected this year for terms expiring in 2006.2008. The nominees for election as recommended by the Nominating and Governance Committee ofand selected by the Company’s Board of Directors are: ErrollWilliam D. Harvey, Singleton B. Davis, Jr., Robert W. SchlutzMcAllister and Wayne H. Stoppelmoor.Anthony R. Weiler. Each of the nominees is currently serving as a Directordirector of the Company. Each person elected as Directora director will serve until the Annual Meeting of Shareowners of the Company in 20062008, or until his or her successor has been duly elected and qualified.

 

Directors will be elected by a plurality of the votes cast at the meeting (assuming a quorum is present). Consequently, any shares not voted at the meeting whether by abstentionor otherwise, will have no effect on the election of Directors.directors. The proxies solicited may be voted for a substitute nominee or nominees if any of the nominees are unable to serve, or for good reason will not serve, a contingency not now anticipated.

 

Brief biographies of the Directordirector nominees and continuing Directorsdirectors follow. These biographies include their ageages (as of Dec. 31, 2002)2004), an account of their business experience and the names of publicly held and certain other corporations of which they are also Directors.directors. Except as otherwise indicated, each nominee and continuing Directordirector has been engaged in his or her present occupation for at least the past five years.

 

NOMINEES

 

LOGO

LOGO  

ERROLL B. DAVIS, JR.WILLIAM D. HARVEY

Age 55

  

Director Since 1984since 2005

Nominated term expires in 2008

  

Age 58

Nominated Term Expires in 2006

Mr. Davis joined the Company in 1978 and served as President of the Company from 1987 until 1998. He was elected Chief Executive Officer of the Company in 1988. Mr. Davis has been President and Chief Executive Officer of AEC since 1990. He was elected Chairman of the Board of the Company and AEC in 2000. Mr. Davis has also served as Chief Executive Officer of AER and IP&L (or predecessor companies) since 1998. He is a member of the Boards of Directors of BP p.l.c.; PPG Industries, Inc.; Electric Power Research Institute; and the Edison Electric Institute, where he also serves as Chairman. Mr. DavisHarvey has served as a Director of AEC since 1982, of AER since 1988 and of IP&L (or predecessor companies) since 1998.

LOGO

ROBERT W. SCHLUTZ

Director Since 1998

Age 66

Nominated Term Expires in 2006

Mr. Schlutz is President of Schlutz Enterprises, a diversified farming and retailing business in Columbus Junction, Iowa. Mr. Schlutz has served as a Director of IP&L (or predecessor companies) since 1989 and of AEC and AER since 1998. Mr. Schlutz is Chairperson of the Environmental, Nuclear, Health and Safety Committee.

LOGO

WAYNE H. STOPPELMOOR

Director Since 1998

Age 68

Nominated Term Expires in 2006

Mr. Stoppelmoor served as Vice Chairman of the Board of the Company and AEC from April 1998 until April 2000. Prior to 1998, he was Chairman, President and Chief Executive Officer of Interstate Power Company, a predecessor to IP&L. He retired as Chief Executive Officer of Interstate Power Company in 1997. Mr. Stoppelmoor has served as a Director of IP&L (or predecessor companies) since 1986 and of AEC and AER since 1998.

The Board of Directors unanimously recommends a vote FOR all nominees for election as Directors.

CONTINUING DIRECTORS


LOGO

ALAN B. ARENDS

Director Since 1998

Age 69

Term Expires in 2005

Mr. Arends is Chairman of the Board of Directors of Alliance Benefit Group Financial Services Corp., Albert Lea, Minn., an employee benefits company that he founded in 1983. He has served as a Director of IP&L (or predecessor companies) since 1993 and of AEC and AER since 1998.

LOGO

JACK B. EVANS

Director Since 2000

Age 54

Term Expires in 2004

Mr. Evans is a Director and since 1996 has served as President of The Hall-Perrine Foundation, a private philanthropic corporation in Cedar Rapids, Iowa. Previously, Mr. Evans was President and Chief Operating Officer of SCI Financial Group, Inc., a regional financial services firm. Mr. Evans is a DirectorAEC and Chief Operating Officer of Gazette Communications,IP&L, the Federal Reserve BankCompany and Resources since January 2004, and President of ChicagoResources since January 2005. He previously served as Executive Vice President – Generation for AEC, IP&L and Nuveen Institutional Advisory Corp.,Resources and President of the Company from 1998 to January 2004. He also previously served as the Company’s Senior Vice President from 1993 to 1998, Vice President and General Counsel from 1990 to 1993 and Vice ChairmanPresident and Associate General Counsel from 1986 to 1990. He was recommended as a Director of United Firenominee by the Nominating and Casualty Company. Mr. Evans has servedGovernance Committee and appointed as a Director of the Company, AEC, IP&L, (or predecessor companies) and AER since 2000. Mr. Evans is Chairperson ofResources in January 2005 in connection with the Audit Committee.

LOGO

KATHARINE C. LYALL

Director Since 1986

Company’s succession plan.

Age 61

Term Expires in 2005

Ms. Lyall is President of the University of Wisconsin System in Madison, Wis. In addition to her administrative position, she is a professor of economics at the University of Wisconsin-Madison. She serves on the Boards of Directors of the Kemper National Insurance Companies, M&I Corporation and the Carnegie Foundation for the Advancement of Teaching. Ms. Lyall has served as a Director of AEC and AER since 1994 and of IP&L (or predecessor companies) since 1998.

LOGO

LOGO
  

SINGLETON B. McALLISTERMCALLISTER

Age 52

  

Director Sincesince 2001

Nominated term expires in 2008

  

Age 50

Term Expires in 2005

Ms. McAllister ishas been a partner within the public law and policy strategies group of the Washington, D.C. law firm office of Sonnenschein, Nath & Rosenthal, LLP since 2003. She was previously a partner at Patton Boggs LLP, a Washington, D.C.-basedD.C. law firm.firm, from 2001 to 2003. From 1996 until early 2001, Ms. McAllister was General Counsel for the United States Agency for International Development. She was also a partner at Reed, Smith, Shaw and McClay where she specialized in government relations and corporate law. She serves on the Board of Directors of United Rentals, Inc. Ms. McAllister has served as a Director of AEC, IP&L (or predecessor companies) and AER since 2001.

LOGO

DAVID A. PERDUE

Director Since 2001

Age 53

Term Expires in 2004

Mr. Perdue was named Chief Executive Officer and a Director of Dollar General Corporation, a retail sales organization headquartered in Goodlettsville, Tenn., in April 2003. Prior to this position, he served as Chairman and Chief Executive Officer of Pillowtex Corporation, a textile manufacturing company located in Kannapolis, N. C., from July 2002 to March 2003. Prior to this position, he was President and Chief Executive Officer of the Reebok Brand for Reebok International Limited. Prior to joining Reebok in 1998, he was Senior Vice President of Operations at Haggar, Inc. Mr. Perdue has served as a Director of AEC, IP&L (or predecessor companies) and AER since 2001.

LOGO

JUDITH D. PYLE

Director Since 1994

Age 59

Term Expires in 2004

Ms. Pyle is Vice Chair of The Pyle Group, a financial services company located in Madison, Wis. Prior to assuming her current position, Ms. Pyle served as Vice Chairman and Senior Vice President of Corporate Marketing of Rayovac Corporation (a battery and lighting products manufacturer), Madison, Wis. In addition, Ms. Pyle is Vice Chairman of Georgette Klinger, Inc., and a Director of Uniek, Inc. Ms. Pyle has served as a Director of AEC and AERResources since 1992 and of IP&L (or predecessor companies) since 1998.2001. Ms. PyleMcAllister is Chairperson of the Compensation and Personnel Committee.

LOGO

LOGO  

ANTHONY R. WEILER

Age 68

  

Director Sincesince 1998

Nominated term expires in 2008

  

Age 66

Term Expires in 2005

Mr. Weiler is Chairman and President of A. R. Weiler Co. LLC, a consultantconsulting firm for several home furnishings organizations. Prior to assuming his current position, Mr. Weiler had beenHe was previously a Senior Vice President forof Heilig-Meyers Company, a national furniture retailer headquartered in Richmond, Va. He is a Director of the Retail Home Furnishings Foundation.
Mr. Weiler has served as a Director of IP&L (or predecessor companies) since 1979 and of AEC and AERResources since 1998. Mr. Weiler is Chairperson of the Nominating and Governance Committee.Committee and the Lead Independent Director.

The Board of Directors unanimously recommends a vote FOR all nominees for election as directors.

CONTINUING DIRECTORS

LOGO

ERROLL B. DAVIS, JR.

Age 60

Director since 1984

Term expires in 2006

Mr. Davis joined the Company in 1978 and served as President of the Company from 1987 until 1998. He was elected Chief Executive Officer of the Company in 1988. Mr. Davis has served as Chairman of the Board of the Company and AEC since 2000 and as Chief Executive Officer of AEC since 1990. He also served as President of AEC from 1990 through 2003. He has also served as Chief Executive Officer of Resources and IP&L (or predecessor companies) since 1998. He is a member of the Boards of Directors of BP p.l.c.; PPG Industries, Inc.; Union Pacific Corporation; Electric Power Research Institute; the Edison Electric Institute; and the U. S. Olympic Committee. Mr. Davis has served as a Director of AEC since 1982, of Resources since 1988 and of IP&L (or predecessor companies) since 1998.
LOGO

MICHAEL L. BENNETT

Age 51

Director since 2003

Term expires in 2007

Mr. Bennett has served as President and Chief Executive Officer of Terra Industries Inc., an international producer of nitrogen products and methanol ingredients headquartered in Sioux City, Iowa, since April 2001. From 1997 to 2001, he was Executive Vice President and Chief Operating Officer of Terra Industries Inc. He also serves as Chairman of the Board for Terra Nitrogen Corp., a subsidiary of Terra Industries Inc. Mr. Bennett has served as a Director of AEC, IP&L and Resources since 2003. Mr. Bennett is Chairperson of the Audit Committee.

LOGO

ANN K. NEWHALL

Age 53

Director since 2003

Term expires in 2006

Ms. Newhall is Executive Vice President, Chief Operating Officer, Secretary and a Director of Rural Cellular Corporation, a cellular communications corporation located in Alexandria, Minn. She has served as Executive Vice President and Chief Operating Officer since August 2000, as Secretary since February 2000 and as a Director since August 1999. Prior to assuming her current positions, she served as Senior Vice President and General Counsel from 1999 to 2000. She was previously a shareholder and President of the Moss & Barnett law firm in Minneapolis, Minn. Ms. Newhall has served as a Director of AEC, IP&L and Resources since 2003.
LOGO

DAVID A. PERDUE

Age 55

Director since 2001

Term expires in 2007

Mr. Perdue is Chairman of the Board and Chief Executive Officer of Dollar General Corporation, a sales organization headquartered in Goodlettsville, Tenn. He was named Chief Executive Officer and a Director in April 2003 and elected Chairman of the Board in June 2003. From July 2002 to March 2003, he was Chairman and Chief Executive Officer of Pillowtex Corporation, a textile manufacturing company located in Kannapolis, N.C. Pillowtex filed for bankruptcy in July 2003 after emerging from a previous bankruptcy in May 2002. From 1998 to 2002, he was employed by Reebok International Limited, where he served as President of the Reebok Brand from 2000 to 2002. Mr. Perdue has served as a Director of AEC, IP&L (or predecessor companies) and Resources since 2001.
LOGO

JUDITH D. PYLE

Age 61

Director since 1994

Term expires in 2007

Ms. Pyle is President of Judith Dion Pyle and Associates, a financial services company located in Middleton, Wis. Prior to assuming her current position in 2003, she served as Vice Chair of The Pyle Group, a financial services company located in Madison, Wis. She previously served as Vice Chair and Senior Vice President of Corporate Marketing of Rayovac Corporation, a battery and lighting products manufacturer located in Madison, Wis. In addition, Ms. Pyle is a Director of Uniek, Inc. Ms. Pyle has served as a Director of AEC and Resources since 1992 and of IP&L (or predecessor companies) since 1998.

LOGO

ROBERT W. SCHLUTZ

Age 68

Director since 1998

Term expires in 2006

Mr. Schlutz is President of Schlutz Enterprises, Inc., a diversified farming and retailing business in Columbus Junction, Iowa. Mr. Schlutz has served as a Director of IP&L (or predecessor companies) since 1989, and of AEC and Resources since 1998. Mr. Schlutz is Chairperson of the Environmental, Nuclear, Health and Safety Committee.

MEETINGS AND COMMITTEES OF THE BOARD

 

The full Board of Directors has standing Audit; Compensation and Personnel; Nominating and Governance; Environmental, Nuclear, Health and Safety; Nominating and Governance; and Capital Approval Committees. The Board of Directors has adopted formal written charters for each of the Audit, Compensation and Personnel, and Nominating and Governance Committees, which are available, free of charge, on AEC’s Web site atwww.alliantenergy.com/investors under the “Corporate Governance” caption or in print to any shareowner who requests them from the Company’s Corporate Secretary. The following is a description of each of these committees:

 

Audit Committee

The Audit Committee held fourseven joint meetings (the Company, AEC, IPLIP&L and AER)Resources) in 2002.2004. The Committee currently consists of J. B. EvansM. L. Bennett (Chair), A. B. Arends, K. C. Lyall, S. B. McAllister, A. K. Newhall and D. A. Perdue. Each of the members of the Committee is independent as defined by the New York Stock Exchange (“NYSE”) listing standards and SEC rules. The Board of Directors has determined that Mr. Bennett and one additional Audit Committee member qualify as “audit committee financial experts” as defined by SEC rules. The Audit Committee is responsible for assisting Board oversight of: (1) the integrity of the Company’s financial statements,statements; (2) the Company’s compliance with legal and regulatory requirements,requirements; (3) the independent auditors’ qualifications and independence,independence; and (4) the performance of the Company’s internal audit function and independent auditors. The Audit Committee is also directly responsible for the appointment, retention, termination, compensation and oversight of the Company’s independent auditors.

 

Compensation and Personnel Committee

The Compensation and Personnel Committee held sixfour joint meetings in 2002.2004. The Committee currently consists of S. B. McAllister (Chair), M. L. Bennett, D. A. Perdue and J. D. PylePyle. Each of the members of the Committee is independent as defined by the NYSE listing standards. This Committee reviews and approves corporate goals and objectives relevant to Chief Executive Officer (“CEO”) compensation, evaluates the CEO’s performance and determines and approves as a committee, or together with the other independent directors, the CEO’s compensation level based on the evaluation of the CEO’s performance. In addition, the Committee has responsibilities with respect to the Company’s executive compensation and incentive programs and management development programs.

Nominating and Governance Committee

The Nominating and Governance Committee held three joint meetings in 2004. The Committee currently consists of A. R. Weiler (Chair), K. C. Lyall, A. B. Arends, J. B. EvansK. Newhall and D. A. Perdue.R. W. Schlutz. Each of the members of the Committee is independent as defined by the NYSE listing standards. This Committee sets executive compensation policy, administersCommittee’s responsibilities are to: (1) identify individuals qualified to become Board members, consistent with the AEC Long-Term Incentive Program, reviewscriteria approved by the performance ofBoard, and approves salariesto recommend nominees for certain officersdirectorships to be filled by the Board or shareowners; (2) identify and certain other management personnel, reviewsrecommend Board members qualified to serve on Board committees; (3) develop and recommendsrecommend to the Board a set of corporate governance principles; (4) oversee the evaluation of the Board and the Company’s management; and (5) advise the Board with respect to other matters relating to corporate governance of the Company.

In making recommendations to the Company’s Board of Directors of nominees to serve as directors, the Nominating and Governance Committee will examine each director nominee on a case-by-case basis regardless of who recommended the nominee and take into account all factors it considers appropriate, which may include strength of character, mature judgment, career specialization, relevant technical skills or financial acumen, diversity of viewpoint and industry knowledge. However, the Committee believes that, to be recommended as a director nominee, each candidate must:

display the highest personal and professional ethics, integrity and values.

have the ability to exercise sound business judgment.

be highly accomplished in his or her respective field, with superior credentials and recognition and broad experience at the administrative and/or policy-making level in business, government, education, technology or public interest.

have relevant expertise and experience, and be able to offer advice and guidance to the CEO based on that expertise and experience.

be independent of any particular constituency, be able to represent all shareowners of the Company and be committed to enhancing long-term shareowner value.

have sufficient time available to devote to activities of the Board of Directors and to enhance his or her knowledge of the Company’s business.

The Committee also believes the following qualities or skills are necessary for one or more directors to possess:

At least one director should have the requisite experience and expertise to be designated as an “audit committee financial expert” as defined by the applicable rules of the SEC.

Directors generally should be active or former senior executive officers of public companies or leaders of major and/or complex organizations, including commercial, governmental, educational and other non-profit institutions.

Directors should be selected so that the Board of Directors is a diverse body, with diversity reflecting age, gender, race and political experience.

The Nominating and Governance Committee will consider nominees recommended by shareowners in accordance with the Company’s Nominating and Governance Committee Charter and the Corporate Governance Principles.

The Company and the Committee maintain a file of recommended potential director nominees which is reviewed at the time a search for a new or changed employee benefit plans, reviews majordirector needs to be performed. To assist the Committee in its identification of qualified director candidates, the Committee may engage an outside search firm.

Any shareowner wishing to make a recommendation should write to the Corporate Secretary of the Company and include appropriate biographical information concerning each proposed nominee. The Corporate Secretary will forward all recommendations to the Committee. The Company’s Bylaws also set forth certain requirements for shareowners wishing to nominate director candidates directly for consideration by shareowners. These provisions require such nominations to be made pursuant to timely notice (as specified in the Bylaws) in writing to the Corporate Secretary of negotiated employment contracts, and reviews human resource development programs.the Company.

 

Environmental, Nuclear, Health and Safety Committee

The Environmental, Nuclear, Health and Safety Committee held threetwo joint meetings in 2002.2004. The Committee currently consists of R. W. Schlutz (Chair), J. L. Hanes,K. C. Lyall, J. D. Pyle and A. R. Weiler. The Committee’s responsibilities are to review environmental policy and planning issues of interest to the Company, including matters involving the Company before environmental regulatory agencies and compliance with air, water and waste regulations. In addition, the Committee reviews policies and operating issues related to the Company’s nuclear generating station investments, including planning and funding for decommissioning of the plants. The Committee also reviews health and safety relatedsafety-related policies, activities and operational issues as they affect employees, customers and the general public.

 

Nominating and Governance Committee

The Nominating and Governance Committee held two joint meetings in 2002. The Committee currently consists of A. R. Weiler (Chair), J. L. Hanes, K. C. Lyall, S. B. McAllister and R. W. Schlutz. This Committee’s responsibilities include recommending and nominating new members of the Board, recommending committee assignments and committee chairpersons, evaluating overall Board effectiveness and compensation, preparing an annual report on Chief Executive Officer effectiveness, and considering and developing recommendations to the Board of Directors on other corporate governance issues. In nominating persons for election to the Board, the Nominating and Governance Committee will consider nominees recommended by shareowners. Any shareowner wishing to make a recommendation should write to the Corporate Secretary of the Company, who will forward all recommendations to the Committee. The Company’s Bylaws also permit shareowner nominations of candidates for election as Directors. These provisions require such nominations to be made pursuant to timely notice (as specified in the Bylaws) in writing to the Corporate Secretary of the Company.

Capital Approval Committee

The Capital Approval Committee held no meetings in 2002.2004. The Committee currently consists of J. B. Evans, J.M. L. Bennett, D. PyleA. Perdue and A. R. Weiler. Mr. Davis is the Chair and a non-voting member of this Committee. The purpose of this Committee is the evaluation ofto evaluate certain investment proposals where (a)(1) an iterative bidding process is required, and/or (b)(2) the required timelines for such a proposal would not permit the proposal to be brought before a regular meeting of the Board of Directors and/or a special meeting of the full Board of Directors is not practical or merited.

 

The Board of Directors held seven joint meetings during 2002.2004. Each Directordirector attended at least 85%75% of the aggregate number of meetings of the Board and Board committees on which he or she served.

 

The Board and each Board committee conductsconduct performance evaluations annually to determine itstheir effectiveness and suggestssuggest improvements for consideration and implementation. In addition, the Compensation and Personnel Committee evaluates Mr. Davis’ performance as CEO on an annual basis.

Board members are not expected to attend the Company’s Annual Meeting. In 2004, none of the Board members were present for the Company’s Annual Meeting.

CORPORATE GOVERNANCE

Corporate Governance Principles

The Board of Directors has adopted Corporate Governance Principles that, in conjunction with the Board committee charters, establish processes and procedures to help ensure effective and responsive governance by the Board. The Corporate Governance Principles are available, free of charge, on AEC’s Web site atwww.alliantenergy.com/investors under the “Corporate Governance” caption or in print to any shareowner who requests them from the Company’s Corporate Secretary.

The Board of Directors has adopted certain categorical standards of independence to assist it in making determinations of director independence under the NYSE listing standards. Under these categorical standards, the following relationships that currently exist or that have existed, including during the preceding three years, willnot be considered to be material relationships that would impair a director’s independence:

A family member of the director is or was an employee (other than an executive officer) of the Company.

A director, or a family member of the director, receives or received less than $100,000 during any twelve-month period in direct compensation from the Company, other than director and committee fees and pension or other forms of deferred compensation for prior service (provided that such compensation is not contingent in any way on continued service with the Company).

A director, or a family member of the director, is a former partner or employee of the Company’s internal or external auditor but did not personally work on the Company’s audit within the last three years; or a family member of a director is employed by an internal or external auditor of the Company but does not participate in such auditor’s audit, assurance or tax compliance practice.

A director, or a family member of the director, is or was employed other than as an executive officer of another company where any of the Company’s present executives serve on that company’s compensation committee.

A director is or was an executive officer, employee or director of, or has or had any other relationship (including through a family member) with, another company, that makes payments (other than contributions to tax exempt organizations) to, or receives payments from, the Company for property or services in an amount which, in any of the last three fiscal years, does not exceed the greater of $1 million or 2% of such other company’s consolidated gross revenues.

A director is or was an executive officer, employee or director of, or has or had any other relationship (including through a family member) with, a tax exempt organization to which the Company’s discretionary charitable contributions in any single fiscal year do not exceed the greater of $1 million or 2% of such organization’s consolidated gross revenues.

In addition, any relationship that a director (or an “immediate family member” of the director) previously had that constituted an automatic bar to independence under NYSE listing standards will not be considered to be a material relationship that would impair a director’s independence three years after the end of such relationship in accordance with NYSE listing standards.

Based on these standards, the Board of Directors has affirmatively determined by resolution that each of the Company’s directors (other than Mr. Davis, the Company’s Chairman and CEO, and Mr. Harvey, the Company’s Chief Operating Officer (“COO”)) has no material relationship with the Company and, therefore, is independent in accordance with the NYSE listing standards. The Board of Directors will regularly review the continuing independence of the directors.

The Corporate Governance Principles provide that at least 75% of the members of the Board of Directors must be independent directors under the NYSE listing standards. The Audit, Compensation and Personnel, and Nominating and Governance Committees must consist of all independent directors.

Lead Independent Director; Executive Sessions

The Corporate Governance Principles provide that the chairperson of the Nominating and Governance Committee shall be the designated “Lead Independent Director” and will preside as the chair at meetings or executive sessions of the independent directors. As the Chairperson of the Nominating and Governance Committee, Mr. Weiler is currently designated as the Lead Independent Director. At every regular in-person meeting of the Board of Directors, the independent directors meet in executive session with no member of Company management present.

Communication with Directors

Shareowners and other interested parties may communicate with the full Board, evaluate Mr. Davis’ performancenon-management directors as a group or individual directors, including the Lead Independent Director, by providing such communication in writing to the Company’s Corporate Secretary, who will post such communications directly to the Company’s Board of Directors’ Web site.

Ethical and Legal Compliance Policy

The Company has adopted a Code of Ethics that applies to all employees, including its CEO, COO, Chief ExecutiveFinancial Officer and Chief Accounting Officer, as well as its Board of Directors. The Company makes its Code of Ethics available, free of charge, on an annual basis.

AEC’s Web site atwww.alliantenergy.com/investors under the “Corporate Governance” caption or in print to any shareowner who requests it from the Company’s Corporate Secretary. The Company intends to satisfy the disclosure requirements under Item 5.05 of Form 8-K regarding amendments to, or waivers from, the Code of Ethics by posting such information on its Web site address stated above under the “Corporate Governance” caption.

COMPENSATION OF DIRECTORS

 

No retainer fees are paid to Mr. Davis or Mr. Harvey for histheir service on the Company’s Board of Directors. In 2002,2004, all other Directorsdirectors (the “non-employee Directors”directors”), each of whom served on the Boards of the Company, AEC, IP&L and AER,Resources, received an annual retainer for service on all four Boards consisting of $30,000$70,000 in cash. Also, in 2004, the Chairperson of the Audit Committee received an additional $7,500 cash retainer and 1,000the Chairpersons of the Compensation and Personnel, Nominating and Governance, and Environmental, Nuclear, Health, and Safety Committees received an additional $5,000 cash retainer. Travel expenses incurred by the Directors are paid for each meeting attended.

In 2005, the non-employee directors will each receive a cash retainer of $85,000. In 2005, the Chairperson of the Audit Committee will receive an additional $10,000 cash retainer; the Chairpersons of the Compensation and Personnel, Nominating and Governance, and Environmental, Nuclear, Health, and Safety Committees will each receive an additional $5,000 cash retainer; other members of the Audit Committee will each receive an additional $3,500 cash retainer; and the Lead Independent Director will receive an additional $15,000 cash retainer.

Each director is encouraged to voluntarily elect to use not less than 50% of his or her cash retainer to purchase shares of AEC common stock pursuant to AEC’s Shareowner Direct Plan or to defer such amount through the AEC stock account in the AEC Director’s Deferred Compensation Plan. Travel expenses are paid for each meeting day attended.

 

Director’s Deferred Compensation Plan

Under the AEC Director’s Deferred Compensation Plan, Directorsdirectors may elect to defer all or part of their retainer fee. Amounts deposited to a Deferred Compensation Interest Account receive an annual return based on the A-Utility Bond Rate with a minimum return no less than the prime interest rate published inThe Wall Street Journal.Journal, provided that the return may not be greater than 12% or less than 6%. Amounts deposited to anthe AEC Stock Account whether the cash portion or the stock portion of the Director’s compensation, are treated as though invested in the common stock of AEC and will be credited with dividends, which will be treated as if reinvested. Annually, the DirectorThe director may elect that the AEC Deferred Compensation Account will be paid in a lump sum or in annual installments for up to 10 years beginning in the year of or one, two or three tax yearyears after retirement or resignation from the Board.Board of Directors of AEC.

 

Director’s Charitable Award Program

AEC maintains a Director’s Charitable Award Program for thecertain members of its Board of Directors beginning after three years of service. The participants in this Program currently are E. B. Davis, K. C. Lyall, D. A. Perdue, J. D. Pyle and A. R. Weiler. S. B. McAllister has enrolled in the Program and is expected to become a participant. The purpose of the Program is to recognize the interest of the Company and its Directorsdirectors in supporting worthy institutions, and to enhance the Company’s Director benefit program so that the Company is able to continue to attract and retain Directors of the highest caliber.institutions. Under the Program, when a Directordirector dies, the Company and/or AEC will donate a total of $500,000 to one qualified charitable organization or divide that amount among a maximum of fourfive qualified charitable organizations selected by the individual Director.director. The individual Directordirector derives no financial benefit from the Program. All deductions for charitable contributions are taken by the Company and/or AEC, and the donations are funded by the Company or AEC through life insurance policies on the Directors.directors. Over the life of the Program, all costs of donations and premiums on the life insurancepolicies,insurance policies, including a return of the Company’s or AEC’s cost of funds, will be recovered through life insurance proceeds on the Directors.directors. The Program, over its life, will not result in any material cost to the Company or AEC. The Board of Directors of AEC has terminated this Program for all new directors who join the Board after Jan. 1, 2005.

 

Director’s Life Insurance Program

AEC maintains a split-dollar Director’s Life Insurance Program for non-employee Directors, beginning after three years of service, whichdirectors. The participants in this Program currently include K. C. Lyle, J. D. Pyle and A. R. Weiler. The Program provides a maximum death benefit of $500,000 to each eligible Director.director. Under the split-dollar arrangement, Directorsdirectors are provided a death benefit only and do not have any interest in the cash value of the policies. The Life Insurance Program is structured to pay a portion of the total death benefit to AEC to reimburse AEC for all costs of the program,Program, including a return on its funds. The Life Insurance Program, over its life, will not result in any material cost to AEC. The imputed income allocations reported for each Directordirector in 20022004 under the Director’s Life Insurancethis Program were as follows: A. B. Arends—$50, J. L. Hanes—$50, K. C. Lyall—$448,Lyall — $528, J. D. Pyle—$20, W. H. Stoppelmoor—$948Pyle — $29, and A. R. Weiler—$50.Weiler — $50. In November 2003, the Board of Directors of AEC terminated this insurance benefit for any director not already having the required vesting period of three years of service and for all new directors.

 

Pension Arrangements

Prior to April 1998, Mr. Lee Liu, a Director who will be retiring at AEC’s Annual Meeting on May 28, 2003, participated in the IES Industries Inc. retirement plan, which has been transferred to Alliant Energy Corporate Services. Mr. Liu’s benefits under the plan have been “grandfathered” to reflect the benefit plan formula in effect in April 1998. See “Retirement and Employee Benefit Plans—IES Industries Pension Plan.”

Alliant Energy Corporate Services also maintains a non-qualified Supplemental Retirement Plan (“SRP”) for eligible former officers of IES Industries Inc. Mr. Liu participates in the SRP. The SRP generally provides for payment of supplemental retirement benefits equal to 75% of the officer’s base salary in effect at the date of retirement, reduced by benefits receivable under the qualified retirement plan, for a period not to exceed 15 years following the date of retirement. The SRP also provides for certain death benefits to be paid to the officer’s designated beneficiary and benefits if an officer becomes disabled under the terms of the qualified retirement plan.

OWNERSHIP OF VOTING SECURITIES

 

All of the common stock of the Company is held by AEC. None of the directors or officers of the Company own any shares of the Company’s preferred stock. Listed in the following table are the number of shares of AEC’s common stock beneficially owned by (1) the executive officers listed in the Summary Compensation Table, and(2) all director nominees and Directorsdirectors of AEC and the Company, as well as the number of shares owned by Directorsand (3) all director nominees, directors and executive officers of AEC and the Company as a group as of Feb. 28,2003.28, 2005. The Directorsdirectors and executive officers of AEC and the Company as a group owned 1.8%1.4% of the outstanding shares of AEC common stock on that date. No individual Directordirector or officer owned more than 1% of the outstanding shares of AEC common stock on that date. To the Company’s knowledge, no shareowner beneficially owned 5% or more of AEC’s outstanding common stock as of Dec. 31, 2002.

 

NAME OF BENEFICIAL OWNER


  

SHARES
BENEFICIALLY
OWNED(1)



 

Executive Officers(2)

Thomas L. Aller

Executives101,264(2)(3)

Eliot G. Protsch

210,089(3)

Barbara J. Swan

149,575(3)

Director Nominees

    

William D. Harvey

  

135,155218,536

(3)

Eliot G. ProtschSingleton B. McAllister

  

139,4435,054

(3)

Thomas M. WalkerAnthony R. Weiler

  

91,63917,888

(3)

Pamela J. Wegner

100,781

(3)

Director NomineesDirectors

    

Michael L. Bennett

3,482(3)

Erroll B. Davis, Jr.

  

473,619799,433

(3)

Robert W. Schlutz.

16,791

(3)

Wayne H. Stoppelmoor

133,935

(3)

Directors

Alan B. Arends.

9,418

(3)

Jack B. Evans

36,363

(3)

Joyce L. Hanes(4)

8,585

(3)

Lee Liu(4)

192,386

(3)

Katharine C. Lyall

  

14,540

16,567

(4)

Singleton B. McAllisterAnn K. Newhall

  

2,710

7,408

(3)

David A. Perdue

  

3,9587,518

(3)

Judith D. Pyle

  

13,043

14,111

Anthony R. WeilerRobert W. Schlutz

  

15,40921,271

(3)

All ExecutivesExecutive Officers and Directors as a Group

2315 people, including those listed above.above

  

1,710,8291,673,240

(3)

 

(1)Total shares of AEC common stock outstanding as of Feb. 28, 2003,2005, were 92,658,243.116,183,026.

 

(2)Stock ownership of Mr. Davis is shown with the Directors.directors and stock ownership for Mr. Harvey is shown with the director nominees.

 

(3)Included in the beneficially owned shares shown are indirect ownership interests with shared voting and investment powers: Mr. Davis—8,467,Davis — 9,435, Mr. Evans—1,000, Ms. Hanes—604,Harvey — 2,826, Mr. Liu—19,755, Mr. Weiler—Weiler — 1,389, Mr. Harvey—2,595Protsch — 845 and Mr. Protsch—783;Aller – 1,000; shares of common stock held in deferred compensation plans: Mr. Arends—4,227,Bennett — 3,082, Mr. Davis—42,865,Davis — 50,744, Mr. Evans—5,363,Harvey — 29,011, Ms. Hanes—200,McAllister — 2,104, Ms. Newhall — 6,110, Mr. Perdue—3,958,Perdue — 7,518, Mr. Schlutz—6,252,Schlutz — 9,797, Mr. Weiler—4,228,Weiler — 6,707, Mr. Harvey—26,479,Aller — 6,695, Mr. Protsch—32,388, Mr. Walker—17,437Protsch — 35,235 and Ms. Wegner—17,884Swan — 21,526 (all executive officers and Directorsdirectors as a group—203,104)group — 183,042); and stock options exercisable on or within 60 days of Feb. 28, 2003:2005: Mr. Davis—388,778,Davis — 667,566, Mr. Liu—148,849,Harvey — 149,977, Mr. Stoppelmoor—119,201,Aller — 86,136, Mr. Harvey—87,403, Mr. Protsch—87,403, Mr. Walker—70,637Protsch — 139,157 and Ms. Wegner—73,859Swan — 110,644 (all executive officers and Directorsdirectors as a group—1,231,041)group — 1,240,675).

 

(4)Ms. Hanes and Mr. LiuLyall will retire as Directorsa director of the Company at AEC’s 2005 Annual Meeting on May 28, 2003.19, 2005.

 

 

None of the Directors or officers of the Company own any shares of the Company’s preferred stock. To the Company’s knowledge, no shareowner beneficially owned5%owned 5% or more of any class of the Company’s preferred stock as of Dec. 31, 2002.2004. The following table sets forth information, as of Dec. 31, 2004 regarding beneficial ownership by the only persons known to AEC to own more than 5% of AEC’s common stock. The beneficial ownership set forth below has been reported on Schedule 13G filings with the SEC by the beneficial owners.

 

Amount and Nature of Beneficial Ownership

  Voting Power Investment Power    

Name and Address of Beneficial Owner

 Sole Shared Sole Shared Aggregate Percent
of
Class

Franklin Resources, Inc.

(and certain affiliates)

One Franklin Parkway

San Mateo, CA 94403

 6,411,600 0 6,411,600 0 6,411,600 5.6%

Hotchkis & Wiley Capital Management, LLC

(and certain affiliates)

725 South Figueroa Street 39th Floor

Los Angeles, CA 90017-5439

 5,382,800 0 6,566,600 0 6,566,600 5.7%

COMPENSATION OF EXECUTIVE OFFICERS

 

The following Summary Compensation Table sets forth the total compensation paid by the Company, AEC and AEC’s other subsidiaries to the Chief Executive Officer and the fourcertain other most highly compensated executive officers of the Company for all services rendered during 2002, 20012004, 2003 and 2000.2002.

 

SUMMARY COMPENSATION TABLE


 

Name and Principal Position

Year

Annual Compensation

Long-Term Compensation

All Other

Compensation(3)


Base

Salary

Bonus

Other

Annual

Compensation(1)

Awards

Payouts

    
Annual CompensationLong-Term Compensation 
     Awards(2)Payouts

Securities UnderlyingName and

Options

(Shares)(2)Principal Position

 

LTIPYear

Payouts

 


Base
Salary
Bonus

Other
Annual
Compensation(1)


Restricted
Stock
Awards(3)
Securities
Underlying
Options

(Shares)

LTIP
Payouts

All Other
Compensation(4)

Erroll B. Davis, Jr.

Chairman and

Chief Executive Officer

 

2004
2003
2002

2001

2000

 

$



749,019
685,000

683,269

637,692


685,000
 

$



375,197
0

489,364

895,200


0
 

$



0

11,265

11,875

74,987
14,949
17,582
 

151,687

108,592

111,912

$

300,453
0
0
 

$

0

359,605

196,711

234,732
151,687
151,687
 

$



63,067

50,284

52,619

0
0
0

$

138,719
45,253
45,485

William D. Harvey

PresidentChief Operating Officer

 

2004
2003
2002

2001

2000

 



459,442
290,000
282,500

274,616

264,615

 



206,805
0

161,233

206,541


0
 



0

4,061

4,234

6,246
5,954
7,707
 

26,642

21,798

21,063



100,143
0
0
 

0

92,209

47,474

73,454
26,642
26,642
 



25,307

42,944

42,230

0
0
0



48,896
15,562
17,599

Eliot G. Protsch

Executive Vice President

2002

2001

2000

282,500

274,616

264,615

0

143,688

214,942

0

893

1,423

26,642

21,798

21,063

0

92,209

47,474

22,448

38,372

38,058


Thomas M. Walker

Executive Vice President & Chief Financial Officer

 2004
2003
2002


364,539
290,000
282,500


142,167
0
0


6,014
4,825
6,131


149,981
0
0
40,996
26,642
26,642


0
0
0


43,611
15,605
16,318

2002Barbara J. Swan

2001

2000President

 

277,500

264,615

254,616

2004
2003
2002
 



0

133,852

190,026

298,674
265,000
260,000
 



110,791
0


0

0

 

25,673

21,005

20,268



5,255
0
6,716
 



100,143
0

88,597

47,474


0
 

32,026
24,705
24,705

44,841

6,207

6,166




0
0
0


18,843
14,536
16,356

Pamela J. WegnerThomas L. Aller(5)

ExecutiveSenior Vice President

 

2004
2003
2002

2001

2000

 



270,000

264,615

254,608

237,692
200,000
190,000
 



123,203
189,170
0

124,312

180,285

 



0

2,267

2,416


0
0
 

25,673

21,005

20,268



0
0
0
 

0

88,597

27,563

21,654
17,438
17,438
 



28,441

35,370

34,377

0
0
0



4,164
8,693
8,223

 

(1)Other Annual Compensation consists of income tax gross-ups for reverse split-dollar life insurance.insurance and, for Mr. Davis only, air travel. Certain personal benefits provided by the Company or AEC to the executive officers named in the Summary Compensation Table above are not included in the Table. The aggregate amount of such personal benefits for each such executive officer in each year reflected in the Table did not exceed the lesser of $50,000 or 10% of the sum of such executive officer’s base salary and bonus in each respective year.

 

(2)Awards made in 20022004 were in addition to performance share awards as described in the table entitled “Long-Term Incentive Awards in 2002.2004.

 

(3)The amounts in the Summary Compensation Table above for restricted stock in 2004 represent the market value based on the closing price of AEC common stock on the date of the grants. The restricted stock awards are subject to (i) two year cliff vesting in the case of 2,008 shares for Mr. Protsch, and (ii) the remaining awards are subject to three year cliff vesting. As of Dec. 31, 2004, the total number of shares of AEC restricted common stock (and their market value based on the closing price of AEC common stock on that date) held by each executive officer listed in the Summary Compensation Table above were as follows: Mr. Davis, 11,605 shares ($331,903); Mr. Harvey, 3,868 shares ($110,625); Mr. Protsch, 5,876 shares ($168,054); Ms. Swan, 3,868 shares ($110,625); and Mr. Aller, 0 shares ($0).

(4)The table below shows the components of the compensation reflected under this column for 2002:2004:

 


    

Erroll B. Davis, Jr.

    

William D. Harvey

    

Eliot G. Protsch

    

Thomas M. Walker

    

Pamela J. Wegner



 
  Erroll B. Davis, Jr.  William D. Harvey  Eliot G. Protsch  Barbara J. Swan  Thomas L. Aller

A.

    

$

20,550

    

$

7,825

    

$

8,475

    

$

5,500

    

$

6,850

 $22,672 $6,580 $8,140 $6,272 $2,591

B.

    

 

37,568

    

 

16,469

    

 

13,312

    

 

37,486

    

 

19,793

  95,649  35,096  28,058  7,500  0

C.

    

 

4,949

    

 

1,013

    

 

661

    

 

1,855

    

 

1,798

  8,470  3,244  1,373  1,095  1,573

D.

  11,928  3,976  6,040  3,976  0

Total

    

$

63,067

    

$

25,307

    

$

22,448

    

$

44,841

    

$

28,441

 $138,719 $48,896 $43,611 $18,843 $4,164

 

A.Matching contributions to the AEC 401(k) Savings Plan and Deferred Compensation Plan

B.Reverse split-dollarSplit dollar life insurance premiums

C.Life insurance coverage in excess of $50,000
D.Dividends earned in 2004 on AEC restricted stock

(5)Mr. Aller became an executive officer of the Company in September 2003, and previously served as an officer of Resources.

STOCK OPTIONS

 

The following table sets forth certain information concerning options to purchase shares of AEC common stock options granted during 20022004 to the executives named below:

 

STOCK OPTION GRANTS IN 20022004


 


 

Individual Grants

 

Potential Realizable Value at Assumed Annual Rates of Stock Price Appreciation for Option Term(2)


 Individual Grants  
 

 
 
Potential Realizable Value at
Assumed Annual Rates

of Stock Price Appreciation
for Option Term(3)

Name

 

Number of Securities

Underlying

Options Granted(1)

  

% of Total Options Granted to Employees in Fiscal Year

  

Exercise or Base Price

($/Share)

 

Expiration

Date

 

5%

 

10%

 Grant
Date (1)
 Number of
Securities
Underlying
Options Granted (2)
 % of Total Options
Granted to
Employees in
Fiscal Year
 
 
 
 
  
 
 
Exercise or
Base Price
($/Share)
 Expiration
Date
  5%  10%

Erroll B. Davis, Jr.

 

151,687

  

16.0

%

 

$

27.79

 

5/16/12

 

$

6,866,870

 

$

10,935,116

 01/02/04
01/02/04
02/09/04
 146,917
74,413
13,402
 21.6
11.0
2.0
%
%
%
 $
 
 
24.90
31.54
25.93
 01/02/14
01/02/14
01/02/14
 $
 
 
2,300,720
671,205
215,638
 $
 
 
5,829,667
2,458,606
544,925

William D. Harvey

 

26,642

  

2.8

%

 

 

27.79

 

5/16/12

 

 

1,206,083

 

 

1,920,622

 01/02/04
02/09/04
 50,938
22,516
 7.5
3.3
%
%
  
 
24.90
25.93
 01/02/14
01/02/14
  
 
797,689
362,282
  
 
2,021,220
915,501

Eliot G. Protsch

 

26,642

  

2.8

%

 

 

27.79

 

5/16/12

 

 

1,206,083

 

 

1,920,622

 01/02/04
02/09/04
 31,099
9,897
 4.6
1.5
%
%
  
 
24.90
25.93
 01/02/14
01/02/14
  
 
487,010
159,243
  
 
1,234,008
402,412

Thomas M. Walker

 

25,673

  

2.7

%

 

 

27.79

 

5/16/12

 

 

1,162,217

 

 

1,850,767


Pamela J. Wegner

 

25,673

  

2.7

%

 

 

27.79

 

5/16/02

 

 

1,162,217

 

 

1,850,767


Barbara J. Swan

 01/02/04
02/09/04
 28,418
3,608
 4.2
0.5
%
%
  
 
24.90
25.93
 01/02/14
01/02/14
  
 
445,026
58,053
  
 
1,127,626
146,701

Thomas L. Aller

 01/02/04
02/09/04
 18,767
2,887
 2.8
0.4
%
%
  
 
24.90
25.93
 01/02/14
01/02/14
  
 
293,891
46,452
  
 
744,675
117,385

 

(1)The three separate grants of non-qualified stock options to purchase shares of AEC common stock are as follows: (a) All of the named executives received options on Jan. 2, 2004 as part of AEC’s annual long-term incentive (LTI) grant; (b) On Jan. 2, 2001, Mr. Davis was granted options that inadvertently exceeded the individual limit for option grants under the applicable plan by 74,413 shares. These options had an exercise price of $31.54, the fair market value of AEC’s common stock at the time of grant. AEC determined that the options in excess of the individual limit were not valid, so on Jan. 2, 2004, to make him whole, the Compensation Committee granted Mr. Davis 74,413 options from the current plan, at the same exercise price of $31.54; and (c) Supplemental grants of options were made on Feb. 9, 2004, to all named executives to adjust target values for the 2004 LTI awards to account for new salaries, target incentive changes and/or promotions.

(2)Consists of non-qualified stock options to purchase shares of AEC common stock granted pursuant to the AEC’s Equity Incentive Plan.stock. Options were granted on May 16, 2002, and have a three-year vesting schedule pursuant to which one-third of the options become exercisable on each of Jan. 1, 2003; Jan. 1, 2004; and Jan. 1, 2005.vest as outlined below. Upon a “change in control” of AEC as defined in the Plan or upon retirement, disability or death of the option holder, the options will become immediately exercisable.

 

Jan. 2, 2004 grant for all named executives

-1/3rd vests 1/2/05, 1/3rd vests 1/1/06, 1/3rd vests 1/1/07

Jan. 2, 2004 replacement grant for Mr. Davis

-100% vests 1/2/05 (same vesting date used for prior grant)

Feb. 9, 2004 grant for all named executives

-1/3rd vests 2/9/05, 1/3rd vests 1/1/06, 1/3rd vests 1/1/07

(2)(3)The hypothetical potential appreciation shown for the named executives is required by rules of the SEC. The amounts shown do not represent the historical or expected future performance of AEC’s common stock. InRather, in order for the named executives to realize the potential values set forth in the 5% and 10% columns in the table above, the price per share of AEC’s common stock would be $45.27 and $72.09, respectively,as follows for each of the grants, all as of the expiration date of the options.

   5%

  10%

Jan. 2, 2004 grant for all named executives

  $40.56  $64.58

Jan. 2, 2004 replacement grant for Mr. Davis

   40.56   64.58

Feb. 9, 2004 grant for all named executives

   42.02   66.59

 

The following table provides information for the executives named below regarding options exercised in 2004 and the number and value of exercisable and unexercisedunexercisable options. None of the executives exercised options in fiscal year 2002.

 

AGGREGATE OPTION EXERCISES IN 2004 AND OPTION VALUES AT DEC. 31, 20022004


 


    

Number of Securities Underlying

Unexercised Options at Fiscal Year End

    

Value of Unexercised

In-the-Money Options at Year End(1)


 

Shares
Acquired

on Exercise

 

Value
Realized

($)

 Number of Securities
Underlying Unexercised
Options at Fiscal Year End
 

Value of Unexercised

In-the-Money Options

at Year End(1)

Name

    

Exercisable

    

Unexercisable

 

Shares
Acquired

on Exercise

 

Value
Realized

($)

 Exercisable Unexercisable  Exercisable  Unexercisable

Erroll B. Davis, Jr.

    

264,715

    

261,385

    

$

0

    

$

0

 -- $-- 451,687 386,419 $699,194 $1,811,580

William D. Harvey

    

64,235

    

48,195

    

 

0

    

 

0

 --  -- 112,430 100,096  126,724  465,010

Eliot G. Protsch

    

64,235

    

48,195

    

 

0

    

 

0

 --  -- 112,430 67,638  126,724  357,913

Thomas M. Walker

    

48,322

    

46,432

    

 

0

    

 

0


Pamela J. Wegner

    

51,544

    

46,432

    

 

0

    

 

0


Barbara J. Swan

 8,235  72,221 86,398 56,731  18,100  315,467

Thomas L. Aller

 --  -- 67,292 39,092  77,978  218,801

 

(1)Based on the closing per share price of AEC’sAEC common stock on Dec. 31, 2002.2004 of $28.60.

 

LONG-TERM INCENTIVE AWARDS

 

The following table provides information concerning long-term incentive awards made to the executives named below in 2002.2004.

 

LONG-TERM INCENTIVE AWARDS IN 20022004


 


Name

    

Number of

Shares,

Units or

Other Rights

(#)(1)

    

Performance

or Other

Period Until

Maturation

or Payout

  

Estimated Future Payouts Under

Non-Stock Price-Based Plans

  Number of
Shares, Units

or Other Rights
(#)(1)
  Performance or
Other Period

Until Maturation
or Payout
  Estimated Future Payouts Under
Non-Stock Price-Based Plans
 
  Threshold
(#)
  Target
(#)
  Maximum
(#)
      

Threshold

(#)

  

Target

(#)

  

Maximum

(#)


Erroll B. Davis, Jr.

    

29,579

    

1/01/05

  

14,790

  

29,579

  

59,158

  36,020  1/1/2007  18,010  36,020  72,040

William D. Harvey

    

5,937

    

1/01/05

  

2,969

  

5,937

  

11,874

  16,486  1/1/2007  8,243  16,486  32,972

Eliot G. Protsch

    

5,937

    

1/01/05

  

2,969

  

5,937

  

11,874

  9,208  1/1/2007  4,604  9,208  18,416

Thomas M. Walker

    

5,721

    

1/01/05

  

2,861

  

5,721

  

11,442


Pamela J. Wegner

    

5,721

    

1/01/05

  

2,861

  

5,721

  

11,442


Barbara J. Swan

  7,194  1/1/2007  3,597  7,194  14,388

Thomas L. Aller

  5,064  1/1/2007  2,532  5,064  10,128

 

(1)Consists of performance shares awarded underas part of AEC’s Long-Term Equity Incentive Plan.annual LTI grant. The payout from the performance shares is based on two equally-weighted performance components: AEC’s three-year Total Shareowner Return (TSR)(“TSR”) relative to an investor-owned utility peer group and annualized earnings per share growth versus internally set performance hurdles contained induring the Alliant Energy Strategic Plan during thethree-year performance cycle ending Dec. 31, 2004.2006. Payouts are subject to modification pursuant to a performance multiplier that ranges from 0 to 2.00, and will be made in shares of AEC common stock or a combination of AEC common stock and cash.

CERTAIN AGREEMENTS

 

Mr. Davis currently has an employment agreement with AEC, pursuant to which he will serve as the Chairman President and Chief Executive Officer of AEC until the expiration of the current term of the agreement on April 21, 2004. Thereafter,the date of AEC’s 2006 Annual Meeting, but no later than May 30, 2006. In addition, he will serve as the Chief Executive Officer of AEC during the term of the agreement will automatically renew for successive one-year terms, unless either Mr. Davis or AEC gives prior written noticeotherwise determined by the Board of his or its intent to terminate the agreement.Directors. Mr. Davis will also serve as the Chief Executive Officer of AEC and a Director of each subsidiary of AEC, including the Company, duringas long as he holds the term of his employment agreement.same position for AEC. Pursuant to Mr. Davis’the employment agreement, he isMr. Davis will be paid an annual base salary of not less than $450,000. Mr. Davis’ current salary under his employment agreement is $685,000.$750,000. Mr. Davis also haswill have the opportunity to earn short-term and long-term incentive compensation (including stock options, restricted stock and other long-term incentive compensation) at least equal to other executive officers and receive supplemental retirement benefits (including continued participation in the Company’sAEC Executive Tenure Compensation Plan) and life insurance providing a death benefit of three times his annual salary. For purposes of AEC’s Supplemental Executive Retirement Plan described in detail under “Retirement and Employee Benefit Plans,” (i) Mr. Davis will be deemed to have been paid an annual bonus for 2003 of $595,539 (the amount that he would have received had he been eligible for such a bonus for such year); (ii) if Mr. Davis ceases to be the Chief Executive Officer while remaining the Chairman in 2005 and if the annual bonus for 2005 payable in 2006 is less than the target award for Mr. Davis for 2005, Mr. Davis will be deemed to have earned the target award; (iii) a special calculation will apply to protect the dollar amount that Mr. Davis could have been paid on May 1, 2003 if he had retired on April 30, 2003; and (iv) upon termination of employment Mr. Davis generally will be deemed to be a retiree not subject to the early commencement reduction factors that would otherwise apply. For purposes of AEC’s Executive Tenure Compensation Plan, the Board of Directors has determined to treat Mr. Davis as an eligible retiree at his future termination of employment, regardless of the circumstances other than death. If, prior to the end of the term of the agreement, the employment of Mr. Davis is terminated by AEC without cause (as defined in the employment agreement), or if Mr. Davis terminates his employment for good reason (as defined in the employment agreement), or if the employment of Mr. Davis is terminated as a result of the mutual agreement of Mr. Davis and the Board of Directors of AEC, AEC or its affiliates will continue to provide the compensation and benefits called for by the employment agreement through the later of the end of the term of the agreement or one year after such termination of employment agreement (with incentive compensation based on the maximum potential awards and with any stock compensation paid in cash), and all unvested stock compensation will vest immediately. If Mr. Davis dies or becomes disabled, or terminates his employment without good reason duringprior to the end of the term of his respective employmentthe agreement, AEC or its affiliates will pay to Mr. Davis or his beneficiaries or estate all compensation earned through the date of death disability or such termination (including previously deferred compensation and pro rata incentive compensation based upon the maximum potential awards). If Mr. Davis’ employment is terminated by reason of his disability, he will be entitled to such benefits as may be provided by AEC’s current disability program. If Mr. Davis is terminated for cause, AEC or its affiliates will pay his base salary through the date

of termination plus any previously deferred compensation. In any such case, Mr. Davis shall also be eligible for the benefits he has accrued under the applicable retirement plans, including the benefits under the Supplemental Executive Retirement Plan and the Executive Tenure Compensation Plan. Under Mr. Davis’the employment agreement, if any payments thereunder constitute an excess parachute payment under the Internal Revenue Code (the “Code”(“Code”), then AEC will pay to Mr. Davis the amount necessary to offset the excise tax and any applicable taxes on this additional payment.

 

AEC currently has in effect key executive employment and severance agreements (the “KEESAs”) with certain executive officers and key employees of AEC (including Messrs. Davis, Harvey, Protsch Walkerand Aller and Ms. Wegner)Swan). The KEESAs provide that each executive officer who is a party thereto is entitled to benefits if, within a period of up to three years (depending on which executive is involved) after a change in control of AEC (as defined in the KEESAs) (the “Employment Period”), the officer’s employment is ended through (a) termination by AEC, other than by reason of death or disability or for cause (as defined in the KEESAs); or (b) termination by the officer due to a breach of the agreement by AEC or a significant change in the officer’s responsibilities; or (c) in the case of Mr. Davis’ agreement, termination by Mr. Davis following the first anniversary of the change of control. The benefits provided are (a) a cash termination payment of up to three times (depending on which executive is involved) the sum of the officer’s annual salary and his or her average annual bonus during the three years before the termination; and (b) continuation for up to the end of the Employment Period of equivalent hospital, medical, dental, accident and life insurance coverage as in effect at the time of termination. Each KEESA for executive officers below the level of Executive Vice President of AEC provides that if any portion of the benefits under the KEESA or under any other agreement for the officer would constitute an excess parachute payment for purposes of the Code, benefits will be reduced so that the officer will be entitled to receive $1 less than the maximum amount which he or she could receive without becoming subject to the 20% excise tax imposed by the Code on certain excess parachute payments, or which AEC may pay without loss of deduction under the Code. The KEESAs for the Chief Executive Officer, President, Senior Executive Vice President and the Executive Vice Presidents of AEC (including Messrs. Davis, Harvey, Protsch Walkerand Aller and Ms. Wegner)Swan) provide that if any payments thereunder or otherwise constitute an excess parachute payment, AEC will pay to the appropriate officer the amount necessary to offset the excise tax and any additional taxes on this additional payment. Mr. Davis’ employment agreement as described above limits benefits paid thereunder to the extent that duplicate payments would be provided to him under his KEESA.

 

RETIREMENT AND EMPLOYEE BENEFIT PLANS

 

Alliant Energy Cash Balance Pension Plan

Salaried employees (including officers) of the Company are eligible to participate in the Alliant Energy Cash Balance Pension Plan (the “Pension Plan”) maintained by Alliant Energy Corporate Services. The Pension Plan bases a participant’s defined benefit pension on the value of a hypothetical account balance. For individuals participating in the Pension Plan as of Aug. 1, 1998, a starting account balance was created equal to the present value of the benefit accrued as of Dec. 31, 1997, under the applicable prior benefit formula. In addition, such individuals received a special one-time transition credit amount equal to a specified percentage varying with age multiplied by credited service and pay. For 1998 and thereafter, a participant receives annual credits to the account equal to 5% of base pay (including certain incentive payments, pre-tax deferrals and other items), plus an interest credit on all prior accruals equal to 4%, plus a potential share of the gain on the investment return on assets in the trust investment for the year.

 

The life annuity payable under the Pension Plan is determined by converting the hypothetical account balance credits into annuity form. Individuals who were participants in the Pension Plan on Aug. 1, 1998, are in no event to receive any less than what would have been provided under the prior formula that was applicable to them, had it continued, if they terminate on or beforeAug.before Aug. 1, 2008, and do not elect to commence benefits before the age of 55.

 

All of the individuals listed in the Summary Compensation Table participate in the Pension Plan and are “grandfathered” under the applicable prior plan benefit formula. Because their estimated benefits under the applicable prior plan benefit formula are expected to be higher than under the Pension Plan formula, utilizing current assumptions, their benefits would currently be determined by the applicable prior plan benefit formula. The following tables illustrate the estimated annual benefits payable upon retirement at age 65 under the applicable prior plan formula based on average annual compensation and years of service. To the extent benefits under the Pension Plan are limited by tax law, any excess will be paid under the Unfunded Excess Plan described below.

 

Company Plan A Prior Formula.

One of the applicable prior plan formulas provided retirement income based on years of credited service and final average compensation for the 36 highest consecutive months, with a reduction for Social Security

offset. The individuals listed in the Summary Compensation Table covered by this formula are Messrs. Davis, Harvey and Protsch and Ms. Wegner.Swan. The benefits would be as follows:

 

Company Plan A Prior Plan Formula Table

 

Average

Annual

Compensation


    

Annual Benefit After Specified Years in Plan


    Annual Benefit After Specified Years in Plan

15


    

20


    

25


    

30+


15

    20

    25

    30+

$ 200,000

    

$

55,000

    

$

73,333

    

$

91,667

    

$

110,000

    $55,000    $73,333    $91,667    $110,000

300,000

    

 

82,500

    

 

110,000

    

 

137,500

    

 

165,000

     82,500     110,000     137,500     165,000

400,000

    

 

110,000

    

 

146,667

    

 

183,333

    

 

220,000

     110,000     146,667     183,333     220,000

500,000

    

 

137,500

    

 

183,333

    

 

229,167

    

 

275,000

     137,500     183,333     229,167     275,000

600,000

    

 

165,000

    

 

220,000

    

 

275,000

    

 

330,000

     165,000     220,000     275,000     330,000

700,000

    

 

192,500

    

 

256,667

    

 

320,833

    

 

385,000

     192,500     256,667     320,833     385,000

800,000

    

 

220,000

    

 

293,333

    

 

366,667

    

 

440,000

     220,000     293,333     366,667     440,000

900,000

    

 

247,500

    

 

330,000

    

 

412,500

    

 

495,000

     247,500     330,000     412,500     495,000

1,000,000

    

 

275,000

    

 

366,667

    

 

458,333

    

 

550,000

     275,000     366,667     458,333     550,000

1,100,000

    

 

302,500

    

 

403,333

    

 

504,167

    

 

605,000

     302,500     403,333     504,167     605,000

 

For purposes of the Pension Plan, compensation means payment for services rendered, including vacation and sick pay, and is substantially equivalent to the salary amounts reported in the Summary Compensation Table. PensionPlanPension Plan benefits depend upon length of Pension Plan service (up to a maximum of 30 years), age at retirement and amount of compensation (determined in accordance with the Pension Plan) and are reduced by up to 50% of Social

Security benefits. The estimated benefits in the table above do not reflect the Social Security offset. The estimated benefits are computed on a straight-life annuity basis. Benefits will be adjusted if the employee receives one of the optional forms of payment. Credited years of service under the Pension Plan for covered persons named in the Summary Compensation Table are as follows: Erroll B. Davis, Jr., 2325 years; William D. Harvey, 1517 years; Eliot G. Protsch, 2325 years; and PamelaBarbara J. Wegner, 8Swan, 16 years.

 

IES Industries Pension Plan Prior Formula.

Another of the The other applicable prior plan formulasformula provided retirement income based on years of service and final average compensation for the highest consecutive 36 months out of the last 10 years of employment. TheMr. Aller is the only individual listed in the Summary Compensation Table covered by this formula is Mr. Walker.formula. The benefits would be as follows:

 

IES Industries Pension Plan Prior Formula Table

 

Average Annual

Compensation


  

Annual Benefit After Specified Years in Plan


    Annual Benefit After Specified Years in Plan

15


  

20


  

25


  

30


  

35


15

    20

    25

    30

    35

$200,000

  

$

43,541

  

$

58,056

  

$

72,570

  

$

87,083

  

$

101,597

$ 200,000

    $42,847    $57,130    $71,413    $85,696    $99,978

300,000

  

 

66,792

  

 

89,056

  

 

111,320

  

 

133,583

  

 

155,847

     66,098     88,130     110,163     132,196     154,228

400,000

  

 

90,042

  

 

120,056

  

 

150,070

  

 

180,083

  

 

210,097

     89,348     119,130     148,913     178,696     208,478

500,000

  

 

113,292

  

 

151,056

  

 

188,820

  

 

226,583

  

 

264,347

     112,598     150,130     187,663     225,196     262,728

600,000

  

 

136,542

  

 

182,056

  

 

227,569

  

 

273,083

  

 

318,597

     135,848     181,130     226,413     271,696     316,978

 

For purposes of the Pension Plan, compensation means payment for services rendered, including vacation and sick pay, and is substantially equivalent to the salary amounts reported in the Summary Compensation Table. Pension Plan benefits depend upon length of Pension Plan service (up to a maximum of 35 years), age at retirement and amount of compensation (determined in accordance with the Pension Plan). The estimated benefits are computed on a straight-life annuity basis. Benefits will be adjusted if the employee receives one of the optional forms of payment. Mr. WalkerAller has six11 credited years of credited service under the Pension Plan.

 

Unfunded Excess Plan—Alliant Energy

Corporate Services maintains an Unfunded Excess Plan that provides funds for payment of retirement benefits above the limitations on payments from qualified pension plans in those cases where an employee’s retirement benefits exceed the qualified plan limits. The Unfunded Excess Plan provides an amount equal to the difference between the actual pension benefit payable under the Pension Plan and what such pension benefit would be if calculated without regard to any limitation imposed by the Code on pension benefits or covered compensation.

 

Unfunded Executive Tenure Compensation Plan—Alliant Energy

Corporate Services maintains an Unfunded Executive Tenure Compensation Plan to provide incentive for selected key executives to remain in the service of AEC by providing additional compensation that is payable only if the executive

remains with AEC until retirement (orother termination if approved by the Board of Directors). In the caseDirectors of the Chief Executive Officer only, in the event that the Chief Executive Officer (a) is terminated under his employment agreement with AEC as described above other than for cause, death or disability (as those terms are defined in the employment agreement); (b) terminates his employment under the employment agreement for good reason (as such term is defined in the employment agreement); or (c) is terminated as a result of a failure of the employment agreement to be renewed automatically pursuant to its terms (regardless of the reason for such non-renewal), then for purposes of the Plan, the Chief Executive Officer shall be deemed to have retired at age 65 and shall be entitled to benefits under the Plan.AEC). Any participant in the Plan must be approved by the Board of Directors.Directors of AEC. Mr. Davis was the only active participant in the Plan as of Dec. 31, 2002.2004. The Plan provides for monthly payments to a participant after retirement (at or after age 65, or with Board approval, prior to age 65) for 120 months. The payments will be equal to 25% of the participant’s highest average salary for any consecutive 36-month period. If a participant dies prior to retirement or before 120 payments have been made, the participant’s beneficiary will receive monthly payments equal to 50% of such amount for 120 months in the case of death before retirement or, if the participant dies after retirement, 50% of such amount for the balance of the 120 months. Annual benefits of $171,250$187,500 would be payable to Mr. Davis upon retirement, assuming he continues in Alliant Energy Corporate Services’the service of AEC until retirement at the same salary as was in effect on Dec. 31, 2002.2004.

 

Supplemental Executive Retirement Plan

AEC maintains an unfunded Supplemental Executive Retirement Plan (“SERP”) to provide incentive for key executives to remain in the service of AEC by providing additional compensation that is payable only if the executive remains with AEC until retirement, disability or death. While the SERP provides different levels of benefits depending on the executive covered, this summary reflects the terms applicable to all of the individuals listed in the Summary Compensation Table. Participants in the SERP must be approved by the Compensation and Personnel Committee of the Board.Board of Directors of AEC. The SERP provides for payments of 60% of the participant’s average annual earnings (base salary and bonus) for the highest paid three years out of the last 10 years of the participant’s employment reduced by the sum of benefits payable to the officer from the officer’s defined benefit plan and the Unfunded Excess Plan. The normal retirement date under the SERP is age 62 with at least 10 years of service and early retirement is at age 55 with at least ten10 years of service. If a participant retires prior to age 62, the 60% payment under the SERP isreducedis reduced by 3% per year for each year the participant’s retirement date precedes his or his/her normal retirement date. The actuarial reduction factor will be waived for participants who have attained age 55 and have a minimum of 10 years of service in a senior executive position with AEC after April 21, 1998. At the timely election of the participant, benefits under the SERP will be made in a lump sum, in installments over a period of up to 10 years, or for the lifetime of the participant. If the lifetime benefit is selected and the participant dies prior to receiving 12 years of payments, payments continue to any surviving spouse or dependent children of a deceased participant who dies while still employed by AEC, payable for a maximum of 12 years. A post-retirement death benefit of one times the participant’s final average earnings at the time of retirement will be paid to the designated beneficiary. Messrs. Davis, Harvey, Protsch Walkerand Aller and Ms. WegnerSwan are participants in the SERP. The following table shows the amount of retirement payments under the SERP, assuming a minimum of 10 years of service at retirement age and payment in the annuity form.

 

Supplemental Executive Retirement Plan Table

 

Average

Annual

Compensation


    

Annual Benefit After Specified Years in Plan


        Annual Benefit After Specified Years in Plan    

<10 Years


    

>10 Years*


<10 Years

    >10 Years*

$ 200,000

    

0

    

$

120,000

    $0    $120,000

300,000

    

0

    

 

180,000

     0     180,000

400,000

    

0

    

 

240,000

     0     240,000

500,000

    

0

    

 

300,000

     0     300,000

600,000

    

0

    

 

360,000

     0     360,000

700,000

    

0

    

 

420,000

     0     420,000

800,000

    

0

    

 

480,000

     0     480,000

900,000

    

0

    

 

540,000

     0     540,000

1,000,000

    

0

    

 

600,000

     0     600,000

1,100,000

    

0

    

 

660,000

     0     660,000

*Reduced by the sum of the benefit payable from the applicable defined benefit pension plan and the Unfunded Excess Plan.

 

Key Employee Deferred Compensation Plan

AEC maintains an unfundeda Key Employee Deferred Compensation Plan under which participants may defer up to 100% of base salary and incentive compensation and eligible SERP payments.compensation. Participants who have made the maximum allowed contribution to the AEC-sponsored 401(k) Savings Plan may receive an additional credit to the Deferred Compensation Plan. The credit will be equal to 50% of the lesser of (a) the amount contributed to the 401(k) Savings Plan plus the amount deferred under this Plan; or (b) 6% of base salary, reduced by the amount of any matching contributions in the 401(k) Savings Plan. The employee may elect to have his or her deferrals credited to an Interest Account or an AEC Stock Account. Deferrals and matching contributions to the Interest Account receive an annualreturn based on the A-Utility Bond Rate with a minimum return no less than the prime

interest rate published inThe Wall Street Journal, provided that the return may not be greater than 12% or less than 6%. Deferrals and matching contributions credited to the AEC Stock Account are treated as though invested in AEC common stock and will be credited with dividends, which will be treated as if reinvested. The shares of common stock identified as obligations under the Plan are held in a rabbi trust. Payments from the Plan may be made in a lump sum or in annual installments for up to 10 years at the election of the participant. Participants are selected by the Chief Executive Officer of Alliant Energy Corporate Services. Messrs. Davis, Harvey, Protsch Walkerand Aller and Ms. WegnerSwan are participants in the Plan.

REPORT OF THE COMPENSATION AND PERSONNEL

COMMITTEE ON EXECUTIVE COMPENSATION

 

To Our Shareowners:

The Compensation and Personnel Committee (the “Committee”) of the Board of Directors of the Company is currently comprisedcomposed of four non-employee Directorsindependent directors (the same Directorsdirectors that comprise the AEC Compensation and Personnel Committee.)Committee). The following is a report prepared by these Directorsdirectors with respect to compensation paid by AEC, the Company and AEC’s other subsidiaries.

 

The Committee assesses the effectiveness and competitiveness of, approves the design of, and administers executive compensation programs within a consistent total compensation framework for the Company. The Committee also reviews and approves all salary arrangements and other remuneration for executives,executive officers, evaluates executive officer performance, and considers related matters. It also makes recommendations to the Nominating and Governance Committee regarding Director compensation. To support it in carrying out its mission, the Committee engages an independent consultant (which is retained by the Committee rather than Company executives).

The Committee Charter was amended in January 2004 to provide assistance.enhance corporate governance through the adoption of recommended and required modifications detailing the role and functions of the Committee in compliance with the NYSE listing standards.

 

The Committee is committed to implementing an overall compensation program for executivesexecutive officers that furthers the Company’s mission. Therefore, the Committee adheres to the following compensation policies, which are intended to facilitate the achievement of the Company’s business strategies:

 

·Executive management compensation (and particularly, long-term incentive compensation) should be closely and strongly aligned with the long-term interests of AEC’s shareowners.
Executive management compensation (and particularly, long-term incentive compensation) should be closely and strongly aligned with the long-term interests of AEC’s shareowners and customers.

Total compensation should enhance the Company’s ability to attract, retain and encourage the development of exceptionally knowledgeable and experienced executive officers, upon whom, in large part, the successful operation and management of the Company depends.

 

·Total compensation should enhance the Company’s ability to attract, retain and encourage the development of exceptionally knowledgeable and experienced executives, upon whom, in large part, the successful operation and management of the Company depends.

 ·Base salary levels should be targeted at a competitive market range of base salaries paid to executivesexecutive officers of comparable companies. Specifically, the CommitteeCompany targets the median (50th) percentile(50th percentile) of base salaries paid by a selected groupcompanies of similar revenue base within the utility and general industry companies.industries.

 

·Incentive compensation programs should strengthen the relationship between pay and performance by emphasizing variable, at-risk compensation that is consistent with meetingpredetermined corporate, subsidiary, business unit and individual performance goals. In addition, the Committee targets incentive levels at the median (50th percentile) of incentive compensation paid by a selected group of utility and general industry companies.
Incentive compensation programs should strengthen the relationship between pay and performance by emphasizing variable at-risk compensation that is consistent with meeting predetermined corporate, subsidiary, business unit and individual performance goals. In addition, the Committee targets incentive levels at the median (50th percentile) of incentive compensation paid by companies of similar revenue base within the utility and general industries.

 

Components of Compensation

The major elements of theAEC’s executive compensation program are base salary, short-term (annual) incentives, and long-term (equity) incentives.incentives and other benefits. These elements are addressed separately below.in this report. In setting the level for each major component of compensation, the Committee considers all elements of an executive’sexecutive officer’s total compensation package, including employee benefit and perquisite programs. The Committee’s goal is to provide an overall compensation package for each executive officer that is competitive to the packages offered otherto similarly situated executives. Theexecutive officers at companies of similar size within the industry.

For 2004, the Committee has determined that total executive compensation at target levels including that for Mr. Davis, is in line with competitive compensation of the comparison group ofcomparative companies.

 

To ensure the Committee has adequate time to consider executive officers’ total compensation for the coming year, Committee members are provided detailed compensation information in advance of the second to last Committee meeting of the previous year, which is then presented and analyzed at that Committee meeting. Committee members then have time between meetings to raise questions and ask for additional information. The Committee then makes final decisions regarding compensation at the last Committee meeting of the previous year.

Base Salaries

The Committee annually reviews each executive’sexecutive officer’s base salary. Base salaries are targeted at a competitive market range (i.e., at the median level) when comparing both utility and non-utility (general industry) data from similarly-sized companies, with utility-specific positions based exclusively on energy industry data. The industry peer group the Committee used for assessing compensation is the S&P Midcap 400 Utilities Index. The Committee annually adjusts base salaries to recognize changes in the market, AEC performance, varying levels of responsibility, and executive officers’ prior experience and breadth of knowledge. Increases to base salaries are driven primarily by market adjustments for a particular salary level, which generally limits across-the-board increases. Theincreases, though the Committee does not consideralso considers individual performance factors in setting base salaries. The Committee reviewedreviews executive salaries for market comparability using utility and general industry data contained in published compensation surveys published by Edison Electric Institute, American Gas Association and several compensation consulting firms. Based on the foregoing and market conditions, the Committee established the annual salary for Mr. Davis at $685,000 for the 2002 fiscal year.surveys.

 

In consideration of industry conditionsBased on this data and corporate performance,consultation with the independent executive compensation consultant, the Committee determined that the Chief Executive Officer and the Executive Vice Presidents would not receive aapproved base salary increaseincreases for 2003.executive officers in 2004.

 

Short-Term Incentives

TheAEC’s short-term (annual) incentive program promotes the Committee’s pay-for-performance philosophy by providing executivesexecutive officers with direct financial incentives in the form of annual cash bonuses tied to the achievement of corporate,AEC, subsidiary and business unit and individual performance goals. Annual bonus opportunities allow the Committee to communicate specific goals that are of primary importance during the coming year and motivate executivesexecutive officers to achieve these goals. The Committee onOn an annual basis, the Committee reviews and approves the program’s performance goals, the relative weight assigned to each goal and the targeted and maximum award levels. A description of the short-term incentive programsprogram available during 20022004 to executive officers follows.

 

Alliant Energy Corporation Management Incentive Compensation PlanIn 2002,2004, the Alliant Energy Corporation Management Incentive Compensation Plan (the “MICP”) covered executivesexecutive officers and was based on achieving annual targets infor AEC and business unit performance. AEC corporate performance that includedwas gauged on earnings per share (“EPS”),from continuing operations, total cash flow from continuing operations, Lean Six Sigma savings, environmental, health and safety assessment closure rates, and diversity initiatives. Business unit performance was gauged on those goals and environmental targets forother operational measures specific to the utility businesses, and business unit and individual performance goals.unit. Target and maximum bonus awards under the MICP in 20022004 were set at the median of the utility and general industry market levels. The Committee considered these targets to be achievable, but to require above-average performance from each of the executives.substantially challenging. The level of performance achieved in each category determines actual payment of bonuses as a percentage of annual salary. Weighting factors are applied to the percentage achievement under each category to determine overall performance. If a pre-determined EPSearnings per share from continuing operations target is not met, there is no bonus payment associated with the MICP. If the threshold performance for any other performance target is not reached, there is no bonus payment associated with that particular category. Once the designated maximum performance is reached, there is no additional payment for performance above the maximum level. The actual percentage of salary paid as a bonus, within the allowable range, is equal to the weighted average percent achievement for all the performance categories. Potential MICP awardstargets range from 0% to 100%

80% of annualbase salary for eligible executives other than Mr. Davis.

In 2002, Mr. Davis was covered by the MICP. Awards for Mr. Davis, under the MICP in 2002 were based onto 30-65% of base salary for other executive officers, with a maximum possible payout for all of two times their target percentage.

After assessing corporate and strategic goal achievement in relation to predetermined goals. For each plan year, the Committee determines thebusiness unit performance apportionment for Mr. Davis. In 2002, that apportionment was 80% for corporate performance and 20% for strategic goal performance. Corporate performance is measured based on corporate-wide EPS, environmental, diversity and safety targetsagainst established at the beginning of the year. Strategic goals, are measured based on the achievement of certain specific goals, which included strategy development and implementation, established for Mr. Davis by the Committee. The 2002 MICP award range for Mr. Davis was from 0% to 150% of annual salary.

Because the corporate EPS goal was not achieved, there was no payout from the MICP for performance for the year ended Dec. 31, 2002.

Due to industry and market conditions and overall corporate performance, the Committee determined that the Chief Executive Officer and Executive Vice Presidents will participate in the MICP, but will notexecutive officers were eligible to receive MICP awards if earned, for 20032004 plan year performance.

 

Long-Term Incentives

The Committee strongly believes compensation for executivesexecutive officers should include long-term, at-risk pay to strengthen the alignment of the interests of the shareowners and management. In this regard, the Alliant Energy Corporation Long-Term Equity Incentive Plan and the Alliant Energy Corporation 2002 Equity Incentive Plan each permitsAEC maintains plans that permit grants of stock options, restricted stock and performance units/shares with respect to AEC’s common stock. The Committee believes that the incentive plans balance the Company’s annual compensation programs by emphasizing compensation based on the long-term, successful performance of the Company from the perspective of AEC’s shareowners.

In determining actual award levels under the Alliant Energy Corporation Long-Term Incentive Program, the Committee sought to provide competitive total compensation opportunities to executive officers while also taking performance factors into account. As such, award levels for 2004 were based on a competitive analysis of similarly sized utility and general industry companies that took into consideration the market level of long-term incentives, the competitiveness of the total compensation package and AEC performance. Award levels were targeted to the median of the range of such awards paid by comparable companies. A description of the long-term incentive programs available during 2002 to executive officers under the Alliant Energy Corporation Long-Term Equity Incentive Plan and the Alliant Energy Corporation 2002 Equity Incentive Plan is set forth below.during 2004 follows.

 

Alliant Energy Corporation Long-Term Incentive Program—ProgramThe Alliant Energy Corporation Long-Term Incentive Program covered executivesall executive officers and consisted of the following components in 2002:2004: non-qualified stock options and performance shares. Select executive officers were also awarded grants of restricted stock for retention purposes.

Non-qualified stock options provide a reward that is directly tied to the benefit shareowners receive from increases in the price of AEC’s common stock. The payout from thePayout of performance shares granted in 2002 is based on two equally-weighted performance components: AEC’s three-year total shareowner return to shareowners(“TSR”) relative to an investor-owned utility peer group, (TSR), and on AEC’s three-year annualized EPS growth versus internally setearnings per share growth. Payout of performance hurdles containedshares granted in 2003 and 2004 is based solely on AEC’s three-year TSR relative to the Alliant Energy Strategic Plan.peer group. Thus, the Committee believes the two components of the Long-Term Incentive Program (i.e., stock options and performance shares) provide incentives for management to produce superior shareowner returns on

both an absolute and relative basis. During 2002,2004, the Committee made a grantgrants of stock options and performance shares to various executive officers, including Messrs. Davis, Harvey, Protsch Walkerand Aller and Ms. Wegner.Swan. All option grants had a per share exercise pricesprice equal to the fair market value of a share of AEC common stock on the day following the date the grants were approved. Options vest on a one-third basis at the beginning of each calendar year after grant and have a 10-year term from the date of the grant. Executives in the Alliant Energy Corporation Long-Term Incentive ProgramThe performance share grants, with final awards that range from zero to 200% of target, were also granted performance shares. Performance shares will be paid out in a combination of AEC common stock and cash. The award will be modified by a performance multiplier, which ranges from 0 to 2.00 based on corporate performance.performance against the criteria described above.

Due to AEC’s three-year annualized earnings per share growth and TSR goals not being achieved, there was no performance share payout for the 2002 grant which had a three-year cycle ending in December 2004.

 

In addition to stock options and performance shares, executive officers, including Mr. Davis, received grants of AEC restricted stock in 2004. The AEC restricted stock vests 100% two or three years after the date of grant, as the case may be (with immediate vesting in case of death, disability or retirement). These grants of AEC restricted stock were made for the purpose of recognizing and retaining these key individuals.

Following an extensive review of AEC’s long-term incentive programs, the Committee determined that, commencing in 2005, performance-contingent AEC restricted stock would replace stock options as a component of an executive officer’s long-term incentive grant. Thus, performance shares and performance-contingent restricted stock will comprise the total target award for 2005.

Other Benefits

Basic benefit programs that are made available to all other salaried employees are also made available to executive officers, including AEC’s 401(k) Savings Plan and the Cash Balance Pension Plan. In addition, executive officers are eligible to participate in AEC’s Excess Plan, Supplemental Executive Retirement Plan and Key Employee Deferred Compensation Plan – all as described in the Retirement and Benefit Plans section of this proxy statement. Executive officers are also eligible for a separate Executive Health Care Plan (medical and dental) and flexible perquisites.

Certain executive officers receive individually owned life insurance policies. Premiums paid by AEC for this insurance were taxed as bonuses to the individual officers beginning in 2004.

Compensation of the Chairman and Chief Executive Officer

When determining actualthe compensation package of the Chairman and CEO, the Committee follows the same general policies that guide compensation decisions for other executive officers. Thus, the Committee based Mr. Davis’ award levels under the Alliant Energy Corporation Long-Term Incentive Program, the Committee was primarily concerned with providing a competitive total compensation opportunity level to officers. As such, award levels (including awards made to Mr. Davis) were based on a competitivean analysis of similarly sized utility and general industry companies that took into consideration the market level of long-term incentives, as well as the competitiveness of the total compensation package.package, as well as AEC corporate performance.

As was the case for other executive officers, Mr. Davis received a base salary increase in 2004 to $750,000 from his previous level of $685,000, which had been in effect for both 2002 and 2003. The Committee then established award ranges and individual award levelsapproved the salary increase based on responsibility levelits evaluation of Mr. Davis’ performance and market competitiveness. Noon a review of competitive data.

For 2004, Mr. Davis’ short-term incentive payout was based solely on AEC’s performance on the corporate or individual performance measures were reviewed in connectiongoals described above. The Committee approved a final 2004 incentive payout for Mr. Davis of $375,197 based on achievement of these pre-established goals.

For 2004, Mr. Davis’ target long-term incentive percentage was 200% of base salary, with the awards of options and performance shares. Award levels were targeted to the median of the range of such awards paid by comparable companies. The Committee did not consider the amounts of options andtotal award comprising performance shares already outstanding or previously granted when making awardsand stock options. In addition to these grants, the Committee also approved a grant of AEC restricted stock for 2002.recognition and retention purposes. All of Mr. Davis’ 2004 awards in 2002 under the Long-Term Incentive Programlong-term incentive program are shown in the tables under “Stock Option Grants in 2002”2004” and “Long-Term Incentive Awards in 2002.2004.

 

DueShare Ownership Guidelines

AEC has established share ownership guidelines for executive officers as a way to better align the corporate EPS and TSR goals not being achieved, there was no payoutfinancial interests of its officers with those of its shareowners. Under these guidelines, the requisite ownership numbers are 85,000 shares for the performance share portionChief Executive Officer, 36,000 shares for Executive Vice Presidents and 12,000 shares for Vice Presidents. These executive officers are expected to make continuing progress toward compliance with these guidelines. Individuals at the participating levels are asked to achieve the recommended ownership multiple within a 5-year period from the effective date of becoming an officer. The Chief Executive Officer retains the Long-Term Incentive Program’s three-year cycle that ended in Dec. 2002.right to grant special dispensation for hardship, promotions or new hires.

 

Policy with Respect to the $1 Million Deduction Limit

Section 162(m) of the Code generally limits the corporate deduction for compensation paid to executive officers named in the proxy statement to $1 million, unless such compensation is based upon performance objectives meeting certain regulatory criteria or is otherwise excluded from the limitation. Based on the Committee’s commitment to link compensation with performance as described in this report, the Committee intends to qualify future compensation paid to the Company’s executive officers for deductibility by the Company under Section 162(m) except in limited appropriate circumstances. All taxable income for 2004 of the executive officers of the Company qualified under Section 162(m) as deductible by the Company.

 

Conclusion

The Committee believes the existing executive compensation policies and programs provide an appropriate level of competitive compensation for the Company’s executives.executive officers. In addition, the Committee believes that the long- and short-term performance incentives effectively align the interests of executivesexecutive officers and shareowners toward a successful future for the Company.

 

COMPENSATION AND PERSONNEL COMMITTEE

Judith D. PyleSingleton B. McAllister (Chairperson)

Alan B. Arends

Jack B. EvansMichael L. Bennett

David A. Perdue

Judith D. Pyle

REPORT OF THE AUDIT COMMITTEE

 

To Our Shareowners:

The Audit Committee (the “Committee”) of the Board of Directors of the Company is composed of five independent Directors,four directors, each of whom is independent as defined inunder the New York Stock Exchange’sNYSE listing standards.standards and SEC rules. The Committee operates under a written charter adopted by the Board of Directors. The Audit Committee Charter of the Company as amended by the Board of Directors on March 19, 2003, is attached as Appendix A to this proxy statement. Under the Charter, among other things, the Committee is responsible for the appointment, compensation and oversight of the Company’s independent auditors.

 

The Company’s management (“management”) is responsible for the Company’s internal controls and the financial reporting process, including the system of internal controls. The independent auditors are responsible for expressing an opinion on the conformity of the Company’s audited consolidated financial statements with accounting principles generally accepted accounting principles.in the United States of America. The Committee has reviewed and discussed the audited consolidated financial statements with management and the independent auditors. The Committee has discussed with the independent auditors matters required to be discussed by Statement on Auditing Standards No. 61 (Communication With Audit Committees).

 

The Company’s independent auditors have provided to the Committee the written disclosures required by Independence Standards Board Standard No. 1 (Independence Discussions with Audit Committees), and the Committee discussed with the independent auditors their independence.

The Committee pre-approveshas adopted a policy that requires advance approval of all audit, audit-related, tax and other permitted services performed by the independent auditor. The policy provides for pre-approval by the Committee of specifically defined audit and non-audit services after the Committee is provided with the appropriate level of details regarding the specific services to be provided. The policy does not permit delegation of the Committee’s authority to management. In the event the need for specific services arises between Committee meetings, the Committee has delegated to the Chairperson of the Committee authority to approve permitted services provided bythat the independent auditors.Chairperson reports any decisions to the Committee at its next scheduled meeting.

 

The principal accounting fees that were billed to the Company and AEC paid toby its independent auditors for 2001 and 2002 forwork performed on behalf of the Company and AECits subsidiaries for 2003 and 2004 were as follows:

 

   

2001


  

2002


 

Audit Fees

  

$

1,194,000

  

$

2,843,000

(1)

Audit Related Fees(2)

  

 

146,000

  

 

19,000

 

Tax Fees(3)

  

 

491,000

  

 

1,125,000

 

All Other Fees(4)

  

 

36,000

  

 

297,000

 


(1)Includes approximately $1.4 million for 2000 and 2001 re-audit fees.
   2003

  2004

Audit Fees(1)

  $        319,000  $        987,000

Audit-Related Fees

   98,000   348,000

Tax Fees

   162,000   70,000

All Other Fees

   21,000   22,000

 

(1)The Audit Fees for 2004 included additional fees required by Section 404 of the Sarbanes-Oxley Act related to AEC’s internal controls for financial reporting that were not required in 2003.

(2)Audit Related Fees consisted of the fees billed for employee benefits plan audits, attest services required by statute or regulations and, in 2001 only, due diligence related to acquisitions and consultations concerning financial accounting and reporting not classified as audit fees.

 

(3)Tax Fees consisted of the fees billed for professional services rendered for tax compliance, tax advice and tax planning, including all services performed by the professional staff in the independent auditors’ tax division, except those rendered in connection with the audit.

Audit-Related Fees consisted of the fees billed for employee benefits plan audits and attest services not required by statute or regulations for both 2003 and 2004, and Sarbanes-Oxley Section 404 planning for 2004.

 

(4)All Other Fees in 2001 and 2002 consisted of fees for generation strategy consultation; in 2001 only, a human resource project; and, in 2002 only, the license fee for a tax software product.

Tax Fees consisted of the fees billed for professional services rendered for tax compliance, tax advice and tax planning, including all services performed by the professional staff in the independent auditors’ tax division, except those rendered in connection with the audit.

All Other Fees consisted of license fees for tax and accounting research software products.


The Audit Committee does not consider the provision of non-audit services by the independent auditors described above to be incompatible with maintaining auditor independence.

 

The Committee discussed with the Company’s internal and independent auditors the overall scopes and plans for their respective audits. The Committee meets with the internal and independent auditors, with and without management present, to discuss the results of their examinations, the evaluation of the Company’s internal controls and overall quality of the Company’s financial reporting.

 

Based on the Committee’s reviews and discussions with management, the internal auditors and the independent auditors referred to above, the Committee recommended to the Board of Directors that the audited consolidated financial statements be included in the Company’s Annual Report on Form 10-K for the year ended Dec. 31, 2002,2004 for filing with the SEC.

 

AUDIT COMMITTEE

Jack B. EvansMichael L. Bennett (Chairperson)

Alan B. Arends

Katharine C. Lyall

Singleton B. McAllister

Ann K. Newhall

David A. Perdue

SECTION 16(a) BENEFICIAL OWNERSHIP

REPORTING COMPLIANCE

 

TheSection 16(a) of the Securities Exchange Act of 1934 requires the Company’s Directors, its executive officersdirectors and certain other officers are required to report theirfile reports of ownership and changes in ownership of the Company’s Preferredpreferred stock and any changes in that ownership towith the SEC and the New York Stock Exchange. To the bestNYSE. As a matter of practice, the Company’s knowledge, all requiredfilingsShareowner Services Department assists the Company’s reporting persons in 2002 were properly madepreparing initial reports of ownership and reports of changes in a timely fashion. In makingownership and files those reports on their behalf. The Company is required to disclose in this proxy statement the above statements,failure of reporting persons to file these reports when due. Based on the Company has relied on thewritten representations of the reporting persons involved and on copies of theirthe reports filed with the SEC.SEC, the Company believes that all reporting persons of the Company satisfied these filing requirements.

 

By Order of the Board of Directors,

 

LOGO

/s/ F. J. Buri

F. J. Buri

Corporate Secretary

 

APPENDIX A – AUDIT COMMITTEE CHARTER

 

Purposes and Role of Committee

The purposes of the Audit Committee (the “Committee”) of the Board of Directors (the “Board”) of Alliant Energy Corporation (the “Company”) are to: (1) assist Board oversight of (a) the integrity of the Company’s financial statements, (b) the Company’s compliance with legal and regulatory requirements, (c) the independent auditors’ qualifications and independence, and (d) the performance of the Company’s internal audit function and independent auditors; and (2) prepare the report that Securities and Exchange Commission (“Commission”) rules require to be included in the Company’s annual proxy statement.

The role of the Committee is oversight. Management and the internal auditing department are responsible for maintaining and evaluating appropriate accounting and financial reporting principles and policies and internal controls and procedures designed to ensure compliance with accounting standards and applicable laws and regulations. The independent auditors are responsible for auditing the financial statements and assessing the Company’s internal controls.

Committee Membership

The Committee shall consist of three or more members of the Board, each of whom satisfies the requirements for independence and experience under Section 10A(m)(3) of the Securities Exchange Act of 1934 (the “Exchange Act”), Commission rules and the listing standards of the New York Stock Exchange (the “NYSE”). The Board will endeavor to ensure that at least one Committee member shall qualify as an “audit committee financial expert” as defined by SEC rules. Committee members may not serve on audit committees of more than two other public companies. Committee members shall serve at the pleasure of the Board and for such term or terms as the Board may determine.

Committee Structure and Operations

The Board shall designate one member of the Committee as its Chair. The Committee shall meet in formal session at least three times each year and, in addition, hold quarterly meetings with the independent auditors and management to discuss the annual audited financial statements and the quarterly earnings releases. Additional meetings shall be held when deemed necessary or desirable by a majority of the Committee or its Chair. The Committee will meet periodically in executive session without management present.

A majority of the Committee members currently holding office constitutes a quorum for the transaction of business. The Committee may take action only upon the affirmative vote of a majority of the Committee members present at a duly held meeting. The Committee may meet in person or telephonically, and may act by unanimous written consent. The Committee may invite such members of management to its meetings as it deems desirable or appropriate.

Committee Duties

The duties of the Committee are to:

1.Be directly responsible for the appointment (including the sole authority to approve all audit engagement fees and terms, as well as significant non-audit engagements), termination, compensation and oversight of the Company’s independent auditors (including resolution of disagreements between management and the independent auditors regarding financial reporting) for the purpose of preparing or issuing an audit report or related work. The independent auditors must report directly to the Committee.

2.Pre-approve all audit services and permitted non-audit services to be performed by the independent auditors, subject to the de minimus exceptions for non-audit services described in Section 10A(i)(1)(B) of the Exchange Act that are approved by the Committee prior to the completion of the audit. The Committee may delegate authority to grant pre-approvals of audit services and permitted non-audit services to subcommittees consisting of one or more of its members, provided that decisions of such subcommittee to grant pre-approvals shall be presented to the full Committee at its next scheduled meeting.

3.

Review with the independent auditors the scope of the prospective audit, the estimated fees therefore and such other matters pertaining to such audit as the Committee may deem appropriate. Receive copies of the annual comments from

the independent auditors on accounting procedures and systems of control. Recommend to the Board the acceptance of such audits that are accompanied by certification.

4.Review and discuss with management and the independent auditors, before filing with the Commission, the annual audited financial statements and quarterly financial statements, including the Company’s disclosures under “Management’s Discussion and Analysis of Financial Condition and Results of Operations,” and recommend to the Board whether the audited financial statements should be included in the Company’s Form 10-K.

5.Discuss with management and the independent auditors the Company’s earnings press releases (including the use of “pro forma” or “adjusted” non-GAAP information), as well as financial information and earnings guidance provided to analysts and rating agencies.

6.Discuss with management, the internal auditing department and the independent auditors: (1) major issues regarding accounting principles and financial statement presentations, including any significant changes in the Company’s selection or application of accounting principles, and major issues as to the adequacy of the Company’s internal controls and any special audit steps adopted in light of material control deficiencies; (2) analyses prepared by management and/or the independent auditors setting forth significant financial reporting issues and judgments made in connection with the preparation of the financial statements, including analyses of the effects of alternative GAAP methods on the financial statements; (3) the effect of regulatory and accounting initiatives, as well as off-balance sheet structures, on the financial statements of the Company.

7.Review and discuss quarterly reports from the independent auditors on: all critical accounting policies and practices to be used; all alternative treatments of financial information within GAAP that have been discussed with management, ramifications of the use of such alternative disclosures and treatments and the preferred treatment by the independent auditors; other material written communications between the independent auditors and management, such as any management letter or schedule of unadjusted differences.

8.Review and discuss with the independent auditors the matters required to be discussed by Statement on Auditing Standards No. 61 relating to the conduct of the audit, including any audit problems or difficulties and management’s response, any restrictions on the scope of activities or access to requested information, and any significant disagreements with management. The review shall include a discussion of the responsibilities, budget and staffing of the Company’s internal audit function.

9.Review the action taken by management on the internal auditors’ and independent auditors’ recommendations.

10.Review with the senior internal audit executive the annual internal audit plan and scope of internal audits.

11.Make or cause to be made, from time to time, such other examinations or reviews as the Committee may deem advisable with respect to the adequacy of the systems of internal controls and accounting practices of the Company and its subsidiaries and with respect to current accounting trends and developments, and take such action with respect thereto as may be deemed appropriate.

12.Review the appointment, reassignment and replacement of the senior internal audit executive.

13.Set clear policies for hiring by the Company of employees or former employees of the independent auditors.

14.Meet privately, on a periodic basis, with the independent auditors, the internal auditors and members of management as appropriate.

15.Review disclosures made to the Committee by the Company’s Chief Executive Officer and Chief Financial Officer during their certification process for the Form 10-K and Form 10-Q about any significant deficiencies in the design or operation of internal controls or material weaknesses therein and any fraud involving management or other employees who have a significant role in the Company’s internal controls.

16.Review with management, the independent auditors and the senior internal audit executive the adequacy of, and any significant changes in, the internal controls; the accounting policies, procedures or practices of the Company and its subsidiaries; and compliance with corporate policies, directives and applicable laws.

17.Annually receive from and discuss with the independent auditors a written statement delineating all relationships between the auditors and the Company that may have a bearing on the auditors’ independence.

18.Obtain and review, at least annually, a report by the independent auditors describing: the independent auditors’ internal quality-control procedures; any material issues raised by the most recent internal quality-control review, or peer review, of the firm, or by any inquiry or investigation by governmental or professional authorities, within the preceding five years, respecting one or more independent audits carried out by the firm, and any steps taken to deal with any such issues; and (to assess the auditors’ independence) all relationships between the independent auditors and the Company. Evaluate the qualifications, performance and independence of the independent auditors taking into account the opinions of management and the internal auditors. The Committee shall present its conclusions with respect to the independent auditors to the Board.

19.Review and evaluate the lead partner of the independent auditors.

20.Ensure the rotation of audit partners as required by Commission rules. Consider whether, in order to ensure continuing auditor independence, there should be regular rotation of the audit firm itself.

21.Establish procedures for the receipt and handling of complaints received by the Company regarding accounting, internal accounting controls, or auditing matters; and the confidential, anonymous submission by employees of the Company and its affiliates of concerns regarding questionable accounting, internal control or auditing matters.

22.Review the status of compliance with laws, regulations, and internal procedures, contingent liabilities and risks that may be material to the Company, the scope and status of systems designed to ensure Company compliance with laws, regulations and internal procedures.

23.Discuss with management the Company’s policies with respect to risk assessment and risk management, the Company’s major financial risk exposures and the steps management has taken to monitor and control such exposures.

24.Conduct or authorize investigations into any matters within the Committee’s scope of responsibility, consistent with procedures to be adopted by the Committee.

25.As appropriate, obtain advice and assistance from outside legal, accounting or other advisors.

26.Review and assess the adequacy of this charter at least annually, and recommend any amendments it deems appropriate to the Board for approval.

Committee Reports

1.Report to the Board on a regular basis on the activities of the Committee. This report shall include a review of any issues that arise with respect to the quality or integrity of the Company’s financial statements, the Company’s compliance with legal or regulatory requirements, the performance and independence of the Company’s independent auditors, or the performance of the internal audit function.

2.Conduct, and present to the Board, an annual performance evaluation of the Committee, which shall assess the performance of the Committee with respect to the duties and responsibilities of the Committee as set forth in this charter.

3.Report on matters required by the rules of the Commission to be disclosed in the Company’s annual proxy statement.

Resources and Authority of the Committee

The Committee shall have the authority, as it deems necessary to carry out its duties, to retain, discharge and approve fees and other terms for retention of its own independent experts in accounting and auditing, legal counsel and other independent experts or advisors. The Company shall provide for appropriate funding, as determined by the Committee, for payment of compensation to the independent auditors for the purpose of rendering or issuing an audit report or related work and to any experts or advisors employed by the Committee. The Committee may direct any officer or employee of the Company or request any employee of the Company’s independent auditors, outside legal counsel or other consultants or advisors to attend a Committee meeting or meet with any Committee members.

APPENDIX B – WISCONSIN POWER AND LIGHT COMPANY

ANNUAL REPORT

 

For the Year Ended December 31, 20022004

 

Contents


  

Page



DefinitionsThe Company

  

B-2

A-2

The CompanySelected Financial Data

  

B-3

A-2

Selected Financial Data

B-3

Management’s Discussion and Analysis of Financial Condition and Results of Operations

  

B-4

A-3

Report of Independent Auditors’ ReportRegistered Public Accounting Firm

  

B-15

A-15

Consolidated Financial Statements

   

Consolidated Statements of Income

  

B-17

A-16

Consolidated Balance Sheets

  

B-18

A-17

Consolidated Statements of Cash Flows

  

B-20

A-19

Consolidated Statements of Capitalization

  

B-21

A-20

Consolidated Statements of Changes in Common Equity

  

B-22

A-21

Notes to Consolidated Financial Statements

  

B-23

A-22

Shareowner Information

  

B-37

A-39

Executive Officers and Directors

  

B-37

A-40

 

DEFINITIONS

Certain abbreviations or acronyms used in the textWisconsin Power and notes of this report are defined below:

Abbreviation or Acronym


Definition


AFUDC

Allowance for Funds Used During Construction

Alliant Energy

Alliant Energy Corporation

ATC

American Transmission Company, LLC

CAA

Clean Air Act

Corporate Services

Alliant Energy Corporate Services, Inc.

DNR

Department of Natural Resources

Dth

Dekatherm

EPA

U.S. Environmental Protection Agency

FASB

Financial Accounting Standards Board

FERC

Federal Energy Regulatory Commission

FIN

FASB Interpretation No.

FIN 45

Guarantor’s Accounting and Disclosure Requirements for Guarantees, Including Indirect Guarantees of Indebtedness to Others

FIN 46

Consolidation of Variable Interest Entities

GAAP

Accounting Principles Generally Accepted in the U.S.

ICC

Illinois Commerce Commission

IES

IES Industries Inc.

IESU

IES Utilities Inc.

IPC

Interstate Power Company

IP&L

Interstate Power and Light Company

Kewaunee

Kewaunee Nuclear Power Plant

KWh

Kilowatt-hour

MD&A

Management’s Discussion and Analysis of Financial Condition and Results of Operations

MGP

Manufactured Gas Plants

Moody’s

Moody’s Investors Service

MW

Megawatt

MWh

Megawatt-hour

NEPA

National Energy Policy Act of 1992

PSCW

Public Service Commission of Wisconsin

PUHCA

Public Utility Holding Company Act of 1935

Resources

Alliant Energy Resources, Inc.

SEC

Securities and Exchange Commission

SFAS

Statement of Financial Accounting Standards

SFAS 115

Accounting for Certain Investments in Debt and Equity Securities

SFAS 133

Accounting for Derivative Instruments and Hedging Activities

SFAS 143

Accounting for Asset Retirement Obligations

South Beloit

South Beloit Water, Gas and Electric Company

TBD

To Be Determined

U.S.

United States of America

WP&L

Wisconsin Power and Light Company

WPLH

WPL Holdings, Inc.

WP&LLight Company (WPL) filed a combined Form 10-K for 20022004 with the SEC;Securities and Exchange Commission; such document included the filings of WP&L’sWPL’s parent, Alliant Energy IP&LCorporation (Alliant Energy), Interstate Power and WP&L.Light Company (IPL) and WPL. The primary first tier subsidiaries of Alliant Energy are WPL, IPL, Alliant Energy Resources, Inc. (Resources) and Alliant Energy Corporate Services, Inc. (Corporate Services). Certain portions of MD&AManagement’s Discussion and Analysis of Financial Condition and Results of Operations (MDA) and the Notes to Consolidated Financial Statements included in this WP&L Proxy StatementWPL Annual Report represent excerpts from the combined Form 10-K. As a result, the disclosure included in this WP&L Proxy StatementWPL Annual Report at times includes information relating to Alliant Energy, IP&L,IPL, Resources and/or Corporate Services. All required disclosures for WP&LWPL are included in this proxy statementAnnual Report thus such additional disclosures represent supplemental information.

 

THE COMPANY

 

In April 1998, WPLH, IES and IPC completed a merger resulting in Alliant Energy. The primary first tier subsidiaries of Alliant Energy include: WP&L, IP&L, Resources and Corporate Services.

WP&LOverview- WPL was incorporated in Wisconsin1917 in 1917Wisconsin as Eastern Wisconsin Electric Company andCompany. WPL is a public utility engaged principally in the generation, distribution and sale of electric energy; and the purchase, distribution, transportation and sale of natural gas; and the provision of water servicesgas in selective markets. Nearly all of WP&L’sWPL’s customers are located in south and central Wisconsin. WP&LWPL operates in municipalities pursuant to permits of indefinite duration, which are regulated by Wisconsin law. At Dec. 31, 2002, WP&L2004, WPL supplied electric and gas service to 430,406445,198 and 170,123176,045 (excluding transportation and other) customers, respectively. WP&LWPL also had 19,527 water customers.provides various other energy-related products and services, including construction management services for wind farms. In 2004, 2003 and 2002, 2001 and 2000, WP&LWPL had no single customer for which electric, gas, water and/or waterother sales accounted for 10% or more of WP&L’sWPL’s consolidated revenues. WPL Transco LLC is a wholly-owned subsidiary of WP&LWPL and holds WP&L’sWPL’s investment in ATC. WP&LAmerican Transmission Company LLC. WPL also owns all of the outstanding capital stock of South Beloit Water, Gas and Electric Company, a public utility supplying electric, gas and water service, principally in Winnebago County, Illinois, which was incorporated in 1908. WP&L also owns varying interests in several other subsidiaries and investments that are not material to WP&L’s operations.

 

WP&LRegulation- WPL is subject to regulation by the PSCW as toPublic Service Commission of Wisconsin (PSCW) for service territories in Wisconsin for retail utility rates and standards of service, accounts,accounting requirements, issuance and use of proceeds of securities, approval of the location and construction of electric generating facilities, certain other additions and extensions to facilities, and in other respects. WP&LWPL is required to file a rate casecases with the PSCW every two years based onusing a forward-looking test year period.

WPL is also subject, but not limited, to regulation by the Illinois Commerce Commission, the Federal Energy Regulatory Commission, the United States Environmental Protection Agency and the Nuclear Regulatory Commission.

 

Electric Utility Operations-As of Dec. 31, 2002, WP&L2004, WPL provided retail electric service to 428,390443,166 retail and 31 wholesale customers 602 communities and 30 wholesale customers. 2002610 communities. 2004 electric utility operations accounted for 81%78% of operating revenues and 90% of operating income. Electric sales are seasonal to some extent with the annual peak normally occurring in the summer months. In 2002,2004, the maximum peak hour demand for WP&LWPL was 2,674 MW2,627 megawatts and occurred on Aug. 1, 2002.July 20, 2004.

 

Gas Utility Operations-As of Dec. 31, 2002, WP&L2004, WPL provided retail natural gas service to 170,123176,045 (excluding transportation and other) customers in 233243 communities. 20022004 gas utility operations accounted for 18%21% of operating revenues and 9%14% of operating income, which includedinclude providing gas services to retail and transportation customers. WP&L’sWPL’s gas sales follow a seasonal pattern. There is an annual base load of gas used for cooking, heating and other purposes, with a large heating peak occurring during the winter season.

 

SELECTED FINANCIAL DATA

 

  

2002


  

2001


  

2000


  

1999


  

1998


  2004 (1)

  2003 (1)

  2002 (1)

  2001

  2000

  

(in thousands)

  (in millions)

Operating revenues

  

$

972,078

  

$

965,353

  

$

862,381

  

$

752,505

  

$

731,448

  $1,209.8  $1,217.0  $989.5  $993.7  $862.4

Earnings available for common stock

  

 

77,614

  

 

70,180

  

 

68,126

  

 

67,520

  

 

32,264

   110.4   111.6   77.6   70.2   68.1

Cash dividends declared on common stock

  

 

59,645

  

 

60,449

  

 

—  

  

 

58,353

  

 

58,341

   89.0   70.6   59.6   60.4   —  

Cash flows from operating activities

   199.3   138.5   223.8   135.9   174.1

Total assets

  

 

1,984,597

  

 

1,875,800

  

 

1,857,024

  

 

1,766,135

  

 

1,685,150

   2,656.1   2,469.3   2,335.1   2,217.5   2,160.6

Long-term obligations, net

  

 

523,308

  

 

523,183

  

 

569,309

  

 

471,648

  

 

471,554

   491.3   453.5   523.3   523.2   569.3

(1)Refer to “Results of Operations” in MDA for a discussion of the 2004, 2003 and 2002 results of operations.

 

Alliant Energy is the sole common shareowner of all 13,236,601 shares of WP&L’sWPL’s common stock outstanding. As such, earnings per share data is not disclosed herein. The 1998 financial results reflect the recording of $17 million of pre-tax merger-related charges.

MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL

CONDITION AND RESULTS OF OPERATIONS (MDA)

 

FORWARD-LOOKING STATEMENTS

 

Statements contained in this report that are not of historical fact are forward-looking statements intended to qualify for the safe harbors from liability established by the Private Securities Litigation Reform Act of 1995. Such forward-looking statements are subject to risks and uncertainties that could cause actual results to differ materially from those expressed in, or implied by, such statements. Some, but not all, of the risks and uncertainties include: factors listed in “Other Matters—Other Future Considerations;” weather effects on sales and revenues; economic and political conditions in WP&L’sWPL’s service territories; federal and state regulatory or governmental actions, including the impact of potential energy-related legislation in Congress and recently enacted federal tax legislation, the ability to obtain adequate and timely rate relief includingto allow for, among other things, the recovery of operating costs, andthe earning of reasonable rates of return;return in current and future proceedings and the payment of expected levels of dividends; unanticipated construction and acquisition expenditures; unanticipated issues in connection with WPL’s construction of new generating facilities; issues related to the supply of purchased electricity and price thereof, including the ability to recover purchased-powerpurchased power and fuel costs through rates; issues related to electric transmission, including recovery of costs incurred, and federal legislation and regulation affecting such transmission; risks related to the operations of Kewaunee;WPL’s nuclear facility and unanticipated issues relating to the anticipated sale of WPL’s interest in the Kewaunee Nuclear Power Plant (Kewaunee); costs associated with WP&L’sWPL’s environmental remediation efforts and with environmental compliance generally; developments that adversely impact WP&L’sWPL’s ability to implement its strategic plan; no material permanent declines in the fair market value of, or expected cash flows from, WP&L’sWPL’s investments; continued access to the capital markets; WP&L’sWPL’s ability to continue cost controlsits comprehensive cost-cutting and operational efficiencies; WP&L’sefficiency efforts; WPL’s ability to identify and successfully complete proposedpotential acquisitions and development projects; WPL’s ability to complete its proposed divestitures of various businesses and investments in a timely fashion and for anticipated proceeds; access to technological developments; employee workforce factors, including changes in key executives, collective bargaining agreements or work stoppages; continued access to the capital markets; the ability to successfully complete ongoing tax audits and changesappeals with no material impact on WPL’s earnings and cash flows; inflation rates; and factors listed in the rate of inflation. WP&L“Other Matters - Other Future Considerations.” WPL assumes no obligation, and disclaims any duty, to update the forward-looking statements in this report.

 

EXECUTIVE SUMMARY

Description of Business-WPL owns a portfolio of electric generating facilities with a diversified fuel mix including coal, nuclear, natural gas and renewable resources. The output from these generating facilities, supplemented with purchased power, is used to provide electric service to approximately 445,000 electric customers in the upper Midwest. WPL also procures natural gas from various suppliers to provide service to approximately 176,000 gas customers in the upper Midwest. WPL’s domestic utility business is its core business and primary source of earnings and cash flows. WPL’s earnings and cash flows are sensitive to various external factors including, but not limited to, the impact of weather on electric and gas sales volumes, the amount and timing of rate relief approved by regulatory authorities and other factors listed in “Forward-Looking Statements.”

Summary of Historical Results of Operations -In 2004, 2003 and 2002, WPL’s earnings available for common stock were $110.4 million, $111.6 million and $77.6 million, respectively. Refer to “Results of Operations” for details regarding the various factors impacting earnings during 2004, 2003 and 2002.

STRATEGIC ACTIONSOVERVIEW

Summary - WPL’s strategic plan is based on the following principles: a regional focus on utility operations; investments in new domestic utility generation; maintaining sustained, long-term strong financial performance with a strong balance sheet and investment grade credit ratings; and maintaining a performance culture focused on accountability and adherence to its corporate values of ethics, safety, diversity, efficiency and attention to the environment. This strategic plan is also concentrated on building and maintaining the generation and infrastructure necessary to provide WPL’s utility customers with safe, reliable and environmentally sound energy service. WPL has also implemented a comprehensive Lean Six Sigma program to assist it in generating cost savings and operational efficiencies in 2005 and beyond.

WPL’s strategy reflects the fact that it has investment opportunities in its utility business that did not exist several years ago. Wisconsin enacted legislation with the goal of assuring reliable electric energy for Wisconsin. The law allows the construction of merchant power plants in the state and streamlines the regulatory approval process for building new generation and transmission facilities. In addition, the Public Service Commission of Wisconsin (PSCW) approved a plan

proposed by another Wisconsin utility, which provides a similar level of investment certainty by leasing generation from an affiliate. These changes have enabled WPL to pursue additional generation investments to serve its customers and to provide WPL with greater certainty regarding the returns on these investments.

Utility Generation Plan -In 2003, Alliant Energy announced a plan to add an additional 615 megawatts (MW) of utility generating capacity to its diversified portfolio by 2010 for WPL. WPL intends to add this new generation to meet increasing customer demand, reduce reliance on purchased power agreements and mitigate the impacts of potential future plant retirements. WPL will continue to purchase energy and capacity in the market and intends to remain a net purchaser of both, but at a reduced level assuming the successful completion of these generation projects. The plan also reflects continued commitments to WPL’s energy efficiency and environmental protection programs. The following is a summary of the significant progress Alliant Energy has made to-date regarding the execution of this plan that directly impacts WPL:

Alliant Energy continues to make progress on acquiring regulatory approvals for the 300 MW, simple-cycle, natural gas-fired generating facility under construction near Sheboygan Falls, Wisconsin. Resources’ Non-regulated Generation business began construction of the generating facility in 2004 and is expected to complete the facility in time to meet increased summer demand in 2005. Alliant Energy is proposing that Resources’ Non-regulated Generation business would own the facility and enter into a long-term agreement with WPL whereby WPL would operate and maintain the facility and have exclusive rights to the generation output. The facility is expected to cost approximately $150 million, of which approximately $120 million had already been expended as of Dec. 31, 2004. The proposed structure is subject to final PSCW approval.

In October 2004, the federal renewable energy production tax credit was extended for generating facilities that will be placed in service prior to Jan. 1, 2006. As a result, Alliant Energy has moved forward with its plans to add 230 MW of wind generation to its diversified generation portfolio, preferably as purchased power agreements. WPL currently plans to add up to 100 MW of additional wind generation to its renewable resource portfolio by the end of 2005.

In May 2004, Alliant Energy announced WPL would pursue plans to build a jointly-owned 500 MW base-load electric plant with Wisconsin Public Service Corporation (WPSC) (respective ownership levels have not yet been determined). The planning process will include feasibility and siting studies. Based on the current energy requirement studies of both companies, WPL expects significant increases in electric supply are likely to be needed to offset rising energy demand and expiring purchased power agreements by 2010.

WPL reviews and updates, as deemed necessary and in accordance with regulatory requirements, its utility generation requirements on a periodic basis.

Asset Divestitures -WPL is committed to streamlining its portfolio of businesses to those that can provide meaningful earnings and cash flows for WPL with acceptable risk profiles, as well as those it is prepared to invest the capital needed to reach the scale necessary to generate such earnings and cash flows.

WPL is currently pursuing the sale of its 41% interest in Kewaunee. In pursuing the sale of this facility, WPL expects to reduce the financial and operational uncertainty associated with nuclear generating facility ownership and operations, yet still retain the benefit of the output from such plant through a purchased power agreement. In November 2004, the PSCW issued a decision rejecting WPL’s and WPSC’s joint application to sell Kewaunee to Dominion Resources, Inc. (Dominion). WPL and WPSC joined Dominion and applied for a rehearing with the PSCW to continue the pursuit of the sale of the plant. In January 2005, the PSCW accepted the rehearing petition and expects to rule on the sale in the first half of 2005. Refer to Note 16 of the “Notes to Consolidated Financial Statements” for additional information regarding the proposed sale of this nuclear generating facility.

 

In November 2002,August 2004, Alliant Energy’s BoardEnergy announced its intention to sell WPL’s and IPL’s Illinois electric and gas utility properties (WPL’s net book value was approximately $20 million to $25 million as of Directors approved certain strategic actions designed to maintainDec. 31, 2004). The administrative costs of serving relatively few customers in a strong credit profilejurisdiction that requires the same regulatory and administrative support as a state with a larger number of customers make it difficult for Alliant Energy (including WP&L), strengthento offer its (including WP&L’s) balance sheet and positionservices cost-effectively. Alliant Energy currently intends to enter into a sales agreement for improved long-term financial performance (including WP&L). The strategic actions signaled a shiftthe Illinois properties in the first half of 2005 and any such sales agreement would be subject to less aggressive growth targets driven primarily by Alliant Energy’s utility operations. Alliant Energy is continuing in its efforts to implement these strategic actions. The actions that directly impact WP&L are as follows:regulatory approvals.

 

1.A plan to raise approximately $200 to $300 million of common equity in 2003, dependent on market conditions. Alliant Energy expects to direct the majority of the proceeds towards additional capital investments in its regulated domestic utilities.

In January 2005, WPL and the city of Ripon, Wisconsin finalized a purchase and sale agreement for the sale of the water utility serving the Ripon area. Pending approval by the PSCW, the transfer of ownership of the water utility is expected to take place in the first half of 2005. WPL also continues to make progress on the sale of its water utility in South Beloit, Illinois.

2.The implementation of additional cost control measures to be accomplished through Alliant Energy’s new Six Sigma program, the operation of its new enterprise resource planning system that was placed in service in October 2002 and by a heightened focus on operating its domestic utility business in a manner that aligns operating expenses with the revenues granted in its various rate filings.

Of all these divestitures, only WPL’s water utility in Ripon qualified as assets held for sale as of Dec. 31, 2004 and none of them have been reported as discontinued operations.

 

RATES AND REGULATORY MATTERS

 

Overview—WP&L -WPL has one utility subsidiary, South Beloit. As a publicBeloit Water, Gas and Electric Company (South Beloit) and is currently subject to federal regulation by the Federal Energy Regulatory Commission (FERC), which has jurisdiction over wholesale rates and certain natural gas facilities, and state regulation in Wisconsin and Illinois for retail utility holding company with significantrates and standards of service. Such regulatory oversight also covers WPL’s plans for construction and financing of new generation facilities and related activities.

WPL conducts its utility assets, WP&L competesoperations in an ever-changing utility industry.business environment. Electric energy generation, transmission and distribution are infacing a period of fundamental change resulting from potential legislative, regulatory, economic and technological changes. These changes impact competitionHowever, the pace of restructuring in WPL’s primary retail electric service territories has been delayed (and may continue to be delayed for a long period of time) due to uncertainty and developments in the electric wholesale and retail markets as customers of electric utilities are being offered alternative suppliers. Such competitive pressures could result in electric utilities losing customers and incurring stranded costs (i.e., assets and other costs rendered unrecoverable as the result of competitive pricing), which would be borne by security holders if the costs cannot be recovered from customers.

WP&L is currently subject to regulation by FERC, and state regulation in Wisconsin and Illinois. FERC regulates competition in the electric wholesale power generation market and each state regulates whether to permit retail competition, the terms of such retail competition and the recovery of any portion of stranded costs that are ultimately determined to have resulted from retail competition. WP&Lindustry. WPL cannot predict the timing of a restructured electric industry or the impact on its

financial condition or results of operations but does believe it is well-positioned to compete in a deregulated competitive market. Although WP&L ultimately believes that the electric industry will be deregulated, the pace of deregulation in its primary retail electric service territories has been delayed due to more recent developments in the industry.operations.

 

Certain Recent Developments—In July 2002, FERC issued a notice -Details of proposed rules intended to standardize the wholesale electric market, which has generated significant industry discussion. Although WP&L believes that standardization of the wholesale electric market is appropriateWPL’s domestic utility rate cases impacting its historical and would benefit market participants, there may be significant changes to the proposed rules before they are adopted. Therefore, WP&L cannot determine the impact the final rules will have on itsfuture results of operations or financial condition.

WP&L’s merger-related price freezes expired in April 2002 and it is currently addressing the recovery of its cost increases through numerous rate filings. WP&L has received final orders in two of its rate cases and currently has two other rate cases pending. Details of these rate cases are as follows (dollars in millions)millions; Electric (E); Gas (G); Water (W); To Be Determined (TBD); Not Applicable (N/A); Fuel-related (F-R)):

 

Case


  

Utility Type


  

Filing

Date


  

Increase Requested


  

Interim Increase Granted (1)


  

Interim Effective Date


  

Final Increase Granted


  

Final

Effective

Date


  

Expected

Final

Effective

Date


  

Notes


2002 retail

  

E/G/W

  

Aug. 2001

  

$

  104

  

$

49

  

April 2002

  

$

82

  

Sept. 2002

  

N/A

  

(2)

2003 retail

  

E/G/W

  

May 2002

  

 

101

  

 

TBD

  

TBD

  

 

TBD

  

TBD

  

April 2003

   

2004 retail

  

E/G/W

  

March 2003

  

 

65

  

 

TBD

  

TBD

  

 

TBD

  

TBD

  

Jan. 2004

   

Wholesale

  

E

  

Feb. 2002

  

 

6

  

 

6

  

April 2002

  

 

3

  

Jan. 2003

  

N/A

  

(3)

         

  

     

         

Total

        

$

276

  

$

55

     

$

85

         
         

  

     

         

Case


  Utility
Type


  Filing
Date


  Increase
Requested


  Interim
Increase
Granted (1)


  Interim
Effective
Date


  Final
Increase
Granted (1)


  Final
Effective
Date


  Expected
Final
Effective
Date


  Return on
Common
Equity


  Notes

 

2002 retail

  E/G/W  8/01  $104  $49  4/02  $82  9/02  N/A  12.3%   

2003 retail

  E/G/W  5/02   123   —    N/A   81  4/03  N/A  12%   

2004 retail

  E/G/W  3/03   87   —    N/A   14  1/04  N/A  12%   

2005/2006 retail

  E/G  9/04   63   N/A  N/A   TBD  TBD  7/05  TBD   (2)

2004 retail (F-R)

  E  2/04   16   16  3/04   10  10/04  N/A  N/A   (3)

2004 retail (F-R)

  E  12/04   9   —    N/A   —    N/A  N/A  N/A   (4)

South Beloit
retail - IL

  G/W  10/03   1   N/A  N/A   1  10/04  N/A  G-9.87%/
W-9.64%
 
 
   

Wholesale

  E  2/02   6   6  4/02   3  1/03  N/A  N/A    

Wholesale

  E  3/03   5   5  7/03   5  2/04  N/A  N/A    

Wholesale

  E  8/04   12   12  1/05   TBD  TBD  8/05  N/A    

(1)Interim rate relief is implemented, subject to refund, pending determination of final rates. The final rate relief granted replaces the amount of interim rate relief granted.

(2)In its September 2002 final order, the PSCW increased the authorized returnThe 2005/2006 retail rate case is based on common equitya test period from 11.7%July 2005 to 12.3%.June 2006.

(3)InSince the fourth quarter of 2002, WP&L reached a settlement agreement with certain wholesale customers for an annualfinal increase of $3 million andwas lower than the interim relief granted, a refund to customers was made in 2004.

(4)The PSCW denied WPL’s request for a rate increase in this proceeding during an oral hearing held in February 2005. WPL expects to receive the final written order in March 2005 and will consider its alternatives upon a thorough review of amounts previously collected in excess of the settlement. The settlement agreement was approved by FERC in January 2003. At Dec. 31, 2002, WP&L had reserved all amounts related to the anticipated refund.such written order.

 

AWith the exception of additions to WPL’s infrastructure, a significant portion of the rate increases included in the previous table reflect the recovery of anticipated increased costs incurred by WP&L,WPL or costs it expects to incur, thusincur. In addition to the 2005/2006 retail base rate case, WPL currently plans to file an estimated $25 million to $35 million fuel-related rate case in the first quarter of 2005, with anticipated approval from the PSCW to implement interim rates for the fuel-related increase to be effective approximately three weeks after the filing is made. The major drivers in WPL’s base rate and fuel-related rate cases for 2005 are both fixed and variable fuel and purchased power costs. Thus, the potential increase in revenues related to these cost increases wouldrate increase requests is not expected to result in a correspondingmeaningful increase in net income. WP&L and South Beloit are currently in the process of determining what other rate case filings may be necessary in 2003.

 

WP&L’sWPL’s retail electric rates are based on annual forecasted fuel and purchased-powerpurchased power costs. Under PSCW rules, WP&LWPL can seek emergency rate increases for increases in the cost of electric fuel and purchased power if the annualit experiences an increase in costs that are more than 3% higher than the estimated costs used to establish rates. For 2001The PSCW attempts to authorize, after a required hearing, interim fuel-related rate increases within 21 days of notice to customers. Any such change in rates would be

effective prospectively and 2002, any collections in excess of costs incurred mustwould require a refund with interest at the overall authorized return on common equity if final rates are determined to be refunded, with interest. Accordingly, WP&L has established a reservelower than interim rates approved. Rate decreases due to overcollection of past fuel and purchased-powerdecreases in fuel-related costs and expects to refund such amount in 2003.can be implemented without hearing. The final ruling from the PSCW could result in an increase or decrease to the reserve that has been recorded.

The PSCW has issued new rules relating to the collection of fuel and purchased-power costs byalso include a process whereby Wisconsin utilities, including WP&L. The new rules and related procedures are intended, among other things, to significantly reduce regulatory lag for the utilities and customers related to the timing of the recovery of increased or decreased fuel and purchased-power costs. Purchased-power capacity costs will now be included in base rates. A process will also exist whereby the utilities can seek deferral treatment of capacity, transmission and emergency changes in fuel-related costs between fuel-related or base rate cases. The new rules are expectedSuch deferrals would be subject to be implemented for WP&L with its pending 2003 retailreview, approval and recovery in future fuel-related or base rate case.cases.

 

Energy-related legislation is currently pending in the United States (U.S.) Congress that, among other proposals, would repeal the Public Utility Holding Company Act of 1935 (PUHCA). However, it is uncertain when or whether such legislation will be enacted or what impact it would have on WPL.

RESULTS OF OPERATIONS

 

Overview—WP&L’s -WPL’s earnings available for common stock increased $7.4 million and $2.1decreased $1.2 million in 20022004 and 2001, respectively.increased $34 million in 2003. The 20022004 decrease was primarily due to increased operating expenses, largely offset by higher electric margins. The 2003 increase was primarily due to higher electric and gas margins, partially offset by increased operating expenses. The 2001 increase was

Electric Margins -Electric margins and megawatt-hour (MWh) sales for WPL were as follows:

   Revenues and Costs (in millions)

  MWhs Sold (in thousands)

 
   2004

  2003

  *

  2002

  **

  2004

  2003

  *

  2002

  **

 

Residential

  $327.8  $316.9  3% $271.9  17% 3,375  3,410  (1%) 3,432  (1%)

Commercial

   180.0   170.3  6%  146.7  16% 2,215  2,167  2% 2,150  1%

Industrial

   262.6   243.8  8%  211.3  15% 4,769  4,595  4% 4,454  3%
   

  

     

     
  
     
    

Total from retail customers

   770.4   731.0  5%  629.9  16% 10,359  10,172  2% 10,036  1%

Sales for resale

   144.1   155.6  (7%)  125.8  24% 3,797  4,196  (10%) 3,654  15%

Other

   25.3   23.5  8%  32.0  (27%) 80  82  (2%) 94  (13%)
   

  

     

     
  
     
    

Total revenues/sales

   939.8   910.1  3%  787.7  16% 14,236  14,450  (1%) 13,784  5%
                     
  
     
    

Electric production fuel and purchased-power expense

   431.5   409.7  5%  352.5  16%               
   

  

     

                   

Margins

  $508.3  $500.4  2% $435.2  15%               
   

  

     

                   

*Reflects the % change from 2003 to 2004.

**Reflects the % change from 2002 to 2003.

   Actual

   
   2004

  2003

  2002

  Normal

Cooling degree days*:

            

Madison

  138  224  356  242

*Cooling degree days are calculated using a 70 degree base. Normal degree days are calculated using a fixed 30-year average most recently updated in February 2002.

Electric margins increased $7.9 million, or 2%, in 2004, primarily due to the impact of various rate increases in 2004 and 2003, which included increased revenues to recover a significant portion of higher electric marginsoperating expenses, and a lower effective income tax rate,weather-normalized sales growth of 3%, including increased industrial sales of 4% which reflects improving economic conditions in WPL’s service territory. These items were partially offset by increased operating expensesthe impact of extremely mild weather conditions in 2004, $8.9 million of lower energy conservation revenues and the effect of implementing seasonal rates in 2003. Cooling degree days in Madison were 43% below normal in 2004. WPL estimates the impact of weather reduced electric margins by approximately $12 million to $14 million in 2004 compared to normal weather. By comparison, WPL estimates that mild weather conditions reduced electric margins by approximately $3 million in 2003 compared to normal weather. The reduced energy conservation revenues were largely offset by lower gas margins.energy conservation expenses.

 

Electric Utility MarginsElectric margins and MWh sales for WP&L were as follows (in thousands):

   

Revenues and Costs


   

MWhs Sold


 
   

2002


  

2001


  

*


   

2000


  

**


   

2002


  

2001


  

*


   

2000


  

**


 

Residential

  

$

271,875

  

$

248,128

  

10

%

  

$

229,668

  

8

%

  

3,432

  

3,318

  

3

%

  

3,151

  

5

%

Commercial

  

 

146,726

  

 

138,269

  

6

%

  

 

127,199

  

9

%

  

2,150

  

2,122

  

1

%

  

2,031

  

4

%

Industrial

  

 

211,310

  

 

207,791

  

2

%

  

 

190,085

  

9

%

  

4,454

  

4,538

  

(2

)%

  

4,688

  

(3

)%

   

  

      

      
  
      
    

Total from ultimate customers

  

 

629,911

  

 

594,188

  

6

%

  

 

546,952

  

9

%

  

10,036

  

9,978

  

1

%

  

9,870

  

1

%

Sales for resale

  

 

125,822

  

 

131,187

  

(4

)%

  

 

115,715

  

13

%

  

3,654

  

3,524

  

4

%

  

3,228

  

9

%

Other

  

 

31,947

  

 

28,075

  

14

%

  

 

29,524

  

(5

)%

  

94

  

61

  

54

%

  

63

  

(3

)%

   

  

      

      
  
      
    

Total revenues/sales

  

 

787,680

  

 

753,450

  

5

%

  

 

692,191

  

9

%

  

13,784


  

13,563


  

2

%

  

13,161


  

3

%

Electric production fuels expense

  

 

132,492

  

 

120,722

  

10

%

  

 

113,208

  

7

%

                 

Purchased-power expense

  

 

217,209

  

 

217,306

  

 

  

 

146,939

  

48

%

                 
   

  

      

                     

Margin

  

$

437,979

  

$

415,422

  

5

%

  

$

432,044

  

(4

)%

                 
   

  

      

                     

* Reflects the percent change from 2001 to 2002.    ** Reflects the percent change from 2000 to 2001.

Due to the formation of ATC on Jan. 1, 2001, the wheeling expenses from ATC included in electric margin in 2002 and 2001 were offset by equity income (WP&L accounts for its investment in ATC under the equity method), reduced other operation and maintenance expenses and lower depreciation expense, resulting in no significant net income impact due to the formation of ATC. On a comparable basis, electric margin increased $22.6$65 million, or 5%15%, and $13.8 million, or 3%, during 2002 and 2001, respectively. The 2002 increase wasin 2003, primarily due to the implementation of various rate increases during 2003 and 2002, including increased revenues to recover a significant portion of WPL’s increased operating expenses, weather-normalized retail sales growth, the impact of WPL implementing seasonal rates in 2002, continued modest retail customer growth and more favorable weather conditions in 2002 compared to 2001, partially offset by2003 for the sluggish economy. The 2001 increase was primarily due tofirst time, lower purchased-powerpurchased power and fuel costs impacting margin, increased residentialmargins and commercialhigher sales due to more favorable weather conditions in 2001 compared to 2000 and continued retail customer growth.non-retail customers. These items were partially offset by $10lower energy conservation revenues and the impact of milder weather conditions in 2003 compared to 2002.

In April 2003, WPL implemented seasonal electric rates that are designed to result in higher rates for the peak demand period from June 1 through Sept. 30 and lower rates in all other periods during each calendar year. As a result, total annual revenues are not expected to be impacted significantly. However, given the seasonal rates were not yet effective in the first quarter of 2003, the impact of seasonal rates increased the 2003 electric margins by approximately $6 million of income recorded in 2000 for a change in estimate of utility services rendered but unbilled at month-end duecompared to the implementation of a refined estimation process2004 and lower industrial sales, largely due to impacts of a slowing economy.2002 electric margins.

 

Gas Utility Margins—Gas -Gas margins and Dthdekatherm (Dth) sales for WP&LWPL were as follows (in thousands):follows:

 

   

Revenues and Costs


   

Dths Sold


 
   

2002


  

2001


  

*


   

2000


  

**


   

2002


  

2001


  

*


   

2000


  

**


 

Residential

  

$

94,509

  

$

107,673

  

(12

)%

  

$

96,204

  

12

%

  

12,863

  

11,754

  

9

%

  

12,769

  

(8

)%

Commercial

  

 

50,121

  

 

58,658

  

(15

)%

  

 

54,512

  

8

%

  

8,574

  

7,572

  

13

%

  

8,595

  

(12

)%

Industrial

  

 

6,980

  

 

8,907

  

(22

)%

  

 

8,581

  

4

%

  

1,303

  

1,197

  

9

%

  

1,476

  

(19

)%

Transportation/other

  

 

27,481

  

 

31,625

  

(13

)%

  

 

5,855

  

440

%

  

18,572

  

16,866

  

10

%

  

13,680

  

23

%

   

  

      

      
  
      
    

Total revenues/sales

  

 

179,091

  

 

206,863

  

(13

)%

  

 

165,152

  

25

%

  

41,312


  

37,389


  

10

%

  

36,520


  

2

%

Cost of gas sold

  

 

110,119

  

 

153,823

  

(28

)%

  

 

107,131

  

44

%

                 
   

  

      

                     

Margin

  

$

68,972

  

$

53,040

  

30

%

  

$

58,021

  

(9

)%

                 
   

  

      

                     

   Revenues and Costs (in millions)

  Dths Sold (in thousands)

 
   2004

  2003

  *

  2002

  **

  2004

  2003

  *

  2002

  **

 

Residential

  $136.4  $137.1  (1%) $94.5  45% 12,456  12,797  (3%) 12,863  (1%)

Commercial

   76.8   74.6  3%  50.1  49% 8,585  8,539  1% 8,574  —   

Industrial

   8.1   9.6  (16%)  7.0  37% 1,098  1,182  (7%) 1,303  (9%)

Transportation/other

   32.5   51.1  (36%)  27.5  86% 20,684  19,796  4% 18,572  7%
   

  

     

     
  
     
    

Total revenues/sales

   253.8   272.4  (7%)  179.1  52% 42,823  42,314  1% 41,312  2%
                     
  
     
    

Cost of gas sold

   165.8   186.3  (11%)  110.1  69%               
   

  

     

                   

Margins

  $88.0  $86.1  2% $69.0  25%               
   

  

     

                   

* Reflects the percent change from 2001 to 2002.    ** Reflects the percent change from 2000 to 2001.

*Reflects the % change from 2003 to 2004.

**Reflects the % change from 2002 to 2003.

   Actual

   
   2004

  2003

  2002

  Normal

Heating degree days*:

            

Madison

  6,831  7,337  6,929  7,485

*Heating degree days are calculated using a 65 degree base. Normal degree days are calculated using a fixed 30-year average most recently updated in February 2002.

 

Gas margins increased $1.9 million, or 2%, in 2004, primarily due to improved results of $3.5 million from WPL’s performance-based gas commodity cost recovery program (benefits are shared by ratepayers and shareowners), partially offset by lower sales to retail customers due to milder weather conditions in 2004 compared to 2003. Gas revenues and cost of gas sold were unusually highhigher in 20012003 compared to 2002 due to the large increase inincreased natural gas prices in the first half of 2001. Due to WP&L’s rate recovery mechanisms for gas costs, theseprices. These increases alone had little impact on WPL’s gas margin.margins given its rate recovery mechanism for gas costs. Gas

margin margins increased $15.9$17 million, or 30%25%, and decreased $5.0 million, or 9%, during 2002 and 2001, respectively. The 2002 increase was largelyin 2003, primarily due to the implementationimpact of a rate increase inincreases implemented during 2003 and 2002, improved resultsperformance of $2.7 million from WP&L’sWPL’s performance-based gas commodity cost recovery program and continued modest retail customer growth and the negative impact high gas prices in early 2001 had on gas consumption during that period. The 2001 decrease was largely due to lower retail sales primarily related to unusually high gas prices earlier in 2001 as some customers either chose alternative fuel sources or used less natural gas, the impact of the slowing economy and lower results from WP&L’s performance-based commodity cost recovery program.growth.

 

Refer to “Rates and Regulatory Matters” for discussion of various electric and gas rate filings. Refer to Note 1(i)1(h) of the “Notes to Consolidated Financial Statements” for information relating to utility fuel and natural gas cost recovery. Refer

Other Revenues -Other revenues decreased $18 million in 2004 primarily due to Note 2lower construction management revenues from WindConnect, resulting from uncertainty in 2004 regarding the extension of the “Notesfederal renewable energy production tax credit. This decrease was largely offset by lower operating expenses related to Consolidated Financial Statements”this activity. In the fourth quarter of 2004, the federal renewable energy production tax credit was extended for generating facilities that will be placed in service prior to Jan. 1, 2006. Other revenues increased $12 million in 2003, primarily due to increased revenues from WindConnect, which were largely offset by higher operating expenses.

Other Operating Expenses - Other operation and maintenance expenses decreased $11 million in 2004, primarily due to $11 million of lower expenses for WindConnect, lower energy conservation expenses and the impact of comprehensive cost-cutting and operational efficiency efforts. These items were partially offset by increases in employee and retiree benefits (comprised of compensation, medical and pension costs). Depreciation and amortization increased $6.1 million in 2004, primarily due to property additions. Taxes other than income taxes increased $4.7 million in 2004, primarily due to increased gross receipts taxes.

Other operation and maintenance expenses increased $53 million in 2003, largely due to increases in the amortization of deferred costs that are now being recovered in rates, employee and retiree benefits, WindConnect and nuclear expenses. The increased nuclear expenses resulted primarily from a planned refueling outage at Kewaunee in 2003. A similar planned outage occurred in 2004 but there was no refueling outage in 2002. These items were partially offset by lower fossil generation expenses. Depreciation and amortization expense decreased $3.8 million in 2003, primarily due to lower software amortizations, partially offset by property additions.

Refer to “Rates and Regulatory Matters” for discussion of WP&L’sthe interplay between utility operating expenses and utility margins given their impact on WPL’s utility rate filings.activities.

 

Other Operating Expenses—Due to the formation of ATC in 2001, WP&L incurred $10 million of operation and maintenance expenses in 2000 that were not incurred in 2001. On a comparable basis, other operation and maintenance expenses increased $29.2 million and $7.6 million for 2002 and 2001, respectively. The 2002 increase was largely due to higher fossil generation, employee benefit, energy conservation, and energy delivery expenses. The 2001 increase was primarily due to higher nuclear operating costs (partially due to a planned refueling outage at Kewaunee in the fourth quarter of 2001), higher uncollectible customer account balances largely due to the unusually high gas prices earlier in the year and higher other administrative and general costs. These items were partially offset by decreased fossil plant maintenance expenses.

Depreciation and amortization expenses increased $7.1 million and decreased $10.8 million for 2002 and 2001, respectively. The 2002 increase was largely due to higher regulatory and software amortizations. Increased earnings on the nuclear decommissioning trust fund were largely offset by lower decommissioning expense based on reduced retail funding levels. The 2001 decrease was primarily due to the impact of the formation of ATC and decreased earnings on the nuclear decommissioning trust fund, partially offset by increased expense due to property additions. The accounting for earnings on the nuclear decommissioning trust funds results in no net income impact. Interest income is increased for earnings on the trust fund, which is offset in depreciation expense.

Taxes other than income taxes increased $3.3 million for 2001 due to increased gross receipts and payroll taxes.

Interest Expense and Other -Interest expense decreased $3.3$4.4 million in 2002and $2.3 million for 2004 and 2003, respectively, primarily due to lower average interest rates on the outstanding borrowings. Interest income increased $13.5 million and decreased $5.0 million in 2002 and 2001, respectively, due to differences in earnings on the nuclear decommissioning trust fund.borrowings outstanding. Equity income from unconsolidated investments increased $15.0$4.3 million in 2001, largely due to ATC beginning operations on Jan. 1, 2001. Miscellaneous, net income decreased $7.3and $3.7 million in 2002for 2004 and 2003, respectively, primarily due to lower incomehigher earnings at American Transmission Company LLC (ATC) resulting from sales of non-commodity products and services and income realized from weather hedges in 2001.rate increases.

 

Income Taxes-The effective income tax rates were 35.6%36.8%, 35.9%36.4%, and 37.5%35.6% in 2002, 20012004, 2003 and 2000,2002, respectively. Refer to Note 5 of the “Notes to Consolidated Financial Statements” for additional information.

 

LIQUIDITY AND CAPITAL RESOURCES

 

Overview—WP&L’s recent - WPL believes it has a strong liquidity position and future financing activities have been and will be undertaken against a backdropexpects to maintain this position over its planning period of increased market concerns about general economic conditions and corporate governance issues2005 to 2009 as well as risks associated with particular sectors of the economy, including the energy industry. As a result of these factors, capital markets have become more restrictive. The commercial paper market, for example, has become more limited for many companies in terms of the amounts ofits available capitalcapacity under its revolving credit facility and the corresponding maturities. Medium- and long-term debt markets have become sensitive to increased credit ratings volatility and to a heightened perception of liquidity risk in the energy sector. As a result, investors have become more selective and have differentiated among otherwise comparable issuers in a way that has made the financing process more challenging. In response to these changing market conditions, WP&L is working closely with its financial advisors and others to access the capital it needs to operate its business.stable operating cash flows. Based on WP&L’s strongexpected operating cash flows, coupled with actions Alliant Energy expects to take to strengthen its and WP&L’s balance sheet, WP&L currentlyWPL believes it will be able to secure the additional capital it requiresrequired to implement its strategic plan. WP&L anticipates financingplan through the 2005 to 2009 planning period. WPL believes its constructionability to secure additional capital has been enhanced by its actions during the last several years to strengthen its balance sheet as is evidenced by, among other items, WPL’s current debt-to-total capitalization ratio of 33% compared to 43% in early 2002.

Primary Sources and Uses of Cash - WPL’s most significant source of cash is electric and gas sales to its utility customers. Cash from these sales reimburse WPL for prudently incurred expenses to provide service to its utility customers and provides WPL a return on the assets that are utilized to provide such services. Operating cash flows are expected to cover a majority of WPL’s utility maintenance capital expenditures during 2003-2005and dividends paid to Alliant Energy. The capital requirements needed to retire maturing debt and pay capital expenditures associated with building additional generation are expected to be financed largely through external financings and proceeds from asset divestitures, supplemented by internally generated funds supplemented, when necessary, by outside financing.funds.

 

Cash Flows -Selected information from the Consolidated Statements of Cash Flows was as follows (in thousands)millions):

 

  

2002


   

2001


   

2000


   2004

 2003

 2002

 

Cash flows from (used for):

            

Operating activities

  

$ 223,750

 

  

$ 135,886

 

  

$ 174,060

 

  $199.3  $138.5  $223.8 

Investing activities

   (214.3)  (108.4)  (187.8)

Financing activities

  

(27,685

)

  

(19,176

)

  

987

 

   (12.0)  (11.6)  (27.7)

Investing activities

  

(187,795

)

  

(116,832

)

  

(174,880

)

 

Cash Flows From Operating Activities -

Historical Changes in Cash Flows From Operating Activities -In 2002, WP&L’s2004, WPL’s cash flows from operating activities increased $61 million primarily due to changes in working capital;capital caused largely by the timing of tax payments and refunds. In 2003, WPL’s cash flows from operating activities decreased $85 million primarily due to changes in the levels of accounts receivable sold and the timing of tax payments and refunds, partially offset by lower pension plan contributions and the impact of rate increases.

Sale of Accounts Receivable - WPL discontinued its sale of accounts receivable program in 2004. Refer to Note 4 of the “Notes to Consolidated Financial Statements” for additional information.

Cash Flows Used For Investing Activities -

Historical Changes in Cash Flows Used For Investing Activities - In 2004, WPL’s cash flows used for investing activities increased $106 million primarily due to increased levels of construction and acquisition expenditures and the 2003 proceeds from the sale of WPL’s water utility serving the Beloit area. In 2003, WPL’s cash flows used for investing activities decreased $79 million primarily due to proceeds received from the transfersale of WP&L’s transmission assetsWPL’s water utility serving the Beloit area and lower nuclear decommissioning trust fund contributions.

Construction and Acquisition Expenditures - Capital expenditures, investments and financing plans are continually reviewed, approved and updated as part of WPL’s ongoing strategic planning and budgeting processes. In addition, material capital expenditures and investments are subject to ATCa rigorous cross-functional review prior to approval. Changes in 2001.WPL’s anticipated construction and acquisition expenditures may result from a number of reasons including, but not limited to, economic conditions, regulatory requirements, ability to obtain adequate and timely rate relief, the level of WPL’s profitability, WPL’s desire to maintain investment-grade credit ratings and reasonable capitalization ratios, variations in

sales, changing market conditions and new opportunities. WPL currently anticipates construction and acquisition expenditures during 2005 and 2006 as follows (in millions):

   2005

  2006

Transmission (gas only) and distribution (electric and gas)

  $120  $125

Generation (existing plants)

   30   30

Environmental

   30   30

Other miscellaneous utility property (includes gas transmission)

   45   40
   

  

   $225  $225
   

  

WPL has not yet entered into contractual commitments relating to the majority of its anticipated capital expenditures. As a result, WPL does have discretion with regard to the level of capital expenditures eventually incurred and it closely monitors and updates such estimates on an ongoing basis based on numerous economic and other factors. Refer to “Strategic Overview” for a further discussion of WPL’s generation plan as well as an update on WPL’s asset divestitures.

Cash Flows Used For Financing Activities -

Historical Changes in Cash Flows Used For Financing Activities - In 2001, WP&L’s cash flows from operating activities decreased due to changes in working capital;2004, WPL’s cash flows used for financing activities increased slightly in 2004 primarily due to a capital contribution from Alliant Energy in 2003 and higher common stock dividends, paid in 2001 as no dividends were declared in 2000 due to management of WP&L’s capital structure, partiallylargely offset by a capital contribution of $35 million by Alliant Energy and changes in the amount of debt issued and retired;retired. In 2003, WPL’s cash flows used for investingfinancing activities decreased in 2001$16 million primarily due to proceeds receiveda higher capital contribution from the transfer of WP&L’s transmission assets to ATC.

Common Equity—The PSCW has indicated it will require an additional equity infusion by Alliant Energy into WP&L during 2003. WP&L anticipates the final PSCW order, which is expectedin 2003 compared to be issued2002, partially offset by changes in the second quarter of 2003, will also include a customer refund provision if the timing and/or amount of the equity infusion differs from the assumptions included in the WP&L rate case.debt issued and retired.

 

Debt—Alliant Energy discontinued the useFinancing Authorizations - WPL has state regulatory agency financing authorization for short-term borrowings of $240 million, $185 million for general corporate purposes and an additional $55 million should WPL repurchase its utility money pool in 2002 and WP&Lvariable rate demand bonds. Issuance of debt securities by WPL is now meeting any short-term borrowing needs by issuing commercial paper.exempt from regulation under provisions of PUHCA.

 

WP&LShelf Registrations - In 2004, WPL filed a shelf registration with the Securities and Exchange Commission, which allows WPL flexibility to offer from time to time up to an aggregate of $150 million of its preferred stock, senior unsecured debt securities and first mortgage bonds. WPL had $50 million remaining available under its shelf registration as of Dec. 31, 2004.

Common Stock Dividends - In its December 2003 rate order, the PSCW stated WPL may not pay annual common stock dividends, including pass-through of subsidiary dividends, in excess of $89 million to Alliant Energy if WPL’s actual average common equity ratio, on a regulatory financial basis, is party to various credit facilities and other borrowing arrangements, someor will fall below the authorized level of which54.01%. WPL’s dividends are summarized below. In additionalso restricted to the specific covenants detailed below underextent that such dividend would reduce the 364-day revolving credit agreement, WP&L’s facilitiescommon stock equity ratio to less than 25%. WPL has common stock dividend payment restrictions based on its bond indentures and borrowing arrangements contain various customarythe terms and conditions, including required capitalization, net worth and interest coverage requirements, maintenance requirements related to bonded property and cross-default provisions.of its outstanding preferred stock. At Dec. 31, 2002, WP&L2004, WPL was in compliance with the financial ratios and covenant requirements under its credit facilities and borrowing arrangements.all such dividend restrictions.

 

Long-term Debt-In October 2002, WP&LAugust 2004, WPL issued $100 million of 6.25% senior debentures due 2034 and used the proceeds to repay short-term debt, including $62 million incurred in connection with the repayment at maturity of 7.75% first mortgage bonds in June 2004, and for general corporate purposes. Refer to “Certain Financial Commitments - Contractual Obligations” for the timing of WPL’s long-term debt maturities. Refer to Note 8 of the “Notes to Consolidated Financial Statements” for additional information on short- and long-term debt.

Short-term Debt - In July 2004, WPL completed the syndication of a 364-day$250 million revolving credit facility totaling $150 million,(facility) which supports commercial paper and is available for direct borrowing orborrowings. This facility is designed to support commercial paper. The new creditbe a five-year facility agreement contains various covenants, including a debt-to-capital ratio of less than 58%. At Dec. 31, 2002, WP&L’s debt-to-capital ratio was 40.7%.

The debt componentwith the length of the capital ratio includes long- and short-term debt (excluding trade payables), capital lease obligations, letters of credit and guarantees offacility subject to various regulatory approvals given the foregoing and unfunded vested benefits under pension plans. The equity component excludes accumulated other comprehensive income (loss).

At Dec. 31, 2002, WP&L had $60 million of commercial paper outstanding, withterm is longer than a weighted average maturity of 34 days and discount rate of 1.6%. There were no bank facility borrowings at Dec. 31, 2002.

364-day facility. WPL expects to receive the remaining regulatory approvals in 2005. In addition to funding working capital needs, the availability of short-term financing provides WP&LWPL flexibility in the issuance of long-term securities. The level of short-term borrowing fluctuates based on seasonal corporate needs, the timing of long-term financingfinancings and capital market conditions. Information regarding commercial paper at Dec. 31, 2004 was as follows (dollars in millions):

Amount outstanding

  $47 

Weighted average maturity

   3 days 

Discount rate

   2.25%

Available capacity

  $193*

*WPL’s capacity is limited to $240 million due to a PSCW regulatory restriction.

Creditworthiness -

Credit Facilities -WPL’s credit facility agreement contains a covenant requiring a debt-to capital ratio of less than 58%. At Dec. 31, 2002, WP&L2004, WPL’s debt-to-capital ratio was authorized by34%. The debt component of the capital ratio includes, where applicable, federal or state regulatory agencies to issuelong- and short-term debt (excluding non-recourse debt and trade payables), capital lease obligations, letters of $240 million, which includes $85 million for general corporate purposes, an additional $100 million should it no longer sell its utility receivablescredit and an additional $55 million should it need to repurchase its variable rate demand bonds.guarantees of the foregoing and unfunded vested benefits under qualified pension plans. The equity component excludes accumulated other comprehensive income (loss).

 

At Dec. 31, 2002, WP&L had $255 millionWPL’s credit facility contains a negative pledge provision, which generally prohibits placing liens on any of long-term debt that will mature prior to Dec. 31, 2007. Depending upon market conditions, it is currently anticipated that a majority of the maturing debt will be refinancedWPL’s property with certain exceptions, including among others, for the issuance of long-term securities.secured debt under WPL’s first mortgage bond indentures, non-recourse project financing and purchase money liens.

 

ReferWPL’s credit facility contains a material adverse change (MAC) clause. Before each extension of credit (each borrowing under the facility), unless the borrowing will be used exclusively to Note 8repurchase commercial paper issued by or on behalf of WPL, WPL must represent and warrant that no MAC has occurred since Dec. 31, 2003. A MAC is defined as a change that would create: (1) a MAC in, or a material adverse effect upon, the operations, business, properties, liabilities (actual or contingent), condition (financial or otherwise) or prospects of the “Notesborrower or the borrower and its subsidiaries taken as a whole; (2) a material impairment of the ability of the borrower to Consolidated Financial Statements” for additional information on short- and long-term debt.perform its obligations under a credit facility agreement to which it is a party; or (3) a MAC upon the legality, validity, binding effect or enforceability against the borrower of the credit agreement to which it is a party.

 

WPL’s credit facility contains a provision that requires, during the term of the facility, any proceeds from asset sales, with certain exclusions, in excess of 20% of WPL’s consolidated assets be used to reduce commitments under its facility. Exclusions include, among others, certain sale and lease-back transactions, and any potential sales of WPL’s nuclear assets.

Credit Ratings and Balance Sheet -Access to the long- and short-term capital and credit markets, and costs of obtaining external financing, are dependent on creditworthiness. WP&LWPL is committed to taking the necessary steps required to maintain stronginvestment-grade credit ratings and a strong balance sheet. Although WPL believes the actions taken in recent years to strengthen its balance sheet.sheet will enable it to maintain investment-grade credit ratings, no assurance can be given that it will be able to maintain its existing credit ratings. If WP&L’sWPL’s credit ratings are downgraded in the future, then WP&L’sWPL’s borrowing costs may increase and its access to capital markets may be limited. If access to capital markets becomes significantly constrained, then WP&L’sWPL’s results of operations and financial condition could be materially adversely affected. In December 2002WPL’s current credit ratings and January 2003, Standard & Poor’s and Moody’s, respectively, issued revised credit ratingsoutlook are as follows (long-term debt ratings only apply to senior debt):

 

   

Standard & Poor’s
Rating Services



  

Moody’s
Investors Service



Secured long-term debt

  

A

A-
  

A1

Unsecured long-term debt

  

BBB+

  

A2

Commercial paper

  A-2P-1

A-2Corporate/issuer

  

P-1

Corporate

A-
  

A-

A2

Outlook

  

Negative

  

Stable

 

Ratings Triggers -The long-term debt of WP&LWPL is not subject to any repayment requirements as a result of explicit credit rating downgrades or so-called “ratings triggers.” However, certain lease agreements do contain such ratings triggers. The threshold for these triggers varies among the applicable leases. In addition, the amount of proceeds available to WP&L from its sale of utility customer accounts receivable program could be reduced in the event of certain credit rating downgrades at the Alliant Energy parent company level. WP&LWPL is also party to various agreements, including purchased-powerpurchased power agreements and fuel contracts that may be deemed to be in default in the event of certainare dependent on maintaining investment-grade credit rating downgrades.ratings. In the event of a downgrade below investment-grade, WPL may need to provide credit support, such a default, WP&L may be able to cure the default in a number of ways, including postingas letters of credit or cash collateral equal to the amount of the exposure, unwindingor may need to unwind the contract or payingpay the underlying obligation. In the event of a downgrade below investment-grade, management believes WPL’s credit facility would provide sufficient liquidity to cover counterparty credit support or collateral requirements under the various purchased power and fuel sales agreements.

 

Sale of Accounts Receivable—Refer to Note 4 of the “Notes to Consolidated Financial Statements” for information on WP&L’s sale of accounts receivable program.

Off-Balance Sheet Arrangements—WP&L - WPL utilizes off-balance sheet synthetic operating leases to finance certain utility railcars and a utility radio dispatch system. Synthetic leases provide favorable financing rates to WP&LWPL while allowing it to maintain operating control of its leased assets. SeveralRefer to Note 3 of WP&L’s synthetic leases involve the use of unconsolidated structured finance or variable interest entities. WP&L has guarantees outstanding related“Notes to theConsolidated Financial Statements” for future minimum lease payments under, and residual value guarantees by WPL, of these synthetic leases. WP&L does not currently anticipateWPL’s credit facility agreement prohibits it from entering into any additional synthetic leases. WP&L also uses variable interestWPL has reviewed the lessor entities forduring its utility saleimplementation of accounts receivable program whereby WP&L uses proceeds from the salerevised Financial Accounting Standards Board Interpretation No. 46, “Consolidation of Variable Interest Entities,” (FIN 46R), and determined that consolidation of these entities is not required. Refer to Note 18 of the accounts receivable and unbilled revenues“Notes to maintain flexibility in its capital structure, take advantage of favorable short-term interest rates and finance a portion of its long-term cash needs. The sale of accounts receivable generates a significant amount of short-term financingConsolidated Financial Statements” for WP&L. If this financing alternative were not available, WP&L anticipates it would have enough short-term borrowing capacity to compensate. Refer to “Ratings Triggers” foradditional information regarding the impact of credit rating downgrades on WP&L related to these synthetic leases and accounts receivable sales program.

Beginning in the third quarter of 2003, under FIN 46 it is reasonably possible that WP&L could be considered the primary beneficiary of certain variable interest entities utilized for its synthetic lease financings and receivable sales program and could be required to consolidate the operating results and associated assets and liabilities of the variable interest entities in its financial statements. WP&L is in the process of evaluating the potential impactsimplementation of FIN 46. WP&L is also currently evaluating the structure of its synthetic leases and receivable sales program to determine if these structures can be modified to qualify for off-balance sheet treatment under FIN 46.

Contractual Obligations—WP&L’s long-term contractual cash obligations as of Dec. 31, 2002 were as follows (in millions):46R.

   

2003


  

2004


  

2005


  

2006


  

2007


  

Thereafter


  

Total


Long-term debt (Note 8)

  

$—  

  

$62

  

$88

  

$—  

  

$105

  

$269

  

$524

Operating leases (Note 3)

  

27

  

61

  

75

  

   76

  

76

  

335

  

650

Purchase obligations (Note 11(b))

  

   86

  

47

  

26

  

15

  

15

  

27

  

216

   
  
  
  
  
  
  
   

$113

  

$170

  

$189

  

$91

  

$196

  

$631

  

$1,390

   
  
  
  
  
  
  

At Dec. 31, 2002, long-term debt as noted in the previous table was included on the Consolidated Balance Sheets. In addition, at Dec. 31, 2002, there were various other long-term liabilities and deferred credits included on the Consolidated Balance Sheets that, due to the nature of the liabilities, the timing of payments cannot be estimated and are therefore excludedCredit Risk - WPL has limited credit exposure from the tables. Operating leases and purchase obligations are amounts committed under contract which were not recorded on the Consolidated Balance Sheets at Dec. 31, 2002, in accordance with GAAP. Purchase obligations represent normal business contracts used to ensure adequate purchased-power, coalelectric and natural gas suppliessales and to minimize exposure to market price fluctuations.In connection with WP&L’s construction and acquisition program, WP&L also enters into commitments related to such program on an ongoing basis.

Credit Risk—Credit risk is inherent in WP&L’s operations and relates to the risk of loss resulting from non-performance of contractual obligations by a counterparty. WP&Lits counterparties. WPL maintains credit risk oversight and sets limits and policies with regards to its counterparties, which management believes minimizes its overall credit risk exposure. However, there is no assurance that such policies will protect WP&LWPL against all losses from non-performance by counterparties.

 

Certain Financial Commitments -

Contractual Obligations - WPL’s long-term contractual cash obligations as of Dec. 31, 2004 were as follows (in millions):

   2005

  2006

  2007

  2008

  2009

  Thereafter

  Total

Long-term debt maturities (Note 8(b))

  $88  $—    $105  $60  $—    $239  $492

Interest - long-term debt obligations

   31   26   22   18   15   165   277

Operating leases (Note 3)

   79   80   80   68   61   191   559

Purchase obligations (Note 11(b)):

                            

Purchased power and fuel commitments

   128   61   32   25   25   65   336

Other

   9   —     —     —     —     —     9
   

  

  

  

  

  

  

   $335  $167  $239  $171  $101  $660  $1,673
   

  

  

  

  

  

  

At Dec. 31, 2004, long-term debt as noted in the previous table was included on the Consolidated Balance Sheet. Included in WPL’s long-term debt obligations was variable rate debt of $55 million, which represented 11% of total long-term debt outstanding. The long-term debt amounts exclude reductions related to unamortized debt discounts. Interest on variable rate debt in the previous table was calculated using rates as of Dec. 31, 2004. Purchased power and fuel commitments represent normal business contracts used to ensure adequate purchased power, coal and natural gas supplies and to minimize exposure to market price fluctuations. Alliant Energy has entered into various purchased power commitments that have not yet been directly assigned to IPL and WPL. Such commitments are not included in the WPL purchase obligations. Other purchase obligations represent individual commitments incurred during the normal course of business which exceeded $1.0 million at Dec. 31, 2004. In connection with its construction and acquisition program, WPL also enters into commitments related to such program on an ongoing basis which are not reflected in the previous table. Refer to “Cash Flows Used For Investing Activities - Construction and Acquisition Expenditures” for additional information. In addition, at Dec. 31, 2004, there were various other long-term liabilities and deferred credits included on the Consolidated Balance Sheet that, due to the nature of the liabilities, the timing of payments cannot be estimated and are therefore excluded from the table. Refer to Note 6 of the “Notes to Consolidated Financial Statements” for anticipated pension and other postretirement benefit funding amounts, which are not included in the previous table.

Environmental—WP&L’s- WPL’s pollution abatement programs are subject to continuing review and are periodically revised due to changes in environmental regulations, construction plans and escalation of construction costs. While management cannot precisely forecastWPL continually evaluates the effectimpact of potential future environmental regulations on operations, it has taken steps to anticipate the future while also meeting the requirements of current environmental regulations.

WP&L’s facilities are subject tofederal, state and federal requirementslocal environmental rulemakings on its operations. While the final outcome of the CAA, including meeting ambient air quality standards. As a result of a new rate-of-progressthese rule developed by the Wisconsin DNR, and based on existing technology, WP&L estimates the total aggregatemakings cannot be predicted, WPL believes that required capital investments necessary to comply withand/or modifications resulting from them could be significant, but expects that prudent expenses incurred by WPL likely would be recovered in rates from its customers. The environmental rulemaking process continually evolves and the new rules will be approximately $19 million in 2003 through 2007. WP&L is also currently addressing various other potential federal and state environmental rulemakings and activities, including: 1) proposed revisions to the Wisconsin Administrative Code concerning the amount of heatfollowing are major emerging issues that WP&L’s generating stations can discharge into Wisconsin waters which could potentially have a significant impact on WP&L’s operation of its Wisconsin generating facilities; 2) potential new rules that may be pursued by the EPA and the states in the WP&L service territory relatedWPL’s operations.

Air Quality - WPL previously responded confidentially to various air emissions; 3) the multiple data requests WP&L has received from the EPAU.S. Environmental Protection Agency (EPA) related to the historical operation of WP&L’sand associated air permitting for certain major Wisconsin coal-fired generating units, which requestsunits. In September 2004, WPL was notified by the EPA that a third party had requested WPL’s response materials. After review of such records, WPL determined that the information would no longer be claimed as confidential. There have been instances where citizen groups have pursued claims against utilities for alleged air permitting violations. WPL has not received any such actions to date and is unable to predict further actions, if any, from the precursorinformation requests from the EPA or third parties.

The 1990 Clean Air Act Amendments mandate preservation of air quality through existing regulations and periodic reviews to penaltiesensure adequacy of these provisions based on scientific data. In 1997, the EPA revised National Ambient Air Quality Standards (NAAQS) for ozone and additionalfine particulate matter. In 2003, the EPA proposed the Clean Air Interstate Rule that would require emission control upgrades to existing power plants. This rule would reduce the current level of power plant sulfur dioxide emissions approximately 40% by 2010 and 70% by 2015, and nitrogen oxide emission levels 50% by 2010 and 65% by 2015. Additional reduction requirements may also be imposed at the state level for those areas that are in non-attainment with NAAQS. WPL believes that the required capital investments and/or modifications resulting from these proposed regulations could be significant.

In 2000, the EPA determined that regulation of hazardous air pollutant emissions from coal and oil-fired electric utility steam generating units was necessary. Under an existing settlement agreement, final utility Maximum Achievable Control Technology (MACT) requirements or alternative regulations must be issued by March 15, 2005. Accordingly, the EPA has published proposed rules requiring control of mercury from coal-fired and nickel from oil-fired generating units. The impact of these regulations on WPL’s generating facilities is subject to the control level mandated in some cases involving similar requeststhe final rules. The Wisconsin Department of Natural Resources (DNR) also independently developed mercury control rules, which became effective in October 2004 for Wisconsin generating facilities, that cap emissions beginning in 2008, followed by subsequent reductions of 40% by 2010 and 75% by 2015. The Wisconsin mercury rule requirements will be superseded by federal mercury emissions standards when published. WPL has begun fuel sampling and will conduct stack testing in 2005 to support the compliance requirements for Wisconsin mercury rules. WPL continues to closely monitor the developments at the federal level related to mercury emissions standards and believes that required capital investments and/or modifications resulting from these rules could be significant.

WPL is also currently monitoring various other electric generating facilities; 4) thepotential federal, state and local environmental rulemakings and activities, including, but not limited to: litigation of federal New Source Review reforms published by the EPA in December 2002; 5)Reforms; Regional Haze evaluations for Best Available Retrofit Technology; and several other legislative and regulatory proposals regarding the control of emissions of air pollutants and greenhouse gases from a variety of sources, including generating facilities;facilities.

Water Quality - The EPA regulation under the Clean Water Act referred to as “316(b)” became effective in September 2004. This regulation requires existing large power plants with cooling water intake structures to apply technology to minimize adverse environmental impacts to fish and 6)other aquatic life. WPL is currently studying such impacts and will have compliance plans in place by the July 2002required date of January 2008. WPL is investigating compliance options and is unable to predict the final outcome, but believes that required capital investments and/or modifications resulting from this regulation could be significant.

WPL is also currently evaluating proposed revisions to the Wisconsin Administrative Code concerning the amount of heat that WPL’s generating stations can discharge into Wisconsin waters. At this time, WPL is unable to predict the final outcome, but believes that required capital investments and/or modifications resulting from this regulation could be significant.

In October 2004, FERC issued an order regarding one of WPL’s hydroelectric project licenses to require WPL to develop a detailed engineering and biological evaluation of potential fish passage alternatives within one year and to install within three years agency-approved fish-protective devices and fish passages. Accordingly, these provisions are now effective and WPL is in the process of working with the appropriate federal and state agencies to comply with these provisions and research solutions. WPL is currently unable to predict the final outcome, but believes that required capital investments and/or modifications resulting from this issue could be significant.

Land and Solid Waste - In 2003, at the request fromof the Wisconsin DNR, that WP&L submitWPL submitted a written plan for facility closure of the Rock River Generating Station landfill and clean-up of itsthe support ponds and all areas where coal combustion waste is present. WP&L cannot presentlyRemoval of ash from half of the remediation area to the landfill was completed in 2004. The remaining targeted ash will be moved to the landfill in 2005 and the landfill will be capped in 2006, with an insignificant total project cost.

WPL is also monitoring various other land and solid waste regulatory changes. This includes a potential EPA regulation for management of coal combustion product in landfills and surface impoundments that could require installation of monitoring wells at some facilities and an ongoing expanded groundwater monitoring program. Compliance with the polychlorinated biphenols (PCB) Fix-it Rule/Persistent Organic Pollutants Treaty could possibly require replacement of all electrical equipment containing PCB insulating fluid which is a substance known to be harmful to human health. The Wisconsin Department of Commerce is proposing new rules related to flammable, combustible and hazardous liquids stored in above-ground storage tanks in which the primary financial impact would be from a secondary containment requirement for all hazardous materials tanks and for hazardous material unloading areas. WPL is unable to predict the final outcome of these proposals or actions,possible regulatory changes at this time, but believes that the required capital investmentsinvestment and/or modifications resulting from themthese potential regulations could be significant. WP&L believes that prudent expenses incurred by it likely would be recovered in rates from its customers.

Refer to Note 11(e) of the “Notes to Consolidated Financial Statements” and “Construction and Acquisition Expenditures” for further discussion of environmental matters.

Construction and Acquisition Expenditures—Capital expenditures, investments and financing plans are continually reviewed, approved and updated as part of WP&L’s ongoing strategic planning and annual budgeting processes. In addition, material capital expenditures and investments are subject to a rigorous cross-functional review prior to approval. Changes in WP&L’s anticipated construction and acquisition expenditures may result from a number of reasons including economic conditions, regulatory requirements, ability to obtain adequate and timely rate relief, the level of WP&L’s profitability, WP&L’s desire to maintain strong credit ratings and reasonable capitalization ratios, variations in sales, changing market conditions and new opportunities. WP&L believes its capital control processes adequately reduce the risks associated with large capital expenditures and investments.

WP&L currently anticipates construction and acquisition expenditures for utility infrastructure and reliability investments to be $160 million in 2003 and $410 million in 2004-2005. WP&L has not entered into contractual commitments relating to the majority of its anticipated capital expenditures. As a result, WP&L does have discretion as to the eventual level of capital expenditures incurred and it closely monitors and updates such estimates on an ongoing basis based on numerous economic and other factors.

OTHER MATTERS

 

Market Risk Sensitive Instruments and Positions—WP&L’s- WPL’s primary market risk exposures are associated with interest rates and commodity and equity prices. WP&LWPL has risk management policies to monitor and assist in controlling these market risks and uses derivative instruments to manage some of the exposures. Refer to Notes 1(j) and 10 of the “Notes to Consolidated Financial Statements” for further discussion of WPL’s derivative financial instruments.

 

Interest Rate Risk -WP&L WPL is exposed to risk resulting from changes in interest rates as a result of its issuance of variable-rate debt utility customer accounts receivable sale program and variable-rate leasing agreements. WP&LWPL manages its interest rate risk by limiting its variable interest rate exposure and by continuously monitoring the effects of market changes on interest rates. WP&L has also historically used interest rate swap and interest rate forward agreements to assist in the management of its interest exposure. In the event of significant interest rate fluctuations, management would take actions to minimize the effect of such changes on WP&L’sWPL’s results of operations and financial condition. Assuming no change in WP&L’sWPL’s consolidated financial structure, if variable interest rates were to average 100 basis points higher (lower) in 20032005 than in 2002, interest2004, expense and pre-tax earnings would increase (decrease) by approximately $2.5$1.2 million. These amounts wereThis amount was determined by considering the impact of a hypothetical 100 basis point increase (decrease) in interest rates on WP&L’sWPL’s consolidated variable-rate debt held the amount outstanding under the utility customer accounts receivable sale program and variable-rate lease balances at Dec. 31, 2002.2004.

 

Commodity Risk—Non-trading—Price RiskWP&L- WPL is exposed to the impact of market fluctuations in the commodity price and transportation costs of electricityelectric and natural gas products it procures and markets. WP&LWPL employs established policies and procedures to manage its risks associated with these market fluctuations including the use of various commodity derivatives. WP&L’sWPL’s exposure to commodity price risks is also significantly mitigated by the current rate making structures in place for the recovery of its electric fuel and purchased energy costs as well as its cost of natural gas purchased for resale.

Under PSCW rules, WPL can seek rate increases for increases in the cost of electric fuel and purchased power if it experiences an increase in costs that are more than 3% higher than the estimated costs used to establish rates. Such rules significantly reduce commodity risk for WPL by reducing the regulatory lag related to the timing of changes in rates for increased fuel and purchased energy costs. WPL’s retail gas tariffs provide for subsequent adjustments to its natural gas rates for changes in the current monthly natural gas commodity price index. Also, WPL has a gas performance incentive which includes a sharing mechanism whereby 50% of all gains and losses relative to current commodity prices, as well as other benchmarks, are retained by WPL, with the remainder refunded to or recovered from customers. Such rate mechanisms combined with commodity derivatives discussed above significantly reduce commodity risk associated with WPL’s cost of natural gas. Refer to Note 1(i)1(h) of the “Notes to Consolidated Financial Statements” for further discussion.

WP&L periodically utilizes gas commodity derivative instruments to reduce the impact of price fluctuations on gas purchased and injected into storage during the summer months and withdrawn and sold at current market prices during the winter months. The gas commodity swaps in place approximate the forecasted storage withdrawal plan during this period. Therefore, market price fluctuations that result in an increase or decrease in the value of the physical commodity are substantially offset by changes in the value of the gas commodity swaps. To the extent actual storage withdrawals vary from forecasted withdrawals, WP&L has physical commodity price exposure. A 10% increase (decrease) in the price of gas would not have a significant impact on the combined fair market value of the gas in storage and related swap arrangements in place at Dec. 31, 2002.

 

Equity Price Risk—Risk -WP&L WPL maintains a trust fund to fund itsthe anticipated nuclear decommissioning costs.costs of Kewaunee. At Dec. 31, 2002 and 2001,2004, this fund was invested primarily in domestic equity and debt instruments.instruments and money market funds. Fluctuations in equity prices or interest rates willdo not affect WP&L’sWPL’s consolidated results of operations as such fluctuations are recorded in equally offsetting amountsoperations. In 2004, WPL liquidated all of investment income and depreciation when they are realized. In 2001, WP&L entered into a four-year hedge on equity assets in its nuclearqualified decommissioning trust fund.fund assets into money market funds as a result of the proposed Kewaunee sale. Refer to Note 10(c)Notes 9 and 16 of the “Notes to Consolidated Financial Statements” for further discussion. Refer to Notes 1(l)“Critical Accounting Policies - Accounting for Pensions and 10Other Postretirement Benefits” for the impact on WPL’s pension and other postretirement benefit costs of changes in the “Notes to Consolidated Financial Statements” for further discussionrate of WP&L’s derivative financial instruments.returns earned by its plan assets, which include equity securities.

 

Accounting Pronouncements—In November 2002, the FASB issued FIN 45 which requires disclosures by a guarantor about its obligations under certain guarantees that it has issued. FIN 45 also requires recognizing, at the inception of a guarantee, a liability for the fair value of the obligation undertaken in issuing the guarantee. The recognition and measurement provisions of FIN 45 are effective on a prospective basis for guarantees issued or modified after Dec. 31, 2002. The disclosure requirements of FIN 45 are effective for financial statements of interim or annual periods ending after Dec. 15, 2002. WP&L- WPL does not anticipate FIN 45 willexpect the various new accounting pronouncements that were effective in 2004 to have a material impact on its financial condition or results of operations. Refer to Note 11(d) of the “Notes to Consolidated Financial Statements” for additional information on guarantees.

In January 2003, the FASB issued FIN 46 which addresses consolidation by business enterprises of variable interest entities. FIN 46 requires consolidation where there is a controlling financial interest in a variable interest entity or where the variable interest entity does not have sufficient equity at risk to finance its activities without additional subordinated financial support from other parties. WP&L will apply the provisions of FIN 46 prospectively for all variable interest entities created after

Jan. 31, 2003. For variable interest entities created before Jan. 31, 2003, WP&L will be required to consolidate all entities in which it is a primary beneficiary beginning in the third quarter of 2003. It is reasonably possible the implementation of FIN 46 will require that certain variable interest entities be included on the Consolidated Balance Sheets. Refer to Notes 3 and 4 of the “Notes to Consolidated Financial Statements” for additional information on variable interest entities related to synthetic leases and the utility customer accounts receivable sale program, respectively.

SFAS 143, which provides accounting and disclosure requirements for retirement obligations associated with long-lived assets, was effective Jan. 1, 2003. SFAS 143 requires that the present value of retirement costs for which WP&L has a legal obligation be recorded as liabilities with an equivalent amount added to the asset cost. The liability is accreted to its present value each period and the capitalized cost is depreciated over the useful life of the related asset. Upon settlement of the liability, an entity settles the obligation for its recorded amount or incurs a gain or loss. The adoption of SFAS 143 will have no impact on WP&L’s earnings, as the effects will be offset by the establishment of regulatory assets or liabilities pursuant to SFAS 71, “Accounting for the Effects of Certain Types of Regulation.”

WP&L has completed a detailed assessment of the specific applicability and implications of SFAS 143. The scope of SFAS 143 as it relates to WP&L primarily includes decommissioning costs for Kewaunee. It also applies to a smaller extent to several other assets including, but not limited to, active ash landfills, water intake facilities, underground storage tanks, groundwater wells, transmission and distribution equipment, easements, leases and the dismantlement of certain hydro facilities. Other than Kewaunee, WP&L’s asset retirement obligations as of Jan. 1, 2003 are not significant.

Prior to January 2003, WP&L recorded nuclear decommissioning charges in accumulated depreciation on its Consolidated Balance Sheets. Upon adoption of SFAS 143, WP&L will reverse approximately $175 million, previously recorded in accumulated depreciation and will record liabilities of approximately $175 million. The difference between amounts previously recorded and the net SFAS 143 liability will be deferred as a regulatory asset and is expected to approximate $0 for WP&L.

WP&L has previously recognized removal costs as a component of depreciation expense and accumulated depreciation for other non-nuclear assets in accordance with regulatory rate recovery. As of Dec. 31, 2002, WP&L estimates that it has approximately $150 million of such regulatory liabilities recorded in “Accumulated depreciation” on its Consolidated Balance Sheets.

In 2001, the FASB issued SFAS 144, “Accounting for the Impairment or Disposal of Long-Lived Assets” which replaced SFAS 121, “Accounting for the Impairment of Long-Lived Assets and for Long-Lived Assets to Be Disposed Of.” SFAS 144 also applies to discontinued operations. SFAS 144 requires that those long-lived assets classified as held for sale be measured at the lower of their carrying amount or the fair value less cost to sell, and that no depreciation, depletion and amortization shall be recorded while an asset is classified as held for sale. Discontinued operations are no longer measured at net realizable value or include amounts for operating losses that have not yet occurred. SFAS 144 also broadens the reporting of discontinued operations to include all components of an entity with operations that can be distinguished from the rest of the entity and that will be eliminated from the ongoing operations of the entity in a planned disposal transaction that is probable of being completed within one year. If the criteria to classify operations as held for sale are subsequently no longer met, the assets classified as held for sale shall be reclassified as held and used in the period the held for sale criteria are no longer met. WP&L adopted SFAS 144 on Jan. 1, 2002.

WP&L does not expect the various other new accounting pronouncements not mentioned above that were effective in 2002 to have a material impact on WP&L’s results of operations or financial condition.

 

Critical Accounting Policies-Based on historical experience and various other factors, WP&LWPL believes the following policies identified below are critical to its business and the understanding of its results of operations as they require critical estimates be made based on the assumptions and judgment of management. The preparation of consolidated financial statements requires management to make various estimates and assumptions that affect revenues, expenses, assets, liabilities and the disclosure of contingencies. The results of these estimates and judgments form the basis for making judgments about the carrying values of assets and liabilities that are not readily apparent from other sources. Actual results may differ from these estimates and judgments. WP&L’sWPL’s management has discussed these critical accounting policies with the Audit Committee of its Board of Directors. Refer to Note 1 of the “Notes to Consolidated Financial Statements” for a discussion of WP&L’sWPL’s accounting policies and the estimates and assumptions used in the preparation of the consolidated financial statements.

Regulatory Assets and Liabilities—LiabilitiesWP&L- WPL is regulated by various federal and state regulatory agencies. As a result, WP&Lit qualifies for the application of Statement of Financial Accounting Standards (SFAS) 71, “Accounting for the Effects of Certain Types of Regulation” (SFAS 71). SFAS 71 which recognizes that the actions of a regulator can provide reasonable assurance of the existence of an asset or liability. Regulatory assets or liabilities arise as a result of a difference between GAAPaccounting principles generally accepted in the U.S. and the accounting principles imposed by the regulatory agencies. Regulatory assets generally represent incurred costs that have been deferred as they are probable of recovery in customer rates. Regulatory liabilities generally represent obligations to make refunds to customers for various reasons.

 

WP&LWPL recognizes regulatory assets and liabilities in accordance with the rulings of its federal and state regulators and future regulatory rulings may impact the carrying value and accounting treatment of WP&L’sWPL’s regulatory assets and liabilities. WP&LWPL periodically assesses whether the regulatory assets are probable of future recovery by considering factors such as regulatory environment changes, recent rate orders issued by the applicable regulatory agencies and the status of any pending or potential deregulation legislation. The assumptions and judgments used by regulatory authorities continue to have an impact on the recovery of costs, the rate of return on invested capital and the timing and amount of assets to be recovered by rates. A change in these assumptions may result in a material impact on WP&L’sWPL’s results of operations. Refer to Note 1(c) of the “Notes to Consolidated Financial Statements” for further discussion.

 

Asset Valuations—

Investments—The Consolidated Balance Sheets include investments in available-for-sale securities accounted for in accordance with SFAS 115. WP&L monitors any unrealized losses from such investments to determine if the loss is considered to be a temporary or permanent decline. The determination as to whether the investment is temporarily versus permanently impaired requires considerable judgment. When the investment is considered permanently impaired, the previously recorded unrealized loss would be recorded directly to the income statement as a realized loss. The Consolidated Balance Sheets also contain various other investments that are evaluated for recoverability when indicators of impairment may exist.

Derivative Financial Instruments—WP&L uses derivative financial instruments to hedge exposures to fluctuations in interest rates, certain commodity prices, volatility in a portion of natural gas sales volumes due to weather and to mitigate the equity price volatility associated with certain investments in equity securities. WP&L does not use such instruments for speculative purposes. To account for these derivative instruments in accordance with the applicable accounting rules, WP&L must determine the fair value of its derivatives. In accordance with SFAS 133, the fair value of all derivative instruments are recognized as either assets or liabilities in the balance sheet with the changes in their value recognized in earnings for the non-regulated businesses, unless specific hedge accounting criteria are met. For WP&L, changes in the derivatives fair values are generally recorded as regulatory assets or liabilities. If an established, quoted market exists for the underlying commodity of the derivative instrument, WP&L uses the quoted market price to value the derivative instrument. For other derivatives, WP&L estimates the value based upon other quoted prices or acceptable valuation methods. WP&L also reviews the nature of its contracts for the purchase and sale of non-financial assets to assess whether the contracts meet the definition of a derivative and the requirements to follow hedge accounting as allowed by the applicable accounting rules. The determination of derivative status and valuations involves considerable judgment. Based on the fuel and natural gas cost recovery mechanisms in place, as well as other specific regulatory authorizations, changes in fair market values of derivatives generally have no impact on WP&L’s results of operations.

Unbilled Revenues -Energy sales to individual customers are based on the reading of their meters, which occurs on a systematic basis throughout the month. At the end of each month, amounts of energy delivered to customers since the date of the last meter reading are estimated and the corresponding estimated unbilled revenue is recorded. The unbilled revenue estimate is based on daily generationsystem demand volumes, estimated customer usage by class, weather impacts, line losses and the most recent customer rates. Such process involves the use of various estimates, thus significant changes in the estimates could have a material impact on WP&L’sWPL’s results of operations.

 

Accounting for Pensions—Pensions and Other Postretirement BenefitsWP&L- WPL accounts for pensions and other postretirement benefits under SFAS 87, “Employers’ Accounting for Pensions.Pensions, and SFAS 106, “Employers’ Accounting for Postretirement Benefits Other Than Pensions,” respectively. Under these rules, certain assumptions are made which represent significant estimates. There are many factors involved in determining an entity’s pension and other postretirement liabilities and costs each period including assumptions regarding employee demographics (including age, life expectancies, and compensation levels), discount rates, assumed rate of returns and funding. Changes made to the plan provisions may also impact current and future pension and other postretirement costs. WP&L’sWPL’s assumptions are supported by historical data

and reasonable projections and are reviewed annually with an outside actuary firm and an investment consulting firm. As of Dec. 31, 2002, WP&LSep. 30, 2004 (WPL’s measurement date), WPL was using a 6.75%6% discount rate to calculate benefit obligations and a 9% annual rate of return on investments. In selecting an assumed discount rate, WP&LWPL reviews various corporate Aa bond indices. The 9% annual rate of return is consistent with WP&L’sWPL’s historical returns and is based on projected long-term equity and bond returns, maturities and asset allocations. Refer to Note 6 of the “Notes to Consolidated Financial Statements” for discussion of the impact of a change in the medical trend rates.

 

Other Future Considerations -In addition to items discussed earlier in MD&A,MDA, the following items could impact WP&L’sWPL’s future financial condition or results of operations:

 

Retirement Benefits—American Jobs Creation Act (AJCA)WP&L’s qualified pension and other postretirement benefit expenses- In October 2004, the AJCA was passed which includes changes to several provisions of the Internal Revenue Code. In addition to the extension of certain renewable energy production tax credits discussed earlier, the key changes that may impact WPL include, but are not limited to, future tax relief for 2003 are currently expecteddomestic manufacturers (including electric production activities). Any potential tax benefits realized as a result of this legislation would be subject to be approximately $7 million higher than in 2002, primarily due to unfavorable asset returns, a reduction in the discount rate used to value plan benefit obligations and expected increases in retiree medical costs. WP&L will pursue the possible recovery of these cost increases in any rate filings it has.all appropriate regulatory reviews.

 

Enterprise Resource Planning (ERP) System—Generating Facility OutageAlliant Energy implemented- On Feb. 20, 2005, Kewaunee was removed from service after a new ERP systempotential design weakness was identified in October 2002 whicha backup cooling system. Plant engineering staff identified the concern and the unit was shutdown in accordance with the plant license. A modification is being made to resolve the issue and it is anticipated that the unit will resultbe back in annual amortization expenseservice at full power in April 2005. The modification costs associated with resolving this issue and the operation and maintenance costs necessary to restart the unit are not expected to have a material adverse impact on WPL’s financial condition or results of approximately $11 million (approximately $5 million for WP&L) for five years. Alliant Energy is seeking rateoperations. WPL plans to seek recovery of the utility portionadditional purchased power costs incurred as a result of this outage through either a request for deferral or in the fuel-related rate case it will be filing in March 2005.

Refer to Note 1(h) of the amortized expenses which represents a significant majority of the amortized expenses.“Notes to Consolidated Financial Statements” for information relating to utility fuel cost recovery.

 

REPORT OF INDEPENDENT AUDITORS’ REPORTREGISTERED PUBLIC ACCOUNTING FIRM

 

To the Board of Directors and Shareowners of Wisconsin Power and Light Company:

 

We have audited the accompanying consolidated balance sheets and statements of capitalization of Wisconsin Power and Light Company and subsidiaries (the “Company”) as of December 31, 20022004 and 2001,2003, and the related consolidated statements of income, cash flows, and changes in common equity for each of the three years in the period ended December 31, 2002.2004. These financial statements are the responsibility of the Company’s management. Our responsibility is to express an opinion on these financial statements based on our audits.

 

We conducted our audits in accordance with auditingthe standards generally accepted inof the United States of America.Public Company Accounting Oversight Board (United States). Those standards require that we plan and perform the audit to obtain reasonable assurance about whether the financial statements are free of material misstatement. The Company is not required to have, nor were we engaged to perform, an audit of its internal control over financial reporting. Our audits included consideration of internal control over financial reporting as a basis for designing audit procedures that are appropriate in the circumstances, but not for the purpose of expressing an opinion on the effectiveness of the Company’s internal control over financial reporting. Accordingly, we express no such opinion.An audit also includes examining, on a test basis, evidence supporting the amounts and disclosures in the financial statements. An audit also includesstatements, assessing the accounting principles used and significant estimates made by management, as well as evaluating the overall financial statement presentation. We believe that our audits provide a reasonable basis for our opinion.

 

In our opinion, such consolidated financial statements present fairly, in all material respects, the financial position of the Company as of December 31, 20022004 and 2001,2003, and the results of its operations and its cash flows for each of the three years in the period ended December 31, 20022004, in conformity with accounting principles generally accepted in the United States of America.

 

As discussed in Note 17 to the consolidated financial statements, on January 1, 2003, the Company adopted Statement of Financial Accounting Standards No. 143, “Accounting for Asset Retirement Obligations.”

DELOITTE & TOUCHE LLP

 

Milwaukee, Wisconsin

March 18, 20032, 2005

CONSOLIDATED FINANCIAL STATEMENTS

 

(THIS PAGE INTENTIONALLY LEFT BLANK)

CONSOLIDATED STATEMENTS OF INCOME

 

  

Year Ended December 31,


   Year Ended December 31,

 
  

2002


   

2001


   

2000


   2004

 2003

 2002

 
  

(in thousands)

   (in millions) 

Operating revenues:

            

Electric utility

  

$

787,680

 

  

$

753,450

 

  

$

692,191

 

  $939.8  $910.1  $787.7 

Gas utility

  

 

179,091

 

  

 

206,863

 

  

 

165,152

 

   253.8   272.4   179.1 

Water

  

 

5,307

 

  

 

5,040

 

  

 

5,038

 

Other

   16.2   34.5   22.7 
  


  


  


  


 


 


  

 

972,078

 

  

 

965,353

 

  

 

862,381

 

   1,209.8   1,217.0   989.5 
  


  


  


  


 


 


Operating expenses:

            

Electric production fuels

  

 

132,492

 

  

 

120,722

 

  

 

113,208

 

Purchased power

  

 

217,209

 

  

 

217,306

 

  

 

146,939

 

Electric production fuel and purchased power

   431.5   409.7   352.5 

Cost of gas sold

  

 

110,119

 

  

 

153,823

 

  

 

107,131

 

   165.8   186.3   110.1 

Other operation and maintenance

  

 

215,689

 

  

 

186,477

 

  

 

188,967

 

   282.1   292.6   239.7 

Depreciation and amortization

  

 

136,232

 

  

 

129,098

 

  

 

139,911

 

   111.0   104.9   108.7 

Taxes other than income taxes

  

 

32,874

 

  

 

32,504

 

  

 

29,163

 

   36.6   31.9   32.9 
  


  


  


  


 


 


  

 

844,615

 

  

 

839,930

 

  

 

725,319

 

   1,027.0   1,025.4   843.9 
  


  


  


  


 


 


Operating income

  

 

127,463

 

  

 

125,423

 

  

 

137,062

 

   182.8   191.6   145.6 
  


  


  


  


 


 


Interest expense and other:

            

Interest expense

  

 

40,202

 

  

 

43,483

 

  

 

44,644

 

   33.5   37.9   40.2 

Interest income

  

 

(21,590

)

  

 

(8,109

)

  

 

(13,143

)

Equity income from unconsolidated investments

  

 

(17,022

)

  

 

(15,535

)

  

 

(552

)

   (25.0)  (20.7)  (17.0)

Allowance for funds used during construction

  

 

(2,639

)

  

 

(4,753

)

  

 

(5,365

)

   (4.5)  (4.0)  (2.6)

Miscellaneous, net

  

 

2,864

 

  

 

(4,391

)

  

 

(2,841

)

Interest income and other

   (1.2)  (2.3)  (0.6)
  


  


  


  


 


 


  

 

1,815

 

  

 

10,695

 

  

 

22,743

 

   2.8   10.9   20.0 
  


  


  


  


 


 


Income before income taxes

  

 

125,648

 

  

 

114,728

 

  

 

114,319

 

   180.0   180.7   125.6 
  


  


  


  


 


 


Income taxes

  

 

44,724

 

  

 

41,238

 

  

 

42,918

 

   66.3   65.8   44.7 
  


  


  


  


 


 


Income before cumulative effect of a change in accounting principle, net of tax

  

 

80,924

 

  

 

73,490

 

  

 

71,401

 

  


  


  


Cumulative effect of a change in accounting principle, net of tax

  

 

—  

 

  

 

—  

 

  

 

35

 

  


  


  


Net income

  

 

80,924

 

  

 

73,490

 

  

 

71,436

 

   113.7   114.9   80.9 
  


  


  


  


 


 


Preferred dividend requirements

  

 

3,310

 

  

 

3,310

 

  

 

3,310

 

   3.3   3.3   3.3 
  


  


  


  


 


 


Earnings available for common stock

  

$

77,614

 

  

$

70,180

 

  

$

68,126

 

  $110.4  $111.6  $77.6 
  


  


  


  


 


 


 

The accompanying Notes to Consolidated Financial Statements are an integral part of these statements.

CONSOLIDATED BALANCE SHEETS

   December 31,

 
   2004

  2003

 
   (in millions) 

ASSETS

         

Property, plant and equipment:

         

Electric plant in service

  $2,128.5  $2,002.0 

Gas plant in service

   316.4   301.2 

Other plant in service

   258.2   268.1 

Accumulated depreciation

   (1,196.6)  (1,137.2)
   


 


Net plant

   1,506.5   1,434.1 

Construction work in progress

   75.8   66.3 

Other, less accumulated depreciation of $0.3 for both periods

   18.7   15.7 
   


 


    1,601.0   1,516.1 
   


 


Current assets:

         

Cash and temporary cash investments

   0.1   27.1 

Accounts receivable:

         

Customer, less allowance for doubtful accounts of $1.1 and $2.7

   139.7   78.9 

Other, less allowance for doubtful accounts of $— and $0.4

   30.5   24.4 

Income tax refunds receivable

   —     16.8 

Production fuel, at average cost

   16.0   17.7 

Materials and supplies, at average cost

   24.2   22.9 

Gas stored underground, at average cost

   30.3   24.3 

Regulatory assets

   21.1   24.2 

Prepaid gross receipts tax

   33.0   28.3 

Assets held for sale

   4.9   6.1 

Other

   18.5   14.6 
   


 


    318.3   285.3 
   


 


Investments:

         

Nuclear decommissioning trust funds

   243.2   233.7 

Investment in American Transmission Company LLC and other

   165.1   144.0 
   


 


    408.3   377.7 
   


 


Other assets:

         

Regulatory assets

   128.6   96.0 

Deferred charges and other

   199.9   194.2 
   


 


    328.5   290.2 
   


 


Total assets

  $2,656.1  $2,469.3 
   


 


The accompanying Notes to Consolidated Financial Statements are an integral part of these statements.

CONSOLIDATED BALANCE SHEETS (Continued)

   December 31,

 
   2004

  2003

 
   (in millions, except per
share and share amounts)
 

CAPITALIZATION AND LIABILITIES

         

Capitalization (Refer to Consolidated Statements of Capitalization):

         

Common stock - $5 par value - authorized 18,000,000 shares; 13,236,601 shares outstanding

  $66.2  $66.2 

Additional paid-in capital

   525.7   525.6 

Retained earnings

   461.7   440.3 

Accumulated other comprehensive loss

   (2.7)  (20.3)
   


 


Total common equity

   1,050.9   1,011.8 
   


 


Cumulative preferred stock

   60.0   60.0 

Long-term debt, net (excluding current portion)

   364.2   336.4 
   


 


    1,475.1   1,408.2 
   


 


Current liabilities:

         

Current maturities

   88.0   62.0 

Variable rate demand bonds

   39.1   55.1 

Commercial paper

   47.0   —   

Accounts payable

   91.0   80.1 

Accounts payable to associated companies

   20.3   22.6 

Regulatory liabilities

   23.8   13.9 

Other

   39.5   33.5 
   


 


    348.7   267.2 
   


 


Other long-term liabilities and deferred credits:

         

Deferred income taxes

   232.6   213.7 

Deferred investment tax credits

   19.9   21.5 

Regulatory liabilities

   215.1   227.9 

Asset retirement obligations

   200.9   187.4 

Pension and other benefit obligations

   85.7   59.0 

Other

   78.1   84.4 
   


 


    832.3   793.9 
   


 


Commitments and contingencies (Note 11)

         

Total capitalization and liabilities

  $2,656.1  $2,469.3 
   


 


The accompanying Notes to Consolidated Financial Statements are an integral part of these statements.

CONSOLIDATED STATEMENTS OF CASH FLOWS

   Year Ended December 31,

 
   2004

  2003

  2002

 
   (in millions) 

Cash flows from operating activities:

             

Net income

  $113.7  $114.9  $80.9 

Adjustments to reconcile net income to net cash flows from operating activities:

             

Depreciation and amortization

   111.0   104.9   108.7 

Other amortizations

   41.4   51.3   27.7 

Deferred tax expense (benefit) and investment tax credits

   8.5   21.8   (5.6)

Equity income from unconsolidated investments, net

   (25.0)  (20.7)  (17.0)

Distributions from equity method investments

   20.5   14.0   13.2 

Other

   (3.7)  (2.3)  (1.2)

Other changes in assets and liabilities:

             

Accounts receivable

   (16.9)  (10.0)  (1.9)

Sale of accounts receivable

   (50.0)  (66.0)  28.0 

Income tax refunds receivable

   16.8   (16.8)  —   

Accounts payable

   8.6   (2.6)  (20.5)

Accrued taxes

   3.2   (13.1)  17.3 

Benefit obligations and other

   (28.8)  (36.9)  (5.8)
   


 


 


Net cash flows from operating activities

   199.3   138.5   223.8 
   


 


 


Cash flows used for investing activities:

             

Utility construction and acquisition expenditures

   (211.5)  (151.6)  (156.9)

Nuclear decommissioning trust funds

   (2.9)  (2.9)  (16.1)

Proceeds from asset sales

   —     21.3   —   

Other

   0.1   24.8   (14.8)
   


 


 


Net cash flows used for investing activities

   (214.3)  (108.4)  (187.8)
   


 


 


Cash flows used for financing activities:

             

Common stock dividends

   (89.0)  (70.6)  (59.6)

Preferred stock dividends

   (3.3)  (3.3)  (3.3)

Capital contribution from parent

   —     200.0   61.0 

Proceeds from issuance of long-term debt

   100.0   —     —   

Reductions in long-term debt

   (62.0)  (70.0)  —   

Net change in commercial paper and other short-term borrowings

   47.0   (60.0)  (30.8)

Other

   (4.7)  (7.7)  5.0 
   


 


 


Net cash flows used for financing activities

   (12.0)  (11.6)  (27.7)
   


 


 


Net increase (decrease) in cash and temporary cash investments

   (27.0)  18.5   8.3 
   


 


 


Cash and temporary cash investments at beginning of period

   27.1   8.6   0.3 
   


 


 


Cash and temporary cash investments at end of period

  $0.1  $27.1  $8.6 
   


 


 


Supplemental cash flows information:

             

Cash paid during the period for:

             

Interest

  $31.3  $39.6  $39.5 
   


 


 


Income taxes, net of refunds

  $40.4  $84.3  $35.9 
   


 


 


The accompanying Notes to Consolidated Financial Statements are an integral part of these statements.

CONSOLIDATED STATEMENTS OF CAPITALIZATION

   December 31,

 
   2004

  2003

 
   (dollars in millions, except
per share amounts)
 

Common equity (Refer to Consolidated Balance Sheets)

  $1,050.9  $1,011.8 
   


 


Cumulative preferred stock:

         

Cumulative, without par value, not mandatorily redeemable - authorized 3,750,000 shares, maximum aggregate stated value $150, redeemable any time:

         

$100 stated value - 4.50% series, 99,970 shares outstanding

   10.0   10.0 

$100 stated value - 4.80% series, 74,912 shares outstanding

   7.5   7.5 

$100 stated value - 4.96% series, 64,979 shares outstanding

   6.5   6.5 

$100 stated value - 4.40% series, 29,957 shares outstanding

   3.0   3.0 

$100 stated value - 4.76% series, 29,947 shares outstanding

   3.0   3.0 

$100 stated value - 6.20% series, 150,000 shares outstanding

   15.0   15.0 

$25 stated value - 6.50% series, 599,460 shares outstanding

   15.0   15.0 
   


 


    60.0   60.0 
   


 


Long-term debt, net:

         

First Mortgage Bonds:

         

1992 Series Y, 7.6%, due 2005

   72.0   72.0 

1991 Series B, variable rate (2.5% at Dec. 31, 2004), due 2005

   16.0   16.0 

1984 Series A, variable rate (2.36% at Dec. 31, 2004), due 2014

   8.5   8.5 

1988 Series A, variable rate (2.15% at Dec. 31, 2004), due 2015

   14.6   14.6 

1991 Series A, variable rate (2.5% at Dec. 31, 2004), due 2015

   16.0   16.0 

1992 Series X, 7.75%, retired in 2004

   —     62.0 
   


 


    127.1   189.1 

Debentures, 7%, due 2007

   105.0   105.0 

Debentures, 5.7%, due 2008

   60.0   60.0 

Debentures, 7.625%, due 2010

   100.0   100.0 

Debentures, 6.25%, due 2034

   100.0   —   
   


 


    492.1   454.1 
   


 


Less:

         

Current maturities

   (88.0)  (62.0)

Variable rate demand bonds

   (39.1)  (55.1)

Unamortized debt discount, net

   (0.8)  (0.6)
   


 


    364.2   336.4 
   


 


Total capitalization

  $1,475.1  $1,408.2 
   


 


The accompanying Notes to Consolidated Financial Statements are an integral part of these statements.

CONSOLIDATED STATEMENTS OF CHANGES IN COMMON EQUITY

   Common
Stock


  Additional
Paid-In
Capital


  Retained
Earnings


  Accumulated
Other
Comprehensive
Loss


  Total
Common
Equity


 
   (in millions) 

2002:

                    

Beginning balance (a)

  $66.2  $264.6  $381.3  ($10.1)  $702.0 

Earnings available for common stock

           77.6      77.6 

Minimum pension liability adjustment, net of tax of ($6.8)

              (10.2)  (10.2)
               

 


Unrealized holding losses on derivatives, net of tax of ($0.1)

              (0.2)  (0.2)

Less: reclassification adjustment for gains included in earnings available for common stock, net of tax of $ 2.4

              3.6   3.6 
               

 


Net unrealized losses on qualifying derivatives

              (3.8)  (3.8)
               

 


Total comprehensive income

                  63.6 

Common stock dividends

           (59.6)     (59.6)

Capital contribution from parent

       61.0          61.0 
   

  

  


 

 


Ending balance

   66.2   325.6   399.3  (24.1)  767.0 

2003:

                    

Earnings available for common stock

           111.6      111.6 

Minimum pension liability adjustment, net of tax of $ 2.8

              4.2   4.2 
               

 


Unrealized holding losses on derivatives, net of tax of ($3.5)

              (6.0)  (6.0)

Less: reclassification adjustment for losses included in earnings available for common stock, net of tax of ($3.8)

              (5.6)  (5.6)
               

 


Net unrealized losses on qualifying derivatives

              (0.4)  (0.4)
               

 


Total comprehensive income

                  115.4 

Common stock dividends

           (70.6)     (70.6)

Capital contribution from parent

       200.0          200.0 
   

  

  


 

 


Ending balance

   66.2   525.6   440.3  (20.3)  1,011.8 

2004:

                    

Earnings available for common stock

           110.4      110.4 

Minimum pension liability adjustment, net of tax of $11.7

              17.6   17.6 
               

 


Total comprehensive income

                  128.0 

Common stock dividends

           (89.0)     (89.0)

Other

       0.1          0.1 
   

  

  


 

 


Ending balance

  $66.2  $525.7  $461.7  ($2.7)  $1,050.9 
   

  

  


 

 


(a)Accumulated other comprehensive income (loss) at January 1, 2002 consisted of ($14.2) of a minimum pension liability adjustment and $4.1 of net unrealized gains on qualifying derivatives.

 

The accompanying Notes to Consolidated Financial Statements are an integral part of these statements.

 

CONSOLIDATED BALANCE SHEETS

   

December 31,


 

ASSETS


  

2002


   

2001


 
   

(in thousands)

 

Property, plant and equipment:

          

Electric plant in service

  

$

1,843,834

 

  

$

1,779,593

 

Gas plant in service

  

 

286,652

 

  

 

280,881

 

Water plant in service

  

 

33,062

 

  

 

32,497

 

Other plant in service

  

 

242,329

 

  

 

243,121

 

Accumulated depreciation

  

 

(1,410,036

)

  

 

(1,328,111

)

   


  


Net plant

  

 

995,841

 

  

 

1,007,981

 

Construction work in progress

  

 

96,746

 

  

 

37,828

 

Other, net

  

 

17,811

 

  

 

18,085

 

   


  


   

 

1,110,398

 

  

 

1,063,894

 

   


  


Current assets:

          

Cash and temporary cash investments

  

 

8,577

 

  

 

307

 

Accounts receivable:

          

Customer, less allowance for doubtful accounts of $1,770 and $1,543

  

 

7,977

 

  

 

33,190

 

Associated companies

  

 

21,484

 

  

 

3,676

 

Other, less allowance for doubtful accounts of $458 and $ —

  

 

18,191

 

  

 

16,571

 

Production fuel, at average cost

  

 

18,980

 

  

 

17,314

 

Materials and supplies, at average cost

  

 

22,133

 

  

 

20,669

 

Gas stored underground, at average cost

  

 

16,679

 

  

 

22,187

 

Regulatory assets

  

 

27,999

 

  

 

5,163

 

Prepaid gross receipts tax

  

 

27,388

 

  

 

25,673

 

Other

  

 

8,599

 

  

 

7,855

 

   


  


   

 

178,007

 

  

 

152,605

 

   


  


Investments:

          

Nuclear decommissioning trust funds

  

 

223,734

 

  

 

215,794

 

Investment in ATC and other

  

 

133,043

 

  

 

127,941

 

   


  


   

 

356,777

 

  

 

343,735

 

   


  


Other assets:

          

Regulatory assets

  

 

102,674

 

  

 

109,864

 

Deferred charges and other

  

 

236,741

 

  

 

205,702

 

   


  


   

 

339,415

 

  

 

315,566

 

   


  


Total assets

  

$

1,984,597

 

  

$

1,875,800

 

   


  


The accompanying Notes to Consolidated Financial Statements are an integral part of these statements.

CONSOLIDATED BALANCE SHEETS (Continued)

   

December 31,


 

CAPITALIZATION AND LIABILITIES


  

2002


   

2001


 
   

(in thousands)

 

Capitalization (See Consolidated Statements of Capitalization):

          

Common stock—$5 par value—authorized 18,000,000 shares;
13,236,601 shares outstanding

  

$

66,183

 

  

$

66,183

 

Additional paid-in capital

  

 

325,603

 

  

 

264,603

 

Retained earnings

  

 

399,302

 

  

 

381,333

 

Accumulated other comprehensive loss

  

 

(24,108

)

  

 

(10,167

)

   


  


Total common equity

  

 

766,980

 

  

 

701,952

 

   


  


Cumulative preferred stock

  

 

59,963

 

  

 

59,963

 

Long-term debt (excluding current portion)

  

 

468,208

 

  

 

468,083

 

   


  


   

 

1,295,151

 

  

 

1,229,998

 

   


  


Current liabilities:

          

Variable rate demand bonds

  

 

55,100

 

  

 

55,100

 

Commercial paper

  

 

60,000

 

  

 

—  

 

Notes payable to associated companies

  

 

—  

 

  

 

90,816

 

Accounts payable

  

 

90,869

 

  

 

94,091

 

Accounts payable to associated companies

  

 

43,276

 

  

 

25,231

 

Accrued taxes

  

 

19,353

 

  

 

2,057

 

Regulatory liabilities

  

 

16,938

 

  

 

7,619

 

Other

  

 

29,064

 

  

 

25,543

 

   


  


   

 

314,600

 

  

 

300,457

 

   


  


Other long-term liabilities and deferred credits:

          

Accumulated deferred income taxes

  

 

191,894

 

  

 

206,245

 

Accumulated deferred investment tax credits

  

 

23,241

 

  

 

24,907

 

Pension and other benefit obligations

  

 

58,921

 

  

 

18,175

 

Customer advances

  

 

36,555

 

  

 

34,178

 

Other

  

 

64,235

 

  

 

61,840

 

   


  


   

 

374,846

 

  

 

345,345

 

   


  


Commitments and contingencies (Note 11)

          

Total capitalization and liabilities

  

$

1,984,597

 

  

$

1,875,800

 

   


  


The accompanying Notes to Consolidated Financial Statements are an integral part of these statements.

CONSOLIDATED STATEMENTS OF CASH FLOWS

   

Year Ended December 31,


 
   

2002


   

2001


   

2000


 
   

(in thousands)

 

Cash flows from operating activities:

               

Net income

  

$

80,924

 

  

$

73,490

 

  

$

71,436

 

Adjustments to reconcile net income to net cash flows from operating activities:

               

Depreciation and amortization

  

 

136,232

 

  

 

129,098

 

  

 

139,911

 

Amortization of nuclear fuel

  

 

6,486

 

  

 

4,554

 

  

 

5,066

 

Amortization of deferred energy efficiency expenditures

  

 

21,179

 

  

 

14,361

 

  

 

14,361

 

Deferred tax benefits and investment tax credits

  

 

(5,562

)

  

 

(6,791

)

  

 

(12,077

)

Equity income from unconsolidated investments, net

  

 

(17,022

)

  

 

(15,535

)

  

 

(552

)

Distributions from equity method investments

  

 

13,199

 

  

 

8,450

 

  

 

992

 

Other

  

 

(22,160

)

  

 

(10,539

)

  

 

(15,451

)

Other changes in assets and liabilities:

               

Accounts receivable

  

 

5,785

 

  

 

14,408

 

  

 

(29,733

)

Accounts payable

  

 

(11,676

)

  

 

(20,549

)

  

 

36,265

 

Accrued taxes

  

 

17,296

 

  

 

(1,225

)

  

 

(3,257

)

Other

  

 

(931

)

  

 

(53,836

)

  

 

(32,901

)

   


  


  


Net cash flows from operating activities

  

 

223,750

 

  

 

135,886

 

  

 

174,060

 

   


  


  


Cash flows from (used for) financing activities:

               

Common stock dividends

  

 

(59,645

)

  

 

(60,449

)

  

 

—  

 

Preferred stock dividends

  

 

(3,310

)

  

 

(3,310

)

  

 

(3,310

)

Capital contribution from parent

  

 

61,000

 

  

 

35,000

 

  

 

—  

 

Proceeds from issuance of long-term debt

  

 

—  

 

  

 

—  

 

  

 

100,000

 

Reductions in long-term debt

  

 

—  

 

  

 

(47,000

)

  

 

(1,875

)

Net change in short-term borrowings

  

 

(30,816

)

  

 

61,572

 

  

 

(96,505

)

Other

  

 

5,086

 

  

 

(4,989

)

  

 

2,677

 

   


  


  


Net cash flows from (used for) financing activities

  

 

(27,685

)

  

 

(19,176

)

  

 

987

 

   


  


  


Cash flows used for investing activities:

               

Utility construction expenditures

  

 

(156,921

)

  

 

(147,032

)

  

 

(131,640

)

Nuclear decommissioning trust funds

  

 

(16,092

)

  

 

(16,092

)

  

 

(16,092

)

Proceeds from formation of ATC and other asset dispositions

  

 

—  

 

  

 

75,600

 

  

 

961

 

Other

  

 

(14,782

)

  

 

(29,308

)

  

 

(28,109

)

   


  


  


Net cash flows used for investing activities

  

 

(187,795

)

  

 

(116,832

)

  

 

(174,880

)

   


  


  


Net increase (decrease) in cash and temporary cash investments

  

 

8,270

 

  

 

(122

)

  

 

167

 

   


  


  


Cash and temporary cash investments at beginning of period

  

 

307

 

  

 

429

 

  

 

262

 

   


  


  


Cash and temporary cash investments at end of period

  

$

8,577

 

  

$

307

 

  

$

429

 

   


  


  


Supplemental cash flows information:

               

Cash paid during the period for:

               

Interest

  

$

39,540

 

  

$

43,237

 

  

$

40,455

 

   


  


  


Income taxes, net of refunds

  

$

35,875

 

  

$

54,161

 

  

$

54,676

 

   


  


  


The accompanying Notes to Consolidated Financial Statements are an integral part of these statements.

CONSOLIDATED STATEMENTS OF CAPITALIZATION

   

December 31,


 
   

2002


   

2001


 
   

(in thousands,

except share amounts)

 

Common equity

  

$

766,980

 

  

$

701,952

 

   


  


Cumulative preferred stock:

          

Cumulative, without par value, not mandatorily redeemable—authorized 3,750,000 shares, maximum aggregate stated value $150,000,000:

          

$100 stated value—4.50% series, 99,970 shares outstanding

  

 

9,997

 

  

 

9,997

 

$100 stated value—4.80% series, 74,912 shares outstanding

  

 

7,491

 

  

 

7,491

 

$100 stated value—4.96% series, 64,979 shares outstanding

  

 

6,498

 

  

 

6,498

 

$100 stated value—4.40% series, 29,957 shares outstanding

  

 

2,996

 

  

 

2,996

 

$100 stated value—4.76% series, 29,947 shares outstanding

  

 

2,995

 

  

 

2,995

 

$100 stated value—6.20% series, 150,000 shares outstanding

  

 

15,000

 

  

 

15,000

 

$25 stated value—6.50% series, 599,460 shares outstanding

  

 

14,986

 

  

 

14,986

 

   


  


   

 

59,963

 

  

 

59,963

 

   


  


Long-term debt:

          

First Mortgage Bonds:

          

1984 Series A, variable rate (1.6% at December 31, 2002), due 2014

  

 

8,500

 

  

 

8,500

 

1988 Series A, variable rate (2.1% at December 31, 2002), due 2015

  

 

14,600

 

  

 

14,600

 

1991 Series A, variable rate (1.85% at December 31, 2002), due 2015

  

 

16,000

 

  

 

16,000

 

1991 Series B, variable rate (1.85% at December 31, 2002), due 2005

  

 

16,000

 

  

 

16,000

 

1992 Series W, 8.6%, due 2027

  

 

70,000

 

  

 

70,000

 

1992 Series X, 7.75%, due 2004

  

 

62,000

 

  

 

62,000

 

1992 Series Y, 7.6%, due 2005

  

 

72,000

 

  

 

72,000

 

   


  


   

 

259,100

 

  

 

259,100

 

Debentures, 7%, due 2007

  

 

105,000

 

  

 

105,000

 

Debentures, 5.7%, due 2008

  

 

60,000

 

  

 

60,000

 

Debentures, 7 5/8%, due 2010

  

 

100,000

 

  

 

100,000

 

   


  


   

 

524,100

 

  

 

524,100

 

   


  


Less:

          

Variable rate demand bonds

  

 

(55,100

)

  

 

(55,100

)

Unamortized debt discount, net

  

 

(792

)

  

 

(917

)

   


  


   

 

468,208

 

  

 

468,083

 

   


  


Total capitalization

  

$

1,295,151

 

  

$

1,229,998

 

   


  


The accompanying Notes to Consolidated Financial Statements are an integral part of these statements.

CONSOLIDATED STATEMENTS OF CHANGES IN COMMON EQUITY

   

Common Stock


  

Additional Paid-In Capital


  

Retained Earnings


   

Accumulated Other Comprehensive Loss


   

Total Common Equity


 
   

(in thousands)

 

2000:

                       

Beginning balance

  

$

66,183

  

$

229,438

  

$

303,476

 

  

$

—  

 

  

$

599,097

 

Earnings available for common stock

          

 

68,126

 

       

 

68,126

 

Unrealized holding losses on derivatives due to cumulative effect of a change in accounting principle, net of tax of ($430)

               

 

(642

)

  

 

(642

)

Other unrealized holding losses on derivatives, net of tax of ($3,634)

               

 

(5,151

)

  

 

(5,151

)

Less: reclassification adjustment for losses included in earnings available for common stock, net of tax of ($769)

               

 

(1,085

)

  

 

(1,085

)

                


  


Net unrealized losses on qualifying derivatives

               

 

(4,708

)

  

 

(4,708

)

                


  


Total comprehensive income

                    

 

63,418

 

Stock options exercised

      

 

78

            

 

78

 

   

  

  


  


  


Ending balance

  

 

66,183

  

 

229,516

  

 

371,602

 

  

 

(4,708

)

  

 

662,593

 

2001:

                       

Earnings available for common stock

          

 

70,180

 

       

 

70,180

 

Minimum pension liability adjustment, net of tax of ($9,552)

               

 

(14,248

)

  

 

(14,248

)

Unrealized holding gains on derivatives, net of tax of $3,932

               

 

5,952

 

  

 

5,952

 

Less: reclassification adjustment for losses included in earnings available for common stock, net of tax of ($1,676)

               

 

(2,837

)

  

 

(2,837

)

                


  


Net unrealized gains on qualifying derivatives

               

 

8,789

 

  

 

8,789

 

                


  


Total comprehensive income

                    

 

64,721

 

Common stock dividends

          

 

(60,449

)

       

 

(60,449

)

Stock options exercised

      

 

87

            

 

87

 

Capital contribution from parent

      

 

35,000

            

 

35,000

 

   

  

  


  


  


Ending balance

  

 

66,183

  

 

264,603

  

 

381,333

 

  

 

(10,167

)

  

 

701,952

 

2002:

                       

Earnings available for common stock

          

 

77,614

 

       

 

77,614

 

Minimum pension liability adjustment, net of tax of ($6,823)

               

 

(10,177

)

  

 

(10,177

)

Unrealized holding losses on derivatives, net of tax of ($92)

               

 

(137

)

  

 

(137

)

Less: reclassification adjustment for gains included in earnings available for common stock, net of tax of $2,432

               

 

3,627

 

  

 

3,627

 

                


  


Net unrealized losses on qualifying derivatives

               

 

(3,764

)

  

 

(3,764

)

                


  


Total comprehensive income

                    

 

63,673

 

Common stock dividends

          

 

(59,645

)

       

 

(59,645

)

Capital contribution from parent

      

 

61,000

            

 

61,000

 

   

  

  


  


  


Ending balance

  

$

66,183

  

$

325,603

  

$

399,302

 

  

($

24,108

)

  

$

766,980

 

   

  

  


  


  


The accompanying Notes to Consolidated Financial Statements are an integral part of these statements.

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

 

(1) SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES

 

(a) General—General -The consolidated financial statements include the accounts of WP&LWisconsin Power and Light Company (WPL) and its principal consolidated subsidiaries WPL Transco LLC and South Beloit. WP&LBeloit Water, Gas and Electric Company. WPL is a direct subsidiary of Alliant Energy Corporation (Alliant Energy) and is engaged principally in the generation, distribution and sale of electric energy; the purchase, distribution, transportation and sale of natural gas; and the provision of water services. Nearly all of WP&L’s retail customersand various other energy-related services including construction management services for wind farms. WPL’s primary service territories are located in south and central Wisconsin.

 

The consolidated financial statements reflect investments in controlled subsidiaries on a consolidated basis. All significant intercompany balances and transactions have been eliminated from the consolidated financial statements. The consolidated financial statements are prepared in conformity with GAAP,accounting principles generally accepted in the United States of America (U.S.), which give recognition to the rate making and accounting practices of FERCthe Federal Energy Regulatory Commission (FERC) and state commissions having regulatory jurisdiction. The preparation of the consolidated financial statements requires management to make estimates and assumptions that affect: a) the reported amounts of assets and liabilities and the disclosure of contingent assets and liabilities at the date of the financial statements; and b) the reported amounts of revenues and expenses during the reporting period. Actual results could differ from those estimates. Certain prior periodFor all periods presented, certain amounts have been reclassified on a basis consistent with the current year presentation.presentation and relate to the reporting of assets held for sale pursuant to Statement of Financial Accounting Standards (SFAS) 144, “Accounting for the Impairment or Disposal of Long-lived Assets” (SFAS 144). Refer to Note 15 for additional information.

 

Unconsolidated investments for which WP&L has at least aWPL does not control, but does have the ability to exercise significant influence over operating and financial policies (generally, 20% non-controllingto 50% voting interestinterest), are generally accounted for under the equity method of accounting. These investments are stated at acquisition cost, increased or decreased for WP&L’sWPL’s equity in net income or loss, which is included in “Equity income from unconsolidated investments” in the Consolidated Statements of Income, and decreased for any dividends received. Investments that do not meet the criteria for consolidation or the equity method of accounting are accounted for under the cost method. Refer to Note 9 for discussion of WP&L’s cost method investments that are marked-to-market in accordance with SFAS 115.

 

(b) Regulation—Regulation -WP&L WPL is subject to regulation under PUHCA,the Securities and Exchange Commission (SEC), the Public Utility Holding Company Act of 1935 (PUHCA), FERC, the PSCWPublic Service Commission of Wisconsin (PSCW), the Illinois Commerce Commission (ICC), the U.S. Environmental Protection Agency, and the ICC.Nuclear Regulatory Commission (NRC). WPL is also subject to regulation by various other federal, state and local agencies.

 

(c) Regulatory Assets and Liabilities—Liabilities -WP&L WPL is subject to the provisions of SFAS 71, “Accounting for the Effects of Certain Types of Regulation,” which provides that rate-regulated public utilities record certain costs and credits allowed in the rate making process in different periods than for non-regulated entities. These are deferred as regulatory assets or accrued as regulatory liabilities and are recognized in the Consolidated Statements of Income at the time they are reflected in rates. As ofAt Dec. 31, 2002, WP&L2004 and 2003, WPL had approximately $6$11 million and $7 million of regulatory assets that were not earning returns.returns, respectively. At Dec. 31, 2002 and 2001, regulatory assets and liabilities were comprised of the following items (in millions):

 

   

Regulatory Assets


  

Regulatory Liabilities


   

2002


  

2001


  

2002


  

2001


Energy efficiency program costs

  

$38.6

  

$33.9

  

$ —  

  

$ —  

Tax-related

  

25.0

  

29.0

  

14.6

  

15.1

Environmental-related

  

19.0

  

18.7

  

0.6

  

0.5

Other

  

48.1

  

33.4

  

17.0

  

7.6

   
  
  
  
   

$130.7

  

$115.0

  

$32.2

  

$23.2

   
  
  
  
   2004

  2003

Minimum pension liability (Note 6)

  $39.4  $—  

Tax-related (Note 1(d))

   20.2   23.4

Asset retirement obligations (Note 17)

   15.3   8.3

Energy conservation program costs

   14.3   22.9

Environmental-related (Note 11(e))

   12.9   16.2

Excess allowance for funds used during construction (AFUDC) (Note 1(f))

   11.9   12.1

Debt redemption costs

   9.6   10.0

Derivatives (Note 10(a))

   6.7   3.6

Other

   19.4   23.7
   

  

   $149.7  $120.2
   

  

 

If a portion of WP&L’s operations becomes no longer subject toWPL believes it is probable that any differences between expenses for legal asset retirement obligations (AROs) calculated under SFAS 143, “Accounting for Asset Retirement Obligations” (SFAS 143), and expenses recovered currently in rates will be recoverable in future rates, and is deferring the provisions of SFAS 71difference as a resultregulatory asset.

At Dec. 31, regulatory liabilities were comprised of competitive restructuring or otherwise,the following items (in millions):

   2004

  2003

Cost of removal obligations

  $198.0  $209.9

Tax-related (Note 1(d))

   17.0   17.9

Gas performance incentive (Note 1(h))

   15.1   10.6

Other

   8.8   3.4
   

  

   $238.9  $241.8
   

  

WPL collects in rates future removal costs for many assets that do not have an associated legal ARO. WPL records a write-down of related regulatory assets would be required, unless some form of transition cost recovery is established byliability for the appropriate regulatory body that would meet the requirements under GAAPestimated amounts it has collected in rates for continued accounting as regulatory assets during such recovery period. In addition, WP&L would be required to determine any impairment of other assets and write-down such assets to their fair value.these future removal costs less amounts spent on removal activities.

 

(d) Income Taxes—Taxes -WP&L WPL is subject to the provisions of SFAS 109, “Accounting for Income Taxes,” and follows the liability method of accounting for deferred income taxes, which requires the establishment of deferred tax assets and liabilities, as appropriate, for all temporary differences between the tax basis of assets and liabilities and the amounts reported in the consolidated financial statements. Deferred taxes are recorded using currently enacted tax rates.

 

Except as noted below, income tax expense includes provisions for deferred taxes to reflect the tax effects of temporary differences between the time when certain costs are recorded in the accounts and when they are deducted for tax return purposes. As temporary differences reverse, the related accumulated deferred income taxes are reversed to income.

Investment tax credits have been deferred and are subsequently credited to income over the average lives of the related property. Other tax credits reduce income tax expense in the year claimed and are generally related to research and development.

 

The PSCW has allowed rate recovery of deferred taxes on all temporary differences since August 1991. WP&LWPL established a regulatory asset associated with those temporary differences occurring prior to August 1991 that will be recovered in future rates through 2007.

 

Alliant Energy files a consolidated federal income tax return. Under the terms of an agreement between Alliant Energy and WP&L, WP&L calculates its federal income tax provisions and makes payments to or receives payments from Alliant Energy as if it were a separate taxable entity.

(e) Temporary Cash Investments—Investments -Temporary cash investments are stated at cost, which approximates market value, and are considered cash equivalents for the Consolidated Balance Sheets and the Consolidated Statements of Cash Flows. These investments consist of short-term liquid investments that have maturities of less than 90 days from the date of acquisition.days.

 

(f) Depreciation of Utility Property, Plant and Equipment—Equipment -WP&L Utility plant is recorded at original cost, which includes overhead, administrative costs and AFUDC. Ordinary retirements of utility plant and salvage value are netted and charged to accumulated depreciation upon removal from utility plant accounts and no gain or loss is recognized. Removal costs reduce the regulatory liability previously established. AFUDC recovery rates, computed in accordance with the prescribed regulatory formula, were as follows:

   2004

  2003

  2002

 

PSCW formula - retail jurisdiction

  15.2% 14.8% 12.6%

FERC formula - wholesale jurisdiction

  12.5% 9.5% 2.6%

WPL records a regulatory asset for all retail jurisdiction construction projects equal to the difference between the AFUDC calculated in accordance with PSCW guidelines and the AFUDC authorized by FERC and amortizes the regulatory asset at a composite rate and time frame established during each rate case. The amount of AFUDC generated by equity and debt was as follows (in millions):

   2004

  2003

  2002

Equity

  $3.7  $2.9  $1.5

Debt

   0.8   1.1   1.1
   

  

  

   $4.5  $4.0  $2.6
   

  

  

Electric plant in service by functional category as of Dec. 31 was as follows (in millions):

   2004

  2003

Distribution

  $1,069.1  $973.5

Generation

   995.0   964.6

Other

   64.4   63.9
   

  

   $2,128.5  $2,002.0
   

  

WPL uses a combination of remaining life, straight-line and sum-of-the-years-digits depreciation methods as approved by the PSCW and the ICC. The remaining depreciable life of the Kewaunee Nuclear Power Plant (Kewaunee), of which WP&LWPL is a co-owner, is based on the PSCW approved revised end-of-life of 2010. Depreciation expense related to the decommissioning of Kewaunee is discussed further in Note 11(f). The average rates of depreciation for electric and gas properties, consistent with current rate making practices, were as follows:

 

  

2002


  

2001


  

2000


  2004

 2003

 2002

 

Electric

  

3.6%

  

3.7%

  

3.6%

  3.5% 3.7% 3.6%

Gas

  

4.1%

  

4.1%

  

4.1%

  4.0% 4.0% 4.1%

 

(g) Property, Plant and EquipmentUtility plant (other than acquisition adjustments)Nuclear fuel for Kewaunee is recorded at its original cost which includes overhead, administrativeand is amortized to expense based upon the quantity of heat produced for electric generation. This accumulated amortization assumes spent nuclear fuel will have no residual value. Estimated future disposal costs and AFUDC. WP&L’s aggregate gross AFUDC recovery rates for 2002, 2001 and 2000, computed in accordance with the prescribed regulatory formula, were 2.6%, 7.9% and 10.8%, respectively.of such fuel are expensed based on kilowatt-hours (KWhs) generated.

 

Other property, plant and equipment is recorded at original cost.cost, the majority of which is depreciated using the straight-line method. Upon retirement or sale of property, plant and equipment, the cost and related accumulated depreciation are removed from the accounts and any gain or loss is included in “Miscellaneous, net” in the Consolidated Statements of Income. Ordinary retirements of utility plant, including removal costs less salvage value, are charged to accumulated depreciation upon removal from utility plant accounts and no gain or loss is recognized.

 

(h)(g) Operating Revenues—Revenues -Revenues from WP&LWPL are primarily from the sale and delivery of electricityelectric and natural gas sales and deliveries and are recorded under the accrual method of accounting and recognized upon delivery. WP&LWPL accrues revenues for services rendered but unbilled at month-end. In 2000, WP&L recorded an increaseWPL serves as a collection agent for sales or various other taxes and records revenues on a net basis. The revenues do not include the collection of $10 million in the estimate of utility services rendered but unbilled at month-end due to the implementation of refined estimation processes.aforementioned taxes.

 

(i)(h) Utility Fuel Cost Recovery—Recovery -WP&L’s WPL’s retail electric rates are based on annual forecastedforecasts that include fuel and purchased-powerpurchased energy costs. Under PSCW rules, WP&LWPL can seek emergency rate increases for increases in the cost of electric fuel and purchased energy if the annualit experiences an increase in costs that are more than 3% higher than the estimated costs used to establish rates and must reduce rates if annual costs are more than 3% lower than the estimated costs used to establish rates. Any collectionsWPL’s retail gas tariffs provide for subsequent adjustments to its natural gas rates for changes in excess of costs incurred will be refunded, with interest. Accordingly, WP&L has established a reserve due to overcollection of past fuel and purchased-power costs and expects to refund such amount in 2003. WP&Lthe current monthly natural gas commodity price index. Also, WPL has a gas performance incentive which includes a sharing mechanism whereby 50% of all gains and losses relative to current commodity prices, as well as other benchmarks, are retained by WP&L,WPL, with the remainder refunded to or recovered from customers. Recovery of capacity related charges associated with WPL’s purchased power costs are recovered from electric customers through changes in base rates.

 

(j) Nuclear Refueling Outage Costs—(i) Generating Facility Outages -Operating expenses incurred during refueling outages at Kewaunee and the maintenance costs incurred during outages for WPL’s various other generating facilities are expensed by WP&L as incurred. A scheduledThe timing of the Kewaunee refueling outage occurred at Kewaunee in late 2001. The next scheduledoutages during 2002 to 2004 and anticipated refueling outage at Kewaunee is anticipatedoutages for 2005 to commence in Spring 2003.2007 are as follows:

2002


2003


2004


2005


2006


2007


None

SpringFallNoneSpringFall

 

(k) Nuclear Fuel—Nuclear fuel for Kewaunee is recorded at its original cost and is amortized to expense based upon the quantity of heat produced for the generation of electricity. This accumulated amortization assumes spent nuclear fuel will have no residual value. Estimated future disposal costs of such fuel are expensed based on KWhs generated.

(l)(j) Derivative Financial Instruments—Instruments -WP&L WPL uses derivative financial instruments to hedge exposures to fluctuations in interest rates, certain electric and gas commodity prices and volatility in a portion of natural gas sales volumes due to weather.

WP&L WPL also utilizes derivatives to mitigate the equity price volatility associated with certain investments in equity securities. WP&LWPL does not use such instruments for speculative purposes. The fair value of all derivatives are recorded as assets or liabilities on the Consolidated Balance Sheets and gains and losses related to derivatives that are designated as, and qualify as hedges, are recognized in earnings when the underlying hedged item or physical transaction is recognized in income. Gains and losses related to derivatives that do not qualify for, or are not designated in hedge relationships, are recognized in earnings immediately. Based on the fuel and natural gas cost recovery mechanisms in place, as well as other specific regulatory authorizations, changes in fair market values of WP&L’sWPL’s derivatives generally have no impact on its results of operations. WP&Loperations, as

they are generally reported as changes in regulatory assets and liabilities. WPL has a number ofsome commodity purchase and sales contracts that have been designated, and qualify for, the normal purchase and sale exception in SFAS 138, “Accounting for Certain Derivative Instruments and Certain Hedging Activities—an Amendment of SFAS 133.” Basedbased on this designation, these contracts are not accounted for as derivative instruments.

 

WP&LWPL is exposed to losses related to financial instruments in the event of counterparties’ non-performance. WP&LWPL has established controls to determine and monitor the creditworthiness of counterparties in order to mitigate its exposure to counterparty credit risk. WP&LWPL is not aware of any material exposure to counterparty credit risk.risk related to its derivative financial instruments. Refer to Note 10 for further discussion of WP&L’sWPL’s derivative financial instruments.

 

(m)(k) Pension Plan—Plan - -For the defined benefit pension plan sponsored by Alliant Energy Corporate Services, Inc. (Corporate Services), a subsidiary of Alliant Energy, Alliant Energy allocates pension costs and contributions to WP&LWPL based on labor costs of plan participants and any additional minimum pension liability based on the funded status of the WP&LWPL group.

 

(n)(l) Asset Valuations -Long-lived assets, excluding regulatory assets, Assets held for sale are reviewed for possible impairment whenever events or changes in circumstances indicate the carrying value of the assets may not be recoverable. Impairment is indicatedeach reporting period and impairment charges are recorded if the carrying value of ansuch asset exceeds its undiscounted future cash flows. An impairment charge is recognized equal to the amount the carrying value exceeds the asset’s fair value. Theestimated fair value is determined by the use of quoted market prices, appraisals, or the use of other valuation techniques such as expected discounted future cash flows.less cost to sell.

 

If events or circumstances indicate the carrying value of investments accounted for under the equity method of accounting may not be recoverable, potential impairment is assessed by comparing the future anticipated cash flows fromfair value of these investments to their carrying values. The estimatedvalues as well as assessing if a decline in fair value less costis temporary. If an impairment is indicated, a charge is recognized equal to sell of assets held for sale are compared each reporting period to their carrying values. Impairment charges are recorded for equity method investments and assets held for sale ifthe amount the carrying value of such asset exceeds the future anticipated cash flows orinvestment’s fair value.

(m) Operating Leases - WPL has certain purchased power agreements that are accounted for as operating leases. Costs associated with these agreements are included in “Electric production fuel and purchased power” in the estimated fair value less costConsolidated Statements of Income based on monthly payments for these agreements. Monthly capacity payments related to sell, respectively.one of these agreements is higher during the peak demand period from May 1 through Sep. 30 and lower in all other periods during each calendar year. These seasonal differences in capacity charges are consistent with market pricing and the expected usage of energy from the plant.

 

(2) UTILITY RATE MATTERS

 

In 2002 and 2001, WP&L had an electric fuel cost recovery mechanism that required WP&L2005, WPL received approval from the PSCW to refund any overcollection of fuel and purchased-power costs. WP&L has recorded the necessary reserve for refunds at Dec. 31, 2002 and 2001. In 2002, WP&L filed a rate case with FERC related$12 million in 2005 to its electric wholesale customers. An interim rate increase, subject to refund, of $6 million annually was granted effective April 2002. The case was subsequently settled with final rates of $3 million annually.natural gas customers for gains realized from its gas performance incentive program. At Dec. 31, 2002, WP&L recorded a reserve2004, WPL reserved for the difference between interim and final rates.all amounts related to these refunds. Refer to Note 1(h) for further discussion of WPL’s fuel cost recovery.

 

(3) LEASES

 

WP&L’sWPL’s operating lease rental expenses, which include certain purchased-powerpurchased power agreements, for 2004, 2003 and 2002 2001 and 2000 were $24.5$63 million, $23.4$25 million and $7.9$23 million, respectively. The purchased-power agreements below include $463Contingent rentals from operating leases that were excluded from these amounts were $0.4 million, $0.9 million and $78$1.1 million respectively,for 2004, 2003 and 2002, respectively. At Dec. 31, 2004, WPL’s future minimum operating lease payments, excluding contingent rentals, were as follows (in millions):

   2005

  2006

  2007

  2008

  2009

  Thereafter

  Total

Certain purchased power agreements

  $69  $70  $72  $64  $58  $177  $510

Synthetic leases

   8   8   7   3   3   13   42

Other

   2   2   1   1   —     1   7
   

  

  

  

  

  

  

   $79  $80  $80  $68  $61  $191  $559
   

  

  

  

  

  

  

The purchased power agreements meeting the criteria as operating leases are such that, over the contract term, WPL has exclusive rights to all or a substantial portion of the output from a specific generating facility. The purchased power agreements total in the previous table includes $429 million and $56 million related to a newthe Riverside plant (Riverside) currently under developmenttolling agreement and the RockGen plant both in Wisconsin. The Riverside plant is expectedpurchased power agreement, respectively. Refer to be placed in-service in 2004. Note 18 for additional information concerning the impacts of Financial Accounting Standards Board (FASB) Interpretation No. 46R, “Consolidation of Variable Interest Entities” (FIN 46R), on these two agreements.

The synthetic leases in the previous table relate to the financing of the utility railcars and a utility radio dispatch systemsystem. The entities that werelease these assets to WPL do not meet the consolidation requirements per FIN46R and are not included on WP&L’sthe Consolidated Balance Sheets. WP&LWPL has guaranteed the residual value of its synthetic leases totaling $14.3which total $8 million in the aggregate. The guarantees extend through the maturity of each respective underlying lease with remaining terms up to 1311 years. Residual value guaranteesguarantee amounts have been included in the future minimum lease payments noted in the table below (in millions):previous table.

   

2003


  

2004


  

2005


  

2006


  

2007


  

Thereafter


  

Total


Certain purchased-power agreements

  

$18.7

  

$51.8

  

$66.3

  

$67.6

  

$69.0

  

$308.6

  

$582.0

Synthetic leases

  

6.4

  

7.6

  

7.5

  

7.4

  

5.5

  

25.5

  

59.9

Other

  

2.0

  

1.1

  

1.2

  

1.0

  

1.0

  

2.2

  

8.5

   
  
  
  
  
  
  
   

$27.1

  

$60.5

  

$75.0

  

$76.0

  

$75.5

  

$336.3

  

$650.4

   
  
  
  
  
  
  

In January 2003, the FASB issued FIN 46 which addresses consolidation by business enterprises of variable interest entities, commonly referred to as “special purpose entities.” FIN 46 requires consolidation where there is a controlling financial interest in a variable interest entity or where the variable interest entity does not have sufficient equity at risk to finance its activities without additional subordinated financial support from other parties. WP&L will apply the provisions of FIN 46 prospectively for all variable interest entities created after Jan. 31, 2003. For variable interest entities created before Jan. 31, 2003, WP&L will be required to consolidate all variable interest entities in which it is the primary beneficiary beginning in the third quarter of 2003. It is reasonably possible the implementation of FIN 46 will require that certain variable interest entities associated with these synthetic leases be included on WP&L’s Consolidated Balance Sheets. WP&L is in the process of analyzing each synthetic lease in accordance with FIN 46. WP&L does not anticipate the adoption of FIN 46 will have a material impact on its results of operations given it estimates the fair market value of the underlying assets is not materially less than the remaining lease obligations at Dec. 31, 2002.

(4) UTILITYSALE OF ACCOUNTS RECEIVABLE

 

Utility customer accounts receivable, including unbilled revenues, arise primarily from the sale of electricityelectric and natural gas.gas sales. At Dec. 31, 20022004 and 2001, WP&L2003, WPL was serving a diversified base of residential, commercial, industrial and industrialwholesale customers and did not have any significant concentrations of credit risk.

 

WP&L participatesIn March 2004, WPL discontinued its participation in a combined utility customer accounts receivable sale program whereby IP&L and WP&L may sell up toit sold a combined maximum amountportion of $250 million (there are no individual subsidiary limits) of their respectiveits accounts receivable to a third-party financial institution on a limited recourse basis through wholly-owned and consolidated variable interestspecial purpose entities. Corporate Services actsacted as a collection agent for the buyer and receivesreceived a fee for collection services that approximates fair value. The agreement expires in April 2006 and is subject to annual renewal or renegotiation for a longer period thereafter.services. Under terms of the agreement, the third-party financial institution purchasespurchased the receivables initially for the face amount. On a monthly basis, this sales price iswas adjusted, resulting in payments to the third-party financial institution of an amount that variesvaried based on interest rates and length of time the sold receivables remainremained outstanding. Collections on sold receivables arewere used to purchase additional receivables from WPL. WPL had no receivables sold and no short-term debt outstanding at the utility subsidiaries.time it discontinued its participation in the program. WPL accounted for the sale of accounts receivable to the third-party financial institution as sales under SFAS 140, “Accounting for Transfers and Servicing of Financial Assets and Extinguishments of Liabilities.” The entity that purchased the receivables did not require consolidation per the guidelines of FIN 46R. Retained receivables were available to the third-party financial institution to pay any fees or expenses due it, and to absorb all credit losses incurred on any of the sold receivables.

 

At Dec. 31, 20022004 and 2001, WP&L2003, WPL had sold $116 million$0 and $88$50 million of receivables,utility customer accounts receivable, respectively. In 2004, 2003 and 2002, 2001 and 2000, WP&LWPL received $1.2 billion, $1.1$30 million, $0.8 billion and $0.9$1.2 billion, respectively, in aggregate proceeds from the sale of accounts receivable. WP&L usesWPL used proceeds from the sale of accounts receivable and unbilled revenues to maintain flexibility in its capital structure, take advantage of favorable short-term rates and finance a portion of its long-term cash needs. WP&L paid feesWPL incurred costs associated with these sales of $0.2 million, $1.2 million and $2.2 million $4.0 millionin 2004, 2003 and $5.0 million in 2002, 2001 and 2000, respectively.

WP&L accounts for the sale of accounts receivable to the third-party financial institution as sales under SFAS 140, “Accounting for Transfers and Servicing of Financial Assets and Extinguishments of Liabilities.” Retained receivables are available to the third-party financial institution to pay any fees or expenses due it, and to absorb all credit losses incurred on any of the sold receivables. Beginning in the third quarter of 2003 under FIN 46, it is reasonably possible that WP&L could be considered the primary beneficiary given the current structure of the variable interest entities related to the program, and could be required to consolidate the operating results and associated assets and liabilities of the variable interest entities in its financial statements. WP&L is currently evaluating the structure of its receivable sales program to determine if this structure can be modified to qualify for off-balance sheet treatment under FIN 46.

 

(5) INCOME TAXES

 

The components of income taxes for WP&LWPL were as follows (in millions):

 

   

2002


   

2001


   

2000


 

Current tax expense:

            

Federal

  

$42.8

 

  

$36.8

 

  

$44.5

 

State

  

9.7

 

  

11.2

 

  

10.5

 

Deferred tax expense (benefit):

            

Federal

  

(5.0

)

  

(4.6

)

  

(9.9

)

State

  

1.2

 

  

(0.4

)

  

(0.3

)

Amortization of investment tax credits

  

(1.8

)

  

(1.8

)

  

(1.9

)

Research and development tax credits

  

(2.2

)

  

—  

 

  

—  

 

   

  

  

   

$44.7

 

  

$41.2

 

  

$42.9

 

   

  

  

   2004

  2003

  2002

 

Current tax expense:

             

Federal

  $45.2  $29.0  $42.8 

State

   13.3   15.7   9.7 

Deferred tax expense (benefit):

             

Federal

   9.7   22.8   (5.0)

State

   0.4   0.6   1.2 

Amortization of investment tax credits

   (1.6)  (1.6)  (1.8)

Research and development tax credits

   (0.7)  (0.7)  (2.2)
   


 


 


   $66.3  $65.8  $44.7 
   


 


 


 

Alliant Energy files a consolidated federal income tax return. Under the terms of an agreement between Alliant Energy and its subsidiaries, including WPL, the subsidiaries calculate their respective federal income tax provisions and make payments to or receive payments from Alliant Energy as if they were separate taxable entities. Separate return amounts are adjusted to reflect state apportionment benefits net of federal tax and the fact that PUHCA prohibits the retention of tax benefits at the parent level. Any difference between the separate return methodology and the actual consolidated return is allocated as prescribed in Alliant Energy’s tax allocation agreement. WPL realized net benefits of $1.2 million, $2.9 million and $0 related to state apportionment and allocation of parent tax benefits in 2004, 2003 and 2002, respectively.

The overall effective income tax rates shown in the following table were computed by dividing total income tax expense by income before income taxes.

 

  

2002


   

2001


   

2000


   2004

 2003

 2002

 

Statutory federal income tax rate

  

35.0

%

  

35.0

%

  

35.0

%

  35.0% 35.0% 35.0%

State income taxes, net of federal benefits

  

6.1

 

  

6.4

 

  

6.0

 

  6.2  5.8  6.1 

Research and development tax credits

  (0.4) (0.3) (1.8)

Amortization of excess deferred taxes

  (0.5) (0.5) (1.4)

Amortization of investment tax credits

  (0.9) (0.9) (1.4)

Adjustment of prior period taxes

  

(1.1

)

  

(2.8

)

  

(0.8

)

  (1.5) (0.8) (1.1)

Amortization of investment tax credits

  

(1.4

)

  

(1.6

)

  

(1.6

)

Amortization of excess deferred taxes

  

(1.4

)

  

(1.5

)

  

(1.3

)

Research and development tax credits

  

(1.8

)

  

—  

 

  

—  

 

Other items, net

  

0.2

 

  

0.4

 

  

0.2

 

  (1.1) (1.9) 0.2 
  

  

  

  

 

 

Overall effective income tax rate

  

35.6

%

  

35.9

%

  

37.5

%

  36.8% 36.4% 35.6%
  

  

  

  

 

 

 

The accumulated deferred income tax (assets) and liabilities included on the Consolidated Balance Sheets at Dec. 31 arise from the following temporary differences (in millions):

 

  

2002


   

2001


 

Property related

  

$201.2

 

  

$200.8

 

Minimum pension liability

  

(16.4

)

  

(9.6

)

Decommissioning

  

(25.2

)

  

(20.8

)

Other

  

32.3

 

  

35.8

 

  

  

  

$191.9

 

  

$206.2

 

  2004

 2003

 
  

  

  Deferred
Tax Assets


 Deferred Tax
Liabilities


  Net

 Deferred
Tax Assets


 Deferred Tax
Liabilities


  Net

 

Property

  ($13.2) $222.7  $209.5  ($14.3) $216.0  $201.7 

Decommissioning

  (23.5)  —     (23.5) (22.2)  —     (22.2)

Investment in American Transmission Co. LLC (ATC)

  —     14.0   14.0  —     7.9   7.9 

Other

  (8.0)  32.6   24.6  (20.2)  39.9   19.7 
  

 

  


 

 

  


Total

  ($44.7) $269.3  $224.6  ($56.7) $263.8  $207.1 
  

 

  


 

 

  


      2004     2003 
     


   


Other current assets

      ($8.0)    ($6.6)

Deferred income taxes

      232.6     213.7 
     


   


Total deferred tax (assets) and liabilities

     $224.6    $207.1 
     


   


 

(6) PENSION PLANS AND OTHER POSTRETIREMENT BENEFITS

 

Substantially all of WP&L’sWPL’s employees are covered by twoseveral non-contributory defined benefit pension plans. Benefits are based on the employees’ years of service and compensation. For theWPL also provides certain defined benefit pension plan sponsored by Corporate Services, Alliant Energy allocates pension costspostretirement health care and life benefits to eligible retirees. In general, the health care plans are contributory with participants’ contributions to WP&L based on labor costs of plan participantsadjusted regularly and any additional minimum pension liability based on each group’s funded status.the life insurance plans are non-contributory. The weighted-average assumptions at the measurement date of Sept.Sep. 30 were as follows:follows (N/A=Not Applicable):

 

  

Qualified Pension Benefits


  

Other Postretirement Benefits


  

2002


  

2001


  

2000


  

2002


  

2001


  

2000


  Qualified Pension Benefits

 Other Postretirement Benefits

 

Discount rate

  

6.75%

  

7.25%

  

8.00%

  

6.75%

  

7.25%

  

8.00%

  2004

 2003

 2002

 2004

 2003

 2002

 

Discount rate for benefit obligations

  6% 6% 6.75% 6% 6% 6.75%

Discount rate for net periodic cost

  6% 6.75% 7.25% 6% 6.75% 7.25%

Expected return on plan assets

  

9%

  

9%

  

9%

  

9%

  

9%

  

9%

  9% 9% 9% 9% 9% 9%

Rate of compensation increase

  

3.5%

  

3.5%

  

3.5%

  

3.5%

  

3.5%

  

3.5%

  3.5% 3.5% 3.5% 3.5% 3.5% 3.5%

Medical cost trend on covered charges:

                     

Initial trend rate

  

N/A

  

N/A

  

N/A

  

10.8%

  

12.0%

  

9.0%

  N/A  N/A  N/A  10% 9.5% 10.8%

Ultimate trend rate

  

N/A

  

N/A

  

N/A

  

5%

  

5%

  

5%

  N/A  N/A  N/A  5% 5% 5%

 

The expected return on plan assets was determined by analysis of forecasted asset class returns as well as actual returns for the plan over the past 10 years. An adjustment to the returns to account for active management of the assets is also made in the analysis. The obligations are viewed as long-term commitments and a long-term approach is used when determining the expected rate of return on assets, which is reviewed on an annual basis.

The components of WP&L’sWPL’s qualified pension benefits and other postretirement benefits costs were as follows (in millions):

 

  

Qualified Pension Benefits


   

Other Postretirement Benefits


   Qualified Pension Benefits

 Other Postretirement Benefits

 
  

2002


   

2001


   

2000


   

2002


   

2001


   

2000


   2004

 2003

 2002

 2004

 2003

 2002

 

Service cost

  

$3.6

 

  

$2.8

 

  

$3.0

 

  

$2.4

 

  

$1.6

 

  

$1.4

 

  $5.0  $4.0  $3.6  $4.0  $3.4  $2.4 

Interest cost

  

10.1

 

  

9.2

 

  

8.9

 

  

4.4

 

  

3.6

 

  

3.3

 

   11.2   10.6   10.1   5.4   5.2   4.4 

Expected return on plan assets

  

(12.2

)

  

(13.7

)

  

(12.9

)

  

(1.6

)

  

(1.7

)

  

(1.6

)

   (15.9)  (13.5)  (12.2)  (1.7)  (1.4)  (1.6)

Amortization of:

                  

Amortization of (*):

   

Transition obligation (asset)

  

(1.7

)

  

(2.1

)

  

(2.1

)

  

1.1

 

  

1.2

 

  

1.2

 

   —     —     (1.7)  1.1   1.1   1.1 

Prior service cost

  

0.4

 

  

0.5

 

  

0.4

 

  

—  

 

  

—  

 

  

—  

 

   0.6   0.4   0.4   —     —     —   

Actuarial loss (gain)

  

1.5

 

  

—  

 

  

—  

 

  

0.1

 

  

(0.6

)

  

(0.8

)

Actuarial loss

   3.0   3.5   1.5   1.4   0.8   0.1 
  

  

  

  

  

  

  


 


 


 


 


 


  

$1.7

 

  

($3.3

)

  

($2.7

)

  

$6.4

 

  

$4.1

 

  

$3.5

 

  $3.9  $5.0  $1.7  $10.2  $9.1  $6.4 
  

  

  

  

  

  

  


 


 


 


 


 


*Unrecognized net actuarial losses in excess of 10% of the projected benefit obligation and unrecognized prior service costs are amortized over the average future service lives of the participants. Unrecognized net transition obligations related to other postretirement benefits are amortized over a 20-year period ending 2012.

 

The pension benefit costbenefits costs shown abovepreviously (and in the following tables) representsrepresent only the pension benefit costbenefits costs for bargaining unit employees of WP&LWPL covered under the bargaining unit pension plan that is sponsored by WP&L.WPL. The benefit obligations and assets associated with WP&L’sWPL’s non-bargaining employees who are participants in other Alliant Energy plans are reported in Alliant Energy’s consolidated financial statementsConsolidated Financial Statements and are not reported above.previously. The pension benefit (income) costbenefits costs for WP&L’sWPL’s non-bargaining employees who are now participants in other Alliant Energy plans waswere $0.5 million, $1.9 million and $0.3 million ($1.5) millionfor 2004, 2003 and ($1.3) million for 2002, 2001 and 2000, respectively. In addition, Corporate Services provides services to WP&L.WPL. The allocated pension benefitbenefits costs associated with these services waswere $2.1 million, $2.0 million and $1.7 million $1.3 millionfor 2004, 2003 and $1.3 million for 2002, 2001 and 2000, respectively. The other postretirement benefit costbenefits costs shown abovepreviously for each period (and in the following tables) representsrepresent the other postretirement benefit costbenefits costs for all WP&LWPL employees. The allocated other postretirement benefit costbenefits costs associated with Corporate Services for WP&L wasWPL were $1.6 million, $0.9 million and $0.5 million $0.3 millionfor 2004, 2003 and $0.3 million for 2002, 2001 and 2000, respectively.

 

The assumed medical trend rates are critical assumptions in determining the service and interest cost and accumulated postretirement benefit obligation related to postretirement benefitbenefits costs. A one percent1% change in the medical trend rates for 2002,2004, holding all other assumptions constant, would have the following effects (in millions):

 

    

1% Increase


    

1% Decrease


  1% Increase

  1% Decrease

 

Effect on total of service and interest cost components

    

$0.6

    

($0.6)

  $1.2  ($1.1)

Effect on postretirement benefit obligation

    

$5.6

    

($5.1)

  $9.7  ($8.7)

A reconciliation of the funded status of WP&L’sWPL’s plans to the amounts recognized on WP&L’sthe Consolidated Balance Sheets at Dec. 31 was as follows (in millions):

 

  

Qualified Pension Benefits


   

Other Postretirement Benefits


 
  

2002


   

2001


   

2002


   

2001


   Qualified Pension Benefits

 Other Postretirement Benefits

 

Change in benefit obligation:

            

Net benefit obligation at beginning of year

  

$139.2

 

  

$115.9

 

  

$60.5

 

  

$42.3

 

  2004

 2003

 2004

 2003

 

Change in projected benefit obligation:

   

Net projected benefit obligation at beginning of year

  $181.0  $156.0  $93.1  $76.6 

Service cost

  

3.6

 

  

2.8

 

  

2.4

 

  

1.6

 

   5.0   4.0   4.0   3.4 

Interest cost

  

10.1

 

  

9.2

 

  

4.4

 

  

3.6

 

   11.2   10.6   5.4   5.2 

Plan participants’ contributions

  

—  

 

  

—  

 

  

1.5

 

  

1.6

 

   —     —     1.6   1.5 

Plan amendments

   5.7   —     —     —   

Actuarial loss

  

10.3

 

  

18.3

 

  

13.2

 

  

16.6

 

   6.9   17.8   7.7   11.7 

Gross benefits paid

  

(7.2

)

  

(7.0

)

  

(5.4

)

  

(5.2

)

   (7.3)  (7.4)  (6.5)  (5.3)
  

  

  

  

  


 


 


 


Net benefit obligation at end of year

  

156.0

 

  

139.2

 

  

76.6

 

  

60.5

 

Net projected benefit obligation at end of year

   202.5   181.0   105.3   93.1 
  

  

  

  

  


 


 


 


Change in plan assets:

               

Fair value of plan assets at beginning of year

  

138.8

 

  

156.3

 

  

17.8

 

  

19.4

 

   175.0   153.5   19.5   16.7 

Actual return on plan assets

  

(8.1

)

  

(10.5

)

  

(1.4

)

  

(0.5

)

   20.2   28.9   2.1   2.2 

Employer contributions

  

30.0

 

  

—  

 

  

4.2

 

  

2.5

 

   5.0   —     4.0   4.4 

Plan participants’ contributions

  

—  

 

  

—  

 

  

1.5

 

  

1.6

 

   —     —     1.6   1.5 

Gross benefits paid

  

(7.2

)

  

(7.0

)

  

(5.4

)

  

(5.2

)

   (7.3)  (7.4)  (6.5)  (5.3)
  

  

  

  

  


 


 


 


Fair value of plan assets at end of year

  

153.5

 

  

138.8

 

  

16.7

 

  

17.8

 

   192.9   175.0   20.7   19.5 
  

  

  

  

  


 


 


 


Funded status at end of year

  

(2.5

)

  

(0.4

)

  

(59.9

)

  

(42.7

)

   (9.6)  (6.0)  (84.6)  (73.6)

Unrecognized net actuarial loss

  

63.5

 

  

34.3

 

  

20.4

 

  

4.4

 

   62.0   62.4   36.4   30.5 

Unrecognized prior service cost

  

3.4

 

  

3.9

 

  

(0.1

)

  

(0.2

)

   8.1   3.0   (0.1)  (0.1)

Unrecognized net transition obligation (asset)

  

—  

 

  

(1.7

)

  

11.5

 

  

12.6

 

Unrecognized net transition obligation

   —     —     9.2   10.3 
  

  

  

  

  


 


 


 


Net amount recognized at end of year

  

$64.4

 

  

$36.1

 

  

($28.1

)

  

($25.9

)

  $60.5  $59.4   ($39.1)  ($32.9)
  

  

  

  

  


 


 


 


Amounts recognized on the Consolidated Balance Sheets
consist of:

               

Prepaid benefit cost

  

$64.4

 

  

$36.1

 

  

$1.5

 

  

$1.3

 

  $60.5  $59.4  $1.6  $1.5 

Accrued benefit cost

  

—  

 

  

—  

 

  

(29.6

)

  

(27.2

)

   —     —     (40.7)  (34.4)
  

  

  

  

  


 


 


 


Net amount recognized at measurement date

  

64.4

 

  

36.1

 

  

(28.1

)

  

(25.9

)

   60.5   59.4   (39.1)  (32.9)
  

  

  

  

  


 


 


 


Contributions paid after 9/30 and prior to 12/31

  

—  

 

  

—  

 

  

1.0

 

  

1.1

 

   —     —     0.6   0.4 
  

  

  

  

  


 


 


 


Net amount recognized at 12/31

  

$64.4

 

  

$36.1

 

  

($27.1

)

  

($24.8

)

  $60.5  $59.4   ($38.5)  ($32.5)
  

  

  

  

  


 


 


 


 

TheIn 2004, the PSCW authorized Wisconsin utilities to record additional minimum pension liability to “Regulatory assets” in lieu of “Accumulated other comprehensive loss” on their Consolidated Balance Sheets. At Dec. 31, 2004 and 2003, Corporate Services allocated a minimum pension liability of $44 million and $34 million, respectively. Included in the following table are WPL’s accumulated benefit obligationobligations, amounts applicable to qualified pension and fair value of plan assets for theother postretirement welfare plansbenefits with accumulated benefit obligations in excess of plan assets, were $74.7 million and $13.7 million, respectively,as well as qualified pension plans with projected benefit obligations in excess of plan assets as of Sept.the measurement date of Sep. 30 2002 and $53.8 million and $8.5 million, respectively, as of Sept. 30, 2001. At Dec. 31, 2002 and 2001, Corporate Services allocated an additional minimum liability of $41.3 million and $0 million, respectively. WP&L’s(in millions):

   Qualified Pension Benefits

  Other Postretirement Benefits

   2004

  2003

  2004

  2003

Accumulated benefit obligation

  $181.8  $165.7  $105.3  $93.1

Plans with accumulated benefit obligations in excess of plan assets:

                

Accumulated benefit obligations

   —     —     103.6   91.5

Fair value of plan assets

   —     —     17.3   16.3

Plans with projected benefit obligations in excess of plan assets:

                

Projected benefit obligations

   202.5   181.0   N/A   N/A

Fair value of plan assets

   192.9   175.0   N/A   N/A

WPL’s net periodic benefit cost is primarily included in “Other operation and maintenance” in the Consolidated Statements of Income. WPL calculates the fair value of plan assets by using the straight market value of assets approach.

 

Postretirement benefit plans are funded via specific assets within certain retirement plans (401(h) assets) as well as a Voluntary Employees’ Beneficiary Association (VEBA) trust. The asset allocation of the 401(h) assets mirror the qualified pension plan assets and the asset allocation of the VEBA trust are reflected in the following table under “Other Postretirement Plans.” The asset allocation for WPL’s qualified pension and other postretirement benefit plans at Sep. 30, 2004 and 2003, and the qualified pension plan target allocation for 2004 were as follows:

   Qualified Pension Plans

  Other Postretirement Plans

 
   

Target

Allocation


  

Percentage of Plan

Assets at Sep. 30,


  

Percentage of Plan

Assets at Sep. 30,


 

Asset Category


  2004

  2004

  2003

  2004

  2003

 

Equity securities

  65-75% 73% 61% 10% 15%

Debt securities

  20-35% 27% 33% 20% 33%

Other

  0-5% —    6% 70% 52%
      

 

 

 

      100% 100% 100% 100%
      

 

 

 

WPL’s plan assets are managed by outside investment managers. WPL’s investment strategy and its policies employed with respect to pension and postretirement assets is to combine both preservation of principal and prudent and reasonable risk-taking to protect the integrity of the assets in meeting the obligations to the participants while achieving the optimal return possible over the long-term. It is recognized that risk and volatility are present to some degree with all types of investments; however, high levels of risk are minimized at the total fund level. This is accomplished through diversification by asset class, number of investments, and sector and industry limits when applicable.

For the pension plans, the mix among asset classes is controlled by long-term asset allocation targets. The assets are viewed as long-term with moderate liquidity needs. Historical performance results and future expectations suggest that equity securities will provide higher total investment returns than debt securities over a long-term investment horizon. Consistent with the goals to maximize returns and minimize risk over the long-term, the pension plans have a long-term investment posture more heavily weighted towards equity holdings. The asset allocation mix is monitored quarterly and appropriate action is taken as needed to rebalance the assets within the prescribed range. Assets related to postretirement plans are viewed as long-term. A mix of both equity and debt securities are utilized to maximize returns and minimize risk over the long-term. Prohibited investment vehicles related to the pension and postretirement plans include, but may not be limited to, direct ownership of real estate, real estate investment trusts, options and futures unless specifically approved, margin trading, oil and gas limited partnerships, commodities, short selling and securities of the managers’ firms or affiliate firms.

WPL estimates that funding for the qualified pension and postretirement benefit plans for 2005 will be $0 and approximately $4 million, respectively.

The expected benefit payments and Medicare subsidies, which reflect expected future service, as appropriate, are as follows:

   2005

  2006

  2007

  2008

  2009

  2010 - 2014

 

Pension benefits

  $7.4  $7.4  $7.6  $7.8  $8.3  $54.8 

Other benefits

   7.5   7.1   7.4   7.9   8.5   53.4 

Medicare subsidies

   —     (0.6)  (0.6)  (0.7)  (0.7)  (4.3)
   

  


 


 


 


 


   $14.9  $13.9  $14.4  $15.0  $16.1  $103.9 
   

  


 


 


 


 


In 2004, WPL adopted FASB Staff Position No. SFAS 106-2, “Accounting and Disclosure Requirements Related to the Medicare Prescription Drug, Improvement and Modernization Act of 2003.” The U.S. Department of Health and Human Services recently provided initial guidance regarding actuarial equivalence. Additional guidance and clarifications are expected to be provided in the future. WPL believes that a substantial portion of its postretirement medical plans will be actuarially equivalent to the Medicare Prescription Drug Plan. WPL anticipates continuing its current prescription drug coverage for currently covered retirees and therefore should be eligible for the subsidy available from Medicare. The estimated reductions in WPL’s 2004 other postretirement benefits costs and accumulated projected benefit obligation are $1 million and $7 million, respectively.

Alliant Energy sponsors several non-qualified pension plans that cover certain current and former key employees. The pension expense allocated to WP&LWPL for these plans was $1.8 million, $1.7 million and $1.5 million $1.0 millionin 2004, 2003 and $1.2 million in 2002, 2001 and 2000, respectively. WP&LWPL has various life insurance policies that cover certain key employees and directors. At both Dec. 31, 20022004 and 2001,2003, the cash surrender value of these investments was $10 million and $9 million, respectively.$11 million. A significant number of WP&LWPL employees also participate in defined contribution pension plans (401(k) plans). WP&L’sWPL’s contributions to the plans, which are based on the participants’ level of contribution, were $2.2$2.3 million, $2.1 million and $2.1$2.2 million in 2002, 20012004, 2003 and 2000,2002, respectively.

 

(7) COMMON AND PREFERRED STOCK

 

(a) Common Stock—Stock -WP&L WPL has dividend payment restrictions based on its bond indentures, the terms of its outstanding preferred stock and state regulatory limitations. WP&L’s preferred stock restricts dividends to the extent that such dividend would reduce the common stock equity ratio to less than 25%. In its September 2002December 2003 rate order, the PSCW stated it must approve the paymentWPL may not pay annual common stock dividends, including pass-through of subsidiary dividends, by WP&Lin excess of $89 million to Alliant Energy in excess of the level forecasted in the order ($62 million annually) if such dividends would reduce WP&L’sWPL’s actual average common equity ratio, on a regulatory financial basis, is or will fall below 44.67%the authorized level of total capitalization.54.01%. As of Dec. 31, 2002, WP&L2004, WPL was in compliance with all such dividend restrictions.

 

(b) Preferred Stock—Stock -The carrying value of WP&L’sWPL’s cumulative preferred stock at both Dec. 31, 20022004 and 20012003 was $60 million. The fair market value, based upon the market yield of similar securities and quoted market prices, at Dec. 31, 20022004 and 20012003 was $48$55 million and $49$53 million, respectively.

 

(8) DEBT

 

(a) Short-Term Debt—Debt -To provide short-term borrowing flexibility and security for commercial paper outstanding, WP&LWPL maintains committed bank lines of credit, of which most require a fee. Alliant Energy discontinued the use of its utility money pool in 2002 and WP&L is now meeting any short-term borrowing needs it has by issuing commercial paper. At Dec. 31, 2001, W&L had money pool borrowings2004, WPL’s short term borrowing arrangements included a $250 million revolving credit facility (facility). The facility is designed to be a five-year facility with the length of $90.8 million.the facility subject to various regulatory approvals given the term is longer than a 364-day facility. Information regarding WP&L’s short-term debtcommercial paper issued under the facility was as follows (dollars in millions):

 

   

2002


  

2001


At Dec. 31:

      

Commercial paper outstanding

  

$60.0

  

$ —  

Discount rates on commercial paper

  

1.6%

  

N/A

Money pool borrowings

  

$ —  

  

$90.8

Interest rates on money pool borrowings

  

N/A

  

2.4%

For the year ended:

      

Average amount of short-term debt (based on daily outstanding balances)

  

$57.4

  

$23.8

Average interest rates on short-term debt

  

1.8%

  

3.7%

   2004

  2003

 

At Dec. 31:

         

Commercial paper outstanding

  $47.0  $—   

Average discount rates - commercial paper

   2.3%  N/A 

For the year ended:

         

Average amount of total short-term debt (based on daily outstanding balances)

  $12.8  $29.8 

Average interest rates - total short-term debt

   1.4%  1.4%

 

(b) Long-Term Debt—Debt -WP&L’s WPL’s First Mortgage Bonds are secured by substantially all of its utility plant. WP&LWPL also maintains indentures relatingrelated to the issuance of unsecured debt securities. WP&L’sWPL’s debt maturities for 20032005 to 20072009 are $0, $62.0 million, $88.0$88 million, $0, $105 million, $60 million, and $105.0 million,$0, respectively. The carrying value of WP&L’sWPL’s long-term debt (including current maturities and variable rate demand bonds) at both Dec. 31, 20022004 and 20012003 was $523 million.$491 million and $454 million, respectively. The fair market value, based upon the market yield of similar securities and quoted market prices, at Dec. 31, 20022004 and 20012003 was $574$532 million and $548$494 million, respectively. WPL’s unamortized debt issuance costs recorded in “Deferred charges and other” on the Consolidated Balance Sheets were $4.0 million and $4.2 million at Dec. 31, 2004 and 2003, respectively.

In August 2004, WPL issued $100 million of 6.25% senior debentures due 2034 and used the proceeds to repay short-term debt, including $62 million incurred in connection with the repayment at maturity of 7.25% first mortgage bonds in June 2004, and for general corporate purposes.

(9) INVESTMENTS AND ESTIMATED FAIR VALUE OF FINANCIAL INSTRUMENTS

 

The carrying amount of WP&L’sWPL’s current assets and current liabilities approximates fair value because of the short maturity of such financial instruments. Since WP&LWPL is subject to regulation, any gains or losses related to the difference between the carrying amount and the fair value of its financial instruments may not be realized by Alliant Energy. Information relating to various investments held by WP&LWPL at Dec. 31 that are marked-to-market as a result of SFAS 115, “Accounting for Certain Investments in Debt and Equity Securities,” (SFAS 115) was as follows (in millions):

 

  

2002


  

2001


  2004

  2003

  

Carrying/

Fair Value


    

Unrealized Gains,

Net of Tax


  

Carrying/

Fair Value


    

Unrealized

Gains,

Net of Tax


  Carrying/
Fair Value


  

Unrealized
Gains,

Net of Tax


  Carrying/
Fair Value


  

Unrealized
Gains,

Net of Tax


Available-for-sale securities:

                            

Nuclear decommissioning trust funds:

                            

Debt securities

  

$131

    

$5

  

$122

    

$2

  $21.0  $0.7  $136.9  $3.3

Equity securities

  

93

    

5

  

94

    

23

   51.3   13.0   96.8   18.6
  
    
  
    

Total

  

$224

    

$10

  

$216

    

$25

  
    
  
    

In accordance with SFAS 115, the carrying values of the investments are adjusted to estimated fair value based upon market values at the end of each quarter.

Refer to Notes 7(b), 8(b) and 10(a) for information regarding the fair values of preferred stock, long-term debt and derivatives, respectively.

 

Nuclear Decommissioning Trust Funds—Funds -At Dec. 31, 2002, $752004, $0.2 million, $24$3.1 million and $32$17.7 million of the debt securities mature in 2003-2010, 2011-20202005-2009, 2010-2019 and 2021-2049,2020-2040, respectively. The fair value of the nuclear decommissioning trust funds, as reported by the trustee, was adjusted for the tax effect of unrealized gains and losses. Net unrealized holding gains were recorded as part of regulatory liabilities or as an offset to regulatory assets related to AROs. The funds realized pre-tax gains (losses) from the sales of securities of $10.3$12 million, $2.1($6) million and $5.2$10 million in 2002, 20012004, 2003 and 2000,2002, respectively (cost of the investments based on specific identification was $92.2 million, $147.4$1.1 billion, $334 million and $202.1$92 million and pre-tax proceeds from the sales were $102.5 million, $149.5$1.1 billion, $328 million and $207.3$102 million, respectively). In January 2004, WPL liquidated all of the qualified decommissioning assets into money market funds as a result of the anticipated Kewaunee sale and at Dec. 31, 2004, the value of the qualified decommissioning assets was $171 million.

 

Investment in ATC—Unconsolidated Equity Investments -At Dec. 31, 20022004 and 2001, WP&L2003, WPL had $154 million and $133 million of investments in equity method investees, respectively, consisting of a 24% ownership interestsinterest in ATC (carrying value of approximately 26.6%$141 million at Dec. 31, 2004) and 26.5%a 50% ownership interest in Wisconsin River Power Company (carrying value of $13 million at Dec. 31, 2004), respectively, and accounts for this investment underrespectively. Summary financial information from the equity method.financial statements of these investments is as follows (in millions):

   2004

  2003

  2002

Operating revenues

  $270.3  $232.3  $211.7

Operating income

   107.1   87.7   75.7

Net income

   90.5   72.1   59.5

As of Dec. 31:

            

Current assets

   39.1   41.5    

Non-current assets

   1,176.6   947.2    

Current liabilities

   194.5   67.9    

Non-current liabilities

   457.7   14.6    

ATC- Pursuant to various agreements, WP&LWPL receives a range of transmission services from ATC. WP&LWPL provides operation, maintenance, and various transitional and construction services to ATC. WP&LWPL and ATC also bill each other for use of shared facilities owned by each party. ATC billed WP&L $38.7WPL $48 million, $41 million and $36.4$39 million in 2004, 2003 and 2002, and 2001, respectively. WP&LWPL billed ATC $18.1$13 million, $12 million and $18.4$18 million in 2004, 2003 and 2002, respectively. At Dec. 31, 2004 and 2001, respectively, and recorded equity earnings2003, WPL owed ATC net amounts of $14.3$2.9 million and $14.6$2.7 million, in 2002 and 2001, respectively.

 

Unconsolidated Equity Investments—Summary financial informationNuclear Management Company, LLC (NMC) - WPL receives services from WP&L’s unconsolidated equity investments’ financial statements is as follows (in millions):NMC for the management and operation of Kewaunee. NMC billed WPL indirectly through Wisconsin Public Service Corporation (WPSC) $34 million, $33 million and $24 million in 2004, 2003 and 2002, respectively, for its allocated portion for Kewaunee.

   

2002


  

2001


  

2000


Operating revenues

  

$211.7

  

$180.3

  

$5.3

Operating income

  

75.7

  

65.8

  

1.3

Net income

  

59.5

  

55.9

  

1.6

As of Dec. 31:

         

Current assets

  

44.7

  

59.5

   

Non-current assets

  

774.4

  

681.4

   

Current liabilities

  

50.8

  

39.3

   

Non-current liabilities

  

7.5

  

4.4

   

(10) DERIVATIVE FINANCIAL INSTRUMENTS

 

(a) Accounting for Derivative Instruments and Hedging Activities—Activities -WP&L WPL records derivative instruments at fair value on the balance sheet as assets or liabilities and changes in the derivatives’ fair values are generally recorded as regulatory assets or liabilities. The PSCW issued a letter to WP&L in August 2002 authorizing accounting for its derivatives in such manner. At Dec. 31, 20022004 and 2001,2003, WP&L had $2.7$4.7 million and $5.9$1.3 million respectively, of derivative assets included in “Other current assets” on its Consolidated Balance Sheets and $7.1$6.7 million and $0.6$3.6 million respectively, of derivative liabilities included in “Other current liabilities” on itsthe Consolidated Balance Sheets.

Cash Flow Hedging Instruments—During 2002 and 2001, WP&L held various derivative instruments designated as cash flow hedging instruments. WP&L utilized gas commodity financial swap arrangements to reduce the impact of price fluctuations on gas purchased and injected into storage during the summer months and withdrawn and sold at current market prices during the winter months pursuant to the natural gas cost incentive sharing mechanism with customers in Wisconsin. WP&L also utilized physical coal purchase contracts, which did not qualify for the normal purchase and sale exception, to manage the price of anticipated coal purchases and sales.Sheets, respectively.

 

In 2002 and 2001, net losses of $0.2 million and $0.1 million, respectively, were recognized relating to the amount of hedge ineffectiveness in accordance with SFAS 133. In 2002 and 2001, WP&L did not exclude any components of the derivative instruments’ gain or loss from the assessment of hedge effectiveness and in 2001 reclassified a loss of $0.9 million into earnings as a result of the discontinuance of hedges. At Dec. 31, 2002, the maximum length of time over which WP&L hedged its exposure to the variability in future cash flows for forecasted transactions was three months and WP&L estimated that gains of $0.3 million will be reclassified from accumulated other comprehensive income (loss) into earnings in 2003 as the hedged transactions affect earnings.

Other Derivatives Not Designated in Hedge Relationships—WP&L’sWPL’s derivatives that were not designated in hedge relationships during 20022004 and/or 20012003 included electricity price collars and physical coal and gas contracts. Electricity price collars were used to manage utility energy costs during supply/demand imbalances. Physical coalCoal and gas contracts that do not qualify for the normal purchase and sale exception were used to manage the price of anticipated coal and gas purchases and sales.

 

(b) Weather Derivatives—Derivatives -WP&L WPL uses weather derivatives to reduce the impact of weather volatility on its natural gas sales volumes. In 20022004, 2003 and 2001,2002, Corporate Services, as agent for IP&L and WP&L,WPL, entered into non-exchange traded options based on heating degree days in which Corporate Services receives payment from the counterparty if actual heating degree days are less than the strike priceheating degree days specified in the contract. Corporate Services paid premiums to enter into these contracts, which are amortized to expense over the contract period. WP&LWPL has used the intrinsic value method to account for these weather derivatives. Information relating to these weather derivatives was as follows (in millions):

 

   2004

  2003

  2002

Premiums paid

  $1.2  $0.9  $0.9

Premiums amortized to expense

   1.0   0.9   0.9

Gains

   —     0.8   0.9

Amounts received from counterparties

   —     —     4.0

(c) Nuclear Decommissioning Trust Fund Investments—Historically, WP&L has entered into combinations of options to mitigate the effect of significant market fluctuations on its common stock investments in its nuclear decommissioning trust funds. The derivative transactions are designed to protect the portfolio’s value while allowing the funds to earn a total return modestly in excess of long-term expectations over the hedge period. Fair value changes of these instruments

WPL’s ratepayers do not impact net income aspay any of the premiums nor do they are recorded as equally offsetting changesshare in the investment in nuclear decommissioning trust funds and accumulated depreciation.gains/losses realized from the weather hedges.

 

(11) COMMITMENTS AND CONTINGENCIES

 

(a) Construction and Acquisition Expenditures—Expenditures -Certain WPL has made certain commitments have been made in connection with 2003its 2005 capital expenditures. During 2003, total construction and acquisition expenditures are estimated to be approximately $160 million.

 

(b) Purchased-Power, Coal and Natural Gas Contracts—Purchase Obligations -Alliant Energy, through its subsidiaries Corporate Services, IP&LInterstate Power and WP&L,Light Company (IPL) and WPL, has entered into purchased-power,purchased power, coal and natural gas supply, transportation and storage contracts. Certain purchased-powerpurchased power commitments are considered operating leases and are therefore not included here, but are included in Note 3. Based on the System Coordination and Operating Agreement, Alliant Energy annually allocates purchased-power contracts to IP&L and WP&L. Such process considers factors such as resource mix, load growth and resource availability. However, for 2003, system-wide purchased-power contracts of $45.1 million (1.6 million MWh) have not yet been directly assigned to IP&L and WP&L since the specific needs of each utility is not yet known. Refer to Note 15 for additional information. Coal contract quantities are directly assigned to specific plants at IP&L and WP&L based on various factors including projected heat input requirements, combustion compatibility and efficiency. However, for 2003-2006, system-wide coal contracts of $56.1 million (7.8 million tons), $37.5 million (7.6 million tons), $28.0 million (4.7 million tons) and $8.2 million (0.9 million tons), respectively, have not yet been directly assigned to IP&L and WP&L since the specific needs of each utility is not yet known. The natural gas supply commitments and purchased-power contracts are alleither fixed price in nature or market-based. The coal commitments are fixed price and the transportation contracts are index-based. Alliant Energy expects to supplement its coal and natural gas supplies with spot market purchases as needed. The table includes commitments for

“take-or-pay” “take-or-pay” contracts which result in dollar commitments with no associated tons or Dths.dekatherms (Dths). Based on the System Coordination and Operating Agreement, Alliant Energy annually allocates purchased power contracts to IPL and WPL, based on various factors such as resource mix, load growth and resource availability. The amounts in the following table reflect these allocated contracts. However, for 2005, system-wide purchased power contracts of $85.9 million (1.7 million megawatt-hours (MWhs)) have not yet been directly assigned to IPL and WPL since the specific needs of each utility are not yet known. Refer to Note 19 for additional information. Coal contract quantities are directly assigned to specific generating stations at WPL based on various factors including projected heat input requirements, combustion compatibility and efficiency. In addition, WPL enters into specific coal transportation contracts for its generating stations. The amounts in the following table reflect these directly assigned coal and corresponding coal transportation contracts. In addition, Corporate Services entered into system-wide coal contracts of $74.7 million (10.6 million tons), $48.7 million (7.4 million tons), $24.0 million (3.8 million tons), $12.2 million (1.8 million tons) and $2.8 million (0.4 million tons) on behalf of IPL and WPL for 2005 to 2009, respectively, to allow flexibility for the changing needs of the quantity of coal consumed by each. These contracts have not yet been directly assigned to IPL and WPL since the specific needs of each utility are not yet known. At Dec. 31, 2002, WP&L’s2004, WPL’s minimum commitments were as follows (dollars and Dths in millions; MWhs and tons in thousands):

 

  

Purchased-power


  

Coal


  

Natural gas


  

Dollars


  

MWhs


  

Dollars


  

Tons


  

Dollars


  

Dths


 Purchased power

 Coal

 Natural gas

2003

  

$31.3

  

219

  

$6.9

  

—  

  

$48.1

  

2

2004

  

8.0

  

219

  

6.9

  

—  

  

32.3

  

—  

 Dollars

 MWhs

 Dollars

 Tons

 Dollars

 Dths

2005

  

—  

  

—  

  

1.3

  

—  

  

25.0

  

—  

 $6.0 —   $8.0 —   $114.4 15

2006

  

—  

  

—  

  

1.3

  

—  

  

14.1

  

—  

  3.2 —    8.0 —    50.0 4

2007

  

—  

  

—  

  

1.3

  

—  

  

13.3

  

—  

  3.2 —    8.0 —    20.9 —  
2008  3.2 —    6.2 —    15.8 —  
2009  3.2 —    6.2 —    15.7 —  

Thereafter

  

—  

  

—  

  

—  

  

—  

  

26.4

  

—  

  10.6 —    31.2 —    22.2 —  

Also, at Dec. 31, 2004, WPL’s other purchase obligations, which represent individual commitments incurred during the normal course of business which exceeded $1.0 million at Dec. 31, 2004, were $9 million for 2005. This excludes lease obligations which are included in Note 3.

 

(c) Legal Proceedings—Proceedings -WP&LWPL is involved in legal and administrative proceedings before various courts and agencies with respect to matters arising in the ordinary course of business. Although unable to predict the outcome of these matters, WP&LWPL believes that appropriate reserves have been established and final disposition of these actions will not have a material adverse effect on its financial condition or results of operations.

 

(d) Guarantees and Commitments—-Refer to Note 3 for discussion of WP&L’sWPL’s residual value guarantees of its synthetic leases. In November 2002, the FASB issued FIN 45 which requires disclosures by a guarantor about its obligations under certain guarantees that it has issued. FIN 45 also requires recognizing, at the inception of a guarantee, a liability for the fair value of the obligation undertaken in issuing the guarantee. The recognition and measurement provisions of FIN 45 are effective on a prospective basis for guarantees issued or modified after Dec. 31, 2002. WP&L does not anticipate FIN 45 will have a material impact on its financial condition or results of operations.

 

(e) Environmental Liabilities—Liabilities -WP&LWPL had recorded the following environmental liabilities, and regulatory assets associated with certain of these liabilities at Dec. 31 (in millions):

 

   

Environmental Liabilities


  

Regulatory Assets


   

2002


  

2001


  

2002


  

2001


MGP sites

  

$6.9

  

$4.4

  

$13.0

  

$11.7

NEPA

  

2.5

  

3.1

  

3.1

  

4.0

Other

  

—  

  

—  

  

2.9

  

3.0

   
  
  
  
   

$9.4

  

$7.5

  

$19.0

  

$18.7

   
  
  
  
   2004

  2003

Manufactured gas plant (MGP) sites

  $5.2  $5.4

Other

   1.3   2.0
   

  

   $6.5  $7.4
   

  

 

MGP Sites—WP&L -WPL has current or previous ownership interests in 14 sites previously associated with the production of gas for which it may be liable for investigation, remediation and monitoring costs relating to the sites. WP&LWPL has received letters from state environmental agencies requiring no further action at fivesix sites. WP&LWPL is working pursuant to the requirements of various federal and state agencies to investigate, mitigate, prevent and remediate, where necessary, the environmental impacts to property, including natural resources, at and around the sites in order to protect public health and the environment.

 

WP&LWPL records environmental liabilities based upon periodic studies, most recently updated in the third quarter of 2002,2004, related to the MGP sites. Such amounts are based on the best current estimate of the remaining amount to be incurred for investigation, remediation and monitoring costs for those sites where the investigation process has been or is substantially completed, and the minimum of the estimated cost range for those sites where the investigation is in its earlier stages. It is possible that future cost estimates will be greater than current estimates as the investigation process proceeds and as additional facts become known. The amounts recognized as liabilities are reduced for expenditures made and are adjusted as further information develops or circumstances change. Costs of future expenditures for environmental remediation obligations are not discounted to their fair value. Management currently estimates the range of remaining costs to be incurred for the investigation, remediation and monitoring of all WP&LWPL’s sites to be approximately $6$5 million to $7 million.

 

Under the current rate making treatment approved by the PSCW, the MGP expenditures of WP&L,WPL, net of any insurance proceeds, are deferred and collected from gas customers over a five-year period after new rates are implemented. Regulatory assets have been recorded by WP&L,WPL, which reflect the probable future rate recovery, where applicable. Considering the

current rate treatment, and assuming no material change therein, WP&LWPL believes that the clean-up costs incurred for these MGP sites will not have a material adverse effect on its financial condition or results of operations.

Settlement has been reached with all of WP&L’sWPL’s insurance carriers regarding reimbursement for its MGP-related costs. Insurance recoveries available at Dec. 31, 2002 for WP&L were $2.1 million. Pursuant to the applicable rate making treatment, WP&L has recorded its recoveries as an offset against its regulatory assets.

NEPA—NEPA requires owners of nuclear power plants to pay a special assessment into a “Uranium Enrichment Decontamination and Decommissioning Fund.” The assessment is based upon prior nuclear fuel purchases. WP&L recovers the costs associated with this assessment through fuel costs over the period the costs are assessed. WP&L continues to pursue relief from this assessment through litigation.

(f) Decommissioning of Kewaunee—FERC, in its most recent interim wholesale rate order effective April 2002, allows WP&L to recover $3 million annually for its share of the cost to decommission Kewaunee. The interim order is subject to refund, pending determination of final rates. The PSCW, in an order effective Jan. 1, 2002, eliminated WP&L’s recovery from retail customers for the cost to decommission Kewaunee due to the trust fund being adequately funded. -Decommissioning expense is included in “Depreciation and amortization” in the Consolidated Statements of Income and the cumulative amount is included in “Accumulated depreciation”“Regulatory liabilities” or, for AROs, is netted in “Regulatory assets” on the Consolidated Balance SheetsSheets. The PSCW and FERC, in orders effective Jan. 1, 2002 and Jan. 1, 2005, respectively, eliminated WPL’s recovery from customers for the cost to decommission Kewaunee, due to the extent recovered through rates.current funded status and the proposed sale of Kewaunee. Additional information relating to the decommissioning of Kewaunee wasis as follows (dollars in millions):

 

WPL’s share of estimated decommissioning cost

  $243.2 

Year dollars in

   2004 

Method to develop estimate

   
 
Site-specific
study
 
 

Assumptions relating to current rate recovery amounts (1):

     

Annual inflation rate

   6.50%

Decommissioning method

   
 
 
Prompt
dismantling
and removal
 
 
 

Year decommissioning to commence

   2013 

After-tax return on external investments:

     

Qualified

   6.12%

Non-qualified

   5.14%

External trust fund balance at Dec. 31, 2004

  $243.2 

After-tax earnings on external trust funds in 2004

  $14.8 

Assumptions relating(1)

Information is related to current rateWPL’s most recent FERC order (prior to the elimination of cost recovery amounts:

WP&L’s share of estimated decommissioning cost

$263.2

Year dollars in

2002

Method to develop estimate

Site-specific study

Annual inflation rate

6.50%

Decommissioning method

Prompt dismantling and removal

Year decommissioning to commence

2013

After-tax return on external investments:

Qualified

6.12%

Non-qualified

5.14%

External trust fund balance at Dec. 31, 2002

$223.7

Internal reserve at Dec. 31, 2002

$ —  

After-tax earnings on external trust fund in 2002

$19.7

for Kewaunee).

 

WP&L is funding all rate recoveriesThe earnings for decommissioning into an external trust fund and funding on a tax-qualified basis to the extent possible. In accordance with its respective regulatory requirements, WP&L records the earnings on the external trust fund as interest income with a corresponding entry to depreciation expense at WP&L. The earningsWPL accumulate in the external trust fund balancesbalance and as an offset to regulatory assets for ARO related earnings or regulatory liabilities for non-ARO related earnings. Refer to Note 16 for information regarding the proposed sale of WPL’s interest in accumulated depreciation on utility plant.Kewaunee and Note 17 for information related to the impact of SFAS 143.

 

(g) Credit Risk - WPL has limited credit exposure from electric and natural gas sales and non-performance of contractual obligations by its counterparties. WPL maintains credit risk oversight and sets limits and policies with regards to its counterparties, which management believes minimizes its overall credit risk exposure. However, there is no assurance that such policies will protect WPL against all losses from non-performance by counterparties.

(h) Nuclear Liability/Insurance -Liability for nuclear accidents is governed by the Price-Anderson Act of 1988 as amended, which sets a statutory limit of $10.8 billion for liability to the public for a single nuclear power plant incident and requires nuclear power plant operators to provide financial protection for this amount. Financial protection for a nuclear incident is provided through a combination of liability insurance ($300 million) and industry-wide retrospective payment plans ($10.5 billion). Under the industry-wide plan, the owners of each operating licensed nuclear reactor in the U.S. are subject to an assessment in the event of a nuclear incident at any nuclear plant in the U.S. Based on its ownership in Kewaunee, WPL could be assessed a maximum of $41 million per nuclear incident, if losses related to the incident exceeded $300 million.

(12) JOINTLY-OWNED ELECTRIC UTILITY PLANT

Under joint ownership agreements with other Wisconsin utilities, WPL has undivided ownership interests in jointly-owned electric generating stations. Each of the respective owners is responsible for the financing of its portion of the construction costs. KWh generation and operating expenses are divided on the same basis as ownership with each owner reflecting its respective costs in its Consolidated Statements of Income. Information relative to WPL’s ownership interest in these facilities at Dec. 31, 2004 was as follows (dollars in millions):

   Fuel Type

  Ownership
Interest %


  Plant in
Service


  Accumulated
Provision for
Depreciation


  Construction
Work In
Progress


Edgewater Unit 5

  Coal  75.0  $238.3  $127.7  $1.3

Columbia Energy Center

  Coal  46.2   195.5   121.0   9.6

Kewaunee

  Nuclear  41.0   204.4   145.7   12.5

Edgewater Unit 4

  Coal  68.2   71.1   41.9   0.9
         

  

  

         $709.3  $436.3  $24.3
         

  

  

Refer to Note 16 for information regarding the proposed sale of WPL’s interest in Kewaunee.

(13) SEGMENTS OF BUSINESS

WPL is a domestic utility, serving customers in Wisconsin and Illinois, and includes three segments: a) electric operations; b) gas operations; and c) other, which includes the water business, various other energy-related products and services including construction management services for wind farms and the unallocated portions of the utility business. Various line items in the following tables are not allocated to the electric and gas segments for management reporting purposes and therefore are included in “Total.” In 2004, 2003 and 2002, gas revenues included $20 million, $45 million and $22 million, respectively, for sales to the electric segment. All other intersegment revenues were not material to WPL’s operations and there was no single customer whose revenues were 10% or more of the consolidated revenues. Certain financial information relating to WPL’s significant business segments was as follows (in millions):

   Electric

  Gas

  Other

  Total

 

2004

                 

Operating revenues

  $939.8  $253.8  $16.2  $1,209.8 

Depreciation and amortization

   95.7   14.8   0.5   111.0 

Operating income (loss)

   164.9   24.8   (6.9)  182.8 

Interest expense, net of AFUDC

               29.0 

Equity income from unconsolidated investments

               (25.0)

Interest income and other

               (1.2)

Income tax expense

               66.3 

Net income

               113.7 

Preferred dividends

               3.3 

Earnings available for common stock

               110.4 

Total assets

   2,097.5   333.3   225.3   2,656.1 

Investments in equity method subsidiaries

   154.3   —     —     154.3 

Construction and acquisition expenditures

   189.1   20.2   2.2   211.5 

2003

                 

Operating revenues

  $910.1  $272.4  $34.5  $1,217.0 

Depreciation and amortization

   89.2   14.6   1.1   104.9 

Operating income

   163.8   25.5   2.3   191.6 

Interest expense, net of AFUDC

               33.9 

Equity income from unconsolidated investments

               (20.7)

Interest income and other

               (2.3)

Income tax expense

               65.8 

Net income

               114.9 

Preferred dividends

               3.3 

Earnings available for common stock

               111.6 

Total assets

   1,950.5   306.2   212.6   2,469.3 

Investments in equity method subsidiaries

   133.3   —     —     133.3 

Construction and acquisition expenditures

   133.0   17.4   1.2   151.6 

2002

                 

Operating revenues

  $787.7  $179.1  $22.7  $989.5 

Depreciation and amortization

   91.7   15.9   1.1   108.7 

Operating income (loss)

   135.1   12.0   (1.5)  145.6 

Interest expense, net of AFUDC

               37.6 

Equity income from unconsolidated investments

               (17.0)

Interest income and other

               (0.6)

Income tax expense

               44.7 

Net income

               80.9 

Preferred dividends

               3.3 

Earnings available for common stock

               77.6 

Total assets

   1,834.7   298.5   201.9   2,335.1 

Investments in equity method subsidiaries

   121.7   —     —     121.7 

Construction and acquisition expenditures

   144.6   10.6   1.7   156.9 

(14) SELECTED CONSOLIDATED QUARTERLY FINANCIAL DATA (UNAUDITED)

Summation of the individual quarters may not equal annual totals due to rounding.

   2004

  2003

   March 31

  June 30

  Sep. 30

  Dec. 31

  March 31

  June 30

  Sep. 30

  Dec. 31

   (in millions)

Operating revenues

  $339.4  $270.7  $286.2  $313.5  $346.9  $254.8  $318.9  $296.3

Operating income

   38.9   51.3   55.0   37.6   18.1   35.7   77.8   60.1

Net income

   22.3   31.2   33.6   26.7   10.1   19.9   47.4   37.5

Earnings available for common stock

   21.5   30.4   32.7   25.8   9.3   19.0   46.6   36.7

(15) ASSETS HELD FOR SALE

WPL has announced its intention to sell its water utility in Ripon, Wisconsin in order to narrow its strategic focus. WPL has applied the provisions of SFAS 144 to the Ripon water utility assets, which are held for sale. SFAS 144 requires that a long-lived asset classified as held for sale be measured at the lower of its carrying amount or fair value, less costs to sell, and to cease depreciation, depletion and amortization. The operating results of WPL’s water utility did not qualify for reporting as discontinued operations at Dec. 31, 2004. At Dec. 31, the components of the Ripon water utility assets held for sale on the Consolidated Balance Sheets were as follows (in millions):

   2004

  2003

 

Property, plant and equipment:

         

Other plant in service

  $5.9  $7.6 

Less: accumulated depreciation

   (2.9)  (2.4)
   


 


Net plant

   3.0   5.2 

Construction work in progress

   1.9   0.9 
   


 


Total assets held for sale

  $4.9  $6.1 
   


 


(16) PROPOSED SALE OF WPL’S INTEREST IN KEWAUNEE

WPL has signed a definitive agreement to sell its 41% ownership interest in Kewaunee to a subsidiary of Dominion Resources, Inc. (Dominion). Approval has already been obtained from the Federal Trade Commission, NRC, Iowa Utilities Board, ICC and Minnesota Public Utilities Commission, and certain approvals have been obtained from FERC. In November 2004, the PSCW issued a decision rejecting WPL’s and WPSC’s joint application to sell Kewaunee to Dominion. WPL and WPSC joined Dominion and filed a petition for a rehearing with the PSCW in December 2004. In the rehearing petition, new information was submitted that addressed the PSCW’s concerns and the petition was accepted in January 2005 on an expedited schedule. WPL anticipates that the PSCW will issue a decision on the sale in March 2005.

Assuming the sale closes, WPL anticipates it will receive approximately $90 million in cash and retain ownership of the trust assets contained in one of the two decommissioning funds it established to cover the eventual decommissioning of Kewaunee. The fund that WPL will retain had an after-tax value of $72 million as of Dec. 31, 2004. Dominion will assume responsibility for the eventual decommissioning of Kewaunee and will receive WPL’s qualified decommissioning trust assets, which had an after-tax value of $171 million as of Dec. 31, 2004. The cash proceeds, after certain transaction costs, from the sale are expected to slightly exceed WPL’s carrying value of the assets being sold. WPL has requested deferral of any gain and related costs from the PSCW. Because any gain realized and the retained decommissioning fund will likely be returned to customers in future rate filings, WPL does not expect this transaction will have a significant impact on its operating results. As of Dec. 31, 2004, WPL’s share of the carrying value of the assets and liabilities included within the sale agreement was as follows (in millions):

Assets:

     

Investments

  $171 

Property, plant and equipment, net *

   88 

Other

   18 
   


   $277 
   


Liabilities:

     

AROs

  $200 

Regulatory liabilities

   (7)
   


   $193 
   


*Includes nuclear fuel, net of amortization

At the closing of the sale, WPL will enter into a long-term purchased power agreement with Dominion to purchase energy and capacity equivalent to the amounts received had current ownership continued. The purchased power agreement, which also will require regulatory approval, will extend through 2013 when Kewaunee’s current operating license will expire. In April 2004, WPL entered into an exclusivity agreement with Dominion. Under this agreement, if Dominion decides to extend the operating license of Kewaunee, Dominion must negotiate only with WPL and WPSC for new purchased power agreements for their respective share of the plant output that would extend beyond Kewaunee’s current operating license termination date. The exclusivity period will start on the closing date of the sale and will extend through Dec. 21, 2011.

(17) ASSET RETIREMENT OBLIGATIONS (AROs)

WPL adopted SFAS 143 on Jan. 1, 2003, which provides accounting and disclosure requirements for retirement obligationsAROs associated with long-lived assets, was adopted by WP&L on Jan. 1, 2003.assets. SFAS 143 requires that when an asset is placed in service the present value of retirement costs for which WP&LWPL has a legal obligation must be recorded as liabilities with an equivalent amount added to the asset cost. The liability is accreted to its present value each period and the capitalized cost is depreciated over the useful life of the related asset. Upon settlement of the liability, an entity settles the obligation for its recorded amount or incurs a gain or loss. The adoption of SFAS 143 will have no impact on WP&L’s earnings, as the effects will be offset by the establishment of regulatory assets or liabilities pursuant to SFAS 71.

 

WP&L has completed a detailed assessment of the specific applicability and implications of SFAS 143. The scope of SFAS 143 as it relates to WP&LWPL primarily includes decommissioning costs for Kewaunee. The differences between the estimated decommissioning costs disclosed in Note 11(f) for Kewaunee and the recorded SFAS 143 liability are primarily related to fuel management costs, non-nuclear demolition costs and the timing of future cash flows. It also applies to a smaller extent to the removal, closure or dismantlement of several other regulated and non-regulated assets including, but not limited to, active ash landfills, water intake facilities, underground storage tanks, groundwater wells, transmission and distribution equipment, easements, leases and the dismantlement of certain hydro facilities. Other than Kewaunee, WP&L’s asset retirement obligations as of Jan. 1, 2003WPL’s current AROs are not significant. Refer to Note 16 for information regarding the proposed sale of WPL’s interest in Kewaunee. A reconciliation of the changes in the AROs is depicted below (in millions):

 

Balance at Jan. 1, 2004

  $187.4

Accretion expense

   13.5
   

Balance at Dec. 31, 2004

  $200.9
   

Prior to January 2003, WP&L recorded nuclear decommissioning charges in accumulated depreciation on its Consolidated Balance Sheets.

Upon adoption of SFAS 143 WP&L will reverse approximately $175 million, previouslyon Jan. 1, 2003, WPL recorded in accumulated depreciation and will record liabilitiesAROs of approximately $175$175.0 million. The difference between amounts previously recorded and the net SFAS 143 liability will be deferred as a regulatory asset and is expected to approximate $0 for WP&L.

 

WP&L has previously recognized removal costs(18) VARIABLE INTEREST ENTITIES

In December 2003, the FASB issued FIN 46R which addresses consolidation by business enterprises of variable interest entities. FIN 46R requires consolidation where there is a controlling financial interest in a variable interest entity or where the variable interest entity does not have sufficient equity at risk to finance its activities without additional subordinated financial support from other parties. WPL adopted FIN 46R for those entities considered to be special-purpose entities as a component of depreciation expense and accumulated depreciation for other non-nuclear assets in accordance with regulatory rate recovery. As of Dec. 31, 2002, WP&L estimates2003, and for all other entities subject to FIN 46R as of March 31, 2004. WPL did not consolidate any entities as a result of this guidance.

After making an ongoing exhaustive effort, WPL concluded that it haswas unable to obtain the information necessary from the counterparties for the Riverside plant tolling agreement and RockGen plant purchased power agreement to determine whether the counterparties are variable interest entities and if WPL is the primary beneficiary. These agreements are currently accounted for as operating leases. The counterparties can sell their energy output and sell some or all of their generating capacity to WPL. In 2004, WPL incurred costs (excluding fuel costs) related to the Riverside contract of $38 million. In each of 2004 and 2003, WPL incurred costs related to the RockGen contract of approximately $150 million of$33 million. WPL’s maximum exposure to loss from these contracts is undeterminable due to the inability to obtain the necessary information to complete such regulatory liabilities recorded in “Accumulated depreciation” on its Consolidated Balance Sheets.evaluation.

 

(12) JOINTLY-OWNED ELECTRIC UTILITY PLANT

Under joint ownership agreements with other Wisconsin utilities, WP&L has undivided ownership interests in jointly-owned electric generating stations. Each of the respective owners is responsible for the financing of its portion of the construction costs. KWh generation and operating expenses are divided on the same basis as ownership with each owner reflecting its respective costs in its Consolidated Statements of Income. Information relative to WP&L’s ownership interest in these facilities at Dec. 31, 2002 was as follows (dollars in millions):

   

Fuel

Type


    

Ownership

Interest %


  

Plant in

Service


  

Accumulated

Provision for

Depreciation


    

Construction

Work-In-

Progress


Edgewater Unit 5

  

Coal

    

75.0

  

$234.8

  

$112.9

    

$0.4

Columbia Energy Center

  

Coal

    

46.2

  

187.5

  

110.3

    

1.6

Kewaunee

  

Nuclear

    

41.0

  

172.6

  

120.9

    

6.8

Edgewater Unit 4

  

Coal

    

68.2

  

60.0

  

36.1

    

1.6

           
  
    
           

$654.9

  

$380.2

    

$10.4

           
  
    

(13) SEGMENTS OF BUSINESS

WP&L is a regulated domestic utility, serving customers in Wisconsin and Illinois, and includes three segments: a) electric operations; b) gas operations; and c) other, which includes the water business and the unallocated portions of the utility business. Various line items in the following tables are not allocated to the electric and gas segments for management reporting purposes and therefore are included in “Total.” In 2002 and 2001, gas revenues included $22 million and $21 million, respectively, for sales to the electric segment. All other intersegment revenues were not material to WP&L’s operations and there was no single customer whose revenues were 10% or more of WP&L’s consolidated revenues. Certain financial information relating to WP&L’s significant business segments was as follows (in millions):

   

Electric


  

Gas


  

Other


  

Total


 

2002

                 

Operating revenues

  

$

787.7

  

$

179.1

  

$

5.3

  

$

972.1

 

Depreciation and amortization

  

 

117.3

  

 

17.7

  

 

1.2

  

 

136.2

 

Operating income

  

 

114.1

  

 

12.0

  

 

1.4

  

 

127.5

 

Interest expense, net of AFUDC

              

 

37.6

 

Interest income

              

 

(21.6

)

Equity income from unconsolidated investments

              

 

(17.0

)

Miscellaneous, net

              

 

2.9

 

Income tax expense

              

 

44.7

 

Net income

              

 

80.9

 

Preferred dividends

              

 

3.3

 

Earnings available for common stock

              

 

77.6

 

Total assets

  

 

1,426.7

  

 

259.5

  

 

298.4

  

 

1,984.6

 

Investments in equity method subsidiaries

  

 

121.7

          

 

121.7

 

Construction and acquisition expenditures

  

 

144.6

  

 

10.6

  

 

1.7

  

 

156.9

 

2001

                 

Operating revenues

  

$

753.5

  

$

206.9

  

$

5.0

  

$

965.4

 

Depreciation and amortization

  

 

111.5

  

 

16.4

  

 

1.2

  

 

129.1

 

Operating income

  

 

121.6

  

 

2.5

  

 

1.3

  

 

125.4

 

Interest expense, net of AFUDC

              

 

38.7

 

Interest income

              

 

(8.1

)

Equity income from unconsolidated investments

              

 

(15.5

)

Miscellaneous, net

              

 

(4.4

)

Income tax expense

              

 

41.2

 

Net income

              

 

73.5

 

Preferred dividends

              

 

3.3

 

Earnings available for common stock

              

 

70.2

 

Total assets

  

 

1,323.9

  

 

224.5

  

 

327.4

  

 

1,875.8

 

Investments in equity method subsidiaries

  

 

117.3

          

 

117.3

 

Construction and acquisition expenditures

  

 

127.9

  

 

16.8

  

 

2.3

  

 

147.0

 

2000

                 

Operating revenues

  

$

692.2

  

$

165.2

  

$

5.0

  

$

862.4

 

Depreciation and amortization

  

 

122.9

  

 

15.9

  

 

1.1

  

 

139.9

 

Operating income

  

 

123.2

  

 

12.2

  

 

1.7

  

 

137.1

 

Interest expense, net of AFUDC

              

 

39.3

 

Interest income

              

 

(13.1

)

Equity income from unconsolidated investments

              

 

(0.5

)

Miscellaneous, net

              

 

(2.9

)

Income tax expense

              

 

42.9

 

Net income

              

 

71.4

 

Preferred dividends

              

 

3.3

 

Earnings available for common stock

              

 

68.1

 

Total assets

  

 

1,344.9

  

 

226.1

  

 

286.0

  

 

1,857.0

 

Investments in equity method subsidiaries

  

 

4.8

          

 

4.8

 

Construction and acquisition expenditures

  

 

114.2

  

 

15.1

  

 

2.3

  

 

131.6

 

(14) SELECTED CONSOLIDATED QUARTERLY FINANCIAL DATA (UNAUDITED)

Summation of the individual quarters may not equal annual totals due to rounding.

   

2002


  

2001


   

March 31


  

June 30


  

Sept. 30


  

Dec. 31


  

March 31


  

June 30


  

Sept. 30


  

Dec. 31


   

(in millions)

Operating revenues

  

$

229.5

  

$

217.5

  

$

249.0

  

$

276.1

  

$

317.2

  

$

204.1

  

$

228.3

  

$

215.8

Operating income

  

 

24.1

  

 

28.6

  

 

35.4

  

 

39.3

  

 

37.0

  

 

23.4

  

 

36.2

  

 

28.8

Net income

  

 

15.7

  

 

12.8

  

 

19.2

  

 

33.2

  

 

19.3

  

 

11.6

  

 

19.9

  

 

22.8

Earnings available for common stock

  

 

14.9

  

 

12.0

  

 

18.3

  

 

32.4

  

 

18.4

  

 

10.7

  

 

19.0

  

 

22.0

(15)(19) RELATED PARTIES

 

WP&LWPL and IP&L have entered intoIPL are parties to a System Coordination and Operating Agreement. The agreement, which has been approved by FERC, provides a contractual basis for coordinated planning, construction, operation and maintenance of the interconnected electric generation and transmission (IPL only) systems of WP&LWPL and IP&L.IPL. In addition, the agreement allows the interconnected system to be operated as a single entity with off-system capacity sales and purchases made to market excess system capability or to meet system capability deficiencies. Such sales and purchases are allocated among WP&LWPL and IP&LIPL based on procedures included in the agreement. The sales amounts allocated to WP&LWPL were $26.9$25 million, $32.1$42 million and $28.6$27 million for 2002, 20012004, 2003 and 2000,2002, respectively. The purchases allocated to WP&LWPL were $205.8$279 million, $209.2$229 million and $130.7$206 million for 2002, 20012004, 2003 and 2000,2002, respectively. The procedures were approved by both FERC and all state regulatory bodies having jurisdiction over these sales. Under the agreement, WP&LWPL and IP&LIPL are fully reimbursed for any generation expense

incurred to support the sale to an affiliate or to a non-affiliate. Any margins on sales to non-affiliates are distributed to WP&LWPL and IP&LIPL in proportion to each utility’s share of electric production at the time of the sale.

 

Pursuant to a service agreement approved by the SEC under PUHCA, WP&LWPL receives various administrative and general services from an affiliate, Corporate Services. These services are billed to WP&LWPL at cost based on payroll and other expenses incurred by Corporate Services for the benefit of WP&L.WPL. These costs totaled $117.7$129 million, $107.0$125 million and $103.4$118 million for 2002, 20012004, 2003 and 2000,2002, respectively, and consisted primarily of employee compensation, benefits and fees associated with various professional services. At Dec. 31, 20022004 and 2001, WP&L2003, WPL had a net intercompany payable to Corporate Services of $31.1$31 million and $32.2$36 million, respectively.

In 2004, Alliant Energy Generation, Inc., a subsidiary of Alliant Energy Resources, Inc. (Resources), billed WPL $7 million related to the construction of the Sheboygan Falls plant. Refer to Note 9 for information regarding related party transactions with NMC and ATC.

 

SHAREOWNER INFORMATION

 

Market Information-The 4.50% series of preferred stock is listed on the American Stock Exchange, with the trading symbol of WIS_PR. All other series of preferred stock are traded on the over-the-counter market. Seventy-one percent71% of WP&L’sWPL’s individual preferred shareowners are Wisconsin residents.

 

Dividend Information-Preferred stock dividends paid per share for each quarter during 20022004 were as follows:

 

Series


  

Dividend


  Dividend

4.40%

  

$1.10

  $1.10

4.50%

  

$1.125

  $1.125

4.76%

  

$1.19

  $1.19

4.80%

  

$1.20

  $1.20

4.96%

  

$1.24

  $1.24

6.20%

  

$1.55

  $1.55

6.50%

  

$0.40625

  $0.40625

 

As authorized by the WP&LWPL Board of Directors, preferred stock dividend record and payment dates for 20032005 are as follows:

 

Record Date


  

Payment Date


February 28

  

March 15

May 31

June 15

August 31

September 15

November 30

  

June 14

August 29

September 15

November 28

December 15

 

Stock Transfer Agent and Registrar

Alliant Energy Corporation

Shareowner Services

P.O. Box 2568

Madison, WI 53701-2568

 

Form 10-K Information-A copy of the combined Annual Report on Form 10-K for the year ended Dec. 31, 2004 as filed with the SEC will be provided without charge upon request. Requests may be directed to Shareowner Services at the above address.

EXECUTIVE OFFICERS AND DIRECTORS

 

EXECUTIVE OFFICERSExecutive Officers - Numbers following the names represent the officer’s age as of Dec. 31, 2004.

 

Erroll B. Davis, Jr., 58, 60, was elected Chairman of the Board effective April 2000 and Chief Executive Officer (CEO) effective April 1998.

 

William D. Harvey, 55, was elected Chief Operating Officer effective January 2004 and was appointed as a board member effective January 2005. He previously served as President since 1998.

Barbara J. Swan, 53, was elected President effective AprilJanuary 2004. She previously served as Executive Vice President and General Counsel since 1998.

 

Eliot G. Protsch 49, was elected Executive Vice President-Energy Delivery effective October 1998. He previously served as Senior Vice President from 1993 to 1998.

Barbara J. Swan,, 51, was elected Executive Vice President and General Counsel effective October 1998. She previously served as Vice President-General Counsel from 1994 to 1998.

Thomas M. Walker, 55, was elected Executive Vice President and Chief Financial Officer (CFO) effective October 1998.January 2004. He previously served as Executive Vice President and CFOChief Financial Officer since 1996 at IESSeptember 2003 and IESU.Executive Vice President-Energy Delivery from 1998 to September 2003.

 

Pamela J. Wegner,Thomas L. Aller, 55, was elected ExecutiveSenior Vice President-Shared Solutions effective October 1998. She previously served as Vice President-Information Services and Administration from 1994 to 1998.

Dundeana K. Doyle, 44, was elected Vice President-Infrastructure SecurityPresident-Energy Delivery effective January 2002. She previously served as Vice President-Customer Operations since December 2000, Vice President-Customer Services and Operations from 1999 to 2000 and Vice President-Customer Services from 1998 to 1999.

Vern A. Gebhart, 49, was elected Vice President-Customer Operations effective January 2002.2004. He previously served as Managing Director-Strategic Projectsinterim Executive Vice President-Energy Delivery since September 2003 and Capital Control since 2000Vice President-Investments at Alliant Energy and Director-Strategic Projects and Capital ControlResources from 1998 to 2000 at Alliant Energy.2003.

 

Thomas L. Hanson 49,, 51, was elected Vice President and Treasurer effective April 2002. He previously served as Managing Director-Generation Services since 2001 at Alliant Energy and General Manager-Business and Financial Performance, Generation from 1998 to 2001 at Alliant Energy.

 

John E. Kratchmer 40,, 42, was elected Vice President-Controller and Chief Accounting Officer effective October 2002. He previously served as Corporate Controller and Chief Accounting Officer since October 2000 and Assistant Controller from 1998 to 2000 at Alliant Energy.2000.

 

Daniel L. Mineck,Directors- 54, was elected Vice President-Performance Engineering and Environmental effective April 1998.Refer to WPL’s Proxy Statement for information on WPL’s board members.

LOGO

 

Barbara A. Siehr, 51, was elected Vice President-Financial PlanningWisconsin Power and Strategic Projects effective October 2002. She previously servedLight Company

Shareowner Services PO Box 2568 Madison, WI 53701-2568

SHAREOWNER INFORMATION NUMBERS

Local Madison, WI 1-608-458-3110 All Other Areas 1-800-356-5343

Indicate your vote by an (X) in the appropriate boxes.

ELECTION OF DIRECTORS

Nominees for terms ending in 2008:

Withhold For All For All For All Except(*)

(01) William D. Harvey

(02) Singleton B. McAllister

(03) Anthony R. Weiler

*TO WITHHOLD AUTHORITY TO VOTE FOR ANY INDIVIDUAL NOMINEE, STRIKE A LINE THROUGH THE NOMINEE’S NAME IN THE LIST ABOVE AND MARK AN (X) IN THE “For All Except” BOX.

PROXY

Please date and sign your name(s) exactly as Managing Director-Operationsshown above and Operations Services since December 2000 at Alliant Energy, General Manager-Operations East from 1999 to 2000 at Alliant Energy and General Manager-Engineering/Operations Services from 1998 to 1999 at Alliant Energy.mail promptly in the enclosed envelope.

Signature Date Signature Date

Kim K. Zuhlke, 49, was elected Vice President-Engineering, Sales & Marketing effective September 1999. He previously served as Vice President-Customer Operations since April 1998 and as Vice President-Customer Services and Sales from 1993 to 1998.

F. J. Buri, 48, was elected Corporate Secretary effective April 2002. He previously served as Senior Attorney since June 1999 at Alliant Energy. Prior to joining Alliant Energy, he was General Counsel and Secretary from 1996 to 1999 at Universal Savings Bank, N.A.

NOTE: None of the executive officers listed above is related to any member of the Board of Directors or nominee for director or any other executive officer. Mr. Davis has an employment agreement with Alliant Energy pursuant to which his term of office is established. All other executive officers have no definite terms of office and serve at the pleasure of the Board of Directors.

Additional Officers

Enrique Bacalao, 53, was elected Assistant Treasurer effective November 1998. Prior to joining Alliant Energy, he was Vice President, Corporate Banking from 1995 to 1998 at the Chicago Branch of The Industrial Bank of Japan, Limited.

Steven F. Price, 50, was elected Assistant Treasurer effective April 1998.

Patricia L. Reininger, 50, was elected Assistant Corporate Secretary effective January 2003. She previously served as Executive Administrative Assistant since August 2000 at Alliant Energy. Prior to joining Alliant Energy, she was Assistant to the Chairperson and Assistant Corporate Secretary from 1993 to 1999 at Sentry Insurance.

Wisconsin Power & Light Company

Shareowner Services

PO Box 2568

Madison WI 53701-2568

SHAREOWNER INFORMATION NUMBERS

Local Madison, WI

1-608-458-3110            

All Other Areas

1-800-356-5343            

Indicate your vote by an (X) in the appropriate boxes.

ELECTION OF DIRECTORS

For All

Withhold

For All

For All

Except(*)

Nominees for terms

ending in 2006:

P

R

O

X

Y

¨

¨

¨

01    Erroll B. Davis, Jr.

02    Robert W. Schlutz

03    Wayne H. Stoppelmoor

* TO WITHHOLD AUTHORITY TO VOTE FOR ANY INDIVIDUAL NOMINEE, STRIKE A LINE THROUGH THE NOMINEE’S NAME IN THE LIST ABOVE AND MARK AN (X) IN THE “For All Except” BOX.

Please date and sign your name(s) exactly as shown above and mail promptly in the enclosed envelope.


Signature                                                                     Date

Important:IMPORTANT: When signing as attorney, executor, administrator, trustee or guardian, please give your full title as such. In the case of JOINT HOLDERS, all should sign.


Signature                                                                     Date

Please fold and detach Proxy Card at perforation if appointing a proxy by mail.


To all Wisconsin Power and Light Company Shareowners:

Please take a moment to vote your shares for the upcoming Annual Meeting of Shareowners.

Above is your 20032005 Wisconsin Power and Light Company proxy card. Please read both sides of the proxyProxy card, note your election, sign and date it. Detach and return promptly in the enclosed self-addressed envelope. Whether or not you are attending,we encourage you to vote your shares.

You are invited to attend the Annual Meeting of Shareowners on Thursday, June 5, 2003Wednesday, May 25, 2005, at 1:2:00 p.m. at the Alliant Energy Corporate Headquarters in the SeineNile Meeting Room at 4902 N. Biltmore Lane, Madison, Wisconsin.


Wisconsin Power & Light Company

P.O. Box 2568

Madison, WI 53701-2568

LOGO

 

WISCONSIN POWER AND LIGHT COMPANY

PO BOX 2568

MADISON, WI 53701-2568


ANNUAL MEETING OF SHAREOWNERS—JUNE 5, 2003


SHAREOWNERS — MAY 25, 2005

The undersigned appoints William D. HarveyBarbara J. Swan and F.J.F. J. Buri, or either of them, attorneys and proxies with the power of substitution to vote all shares of stock of Wisconsin Power and Light Company (the “Company”), held of record in the name of the undersigned at the close of business on April 15, 2003,5, 2005, at the Annual Meeting of Shareowners of the Company to be held at 4902 N. Biltmore Lane, Madison, Wisconsin on June 5, 2003May 25, 2005 at 1:2:00 p.m., and at all adjournments thereof, upon all matters that properly come before the meeting, including the matters described in the Company’s Notice of Annual Meeting, of ShareownersProxy Statement and Annual Report, dated April 21, 2003 and accompanying Proxy Statement,13, 2005, subject to any directions indicated on the reverse side of this card.

This proxy is solicited on behalf of the Board of Directors of Wisconsin Power and Light Company. This proxy, when properly executed, will be voted in the manner directed herein by the shareowner. If no direction is made, the proxies will vote “FOR” the election of all listed director nominees. The Board of Directors recommends a vote “FOR” all listed director nominees.

To access the Alliant Energy Corporation Annual Report and Proxy Statement on the Internet, please open our siteAlliant Energy’s website atwww.alliantenergy.com. www.alliantenergy.com/ annualreports. We encourage you to check out our siteAlliant Energy’s website to see how easy and convenient it is. Click on the Annual Report buttonlink for the Annual Report/Report and Proxy Statement. You may print or just view these materials. Your Internet provider may have usage charges associated with electronic access.