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.     )

 

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x Definitive Proxy Statement

 

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¨ 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)

 

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Reg. (S) 240.14a-101.

SEC 1913 (3-99)



Y O U R  V O T E   I S  I M P O R T A N T

Wisconsin

Power and Light

Company

NOTICEOF 2004 ANNUAL MEETING

PROXY STATEMENTAND

2003 ANNUAL REPORT



 

WISCONSIN POWER AND LIGHT COMPANY

 

ANNUAL MEETING OF SHAREOWNERS

 

DATE: 

Wednesday, June 2, 2004May 25, 2005

TIME: 

3:2:00 p.m., Central Daylight Time

LOCATION: 

Wisconsin Power and Light Company

Nile ConferenceMeeting Room

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

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 Wednesday, June 2, 2004,May 25, 2005, Wisconsin Power and Light Company (the “Company”) will hold its 20042005 Annual Meeting of Shareowners at the offices of Alliant Energy Corporation, 4902 North Biltmore Lane, Nile Meeting Room, Madison, Wis. The meeting will begin at 3:2:00 p.m. Central Daylight Time.

 

Only the sole common shareowner, Alliant Energy Corporation, and preferred shareowners who owned stock at the close of business on April 13, 2004,5, 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 one director for a term expiring at the 2006 Annual Meeting of Shareowners and fourthree directors for terms expiring at the 20072008 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 20032004 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 20032004 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

F. J. Buri
Corporate Secretary

 

Dated and mailed on or about April 16, 200413, 2005.


TABLE OF CONTENTS

 

Questions and Answers

 1

Election of Directors

 4  3

Meetings and Committees of the Board

 7  5

Corporate Governance

 9  7

Compensation of Directors

 10  8

Ownership of Voting Securities

 11  9

Compensation of Executive Officers

 1310

Stock Options

 1511

Long-Term Incentive Awards

 1713

Certain Agreements

 1813

Retirement and Employee Benefit Plans

 2014

Report of the Compensation and Personnel Committee on Executive Compensation

 2317

Report of the Audit Committee

 2621

Section 16(a) Beneficial Ownership Reporting Compliance

 2722

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 Wednesday, June 2, 2004.May 25, 2005. As a shareowner, you are invited to attend the Annual Meeting and are entitled to and requested to vote on the proposalsproposal 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 13, 2004,5, 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% series 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 fivethree nominees to serve on the Company’s Board of Directors one nominee for a term expiring at the 2006 Annual Meeting of Shareowners and four nominees for terms expiring at the 20072008 Annual Meeting of 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 director 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, you may vote FOR all of the director 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 director 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.

 

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 13, 2004,5, 2005, may attend the Annual Meeting.

 

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 Annual Meeting other than the election of directors. If any other business is properly presented at the Annual Meeting, your proxy gives Barbara J. Swan, the Company’s President, and F. J. Buri, the Company’s Corporate Secretary, authority to vote on such matters at 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 the 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 20042005 to be filed with the Securities and Exchange Commission (“SEC”).

 

13.  Q:Q:When are shareowner proposals for the 20052006 Annual Meeting due?
A:All shareowner proposals to be considered for inclusion in the Company’s proxy statement for the 20052006 Annual Meeting must be received at the principal office of the Company by Dec. 18, 2004.14, 2005. In addition, any shareowner who intends to present a proposal from the floor at the 20052006 Annual Meeting must submit the proposal in writing to the Corporate Secretary of the Company no later than March 2, 2005.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, 2003.2004. 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 20042005 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 year ended Dec. 31, 2001 did not contain an adverse opinion, disclaimer of opinion or qualification or modification as to uncertainty, audit scope or accounting principles. During the year ended Dec. 31, 2001 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 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 banks, brokers, nominees and other fiduciaries 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 the Company’s 20032004 Annual Report and this proxy 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 20032004 Annual Report and proxy statement. Upon written or oral request, the Company will mail a separate copy of the 20032004 Annual Report and/orand 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 shown on the first pageNotice of this proxy statement.Annual Meeting.

ELECTION OF DIRECTORS

 

At the Annual Meeting, one director will be elected for a term expiring in 2006 and fourthree directors will be elected for terms expiring in 2007.2008. The nominees for election as recommended by the Nominating and Governance Committee and selected by the Board of Directors are: Ann K. Newhall, for a term expiring in 2006;William D. Harvey, Singleton B. McAllister and Michael L. Bennett, Jack B. Evans, David A. Perdue and Judith D. Pyle for terms expiring in 2007.Anthony R. Weiler. Each of the nominees is currently serving as a director of the Company. Each person elected as a director will serve until the Annual Meeting of Shareowners of the Company in 2006 or 2007, as the case may be,2008, 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 will have no effect on the election of 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 director nominees and continuing directors follow. These biographies include their ageages (as of Dec. 31, 2003)2004), an account of their business experience and the names of publicly held and certain other corporations of which they are also directors. Except as otherwise indicated, each nominee and continuing director has been engaged in his or her present occupation for at least the past five years.

 

NOMINEES

 

LOGOLOGO  

ANN K. NEWHALLWILLIAM D. HARVEY

Age 55

  

Director Since 2003since 2005

Nominated term expires in 2008

  Age 52Mr. Harvey has served as President and Chief Operating Officer of AEC and Chief Operating Officer of IP&L, the Company and Resources since January 2004, and President of Resources since January 2005. He previously served as Executive Vice President – Generation for AEC, IP&L and 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 President and Associate General Counsel from 1986 to 1990. He was recommended as a nominee by the Nominating and Governance Committee and appointed as a Director of the Company, AEC, IP&L, and Resources in January 2005 in connection with the Company’s succession plan.
LOGO  

SINGLETON B. MCALLISTER

Age 52

Director since 2001

Nominated Term Expiresterm expires in 20062008

Ms. McAllister has been a partner in 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. law firm, from 2001 to 2003. From 1996 until 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 IP&L (or predecessor companies), AEC and Resources since 2001. Ms. McAllister is Chairperson of the Compensation and Personnel Committee.
LOGO

ANTHONY R. WEILER

Age 68

Director since 1998

Nominated term expires in 2008

  

Mr. Weiler is Chairman and President of A. R. Weiler Co. LLC, a consulting firm for home furnishings organizations. He was previously a Senior Vice President of 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 Resources since 1998. Mr. Weiler is Chairperson of the Nominating and Governance 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 AERResources since August 2003. She was originally recommended as a nominee in 2003 by a third-party search firm acting on behalf of the Nominating and Governance Committee.

LOGOLOGO  

MICHAEL L. BENNETTDAVID A. PERDUE

Age 55

  

Director Since 2003since 2001

Term expires in 2007

  Age 50Nominated 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 AER since August 2003. He was originally recommended as a nominee in 2003 by a third-party search firm acting on behalf of the Nominating and Governance Committee.

LOGOJACK B. EVANSDirector Since 2000
Age 55Nominated Term Expires in 2007

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 Director of Gazette Communications, Nuveen Institutional Advisory Corp., and Vice Chairman and a Director of United Fire and Casualty Company. Mr. Evans has served as a Director of AEC, IP&L (or predecessor companies) and AER since 2000. Mr. Evans is Chairperson of the Audit Committee.

LOGODAVID A. PERDUEDirector Since 2001
Age 54Nominated Term Expires in 2007

Mr. Perdue is Chairman of the Board and Chief Executive Officer of Dollar General Corporation, a retail sales organization headquartered in Goodlettsville, Tenn. He was electednamed 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 AERResources since 2001.

LOGOLOGO  

JUDITH D. PYLE

Age 61

  

Director Sincesince 1994

Term expires in 2007

  Age 60Nominated 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 ChairmanChair 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 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. Ms. Pyle is Chairperson of the Compensation and Personnel Committee.

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

CONTINUING DIRECTORS

 

LOGOLOGO  

ERROLL B. DAVIS, JR.ROBERT W. SCHLUTZ

Age 68

  

Director Since 1984since 1998

Term expires in 2006

  Age 59Term 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 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. Mr. Davis has served as a Director of AEC since 1982, of AER since 1988 and of IP&L (or predecessor companies) since 1998.

LOGOKATHARINE C. LYALLDirector Since 1986
Age 62Term 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. Ms. Lyall has announced that she will retire as President of the University of Wisconsin System no later than Aug. 31, 2004. She serves on the Boards of Directors of 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.

LOGOSINGLETON B. McALLISTERDirector Since 2001
Age 51Term Expires in 2005

Ms. McAllister has been a partner in the public law and policy strategies group of the Washington, D.C. law firm office of Sonnenschein, Nath & Rosenthal, LLP, since 2003. She previously was a partner at Patton Boggs LLP, a Washington, D.C. law firm, from 2001 to 2003. From 1996 until 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. Ms. McAllister has served as a Director of AEC, IP&L (or predecessor companies) and AER since 2001.

LOGOROBERT W. SCHLUTZDirector Since 1998
Age 67Term 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 AERResources since 1998. Mr. Schlutz is Chairperson of the Environmental, Nuclear, Health and Safety Committee.

 

 

LOGOANTHONY R. WEILERDirector Since 1998
Age 67Term Expires in 2005

 

Mr. Weiler is Chairman and President of A. R. Weiler Co. LLC, a consulting firm for home furnishings organizations. He was previously a Senior Vice President of 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 AER since 1998. Mr. Weiler is Chairperson of the Nominating and Governance Committee.

MEETINGS AND COMMITTEES OF THE BOARD

 

The 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 the Company’s websiteAEC’s Web site atwww.alliantenergy.com/investors under the “Corporate Governance” caption.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 seven joint meetings (the Company, AEC, IP&L and AER) meetingsResources) in 2003.2004. The Committee currently consists of J. B. Evans (Chair), A. B. Arends, M. L. Bennett (Chair), 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. EvansBennett and twoone additional Audit Committee membersmember 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; (2) the Company’s compliance with legal and regulatory requirements; (3) the independent auditors’ qualifications and 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 threefour joint meetings in 2003.2004. The Committee currently consists of J. D. PyleS. B. McAllister (Chair), A. B. Arends, M. L. Bennett, S. B. McAllister and D. A. Perdue.Perdue and J. D. Pyle. 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.

 

Environmental, Nuclear, Health and Safety Committee

The Environmental, Nuclear, Health and Safety Committee held two joint meetings in 2003. The Committee currently consists of R. W. Schlutz (Chair), K. C. Lyall, A. K. Newhall, 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 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 fourthree joint meetings in 2003.2004. The Committee currently consists of A. R. Weiler (Chair), K. C. Lyall, A. K. Newhall and R. W. Schlutz. Each of the members of the Committee is independent as defined by the NYSE listing standards. This Committee’s responsibilities are to: (1) identify individuals qualified to become Board members, consistent with the criteria approved by the Board, and to recommend nominees for directorships to be filled by the Board or shareowners; (2) identify and recommend Board members qualified to serve on Board committees; (3) develop and recommend 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; andvalue.

 

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 isreviewedis reviewed at the time a search for a new director 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 the Company.

 

Environmental, Nuclear, Health and Safety Committee

The Environmental, Nuclear, Health and Safety Committee held two joint meetings in 2004. The Committee currently consists of R. W. Schlutz (Chair), 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-related policies, activities and operational issues as they affect employees, customers and the general public.

Capital Approval Committee

The Capital Approval Committee held twono meetings in 2003.2004. The Committee currently consists of M. L. Bennett, J. B. EvansD. A. Perdue and A. R. Weiler. Mr. Davis is the Chair and a non-voting member of this Committee. The purpose of this Committee is to evaluate certain investment proposals where (1) an iterative bidding process is required, and/or (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 sixseven joint meetings during 2003.2004. Each director attended at least 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 conduct performance evaluations annually to determine their effectiveness and suggest 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 of Shareowners.Meeting. In 2003,2004, none of the Board members were present for the Company’s directors attended the Annual Meeting of Shareowners.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 the Company’s websiteAEC’s Web site atwww.alliantenergy.com/investors under the “Corporate Governance” caption.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. TheseUnder these categorical standards, appear as Appendix 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 Corporate Governance Principles. 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)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 and Compensation and Personnel 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” or“Presiding 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 jointin-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, non-management directors as a group or individual directors, including the PresidingLead 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’ website.Web site.

 

Ethical and Legal Compliance Policy

The Company has adopted a Code of Ethics that applies to all employees, including its CEO, Chief Operating Officer,COO, Chief Financial Officer and Chief Accounting Officer, as well as its Board of Directors. The Company makes its Code of Ethics available, free of charge, on the Company’s website,AEC’s Web site atwww.alliantenergy.com/investors, under the “Corporate Governance” caption and such Code of Ethics is availableor in print to any shareowner who requests it from the Company’s Corporate Secretary. The Company intends to satisfy the disclosure requirements under Item 105.05 of Form 8-K regarding amendments to, or waivers from, the Code of Ethics by posting such information on its websiteWeb site address stated above under the Corporate Governance“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 2003,2004, all other directors (the “non-employee 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 $47,137$70,000 in cash. Of thisAlso, in 2004, the Chairperson of the Audit Committee received an additional $7,500 cash amount,retainer and the 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 electedelect to use $17,137not less than 50% of his or her cash retainer to purchase 1,000 shares of AEC common stock pursuant to AEC’s Shareowner Direct Plan or to defer such amount through the Company StockAEC stock account in the AEC Director’s Deferred Compensation Plan. Travel expenses are paid for each meeting day attended.

In 2004, the non-employee directors will each receive a cash retainer of $70,000. The Directors are encouraged to make a voluntary election to use not less than 50% of this cash retainer to purchase shares of AEC common stock pursuant to AEC’s Shareowner Direct Plan or to defer through the AEC Stock account in AEC’s Director’s Deferred Compensation Plan. In 2004, the Chairperson of the Audit Committee will receive an additional $7,500 cash retainer and the Chairpersons of the Nominating and Governance; Compensation and Personnel; and Environmental, Nuclear, Health, and Safety Committees will receive an additional $5,000 cash retainer.

 

Director’s Deferred Compensation Plan

Under the AEC Director’s Deferred Compensation Plan, directors 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, provided that the return may not be greater than 12% or less than 6%. Amounts deposited to anthe AEC Stock Account are treated as though invested in the common stock of AEC and will be credited with dividends, which will be treated as if reinvested. The director may elect that the AEC Deferred Compensation Account 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 years 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 threeyearsthree 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 directors 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 director 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 five qualified charitable organizations selected by the individual director. The individual director 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. Over the life of the Program, all costs of donations and premiums on the life 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. 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. Under the split-dollar arrangement, directors 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 director in 20032004 under the Director’s Life Insurancethis Program were as follows: A. B. Arends—$50, J. B. Evans—$2, K. C. Lyall—$488,Lyall — $528, J. D. Pyle—$24, W. H. Stoppelmoor—$987Pyle — $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.

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, (2) all director nominees and directors of the Company, and(3)and (3) all director nominees, directors and executive officers as a group as of Feb. 27, 2004.28, 2005. The directors and executive officers of AEC and the Company as a group owned 1.4% of the outstanding shares of AEC common stock on that date. No individual director or officer owned more than 1% of the outstanding shares of AEC common stock on that date.

 

NAME OF BENEFICIAL OWNER


  SHARES
BENEFICIALLY
OWNED(1)


 

ExecutivesExecutive Officers(2)

    

William D. HarveyThomas L. Aller

  167,236101,264(3)

Eliot G. Protsch

  173,717210,089(3)

Barbara J. Swan

  125,590149,575(3)

Director Nominees

William D. Harvey

218,536(3)

Pamela J. WegnerSingleton B. McAllister

  124,4705,054(3)

Thomas M. WalkerAnthony R. Weiler

  1,47817,888(5)(3)
Director Nominees

Directors

    

Michael L. Bennett

3,482(3)

Erroll B. Davis, Jr.

799,433(3)

Katharine C. Lyall

16,567(4)

Ann K. Newhall

  4,116(3)

Michael L. Bennett

1,803(3)

Jack B. Evans

39,0287,408(3)

David A. Perdue

  5,5587,518(3)

Judith D. Pyle

  13,60514,111 
Directors

Alan B. Arends

10,867(3)(4)

Erroll B. Davis, Jr.

556,063(3)

Katharine C. Lyall

15,941

Singleton B. McAllister

4,251(3)

Robert W. Schlutz.Schlutz

  18,990(3)

Wayne H. Stoppelmoor

14,851(4)

Anthony R. Weiler

17,02221,271(3)

All ExecutivesExecutive Officers and Directors as a Group

2115 people, including those listed above.above

  1,572,7161,673,240(3)

 

(1)Total shares of AEC common stock outstanding as of Feb. 27, 2004,28, 2005, were 111,274,686.116,183,026.

 

(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—8,981,Davis — 9,435, Mr. Evans—2,000,Harvey — 2,826, Mr. Weiler—Weiler — 1,389, Mr. Harvey—2,717,Protsch — 845 and Mr. Protsch—820;Aller – 1,000; shares of common stock held in deferred compensation plans: Mr. Arends—5,605,Bennett — 3,082, Mr. Bennett—1,415,Davis — 50,744, Mr. Davis—48,303,Harvey — 29,011, Ms. McAllister — 2,104, Ms. Newhall — 6,110, Mr. Evans—7,028, Ms. McAllister—1,415, Ms. Newhall—2,829,Perdue — 7,518, Mr. Perdue—5,558,Schlutz — 9,797, Mr. Schlutz—7,959,Weiler — 6,707, Mr. Weiler—5,841,Aller — 6,695, Mr. Harvey—27,716, Mr. Protsch—33,879, Ms. Swan—20,698Protsch — 35,235 and Ms. Wegner—18,767Swan — 21,526 (all executive officers and directors as a group—210,729)group — 183,042); and stock options exercisable on or within 60 days of Feb. 27, 2004:28, 2005: Mr. Davis—451,687,Davis — 667,566, Mr. Harvey—112,431,Harvey — 149,977, Mr. Protsch—112,431, Ms. Swan—94,633Aller — 86,136, Mr. Protsch — 139,157 and Ms. Wegner—89,419Swan — 110,644 (all executive officers and directors as a group—1,094,060)group — 1,240,675).

 

(4)Messrs. Arends and StoppelmoorMs. Lyall will retire as directorsa director of the Company at AEC’s 2005 Annual Meeting on May 21, 2004.19, 2005.

 

(5)Mr. Walker resigned from the Company effective Nov. 15, 2003.

To the Company’s knowledge, no shareowner beneficially owned 5% or more of any class of the Company’s preferred stock as of Dec. 31, 2003.2004. The following table sets forth information, as of Dec. 31, 2003,2004 regarding beneficial ownership by the only personpersons known to AEC to own morethanmore than 5% of AEC’s common stock. The beneficial ownership set forth below has been reported on a Schedule 13G filings with the Securities and Exchange CommissionSEC by the beneficial owner.owners.

 

   Amount and Nature of Beneficial Ownership

           
   Voting Power

    Investment Power

    Aggregate

    

Percent

of Class


 

Name and Address of Beneficial Owner


  Sole

  Shared

    Sole

  Shared

        

Franklin Resources, Inc.

(and certain affiliates)
One Franklin Parkway
San Mateo, CA 94403

  6,451,800  0    6,451,800  0    6,451,800    5.8%

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 certain other executive officers of the Company for all services rendered during 2004, 2003 2002 and 2001.2002.

 

SUMMARY COMPENSATION TABLE


 


Name and Principal Position Year Annual Compensation Long-Term Compensation 

All Other

Compensation(5)


Base

Salary

Bonus

Other

Annual
Compensation(1)

AwardsPayouts 
     
     Awards(2)Payouts

Securities
Underlying
Name 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
 $
 
 
685,000749,019
685,000
683,269685,000
$

375,197
0
0
$

74,987
14,949
17,582
$

300,453
0
0
234,732
151,687
151,687
 $
 
 
0
0
489,3640
 $
 
 
14,949138,719
17,582
11,265
151,687
151,687
108,592
$

0
0
359,605
$

45,253
45,485
50,284

William D. Harvey

Chief Operating Officer

 2004
2003
2002
2001
  
 
 
459,442
290,000
282,500


206,805
274,6160
0


6,246
5,954
7,707


100,143
0
0
73,454
26,642
26,642
  
 
 
0
0
161,2330
  
 
 
5,95448,896
7,707
4,061
26,642
26,642
21,798


0
0
92,209


15,562
17,599
42,944

Barbara J. Swan

President

2003
2002
2001


265,000
260,000
254,616


0
0
134,258


0
6,716
3,459
24,705
24,705
20,212


0
0
84,985


14,536
16,356
36,172

Eliot G. Protsch

Chief Financial Officer

 2004
2003
2002
2001
  
 
 
364,539
290,000
282,500


142,167
274,6160
0


6,014
4,825
6,131


149,981
0
0
40,996
26,642
26,642
  
 
 
0
0
143,6880
  
 
 
4,82543,611
6,13115,605
89316,318

Barbara J. Swan

President

2004
2003
2002


298,674
265,000
260,000


110,791
0
0


5,255
0
6,716


100,143
0
0
 26,64232,026
26,64224,705
21,79824,705
  
 
 
0
0
92,2090
  
 
 
15,60518,843
16,31814,536
38,37216,356

Pamela J. WegnerThomas L. Aller(5)

ExecutiveSenior Vice President(3)

 2004
2003
2002
2001
  
 
 
275,000237,692
270,000200,000
264,615190,000


123,203
189,170
0
  
 
 
0
0
124,312


7,282
9,263
2,267
25,673
25,673
21,0050
  
 
 
0
0
88,597


19,641
19,178
35,371

Thomas M. Walker(4)

2003
2002
2001


267,692
277,500
264,615


680,000
0
133,852


13,895
17,543
0
 25,67321,654
25,67317,438
21,00517,438
  
 
 
0
0
88,5970
  
 
 
27,6694,164
27,2978,693
6,2078,223

 

(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 20032004 were in addition to performance share awards as described in the table entitled “Long-Term Incentive Awards in 2003.2004.

 

(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 Jan. 28,Dec. 31, 2004, Ms. Wegner is no longer anthe 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 oflisted in the Company but remains an executive officer of AEC.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)Mr. Walker, the Company’s former Executive Vice President and Chief Financial Officer, resigned from the Company effective Nov. 15, 2003. In connection with such resignation, Mr. Walker entered into a Severance Agreement and Release with AEC, pursuant to which he was paid $680,000, which is reflected in the “Bonus” column above. See “Certain Agreements.”

(5)The table below shows the components of the compensation reflected under this column for 2003:2004:

 


 Erroll B. Davis, Jr. William D. Harvey Barbara J. Swan Eliot G. Protsch Pamela J. Wegner Thomas M. Walker


 
  Erroll B. Davis, Jr.  William D. Harvey  Eliot G. Protsch  Barbara J. Swan  Thomas L. Aller
A. $20,550 $6,000 $6,000 $7,450 $7,375 $6,000 $22,672 $6,580 $8,140 $6,272 $2,591

B.  19,656  8,497  7,576  7,104  10,393  19,830  95,649  35,096  28,058  7,500  0

C.  5,047  1,065  960  1,051  1,873  1,839  8,470  3,244  1,373  1,095  1,573

D.

  11,928  3,976  6,040  3,976  0
Total $45,253 $15,562 $14,536 $15,605 $19,641 $27,669 $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 granted during 20032004 to the executives named below:

 

STOCK OPTION GRANTS IN 20032004


 



 Individual Grants  
 

 
 
Potential Realizable Value at
Assumed Annual Rates

of Stock Price Appreciation
for Option Term(3)

Name

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

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%

Erroll B. Davis, Jr.

 151,687 15.8% $16.82 1/21/13 $1,604,848 $4,066,728 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%  16.82 1/21/13  281,872  714,272 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

 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

Barbara J. Swan

 24,705 2.6%  16.82 1/21/13  261,379  662,341 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

Eliot G. Protsch

 26,642 2.8%  16.82 1/21/13  281,272  714,272

Pamela J. Wegner

 25,673 2.7%  16.82 1/21/13  271,620  688,293

Thomas M. Walker(3)

 25,673 2.7%  16.82 11/15/03  0  0

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 Equity Incentive Plan.stock. Options were granted on Jan. 21, 2003 and have a three-year vesting schedule pursuant to which one-third of the options will become exercisable on each of Jan. 2, 2004, Jan. 2, 2005, and Jan. 2, 2006.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 Securities and Exchange Commission (“SEC”).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 $27.40 and $43.63, respectively,as follows for each of the grants, all as of the expiration date of the options.

 

(3)Pursuant to his Severance Agreement and Release, Mr. Walker’s stock options were cancelled in November 2003. See “Certain Agreements.”
   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 2003.

 

AGGREGATE OPTION EXERCISES IN 2004 AND OPTION VALUES AT DEC. 31, 20032004


 



 

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 Number of Securities Underlying
Unexercised Options at Fiscal Year End
 

Value of Unexercised

In-the-Money Options at Year End(1)

  Exercisable Unexercisable  Exercisable  Unexercisable

Exercisable Unexercisable Exercisable Unexercisable

Erroll B. Davis, Jr.

 388,778 289,009 $0 $1,225,631 -- $-- 451,687 386,419 $699,194 $1,811,580

William D. Harvey

 87,403 51,669  0  215,267 --  -- 112,430 100,096  126,724  465,010

Eliot G. Protsch

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

Barbara J. Swan

 71,426 47,912  0  199,616 8,235  72,221 86,398 56,731  18,100  315,467

Eliot G. Protsch

 87,403 51,669  0  215,267

Pamela J. Wegner

 73,859 49,790  0  207,438

Thomas M. Walker

 0 0  0  0

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, 20032004 of $24.90.$28.60.

LONG-TERM INCENTIVE AWARDS

 

The following table provides information concerning long-term incentive awards made to the executives named below in 2003.2004.

 

LONG-TERM INCENTIVE AWARDS IN 20032004


 


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.

 57,135 1/01/06 28,568 57,135 114,270  36,020  1/1/2007  18,010  36,020  72,040

William D. Harvey

 12,108 1/01/06 6,054 12,108 24,216  16,486  1/1/2007  8,243  16,486  32,972

Eliot G. Protsch

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

Barbara J. Swan

 11,007 1/01/06 5,504 11,007 22,014  7,194  1/1/2007  3,597  7,194  14,388

Eliot G. Protsch

 12,108 1/01/06 6,054 12,108 24,216

Pamela J. Wegner

 11,416 1/01/06 5,708 11,416 22,832

Thomas M. Walker(2)

 12,263 N/A N/A N/A N/A

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 AEC’s three-year Total Shareowner Return (TSR)(“TSR”) relative to an investor-owned utility peer group during the three-year performance cycle ending Dec. 31, 2005.2006. 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.

 

(2)Pursuant to his Severance Agreement and Release, Mr. Walker’s awards were cancelled in November 2003. See “Certain Agreements.”

CERTAIN AGREEMENTS

 

Mr. Davis currently has an employment agreement with AEC, pursuant to which he will serve as the Chairman of AEC until the expiration of the term of the agreement on the date of AEC’s 2006 annual meeting of shareowners,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 unless otherwise determined by the Board of Directors. Mr. Davis will also serve as the Chief Executive Officer of the CompanyAEC and each subsidiary of AEC, including the Company, as long as he holds the same position for AEC. Pursuant to the employment agreement, Mr. Davis will be paid an annual base salary of not less than $750,000. Mr. Davis also will 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 AEC 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 theendthe end of the term of the agreement or one year after such termination of employment (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 terminates his employment without good reason prior to the end of the term of the agreement, AEC or its affiliates will pay to Mr. Davis or his beneficiaries or estate all compensation earned through the date of death 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 the employment agreement, if any payments thereunder constitute an excess parachute payment under the Internal Revenue 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, and Protsch and Mses. SwanAller and Wegner)Ms. 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, and Protsch and Mses. SwanAller and Wegner)Ms. 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.

 

AEC entered into a Severance Agreement and Release with Mr. Walker in connection with the conclusion of his employment with AEC as of November 15, 2003. AEC (a) paid Mr. Walker $680,000, (b) paid $10,000 towards his legal fees associated with the agreement and (c) agreed to provide him with up to $20,000 for either outplacement services or tuition reimbursement. Mr. Walker ceased to be eligible to participate under any of AEC’s stock option, bonus, equity, incentive compensation, non-qualified supplemental retirement plan, medical, dental, life insurance, retirement, pension and other compensation or benefit plans upon his termination of employment, except that he retained vested rights under AEC’s qualified retirement plans and his rights under AEC’s Key Employee Deferred Compensation Plan, and he is eligible for COBRA continuation for his medical and dental plans. If Mr. Walker elects COBRA continuation, AEC will pay for this coverage for up to 18 months. Under the agreement, Mr. Walker agreed to a two-year covenant not to compete and agreed to keep Company information confidential. In connection with the agreement, Mr. Walker provided AEC and its affiliates, including the Company, a general liability release.

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. At the time of his resignation from the Company in November 2003, Mr. Walker had a vested balance of $68,056 in the Pension Plan. The following table illustratestables 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 Harvey and Mses. Swan and Wegner.Ms. 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., 2425 years; William D. Harvey, 17 years; Eliot G. Protsch, 2425 years; William D. Harvey, 16 years;and Barbara J. Swan, 15 years;16 years.

IES Industries Pension Plan Prior Formula. The other applicable prior plan formula provided retirement income based on years of service and Pamela J. Wegner, 9 years.final average compensation for the highest consecutive 36 months out of the last 10 years of employment. Mr. Aller is the only individual listed in the Summary Compensation Table covered by this formula. The benefits would be as follows:

IES Industries Pension Plan Prior Formula Table

Average

Annual

Compensation


    Annual Benefit After Specified Years in Plan

    15

    20

    25

    30

    35

    $          200,000

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

                300,000

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

                400,000

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

                500,000

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

                600,000

     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. Aller has 11 credited years of 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 (or other termination if approved by the Board of Directors)Directors of 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, 2003.2004. 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 the service of AlliantEnergy Corporate ServicesAEC until retirement at the same salary as was in effect on Dec. 31, 2003.2004.

 

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 the CompanyAEC 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 is reduced by 3% per year for each year the participant’s retirement date precedes 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 the Company,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, and Protsch and Mses.Aller and Ms. Swan and Wegner 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 receivean 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, 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, and Protsch and Mses.Aller and Ms. Swan and Wegner 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 fivefour independent directors (the same directors that comprise the AEC Compensation and Personnel Committee). The following is a report prepared by these directors 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.shareowners and customers.

 

Total compensation should enhance the Company’s ability to attract, retain and encourage the development of exceptionally knowledgeable and experienced executives,executive officers, 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) of base salaries paid by companies of similar revenue base within the utility and general industries.

 

Incentive compensation programs should strengthen the relationship between pay and performance by emphasizing variable at-risk compensation that is consistent with meeting predetermined Company,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 similarly sized companies of similar revenue base within the utility and general industries.

 

Components of Compensation

The major elements of AEC’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 comparative 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 also 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 the Edison Electric Institute, the American Gas Association and several compensation consulting firms.surveys.

 

In consideration of industry conditionsBased on this data and Company performance,consultation with the independent executive compensation consultant, the Committee did not increase theapproved base salaries of the Chief Executive Officer and the Executive Vice Presidentssalary increases for executive officers in 2003.

2004.

Short-Term Incentives

AEC’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 20032004 to executive officers follows.

 

Alliant Energy Corporation Management Incentive Compensation PlanIn 2003,2004, 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 (including customer service and reliability) and individual performance goals.unit. Target and maximum bonus awards under the MICP in 20032004 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 150%80% of annualbase salary for Mr. Davis, and from 0% to 100%30-65% of annualbase salary for other eligible executives.executive officers, with a maximum possible payout for all of two times their target percentage.

 

Due to industryAfter assessing corporate and market conditions,business unit performance against established goals, the Committee determined that the Chief Executive Officer and Executive Vice Presidentsexecutive officers were not eligible to receive MICP awards for 20032004 plan year performance.

 

Long-Term Incentives

The Committee strongly believes compensation for executivesexecutive officers should include long-term, at-risk pay tostrengthento strengthen the alignment of the interests of the shareowners and management. In this regard, AEC 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 2003 to executive officers 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 2003:2004: 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. Until 2003, the payout from thePayout of performance shares wasgranted 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 contained in the Alliant Energy Strategic Plan. Beginningshares granted in 2003 and 2004 is based solely on AEC’s three-year TSR was used asrelative to the sole measure ofpeer group. Thus, the performance share plan. Thus,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 2003,2004, the Committee made a grantgrants of stock options and performance shares to various executive officers, including Messrs. Davis, Harvey, and Protsch and Mses. SwanAller and Wegner.Ms. 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. Such executivesThe 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 Company 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 levelcompetitiveness of long-term incentives,the total compensation package, as well as AEC corporate performance.

As was the competitivenesscase 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 approved the salary increase based on its evaluation of Mr. Davis’ performance and on a review of competitive data.

For 2004, Mr. Davis’ short-term incentive payout was based solely on AEC’s performance on the corporate goals 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 total

compensation package. The Committee then established award ranges and individual award levels based on responsibility level and market competitiveness. No corporate or individual performance measures were reviewed in connection 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 andcomprising 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 2003.recognition and retention purposes. All of Mr. Davis’ 2004 awards in 2003 under the Long-Term Incentive Programlong-term incentive program are shown in the tables under “Stock Option Grants in 2003”2004” and “Long-Term Incentive Awards in 2003.2004.

 

DueShare Ownership Guidelines

AEC has established share ownership guidelines for executive officers as a way to better align the 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 December 2003.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 objectivesmeetingobjectives 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

Michael L. Bennett

Singleton B. McAllister

David A. Perdue

Judith D. Pyle

REPORT OF THE AUDIT COMMITTEE

 

To Our Shareowners:

The Audit Committee of the Board of Directors of the Company is composed of fivefour directors, each of whom is independent under the NYSE listing standards and SEC rules. The Committee operates under a written charter adopted by the Board of Directors. The Audit Committee charter, as amended by the Board of Directors on March 11, 2004, is attached as Appendix A to this proxy statement.

 

The Company’s 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 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 has 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 that the Chairperson reports any decisions to the Committee at its next scheduled meeting.

 

The principal accounting fees that were billed to the Company by its independent auditor fees paid by AEC include thoseauditors for work performed on behalf of the Company and certain other AECits subsidiaries for 20022003 and 2003, and2004 were as follows:

 

  2002

 2003

  2003

  2004

Audit Fees(1)

  $2,843,000* $2,293,000  $        319,000  $        987,000

Audit-Related Fees

   19,000   332,000   98,000   348,000

Tax Fees

   1,125,000   435,000   162,000   70,000

All Other Fees

   297,000   54,000   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.

 

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

 

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 and, in 2002, fees for generation strategy consultation.products.


*Includes approximately $1.4 million for 2000 and 2001 re-audit fees

 


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, 2003,2004 for filing with the SEC.

 

AUDIT COMMITTEE

Jack B. Evans (Chairperson)

Alan B. Arends

Michael L. Bennett (Chairperson)

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 and its executivecertain 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 with the SEC and the NYSE. As a matter of practice, the Company’s Shareowner Services Department assists the Company’s reporting persons in preparing initial reports ofownershipof ownership and reports of changes in ownership and files those reports on their behalf. ToThe Company is required to disclose in this proxy statement the bestfailure of the Company’s knowledge, all required filings in 2003 were properly made in a timely fashion. In making the above statements, the Company has reliedreporting persons to file these reports when due. Based on the written representations of the parties involvedreporting persons 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 Wisconsin Power and Light Company (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. While the Committee has the responsibilities and powers set forth in this Charter, it is not the duty of the Committee to conduct audits or determine that the Company’s financial statements and disclosures are complete and accurate and are in accordance with accounting principles generally accepted in the United States of America (“GAAP”) and applicable laws and regulations.

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 without the prior consent of the Board to enable the Board to determine that such service would not impair the ability of such a member to effectively serve on the Audit Committee.

Appointment and Removal of Committee Members

The Committee members shall be appointed by the Board annually or as necessary to fill vacancies upon recommendation of the Company’s Nominating and Governance Committee. Each member shall serve until his or her successor is duly elected and qualified or until such member’s earlier resignation or removal. Any member of the Committee may be removed, with or without cause, by a majority vote of the Board upon recommendation of the Company’s Nominating and Governance Committee.

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 financial statements and earnings releases. Additional meetings shall be held when deemed necessary or desirable at the request of the Chairperson of the Board, the Chief Executive Officer or any Committee member. The Committee will meet periodically in executive session without management present.

Committee Responsibilities

The responsibilities of the Committee are to:

1.Be directly responsible for the appointment, compensation, retention, termination 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. Such pre-approval may be pursuant to pre-approval policies and procedures established by the Committee provided such policies and procedures are detailed as to the particular service to be provided, require the Committee to be informed about each such service prior to making pre-approval decisions and do not include delegation of the Committee’s responsibilities to management. 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.

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.Review and 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; provided that the discussion of financial information and earnings guidance provided to analysts and ratings agencies may be done generally (e.g. discussion of the types of information to be disclosed and the type of presentation to be made) and need not occur in advance of each instance in which the Company may provide such information or guidance.

6.Review and 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 in separate private sessions, on a periodic basis, with each of 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 or material weaknesses in the design or operation of internal control over financial reporting or any fraud, whether or not material, involving management or other employees who have a significant role in the Company’s internal control over financial reporting.

16.As and when required by Commission rules, obtain, on a quarterly basis, reports from management regarding its evaluation of the Company’s disclosure controls and procedures and internal control over financial reporting.

17.As and when required by Commission rules, obtain, on an annual basis, the independent auditors’ attestation report on management’s assessment of the Company’s internal control over financial reporting.

18.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.

19.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.

20.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, Public Company Accounting Oversight Board inspection, or by any inquiry or investigation by governmental or professional authorities (including any material litigation), 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.

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

22.Ensure the rotation of lead and concurring 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.

23.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.

24.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.

25.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.

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

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

Committee Reports

1.Report to the Board on a regular basis on the activities of the Committee (i) following meetings of the Committee, (ii) with respect to such other matters as are relevant to the Committee’s discharge of its responsibilities and (iii) with respect to such recommendations as the Committee may deem appropriate. 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. The report to the Board may take the form of an oral report by the Committee’s Chair or any other member of the Committee designated by the Committee to make such report.

2.Annually produce a report on matters required by the rules of the Commission for inclusion in the Company’s annual proxy statement.

3.Maintain minutes or other records of meetings and activities of the Committee

Annual Performance Evaluation

Conduct 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. In addition, the Committee shall review and reassess, at least annually, the adequacy of this charter and recommend to the Board any improvements to this charter that the Committee considers necessary or appropriate. The Committee shall conduct such evaluations and reviews in such manner as it deems appropriate.

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.

(As Amended March 11, 2004)

APPENDIX B – WISCONSIN POWER AND LIGHT COMPANY

ANNUAL REPORT

 

For the Year Ended December 31, 20032004

 

Contents


  Page

Definitions

B-2

The Company

  B-3A-2

Selected Financial Data

  B-3A-2

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

  B-4A-3

Report of Independent Auditors’ ReportRegistered Public Accounting Firm

  B-18A-15

Consolidated Financial Statements

   

Consolidated Statements of Income

  B-19A-16

Consolidated Balance Sheets

  B-20A-17

Consolidated Statements of Cash Flows

  B-22A-19

Consolidated Statements of Capitalization

  B-23A-20

Consolidated Statements of Changes in Common Equity

  B-24A-21

Notes to Consolidated Financial Statements

  B-25A-22

Shareowner Information

  B-42A-39

Executive Officers and Directors

  B-43A-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

ARO

Asset Retirement Obligation

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 46

Consolidation of Variable Interest Entities

GAAP

Accounting Principles Generally Accepted in the U.S.

ICC

Illinois Commerce Commission

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

N/A

Not Applicable

NEPA

National Energy Policy Act of 1992

NOx

Nitrogen Oxides

NRC

Nuclear Regulatory Commission

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 71

Accounting for the Effects of Certain Types of Regulation

SFAS 109

Accounting for Income Taxes

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

SFAS 149

Amendment of SFAS 133 on Derivative Instruments and Hedging Activities

South Beloit

South Beloit Water, Gas and Electric Company

Standard & Poor’s

Standard & Poor’s Rating Services

TBD

To Be Determined

U.S.

United States of America

VEBA

Voluntary Employees’ Beneficiary Association

WP&L

Wisconsin Power and Light Company

WRPC

Wisconsin River Power Company

WP&LLight Company (WPL) filed a combined Form 10-K for 20032004 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

 

The primary first tier subsidiaries of Alliant Energy include: WP&L, IP&L, Resources and Corporate Services. WP&LOverview- WPL was incorporated in 1917 in Wisconsin as Eastern Wisconsin Electric Company. WP&LWPL 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 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, 2003, WP&L2004, WPL supplied electric and gas service to 436,976445,198 and 172,615176,045 (excluding transportation and other) customers, respectively. WP&LWPL also provides water services in select markets and various other energy-related products and services, including construction management services for wind farms. In 2004, 2003 and 2002, and 2001, WP&LWPL had no single customer for which electric, gas, water and/or other 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 regardingPublic 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 at least 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, 2003, WP&L2004, WPL provided retail electric service to 434,941443,166 retail and 31 wholesale customers 601 communities and 30 wholesale customers. 2003610 communities. 2004 electric utility operations accounted for 75%78% of operating revenues and 85%90% of operating income. Electric sales are seasonal to some extent with the annual peak normally occurring in the summer months. In 2003,2004, the maximum peak hour demand for WP&LWPL was 2,782 MW2,627 megawatts and occurred on Aug.July 20, 2003.2004.

 

Gas Utility Operations- As of Dec. 31, 2003, WP&L2004, WPL provided retail natural gas service to 172,615176,045 (excluding transportation and other) customers in 232243 communities. 20032004 gas utility operations accounted for 22%21% of operating revenues and 13%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

 

  2003(1)

  2002(1)

  2001(1)

  2000

  1999

  2004 (1)

  2003 (1)

  2002 (1)

  2001

  2000

  (in thousands)  (in millions)

Operating revenues

  $1,216,981  $989,525  $993,716  $862,381  $752,505  $1,209.8  $1,217.0  $989.5  $993.7  $862.4

Earnings available for common stock

  111,564  77,614  70,180  68,126  67,520   110.4   111.6   77.6   70.2   68.1

Cash dividends declared on common stock

  70,580  59,645  60,449  --    58,353   89.0   70.6   59.6   60.4   —  

Cash flows from operating activities

  138,495  223,750  135,886  174,060  163,228   199.3   138.5   223.8   135.9   174.1

Total assets

  2,469,277  2,335,138  2,217,457  2,160,554  2,025,709   2,656.1   2,469.3   2,335.1   2,217.5   2,160.6

Long-term obligations, net

  453,509  523,308  523,183  569,309  471,648   491.3   453.5   523.3   523.2   569.3

 

(1)Refer to “Results of Operations” in MD&AMDA for a discussion of the 2004, 2003 2002 and 20012002 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.

MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND

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: 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 to allow for, among other things, the recovery of operating costs, and the earning of reasonable rates of return as well asin current and future proceedings and the payment of expected levels of dividends; unanticipated construction and acquisition expenditures; unanticipated issues in connection with WP&L’sWPL’s construction of new generating facilities; issues related to the supply of purchased electric supplieselectricity 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 WPL’s nuclear facility and unanticipated issues relating to the anticipated sale of WP&L’sWPL’s interest in Kewaunee;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; 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 appeals with no material impact on WP&L’sWPL’s earnings orand cash flows; inflation rates; and factors listed in “Other Matters—Matters - Other Future Considerations.” WP&LWPL 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 OVERVIEW

 

November 2002 PlanSummary - - In 2003, Alliant Energy (including WP&L) completedWPL’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 it (including WP&L) outlined in November 2002 to strengthen its (including WP&L’s) financial profile. A summary ofis also concentrated on building and maintaining the strategic actions completed under the plan that directly impact WP&L is as follows:

Asset sales - in 2003, WP&L sold its water utility serving the Beloit area. WP&L continues to pursue the sale of its water utilities serving the Ripon and South Beloit areas.
Common equity offering - in July 2003, Alliant Energy sold 17.25 million shares (net proceeds of $318 million) of its common stock in a public offering and infused $200 million into WP&L in support of its utility generation and reliability initiatives.
Cost control - Alliant Energy (including WP&L)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 whichto assist it expects to help reduce its operating costsin generating cost savings and improve the efficiency of its operations.

Updated Strategic Plan - Alliant Energy’s domestic utility business (including WP&L) is its core businessoperational efficiencies in 2005 and the sole growth platform within its updated strategic plan. As a result, Alliant Energy views its domestic utility business as the area of its business that is expected to provide the larger share of its long-term earnings growth. It will also be the area of the business that Alliant Energy will invest the bulk of its capital in during 2004 and 2005. In addition, Alliant Energy’s Non-regulated Generation business has refined its focus to support the development, financing and construction of generation to meet the needs of Alliant Energy’s domestic utility business.beyond.

 

Alliant Energy’s updatedWPL’s strategy reflects the fact that it has investment opportunities in its domestic utility business that did not exist several years ago. Wisconsin enacted legislation with the goal of assuring reliable

electric energy for Wisconsin, whichWisconsin. 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. More recently,In addition, the PSCWPublic 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 WP&LWPL to pursue additional generation investments to serve its customers and to provide Alliant EnergyWPL with greater certainty regarding the returns on these investments.

 

Utility Generation Plan -In December 2003, Alliant Energy announced its updated domestic utility generationa plan which is expected to add aan additional 615 megawatts (MW) of utility generating capacity to its diversified portfolio of nameplate generation between 2004 andby 2010 for WP&L as follows (in MW):

Natural gas-fired generation

300

Wind (purchased-power and/or generation)

100

Coal

200

Other

15

Total

615

WP&LWPL. WPL intends to add this new generation to meet increasing customer demand, reduce reliance on purchased-powerpurchased power agreements and mitigate the impacts of potential future plant retirements. WP&LWPL 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. WP&L expects that 300 MW of the natural gas-fired generation will be installed as combustion turbines for peaking generation. The plan also reflects continued commitments to WP&L’sWPL’s energy efficiency and environmental protection programs. WP&L’s capital expenditures associated withThe following is a summary of the significant progress Alliant Energy has made to-date regarding the execution of this plan arethat 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 be approximately $360 million overcomplete the seven-year period of 2004facility in time to 2010.

In January 2004,meet increased summer demand in 2005. Alliant Energy announcedis proposing that Resources’ Non-regulated Generation business has assumed an optionwould 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 purchase a site for a 300 MW natural gas-fired power plant outside Sheboygan Falls, Wisconsin. Subjectthe generation output. The facility is expected to PSCW approval, Resources’ Non-regulated Generation business would construct and own thecost approximately $150 million, plant (ofof which $75approximately $120 million hashad already been expended as of Dec. 31, 20032004. The proposed structure is subject to purchase twofinal 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 August 2004, Alliant Energy announced its intention to sell WPL’s and IPL’s Illinois electric and gas turbines)utility properties (WPL’s net book value was approximately $20 million to $25 million as of Dec. 31, 2004). The administrative costs of serving relatively few customers in a jurisdiction that requires the same regulatory and lease the facilityadministrative support as a state with a larger number of customers make it difficult for Alliant Energy to WP&L. WP&L will operate the plant and utilize the plant’s output. With the appropriate timely regulatory approvals,offer its services cost-effectively. Alliant Energy currently intends to have this facility placed in-service in 2005. In addition, Calpine Corporation is currently constructing a 600 MW natural gas-fired combined cycle power plant in Wisconsin at WP&L’s Rock River plant (Riverside). WP&L has enteredenter into a purchased-powersales agreement for 453 MWthe Illinois properties in the first half of this plant’s output2005 and any such sales agreement would be subject to regulatory approvals.

In January 2005, WPL and the plantcity 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 be placed in-service priortake place in the first half of 2005. WPL also continues to make progress on the sale of its water utility in South Beloit, Illinois.

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

 

RATES AND REGULATORY MATTERS

 

Overview - - WP&L, whichWPL has one utility subsidiary, South Beloit Water, Gas and Electric Company (South Beloit) and is currently subject to federal regulation by FERCthe Federal Energy Regulatory Commission (FERC), which has jurisdiction over wholesale rates and certain natural gas facilities, and state regulation in Wisconsin and Illinois.Illinois for retail utility rates and standards of service. Such regulatory oversight also covers not only current facilities and operations, but also WP&L’sWPL’s plans for construction and financing of new generation facilities and related activities.

 

As a public utility company with significant utility assets, WP&LWPL conducts its utility operations in an ever-changing business environment. Electric energy generation, transmission and distribution are facing a period of fundamental change resulting from potential legislative, regulatory, economic and technological changes. These changes could impact competition inHowever, the electric wholesale and retail markets in the event customers of electric utilities are 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. FERC regulates competition in the electric wholesale power generation market and each state regulates whether

to permit retail competition, the terms that would apply and the recovery of any portion of stranded costs that are ultimately determined to have resulted from retail competition. WP&L cannot predict the timing of a restructured electric industry or the impact on its financial condition or results of operations. The pace of restructuring in itsWPL’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 industry. WPL cannot predict the timing of a restructured electric industry or the impact on its financial condition or results of operations.

 

Certain Recent Developments - - Details of WP&L’sWPL’s domestic utility rate cases impacting its historical and future results of operations since 2001 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 (1)


  

Final

Effective

Date


  

Expected

Final

Effective

Date


  Return
on
Common
Equity


  Notes

   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%     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%  (2)  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%  (3)  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  (4)  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     E  3/03   5   5  7/03   5  2/04  N/A  N/A  

South Beloit

retail - IL

  G/W  10/03  1  N/A  N/A  TBD  TBD  9/04  TBD   

2004 retail

(fuel-only)

  E  2/04  16  TBD  TBD  TBD  TBD  8/04  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)A party representing selected commercial and industrial electric customers had appealed theThe 2005/2006 retail rate case is based on a test period from July 2005 to a court, seeking remand back to the PSCW for further consideration on issues of revenue increase amount and rate design. In December 2003, the court denied the request for remand and affirmed the PSCW’s earlier decision.June 2006.

(3)A number of factors contributed to the final rate relief being set lower than the original request, including lower projected fuel and purchased-power costs, reduced operation and maintenance costs, lower purchased-power incentive costs and reduced capital expenditures.
(4)Since the final increase was lower than the interim relief granted, a refund to customers was made in 2003.2004.

(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 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 increased costs incurred by WP&L,WPL or costs it expects to incur, thusincur. In addition to the total2005/2006 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 rate increases have not or areincrease requests is not expected to result in a correspondingmeaningful increase in net income.

 

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 rate increases for increases in the cost of electric fuel and purchased power if it experiences an extraordinary increase in the cost of fuel or if the annual costs that are more than 3% higher than the estimated costs used to establish rates. Such rules were revised effective for 2003 for WP&L and significantly reduce the regulatory lag for Wisconsin utilities and customers relatedThe PSCW attempts to the timing of changes in rates for increased or decreased fuel and purchased-power costs. The revised rules require that anauthorize, after a required hearing, interim increase/decrease in rates subject to increased/decreased fuel costs, if determined to be justified, be approvedfuel-related rate increases within 21 days of notice to customers. Any such change in rates would be

effective prospectively and would require a refund with interest at the overall authorized return on common equity if final rates are determined to be lower than interim rates approved, and would not include a provision for collection of retroactive fuel cost variances.approved. Rate decreases due to decreases in fuel-related costs can be implemented without hearing. The revised rules also include a process whereby Wisconsin utilities can seek deferral treatment of emergency changes in fuelfuel-related costs between fuel-onlyfuel-related or base rate cases. Such deferrals would be subject to review, approval and recovery in future fuel-onlyfuel-related or base rate cases.

 

Energy-related legislation is currently pending in the U.S.United States (U.S.) Congress that, among other proposals, would repeal PUHCA.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 WP&L.

WPL.

RESULTS OF OPERATIONS

 

Overview - - WP&L’sWPL’s earnings available for common stock increased $34.0 million and $7.4decreased $1.2 million in 2004 and increased $34 million in 2003. The 2004 decrease was primarily due to increased operating expenses, largely offset by higher electric margins. The 2003 and 2002, respectively,increase was primarily due to higher electric and gas margins, partially offset by increased operating expenses.

 

Electric Margins - - Electric margins and MWhmegawatt-hour (MWh) sales for WP&LWPL were as follows (in thousands):follows:

 

  Revenues and Costs

 MWhs Sold

   Revenues and Costs (in millions)

 MWhs Sold (in thousands)

 
  2003

  2002

  *

 2001

  **

 2003

  2002

  *

 2001

  **

   2004

  2003

  *

 2002

  **

 2004

  2003

  *

 2002

  **

 

Residential

  $316,893  $271,875  17%  $248,128  10%  3,410  3,432  (1%) 3,318  3%   $327.8  $316.9  3% $271.9  17% 3,375  3,410  (1%) 3,432  (1%)

Commercial

   170,342   146,726  16%   138,269  6%  2,167  2,150  1%  2,122  1%    180.0   170.3  6%  146.7  16% 2,215  2,167  2% 2,150  1%

Industrial

   243,770   211,310  15%   207,791  2%  4,595  4,454  3%  4,538  (2%)   262.6   243.8  8%  211.3  15% 4,769  4,595  4% 4,454  3%
  

  

   

   
  
   
     

  

   

   
  
   
   

Total from retail customers

   731,005   629,911  16%   594,188  6%  10,172  10,036  1%  9,978  1%    770.4   731.0  5%  629.9  16% 10,359  10,172  2% 10,036  1%

Sales for resale

   155,573   125,822  24%   131,187  (4%) 4,196  3,654  15%  3,524  4%    144.1   155.6  (7%)  125.8  24% 3,797  4,196  (10%) 3,654  15%

Other

   23,508   31,947  (26%)  28,075  14%  82  94  (13%) 61  54%    25.3   23.5  8%  32.0  (27%) 80  82  (2%) 94  (13%)
  

  

   

   
  
   
     

  

   

   
  
   
   

Total revenues/sales

   910,086   787,680  16%   753,450  5%  14,450  13,784  5%  13,563  2%    939.8   910.1  3%  787.7  16% 14,236  14,450  (1%) 13,784  5%
            
  
   
               
  
   
   

Electric production

fuel and purchased- power expense

   409,742   352,539  16%   338,028  4%           

Electric production fuel and purchased-power expense

   431.5   409.7  5%  352.5  16%          
  

  

   

              

  

   

            

Margin

  $500,344  $435,141  15%  $415,422  5%           

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

**Reflects the % change from 2001 toCooling 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 marginmargins increased $65.2$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 operating expenses, and 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 the 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 energy conservation expenses.

Electric margins increased $65 million, or 15%, and $19.7 million, or 5%, forin 2003, and 2002, respectively, primarily due to the implementation of rate increases during 2003 and 2002, including increased revenues to recover a significant portion of WP&L’sWPL’s increased operating expenses, and increasedweather-normalized retail sales from continued modest retail customer growth. Also contributing to the 2003 increase weregrowth, the impact of WP&LWPL implementing seasonal rates in 2003 for the first time, lower purchased-powerpurchased power and fuel costs impacting marginmargins and higher sales to non-retail customers. These items were partially offset by lower energy conservation revenues and the impact of milder weather conditions in 2003 compared to 2002. Also contributing to the 2002 increase were more favorable weather conditions in 2002 compared to 2001, partially offset by the sluggish economy.

In April 2003, WP&LWPL 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 implementedyet effective in the first quarter of 2003, until April, the impact of seasonal rates increased the 2003 electric margins by approximately $6 million in 2003 compared to the 2004 and 2002 when no seasonal rates were in effect. As a result, the first quarter of 2004 margins are expected to be negatively impacted in comparison to the 2003 margin for the same period by a similar amount.

electric margins.

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

 

  Revenues and Costs

 Dths Sold

  Revenues and Costs (in millions)

 Dths Sold (in thousands)

 
  2003

  2002

  *

  2001

  **

 2003

  2002

  *

 2001

  **

  2004

  2003

  *

 2002

  **

 2004

  2003

  *

 2002

  **

 

Residential

  $137,060  $94,509  45%  $107,673  (12%) 12,797  12,863  (1%) 11,754  9%  $136.4  $137.1  (1%) $94.5  45% 12,456  12,797  (3%) 12,863  (1%)

Commercial

  74,594  50,121  49%  58,658  (15%) 8,539  8,574  --    7,572  13%   76.8   74.6  3%  50.1  49% 8,585  8,539  1% 8,574  —   

Industrial

  9,606  6,980  38%  8,907  (22%) 1,182  1,303  (9%) 1,197  9%   8.1   9.6  (16%)  7.0  37% 1,098  1,182  (7%) 1,303  (9%)

Transportation/other

  51,117  27,481  86%  31,625  (13%) 19,796  18,572  7%  16,866  10%   32.5   51.1  (36%)  27.5  86% 20,684  19,796  4% 18,572  7%
  
  
     
   
  
   
     

  

   

   
  
   
   

Total revenues/sales

  272,377  179,091  52%  206,863  (13%) 42,314  41,312  2%  37,389  10%   253.8   272.4  (7%)  179.1  52% 42,823  42,314  1% 41,312  2%
               
  
   
               
  
   
   

Cost of gas sold

  186,285  110,119  69%  153,823  (28%)             165.8   186.3  (11%)  110.1  69%          
  
  
     
              

  

   

            

Margin

  $86,092  $68,972  25%  $53,040  30%           

Margins

  $88.0  $86.1  2% $69.0  25%          
  
  
     
              

  

   

            

 

*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

**Reflects the % change from 2001 toHeating 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 higher in 2003 and 2001 as compared to 2002 due to increased natural gas prices. These increases alone had little impact on WP&L’sWPL’s gas marginmargins given its rate recovery mechanism for gas costs. Gas marginmargins increased $17.1$17 million, or 25%, and $15.9 million, or 30%, forin 2003, and 2002, respectively, primarily due to the impact of rate increases implemented during 2003 and 2002, improved performance of $3$2.7 million from WP&L’sWPL’s performance-based gas commodity cost recovery program (benefits are shared by ratepayers and shareowners), and continued modest customer growth. The 2002 increase was also due to the negative impact high gas prices in early 2001 had on gas consumption during that period.

 

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

 

Other Revenues - -Other revenues decreased $18 million in 2004 primarily due to lower construction management revenues from WindConnect, resulting from uncertainty in 2004 regarding the extension of the federal renewable energy production tax credit. This decrease was largely offset by lower operating expenses related to 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 $11.8$12 million and decreased $10.6 million forin 2003, and 2002, respectively. The 2003 increase was primarily due to increased revenues from WindConnect. The 2002 decrease was primarily due to decreased non-commodity products and services revenues. These 2003 and 2002 variances, which were largely offset by variances in other operation and maintenancehigher 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 $52.9$53 million and $28.7 million forin 2003, and 2002, respectively. The 2003 increase was largely due to increases in the amortization of deferred costs that are now being recovered in rates, employee and retiree benefits, (primarily compensation, medical and pension costs), WindConnect and nuclear expenses. The increased nuclear expenses resulted primarily from a planned refueling outage at Kewaunee in 2003. ThereA similar planned outage occurred in 2004 but there was no refueling outage in 2002. These items were partially offset by lower fossil generation expenses. The 2002 increase was largely due to higher fossil generation, employee and retiree benefits, energy conservation, and transmission and distribution expenses, and higher regulatory amortization, partially offset by decreased non-commodity products and services expenses. A significant portion of these cost increases are being recovered as a result of the rate increases implemented during 2003 and 2002.

Depreciation and amortization expense decreased $3.8 million and $12.3 million forin 2003, and 2002, respectively. The 2003 decrease was primarily due to lower software amortizations, partially offset by property additions. The 2002 decrease was largely due

Refer to lower decommissioning expense based“Rates and Regulatory Matters” for discussion of the interplay between utility operating expenses and utility margins given their impact on reduced retail funding levels, partially offset by higher software amortizations.WPL’s utility rate activities.

 

Interest Expense and Other - - Interest expense decreased $4.4 million and $2.3 million for 2004 and $3.3 million for 2003, and 2002, respectively. The 2003 decrease was largelyrespectively, primarily due to lower average borrowings outstanding. The 2002 decrease was largely due to lower average interest rates on the outstanding borrowings. Equity income from unconsolidated investments increased $4.3 million and $3.7 million for 2004 and 2003, respectively, primarily due to higher earnings at WRPC and ATC.American Transmission Company LLC (ATC) resulting from rate increases.

Income Taxes- The effective income tax rates were 36.8%, 36.4%, and 35.6% in 2004, 2003 and 35.9% in 2003, 2002, and 2001, respectively. Refer to Note 5 of the “Notes to Consolidated Financial Statements” for additional information.

 

LIQUIDITY AND CAPITAL RESOURCES

 

Overview - -WPL believes it has a strong liquidity position and expects to maintain this position over its planning period of 2005 to 2009 as a result of its available capacity under its revolving credit facility and stable operating cash flows. Based on expected operating cash flows, coupled with actions Alliant Energy (including WP&L) has taken and expects to take to strengthen its and WP&L’s balance sheet, WP&LWPL believes it will be able to secure the additional capital it requiresrequired to implement its updated strategic plan. WP&Lplan through the 2005 to 2009 planning period. WPL believes its ability to secure additional capital has been significantly enhanced by its actions during the successful executionlast several years to strengthen its balance sheet as is evidenced by, among other items, WPL’s current debt-to-total capitalization ratio of the strategic actions Alliant Energy announced33% compared to 43% in Novemberearly 2002. Refer to “Strategic Overview - November 2002 Plan” for further discussion.

 

WP&L’s capital requirementsPrimary 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 primarily attributableutilized to construction programs and its debt maturities. WP&L’sprovide such services. Operating cash flows are expected to cover dividends anda majority of WPL’s utility maintenance capital expenditures relatedand dividends paid to infrastructureAlliant Energy. The capital requirements needed to retire maturing debt and reliability investments. WP&L’spay capital expenditures associated with building additional generation are expected to total $360 million through 2010 and are expected to be financed largely through external financings and proceeds from asset divestitures, supplemented by internally generated funds.

 

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

 

  2004

 2003

 2002

 
Cash flows from (used for):  2003

 2002

 2001

    

Operating activities

  $138,495  $223,750  $135,886   $199.3  $138.5  $223.8 

Investing activities

   (214.3)  (108.4)  (187.8)

Financing activities

  (11,595) (27,685) (19,176)   (12.0)  (11.6)  (27.7)

Investing activities

  (108,402) (187,795) (116,832)

 

Cash Flows From Operating Activities -

Historical Changes in Cash Flows From Operating Activities - In 2004, WPL’s cash flows from operating activities increased $61 million primarily due to changes in working capital caused largely by the timing of tax payments and refunds. In 2003, WP&L’sWPL’s cash flows from operating activities decreased $85 million primarily due to changes in working capital,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 from the sale of WPL’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 a rigorous cross-functional review prior to approval. Changes in 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 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 net income. Cashcommon stock dividends, largely offset by changes in the amount of debt issued and retired. In 2003, WPL’s cash flows used for financing activities decreased $16 million primarily due to a higher capital contribution from Alliant Energy in 2003 compared to 2002, partially offset by changes in the amount of debt issued and retired. Cash flows used for investing activities decreased $79 million primarily due to proceeds from the sale of WP&L’s water utility serving the Beloit area and lower contributions to its nuclear decommissioning trust fund. In 2002, WP&L’s cash flows from operating activities increased $88 million due to changes in working capital and cash flows used for investing activities increased $71 million primarily due to proceeds received from the transfer of WP&L’s transmission assets to ATC in 2001.

 

State Regulatory ApprovalsFinancing Authorizations - - At Dec. 31, 2003, WP&L was authorized by the appropriateWPL has state regulatory agencies to issueagency financing authorization for short-term debtborrowings of $240 million, which includes $85$185 million for general corporate purposes an additional $100 million should WP&L no longer sell its utility receivables and an additional $55 million should WP&L need toWPL repurchase its variable rate demand bonds. Issuance of debt securities by WPL is exempt from regulation under provisions of PUHCA.

 

CashShelf Registrations - In 2004, WPL filed a shelf registration with the Securities and Temporary Cash Investments - AsExchange 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, 2003, WP&L had approximately $27 million of cash and temporary cash investments.2004.

 

SaleCommon Stock Dividends - In its December 2003 rate order, the PSCW stated WPL may not pay annual common stock dividends, including pass-through of Accounts Receivablesubsidiary dividends, in excess of $89 million to Alliant Energy if WPL’s actual average common equity ratio, on a regulatory financial basis, is or will fall below the authorized level of 54.01%. WPL’s dividends are also restricted to the extent that such dividend would reduce the common stock equity ratio to less than 25%. WPL has common stock dividend payment restrictions based on its bond indentures and the terms of its outstanding preferred stock. At Dec. 31, 2004, WPL was in compliance with all such dividend restrictions.

Long-term Debt- 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 7.75% 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 48 of the “Notes to Consolidated Financial Statements” for additional information on WP&L’s sale of accounts receivable program.short- and long-term debt.

 

Short-term Debt - - In September 2003, WP&LJuly 2004, WPL completed the syndication of a 364-day$250 million revolving credit facility totaling $200 million,(facility) which supports commercial paper and is available for direct borrowing orborrowings. This facility is designed to support commercial paper. WP&L hasbe a five-year facility with the option to convertlength of the facility intosubject to various regulatory approvals given the term is longer than a one-year term loan. It is expected that WP&L will be able364-day facility. WPL expects to renew or replacereceive the facilityremaining regulatory approvals in 2005. In addition to funding working capital needs, the availability of short-term financing provides WPL flexibility in the issuance of long-term securities. The level of short-term borrowing fluctuates based on favorable terms when it maturesseasonal corporate needs, the timing of long-term financings and capital market conditions. Information regarding commercial paper at Dec. 31, 2004 was as follows (dollars in 2004. Themillions):

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 various covenants, including a requirement to maintaincovenant requiring a debt-to-capitaldebt-to capital ratio of less than 58%. At Dec. 31, 2003, WP&L’s2004, WPL’s debt-to-capital ratio was 29.9%34%. The debt component of the capital ratio includes, where applicable, long- and short-term debt (excluding

non-recourse debt and trade payables), capital lease obligations, letters of credit and guarantees of the foregoing and unfunded vested benefits under qualified pension plans. The equity component excludes accumulated other comprehensive income (loss).

 

In addition to funding working capital needs, the availability of short-term financing provides WP&L 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 financings and capital market conditions. WP&L did not have any commercial paper outstanding at Dec. 31, 2003 and information regarding commercial paper during 2003 was as follows (in millions):

Available capacity at Dec. 31, 2003

  $200.0

Average daily amount outstanding during 2003

   29.8

Maximum daily amount outstanding during 2003

   84.5

WP&L’sWPL’s credit facility contains a negative pledge provision, which generally prohibits placing liens on any of WP&L’sWPL’s property with certain exceptions, including among others, for the issuance of secured debt under WP&L’sWPL’s first mortgage bond indentures, non-recourse project financing and purchase money liens.

 

WP&L’sWPL’s credit facility contains a material adverse change (MAC) clause. Before each extension of credit (each borrowing under the facility), WP&Lunless the borrowing will be used exclusively to repurchase commercial paper issued by or on behalf of WPL, WPL must represent and warrant that no MAC has occurred since Dec. 31, 2002.2003. 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 borrower or the borrower and its subsidiaries taken as a whole; (2) a material impairment of the ability of the borrower to 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 anythe credit agreement to which it is a party.

 

WP&L’sWPL’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 5%20% of WP&L’sWPL’s consolidated assets in any 12-month period be used to reduce commitments under its facility. Exclusions include, among others, certain intercompany sales and certain sale and lease-back transactions.transactions, and any potential sales of WPL’s nuclear assets.

 

Long-term Debt - In September 2003, WP&L retired $70 million of its 8.6% first mortgage bonds due 2027 largely from proceeds of a capital contribution from Alliant Energy.

Refer to “Contractual Obligations” for the timing of WP&L’s long-term debt maturities. Depending upon market conditions, it is currently anticipated that a majority of the maturing debt will be refinanced with the issuance of long-term securities. Refer to Note 8 of the “Notes to Consolidated Financial Statements” for additional information on short- and long-term debt.

Credit Ratings and Balance Sheet - - Access to the 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 investment-grade credit ratings and a strong balance sheet. Refer to “Strategic Overview - November 2002 Plan” for discussion of specific actions taken in this regard. Although WP&LWPL believes the actions taken in 2003recent years to strengthen its balance 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. WP&L’sWPL’s current credit ratings and outlook that were affirmed in January 2004 by both Standard & Poor’s and Moody’s 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

  AA-  A1

Unsecured long-term debt

  BBB+  A2

Commercial paper

  A-2  P-1

Corporate/issuer

  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.” Pre-existing ratings triggers in certain lease agreements were eliminated during 2003. However, WP&LWPL is party to various agreements, including purchased-powerpurchased power agreements fuel contracts and accounts receivable salefuel contracts that are dependent on maintaining investment-grade credit ratings. In the event of a downgrade below investment-grade, WP&LWPL may need to provide credit support, such as letters of credit or cash collateral equal to the amount of the exposure, or may need to unwind the contract or pay the underlying obligation. WP&L is party to an accounts receivable sale agreement that provides thatIn the event of a downgrade below investment-grade, causes WP&L to become ineligible to sell receivables under the program. In the event of downgrades below investment-grade, management believes theWPL’s credit facility at WP&L provideswould provide sufficient liquidity to cover counterparty credit support or collateral requirements under the various purchased-power,purchased power and fuel and receivables sales agreements.

 

Off-Balance Sheet Arrangements - - WP&LWPL 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. Refer to Note 3 of the “Notes to Consolidated Financial Statements” for future minimum lease payments under, and residual value guarantees by WP&L,WPL, of these synthetic leases. WP&L’sWPL’s credit facility agreement prohibits it from entering into any additional synthetic leases. WP&L uses special purpose entities for its limited recourse utility sale of accounts receivable program whereby WP&L uses proceeds from the sale of the accounts receivable and unbilled revenues 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 receivables generates a significant amount of short-term financing for WP&L. Refer to Note 4 of the “Notes to Consolidated Financial Statements” for aggregate proceeds from the sale of accounts receivable. While WP&L does not have any reason to believe this program would be discontinued, if this financing alternative were not available, WP&L anticipates it would have enough short-term borrowing capacity to compensate. Refer to “Ratings Triggers” for the impact of certain credit rating downgrades on WP&L related to the accounts receivable sales program. WP&LWPL has reviewed thesethe lessor entities during its implementation of FINrevised Financial Accounting Standards Board Interpretation No. 46, for those entities that are considered to be special-purpose entities,“Consolidation of Variable Interest Entities,” (FIN 46R), and determined that consolidation of these entities is not required. WP&L continuesRefer to evaluate non-special purpose entities that may require consolidation asNote 18 of March 31, 2004.the “Notes to Consolidated Financial Statements” for additional information regarding the implementation of FIN 46R.

Sales of Non-strategic Assets - WP&L is currently pursuing the sales in 2004 of its interest in its Kewaunee facility and its water utilities serving the Ripon and South Beloit areas. The proceeds realized from these asset sales are expected to be available for debt reduction and other general corporate purposes.

Credit Risk - - WP&LWPL has limited credit exposure from electric and natural gas sales and non-performance of contractual obligations by its counterparties. WP&LWPL 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.

 

Construction and Acquisition ExpendituresCertain Financial Commitments - - Capital expenditures, investments and financing plans are continually reviewed, approved and updated as part of WP&L’s ongoing strategic planning and 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 investment-grade 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 its construction and acquisition expenditures for utility infrastructure and reliability investments to be $228 million in 2004 and $248 million in 2005. WP&L has not yet entered into contractual

commitments relating to the majority of its anticipated capital expenditures. As a result, WP&L 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 - Updated Strategic Plan” for further discussion of Alliant Energy’s domestic generation plan.

 

Contractual Obligations - - - WP&L’sWPL’s long-term contractual cash obligations as of Dec. 31, 20032004 were as follows (in millions):

 

  2004

  2005

  2006

  2007

  2008

  Thereafter

  Total

  2005

  2006

  2007

  2008

  2009

  Thereafter

  Total

Long-term debt (Note 8(b))

  $62  $88  $--  $105  $60  $139  $454

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)

  63  79  80  80  68  259  629   79   80   80   68   61   191   559

Purchase obligations (Note 11(b)):

                                          

Purchased-power and fuel commitments

  67  31  30  28  21  76  253

Purchased power and fuel commitments

   128   61   32   25   25   65   336

Other

  6  --  --  --  --  --  6   9   —     —     —     —     —     9
  
  
  
  
  
  
  
  

  

  

  

  

  

  

  $198  $198  $110  $213  $149  $474  $1,342  $335  $167  $239  $171  $101  $660  $1,673
  
  
  
  
  
  
  
  

  

  

  

  

  

  

 

At Dec. 31, 2003,2004, long-term debt as noted in the previous table was included on the Consolidated Balance Sheet and excludesSheet. 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. Purchased-powerInterest 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,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$1.0 million at Dec. 31, 2003. Alliant Energy has entered into various coal and purchased-power commitments that have not yet been directly assigned to WP&L and IP&L. Such commitments are not included in WP&L’s purchase obligations.2004. In connection with its construction and acquisition program, WP&LWPL also enters into commitments related to such programsprogram on an ongoing basis; these amountsbasis which are not reflected in the previous table. Refer to “Construction“Cash Flows Used For Investing Activities - Construction and Acquisition Expenditures” for additional information. In addition, at Dec. 31, 2003,2004, 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 2004 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. WP&LWPL continually evaluates the impact of potential future federal, state and local environmental rulemakings on its operations. While the final outcome of these rule makings cannot be predicted, WP&LWPL believes that required capital investments and/or modifications resulting from them could be significant, but expects that prudent expenses incurred by WP&LWPL likely would be recovered in rates from its customers. The environmental rulemaking process continually evolves and the following are major emerging issues that could potentially have a significant impact on WP&L’sWPL’s operations.

 

Air Quality - - With regard to current environmental rules, WP&L’s Edgewater facility spent $21 million from 1999 to 2003 to improve its combustion performance. This facility now meets the 2008 Wisconsin DNR NOx compliance goal.

WP&L also hasWPL previously responded confidentially to multiple data requests from the EPA,U.S. Environmental Protection Agency (EPA) related to the historical operation and associated air permitting for certain major Wisconsin coal-fired generating units. Similar requestsIn 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 precursorinstances where citizen groups have pursued claims against utilities for alleged air permitting violations. WPL has not received any such actions to penaltiesdate and capital expenditures requiring installation of air pollution controls at other utilities. However, WP&L has received no response in this regardis unable to predict further actions, if any, from the information requests from the EPA related to information submitted.or third parties.

 

The 1990 CAAClean Air Act Amendments mandate preservation of air quality through existing regulations and periodic reviews to ensure adequacy of these provisions based on scientific data. In 1997, the EPA revised National

Ambient Air Quality Standards (NAAQS) for ozone and fine particulate matter. In December 2003, the EPA proposed anthe Clean Air Interstate Air Quality Rule related to transport of these emissions that would require significantemission control upgrades to existing power plants. This rule would reduce the current level of nationwidepower plant sulfur dioxide emissions approximately 40% by 2010 and 70% by 2015, and NOxnitrogen 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-firedcoal 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 implementedissued by Dec.March 15, 2004.2005. Accordingly, the EPA has published proposed rules for comment requiring control of mercury from coal-fired and nickel from oil-fired generating units. The impact of these regulations on WP&L’sWPL’s generating facilities is subject to the control level mandated in the final rules. In 2001, theThe Wisconsin DNRDepartment of Natural Resources (DNR) also independently developed proposed mercury emission control rules, that could require reductions fromwhich became effective in October 2004 for Wisconsin generating facilities, that cap emissions beginning in 2008, followed by subsequent reductions of 40% by 2010 and 80%75% by 2015. These rules have been sent back to theThe Wisconsin DNR for revisionmercury rule requirements will be superseded by the Wisconsin legislature due to the pending federal mercury regulations.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.

 

WP&LWPL is also currently monitoring various other potential federal, state and local environmental rulemakings and activities, including, but not limited to: litigation of federal New Source Review 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.

 

Water Quality - - In 2002, theThe EPA published a proposed regulation under the Clean Water Act referred to as “316(b)” that is anticipated to be finalizedbecame effective in September 2004. This rule would requireregulation requires existing large power plants with cooling water intake structures to ensure that the location, design, construction, and capacity of cooling water intake structures reflect the bestapply technology available for minimizingto minimize adverse environmental impacts to fish and other aquatic life. WP&LWPL is currently studying such impacts and will have compliance plans in place by the required 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 WP&L’sWPL’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 - - WP&LIn 2003, at the request of the Wisconsin DNR, WPL submitted a written plan for facility closure of the Rock River Generating Station landfill and clean-up of the support ponds and all areas where coal combustion waste is present. Removal 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 possible significantvarious 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 mainprimary financial impact would be from a secondary containment requirement for all hazardous materials tanks and for hazardous material unloading areas. In addition, in December 2003,WPL is unable to predict the outcome of these possible regulatory changes at this time, but believes that the request of the Wisconsin DNR, WP&L submitted a written plan for facility closure of the Rock River Generating Station landfill and clean-up of the support ponds and all areas where coal combustion waste is present.required capital investment and/or modifications resulting from these potential regulations could be significant.

 

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

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&LWPL 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&L WPL 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 also periodically uses 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 20042005 than in 2003, interest2004, expense would increase (decrease) by approximately $1.2 million. This 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, 2003.2004.

 

Commodity Price Risk- Non-trading - WP&LWPL is exposed to the impact of market fluctuations in the commodity price and transportation costs of electric 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. Refer to Note 1(h) of the “Notes to Consolidated Financial Statements” for further discussion.

 

WP&L periodically utilizes commodity derivative instruments to reduce the impact of price fluctuations on electric fuel and purchased energy costs needed to meet its power supply requirements. Under PSCW rules, WP&LWPL can also seek rate increases if it experiences an extraordinary increasefor increases in the cost of electric fuel and purchased energypower if it experiences an increase in costs or if the annual coststhat are more than 3% higher than the estimated costs used to establish rates. Such rules were revised effectivesignificantly reduce commodity risk for 2003 for WP&L and significantly reduceWPL by reducing the regulatory lag for Wisconsin utilities and customers related to the timing of changes in rates for increased or decreased fuel and purchased energy costs. Based on these revised rules, WP&L does not anticipate any significant earnings exposure relatedWPL’s retail gas tariffs provide for subsequent adjustments to fuel and purchased energy costs.

WP&L periodically utilizesits natural gas rates for changes in the current monthly natural gas commodity derivative instrumentsprice 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 the impactcommodity risk associated with WPL’s cost of price fluctuations on natural gas purchased and injected into storage during the summer months and withdrawn and sold at current market prices during the winter months. The natural 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 valuegas. Refer to Note 1(h) of the physical commodity are substantially offset by changes in the value of the natural gas commodity swaps. A 10% increase (decrease) in the price of natural gas would not have a significant impact on the combined fair market value of the natural gas in storage and related swap arrangements in place at Dec. 31, 2003. To the extent actual storage withdrawals vary from forecasted withdrawals, WP&L has physical gas price exposure.“Notes to Consolidated Financial Statements” for further discussion.

 

Equity Price Risk - - WP&LWPL maintains a trust fund to fund itsthe anticipated nuclear decommissioning costs.costs of Kewaunee. At Dec. 31, 2003 and 2002,2004, this fund was invested primarily in domestic equity and debt instruments.instruments and money market funds. Fluctuations in equity prices or interest rates do not affect WP&L’sWPL’s consolidated results of operations. In 2001, WP&L entered into a four-year hedge on equity assets in its nuclear decommissioning trust fund. In January 2004, WP&LWPL liquidated all of its qualified decommissioning trust fund assets into money market funds as a result of the pendingproposed Kewaunee sale. Refer to Notes 10(c)9 and 1516 of the “Notes to Consolidated Financial Statements” for further discussion.

Refer to Notes 1(j)“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 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 adopted FIN 46, related to those entities that are considered to be special-purpose entities, on Dec. 31, 2003 with no material impact on its financial condition or results of operations. WP&L continues to evaluate tolling arrangements, renewable energy entities and any other non-special purpose entities, to determine if they require consolidation under the revised FIN 46 guidance issued by the FASB in December 2003. WP&L will apply the provisions of the revised guidance as of March 31, 2004.

WP&L adopted SFAS 143 on Jan. 1, 2003, which provides accounting and disclosure requirements for retirement obligations associated with long-lived assets (AROs). Refer to Note 16 of the “Notes to Consolidated Financial Statements” for additional information.

WP&L adopted SFAS 149 for contracts entered into or modified after June 30, 2003, except for certain implementation issues and certain provisions of forward purchase and sale contracts and for hedging relationships designated after June 30, 2003. Refer to Note 10(a) of the “Notes to Consolidated Financial Statements” for additional information.

In May 2003, the FASB issued SFAS 150, “Accounting for Certain Financial Instruments with Characteristics of Both Liabilities and Equity,” which requires an issuer to classify outstanding free-standing financial instruments within its scope as a liability on its balance sheet even though the instruments have characteristics of equity. WP&L adopted SFAS 150 on July 1, 2003 with no material impact on its financial condition or results of operations. WP&L continues to evaluate the implications of FSP No. FAS 150-3, “Effective Date, Disclosures, and Transition for Mandatorily Redeemable Financial Instruments of Certain Nonpublic Entities and Certain Mandatorily Redeemable Noncontrolling Interests under FASB Statement No. 150, Accounting for Certain Financial Instruments with Characteristics of Both Liabilities and Equity,” issued in November 2003, which defers the effective date for applying the provisions of SFAS 150 for certain mandatorily redeemable non-controlling interests.

In December 2003, the President signed into law the Medicare Prescription Drug, Improvement and Modernization Act of 2003 (the Act). The Act introduces a prescription drug benefit under Medicare Part D, as well as a federal subsidy to sponsors of retiree health care benefit plans, that provide a benefit that is at least actuarially equivalent to Medicare Part D. As permitted by FSP No. FAS 106-1, “Accounting and Disclosure Requirements Related to the Medicare Prescription Drug, Improvement and Modernization Act of 2003,” WP&L has elected to defer reflecting the effect of the Act on postretirement net periodic benefit cost and the accumulated postretirement benefit obligation in the Consolidated Financial Statements, since specific authoritative guidance on the accounting for the federal subsidy is pending and that guidance, when issued, could require WP&L to change previously reported information. WP&L is currently evaluating the effect of the Act on its other postretirement benefits expense.

WP&L WPL does not expect the various other new accounting pronouncements not mentioned above that were effective in 20032004 to have a material impact on its 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- WP&L WPL is regulated by various federal and state regulatory agencies. As a result, it 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.

 

Derivative Financial Instruments - WP&L uses derivative financial instruments to hedge exposures to fluctuations in 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 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.

SFAS 149 amends and clarifies accounting for derivative instruments, including certain derivative instruments embedded in other contracts, and for hedging activities under SFAS 133. Although SFAS 149 is expected to result in more energy contracts at WP&L qualifying as derivatives, changes in the fair value of these derivatives are generally reported as changes in regulatory assets and liabilities rather than being reported currently in earnings, based on the regulatory treatment. Additionally, WP&L has some commodity purchase and sales contracts that have been designated, and qualify for, the normal purchase and sale exception. Based on this designation, these contracts are not accounted for as derivative instruments.

A number of WP&L’s derivative transactions are based on the fuel and natural gas cost recovery mechanisms in place, as well as other specific regulatory authorizations. As a result, changes in fair market values of such 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 system 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 and Other Postretirement Benefits- WP&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, 2003, WP&LSep. 30, 2004 (WPL’s measurement date), WPL was using a 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 MDA, the following items could impact WPL’s future financial condition or results of operations:

American Jobs Creation Act (AJCA)- 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 domestic manufacturers (including electric production activities). Any potential tax benefits realized as a result of this legislation would be subject to all appropriate regulatory reviews.

Generating Facility Outage- On Feb. 20, 2005, Kewaunee was removed from service after a potential design weakness was identified in a 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 be back in service 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 operations. WPL plans to seek recovery of the additional 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 “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, 2004 and 2003, and 2002, andthe related consolidated statements of income, cash flows, and changes in common equity for each of the three years in the period ended December 31, 2003.2004. 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, 20032004 and 2002,2003, and the results of its operations and its cash flows for each of the three years in the period ended December 31, 20032004, in conformity with accounting principles generally accepted in the United States of America.

 

As discussed in Note 1617 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 3, 20042, 2005

CONSOLIDATED FINANCIAL STATEMENTS

 

CONSOLIDATED STATEMENTS OF INCOME

 

  Year Ended December 31,   Year Ended December 31,

 
  2003

 2002

 2001

   2004

 2003

 2002

 
  (in thousands)   (in millions) 

Operating revenues:

      

Electric utility

  $910,086  $787,680  $753,450   $939.8  $910.1  $787.7 

Gas utility

  272,377  179,091  206,863    253.8   272.4   179.1 

Other

  34,518  22,754  33,403    16.2   34.5   22.7 
  

 

 

  


 


 


  1,216,981  989,525  993,716    1,209.8   1,217.0   989.5 
  

 

 

  


 


 


Operating expenses:

      

Electric production fuel and purchased power

  409,742  352,539  338,028    431.5   409.7   352.5 

Cost of gas sold

  186,285  110,119  153,823    165.8   186.3   110.1 

Other operation and maintenance

  292,554  239,679  211,006    282.1   292.6   239.7 

Depreciation and amortization

  104,896  108,740  121,059    111.0   104.9   108.7 

Taxes other than income taxes

  31,872  32,874  32,504    36.6   31.9   32.9 
  

 

 

  


 


 


  1,025,349  843,951  856,420    1,027.0   1,025.4   843.9 
  

 

 

  


 


 


Operating income

  191,632  145,574  137,296    182.8   191.6   145.6 
  

 

 

  


 


 


Interest expense and other:

      

Interest expense

  37,873  40,202  43,483    33.5   37.9   40.2 

Equity income from unconsolidated investments

  (20,725) (17,022) (15,535)   (25.0)  (20.7)  (17.0)

Allowance for funds used during construction

  (4,024) (2,639) (4,753)   (4.5)  (4.0)  (2.6)

Interest income and other

  (2,209) (615) (627)   (1.2)  (2.3)  (0.6)
  

 

 

  


 


 


  10,915  19,926  22,568    2.8   10.9   20.0 
  

 

 

  


 


 


Income before income taxes

  180,717  125,648  114,728    180.0   180.7   125.6 
  

 

 

  


 


 


Income taxes

  65,843  44,724  41,238    66.3   65.8   44.7 
  

 

 

  


 


 


Net income

  114,874  80,924  73,490    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

  $111,564  $77,614  $70,180   $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

 
  December 31,   (in millions) 

ASSETS


  2003

 2002

    
  (in thousands) 

Property, plant and equipment:

      

Electric plant in service

  $2,002,006  $1,843,834   $2,128.5  $2,002.0 

Gas plant in service

  301,201  286,652    316.4   301.2 

Other plant in service

  275,637  275,391    258.2   268.1 

Accumulated depreciation

  (1,139,599) (1,047,715)   (1,196.6)  (1,137.2)
  

 

  


 


Net plant

  1,439,245  1,358,162    1,506.5   1,434.1 

Construction work in progress

  67,200  96,746    75.8   66.3 

Other, less accumulated depreciaton of $301 and $240

  15,717  17,811 

Other, less accumulated depreciation of $0.3 for both periods

   18.7   15.7 
  

 

  


 


  1,522,162  1,472,719    1,601.0   1,516.1 
  

 

  


 


Current assets:

      

Cash and temporary cash investments

  27,075  8,577    0.1   27.1 

Accounts receivable:

      

Customer, less allowance for doubtful accounts of $2,662 and $1,770

  78,934  7,977 

Associated companies

  -      1,172 

Other, less allowance for doubtful accounts of $422 and $458

  24,374  18,191 

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

  16,795  -        —     16.8 

Accumulated deferred income taxes

  6,594  8,532 

Production fuel, at average cost

  17,655  18,980    16.0   17.7 

Materials and supplies, at average cost

  22,922  22,133    24.2   22.9 

Gas stored underground, at average cost

  24,277  16,679    30.3   24.3 

Regulatory assets

  24,225  27,999    21.1   24.2 

Prepaid gross receipts tax

  28,341  27,388    33.0   28.3 

Assets held for sale

   4.9   6.1 

Other

  7,997  8,599    18.5   14.6 
  

 

  


 


  279,189  166,227    318.3   285.3 
  

 

  


 


Investments:

      

Nuclear decommissioning trust funds

  233,665  223,734    243.2   233.7 

Investment in ATC and other

  144,075  133,043 

Investment in American Transmission Company LLC and other

   165.1   144.0 
  

 

  


 


  377,740  356,777    408.3   377.7 
  

 

  


 


Other assets:

      

Regulatory assets

  95,944  102,674    128.6   96.0 

Deferred charges and other

  194,242  236,741    199.9   194.2 
  

 

  


 


  290,186  339,415    328.5   290.2 
  

 

  


 


Total assets

  $2,469,277  $2,335,138   $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

 
  December 31,   (in millions, except per
share and share amounts)
 

CAPITALIZATION AND LIABILITIES


  2003

 2002

    
  (in thousands, except
share amounts)
 

Capitalization (See Consolidated Statements of Capitalization):

   

Capitalization (Refer to Consolidated Statements of Capitalization):

   

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

  $66,183  $66,183   $66.2  $66.2 

Additional paid-in capital

  525,603  325,603    525.7   525.6 

Retained earnings

  440,286  399,302    461.7   440.3 

Accumulated other comprehensive loss

  (20,235) (24,108)   (2.7)  (20.3)
  

 

  


 


Total common equity

  1,011,837  766,980    1,050.9   1,011.8 
  

 

  


 


Cumulative preferred stock

  59,963  59,963    60.0   60.0 

Long-term debt (excluding current portion)

  336,409  468,208 

Long-term debt, net (excluding current portion)

   364.2   336.4 
  

 

  


 


  1,408,209  1,295,151    1,475.1   1,408.2 
  

 

  


 


Current liabilities:

      

Current maturities

  62,000  -        88.0   62.0 

Variable rate demand bonds

  55,100  55,100    39.1   55.1 

Commercial paper

  -      60,000    47.0   —   

Accounts payable

  80,051  90,869    91.0   80.1 

Accounts payable to associated companies

  22,615  22,964    20.3   22.6 

Accrued taxes

  6,284  19,353 

Regulatory liabilities

  13,874  16,938    23.8   13.9 

Other

  27,196  29,064    39.5   33.5 
  

 

  


 


  267,120  294,288    348.7   267.2 
  

 

  


 


Other long-term liabilities and deferred credits:

      

Accumulated deferred income taxes

  213,652  200,426 

Accumulated deferred investment tax credits

  21,471  23,241 

Deferred income taxes

   232.6   213.7 

Deferred investment tax credits

   19.9   21.5 

Regulatory liabilities

  227,956  15,305    215.1   227.9 

Asset retirement obligations

  187,358  -        200.9   187.4 

Pension and other benefit obligations

  59,042  58,921    85.7   59.0 

Customer advances

  34,895  36,555 

Cost of removal obligations

  -      362,321 

Other

  49,574  48,930    78.1   84.4 
  

 

  


 


  793,948  745,699    832.3   793.9 
  

 

  


 


Commitments and contingencies (Note 11)

      
  

 

Total capitalization and liabilities

  $2,469,277  $2,335,138   $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,   Year Ended December 31,

 
  2003

 2002

 2001

   2004

 2003

 2002

 
  (in thousands)   (in millions) 

Cash flows from operating activities:

      

Net income

  $114,874  $80,924  $73,490   $113.7  $114.9  $80.9 

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

      

Depreciation and amortization

  104,896  108,740  121,059    111.0   104.9   108.7 

Amortization of nuclear fuel

  5,691  6,486  4,554 

Amortization of deferred energy efficiency expenditures

  43,825  21,179  14,361 

Other amortizations

   41.4   51.3   27.7 

Deferred tax expense (benefit) and investment tax credits

  21,785  (5,562) (6,791)   8.5   21.8   (5.6)

Equity income from unconsolidated investments, net

  (20,725) (17,022) (15,535)   (25.0)  (20.7)  (17.0)

Distributions from equity method investments

  14,021  13,199  8,450    20.5   14.0   13.2 

Other

  (461) (1,175) (3,033)   (3.7)  (2.3)  (1.2)

Other changes in assets and liabilities:

      

Accounts receivable

  (9,968) (1,902) 20,408    (16.9)  (10.0)  (1.9)

Sale of accounts receivable

  (66,000) 28,000  (6,000)   (50.0)  (66.0)  28.0 

Income tax refunds receivable

  (16,795) -      -        16.8   (16.8)  —   

Accounts payable

  (2,647) (20,540) (23,653)   8.6   (2.6)  (20.5)

Accrued taxes

  (13,069) 17,296  (1,225)   3.2   (13.1)  17.3 

Other

  (36,932) (5,873) (50,199)

Benefit obligations and other

   (28.8)  (36.9)  (5.8)
  

 

 

  


 


 


Net cash flows from operating activities

  138,495  223,750  135,886    199.3   138.5   223.8 
  

 

 

  


 


 


Cash flows used for financing activities:

   

Common stock dividends

  (70,580) (59,645) (60,449)

Preferred stock dividends

  (3,310) (3,310) (3,310)

Capital contribution from parent

  200,000  61,000  35,000 

Reductions in long-term debt

  (70,000) -      (47,000)

Net change in short-term borrowings

  (60,000) (30,816) 61,572 

Other

  (7,705) 5,086  (4,989)
  

 

 

Net cash flows used for financing activities

  (11,595) (27,685) (19,176)
  

 

 

Cash flows used for investing activities:

      

Utility construction expenditures

  (151,635) (156,921) (147,032)

Utility construction and acquisition expenditures

   (211.5)  (151.6)  (156.9)

Nuclear decommissioning trust funds

  (2,876) (16,092) (16,092)   (2.9)  (2.9)  (16.1)

Proceeds from asset sales

  21,337  -      75,600    —     21.3   —   

Other

  24,772  (14,782) (29,308)   0.1   24.8   (14.8)
  

 

 

  


 


 


Net cash flows used for investing activities

  (108,402) (187,795) (116,832)   (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

  18,498  8,270  (122)   (27.0)  18.5   8.3 
  


 


 


  

 

 

Cash and temporary cash investments at beginning of period

  8,577  307  429    27.1   8.6   0.3 
  

 

 

  


 


 


Cash and temporary cash investments at end of period

  $27,075  $8,577  $307   $0.1  $27.1  $8.6 
  


 


 


  

 

 

Supplemental cash flows information:

      

Cash paid during the period for:

      

Interest

  $39,588  $39,540  $43,237   $31.3  $39.6  $39.5 
  

 

 

  


 


 


Income taxes, net of refunds

  $84,256  $35,875  $54,161   $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,   December 31,

 
  2003

 2002

   2004

 2003

 
  (in thousands, except
share amounts)
   (dollars in millions, except
per share amounts)
 

Common equity (See Consolidated Balance Sheets)

  $1,011,837  $766,980 

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 $150,000,000:

   

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

  9,997  9,997    10.0   10.0 

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

  7,491  7,491    7.5   7.5 

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

  6,498  6,498    6.5   6.5 

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

  2,996  2,996    3.0   3.0 

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

  2,995  2,995    3.0   3.0 

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

  15,000  15,000    15.0   15.0 

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

  14,986  14,986    15.0   15.0 
  

 

  


 


  59,963  59,963    60.0   60.0 
  

 

  


 


Long-term debt:

   

Long-term debt, net:

   

First Mortgage Bonds:

      

1992 Series X, 7.75%, due 2004

  62,000  62,000 

1992 Series Y, 7.6%, due 2005

  72,000  72,000    72.0   72.0 

1991 Series B, variable rate (1.73% at Dec. 31, 2003), due 2005

  16,000  16,000 

1984 Series A, variable rate (1.37% at Dec. 31, 2003), due 2014

  8,500  8,500 

1988 Series A, variable rate (1.29% at Dec. 31, 2003), due 2015

  14,600  14,600 

1991 Series A, variable rate (1.73% at Dec. 31, 2003), due 2015

  16,000  16,000 

1992 Series W, 8.6%, retired in 2003

  -      70,000 

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 
  

 

  


 


  189,100  259,100    127.1   189.1 

Debentures, 7%, due 2007

  105,000  105,000    105.0   105.0 

Debentures, 5.7%, due 2008

  60,000  60,000    60.0   60.0 

Debentures, 7-5/8%, due 2010

  100,000  100,000 

Debentures, 7.625%, due 2010

   100.0   100.0 

Debentures, 6.25%, due 2034

   100.0   —   
  

 

  


 


  454,100  524,100    492.1   454.1 
  

 

  


 


Less:

      

Current maturities

  (62,000) -        (88.0)  (62.0)

Variable rate demand bonds

  (55,100) (55,100)   (39.1)  (55.1)

Unamortized debt discount, net

  (591) (792)   (0.8)  (0.6)
  

 

  


 


  336,409  468,208    364.2   336.4 
  

 

  


 


Total capitalization

  $1,408,209  $1,295,151   $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


   Common
Stock


  Additional
Paid-In
Capital


  Retained
Earnings


 Accumulated
Other
Comprehensive
Loss


 Total
Common
Equity


 
  (in thousands)   (in millions) 

2001:

         

2002:

         

Beginning balance (a)

  $66,183  $229,516  $371,602  ($4,708) $662,593   $66.2  $264.6  $381.3  ($10.1)  $702.0 

Earnings available for common stock

        70,180  70,180          77.6   77.6 

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

         (14,248) (14,248)

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

         (10.2)  (10.2)
         

 

         

 


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)

Capital contribution from parent

     35,000   35,000 

Stock options exercised

     87   87 
  
  
  

 

 

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 

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

         (3,764) (3,764)         (3.8)  (3.8)
         

 

         

 


Total comprehensive income

         63,673           63.6 

Common stock dividends

        (59,645) (59,645)         (59.6)  (59.6)

Capital contribution from parent

     61,000   61,000       61.0    61.0 
  
  
  

 

 

  

  

  


 

 


Ending balance

  66,183  325,603  399,302  (24,108) 766,980    66.2   325.6   399.3  (24.1)  767.0 

2003:

                  

Earnings available for common stock

        111,564  111,564          111.6   111.6 

Minimum pension liability adjustment, net of tax of $2,809

         4,190  4,190 

Minimum pension liability adjustment, net of tax of $ 2.8

         4.2   4.2 
         

 

         

 


Unrealized holding losses on derivatives, net of tax of ($3,543)

         (5,914) (5,914)

Less: reclassification adjustment for losses included in earnings available for common stock, net of tax of ($3,752)

         (5,597) (5,597)

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

         (317) (317)         (0.4)  (0.4)
         

 

         

 


Total comprehensive income

         115,437           115.4 

Common stock dividends

        (70,580) (70,580)         (70.6)  (70.6)

Capital contribution from parent

     200,000   200,000       200.0    200.0 
  
  
  

 

 

  

  

  


 

 


Ending balance

  $66,183  $525,603  $440,286  ($20,235) $1,011,837    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 lossincome (loss) at January 1, 20012002 consisted entirelyof ($14.2) of a minimum pension liability adjustment and $4.1 of net unrealized lossesgains on qualifying derivatives.

 

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 -- 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 and various other energy-related services including construction management services for wind farms. Nearly all of WP&L’s retail customersWPL’s primary service territories are located in south and central Wisconsin.

 

The consolidated financial statements reflect investments in controlled subsidiaries on a consolidated basis. FIN 46, issued by the FASB in January 2003, 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 risk to finance its activities without additional subordinated financial support from other parties. 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. The most significant reclassificationspresentation and relate to the reporting of accumulated costsassets held for sale pursuant to Statement of removal which are non-legal retirement obligations and accumulated decommissioning costs accrued priorFinancial Accounting Standards (SFAS) 144, “Accounting for the Impairment or Disposal of Long-lived Assets” (SFAS 144). Refer to January 1, 2003. Previously, these costs were included as components of “Accumulated Depreciation” but in accordance with recent SEC guidance are now shown in “Cost of removal obligations” on the Consolidated Balance Sheet at Dec. 31, 2002.Note 15 for additional information.

 

Unconsolidated investments for which WP&LWPL does not control, but does have the ability to exercise significant influence over operating and financial policies (generally, 20% to 50% voting interest), are 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.

 

(b) Regulation - - WP&LWPL 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 - - WP&LWPL 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, 2004 and 2003, WPL had $11 million and 2002, WP&L had $7 million and $6 million, respectively, of regulatory assets that were not earning returns.returns, respectively. At Dec. 31, 2003 and 2002, regulatory assets and liabilities were comprised of the following items (in millions):

 

  

Regulatory

Assets


  

Regulatory

Liabilities


  2004

  2003

  2003

  2002

  2003

  2002

Minimum pension liability (Note 6)

  $39.4  $—  

Tax-related (Note 1(d))

   $23.4   $25.0   $17.9  $14.6   20.2   23.4

Energy efficiency program costs

   22.9   38.6   --     --  

Asset retirement obligations (Note 17)

   15.3   8.3

Energy conservation program costs

   14.3   22.9

Environmental-related (Note 11(e))

   16.2   19.0   1.0   0.6   12.9   16.2

Asset retirement obligations (Note 16)

   8.3   --     --     --  

Cost of removal obligations

   --     --     209.9   --  

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

   49.4   48.1   13.0   17.0   19.4   23.7
  

  

  

  

  

  

  $120.2  $130.7  $241.8  $32.2  $149.7  $120.2
  

  

  

  

  

  

WP&LWPL believes it is probable that any differences between expenses for legal AROsasset 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 difference of $8.3 million as a regulatory asset. WP&L also

At Dec. 31, regulatory liabilities were comprised of 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. WP&LWPL records a regulatory liability for the estimated amounts it has collected in rates for these future removal costs less amounts spent on removal activities. At Dec. 31, 2003 and 2002, non-legal removal obligations of $209.9 million and $199.1 million were recorded in “Regulatory liabilities” and “Cost of removal obligations,” respectively, on the Consolidated Balance Sheets.

If a portion of WP&L’s operations becomes no longer subject to the provisions of SFAS 71 as a result of competitive restructuring or otherwise, a write-down of related regulatory assets would be required, unless some form of transition cost recovery is established by the appropriate regulatory body that would meet the requirements under GAAP 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.

 

(d) Income Taxes - - WP&LWPL 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 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.

 

(e) Temporary Cash 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.

 

(f) Property, Plant and Equipment - - Utility plant is recorded at original cost, which includes overhead, administrative costs and AFUDC. WP&L’s aggregateOrdinary 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, for 2003, 2002 and 2001, computed in accordance with the prescribed regulatory formula, were 9.5%, 2.6% and 7.9%, respectively.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%

WP&L

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:

 

  2003

  2002

  2001

  2004

 2003

 2002

 

Electric

  3.7%  3.6%  3.7%  3.5% 3.7% 3.6%

Gas

  4.0%  4.1%  4.1%  4.0% 4.0% 4.1%

 

Nuclear fuel for Kewaunee is recorded at its original cost and 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 of such fuel are expensed based on KWhskilowatt-hours (KWhs) generated.

Other property, plant and equipment is recorded at 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 the Consolidated Statements of Income. 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.

 

(g) Operating Revenues - - Revenues from WP&LWPL are primarily from electric 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. WP&LWPL serves as a collection agent for sales or various other taxes and recordrecords revenues on a net basis. The revenues do not include the collection of the aforementioned taxes.

 

(h) Utility Fuel Cost Recovery - - WP&L’sWPL’s retail electric rates are based on annual forecastedforecasts that include fuel and purchased-powerpurchased energy costs. Under PSCW rules, WP&LWPL can seek rate increases for increases in the cost of electric fuel and purchased energy if it experiences an extraordinary increase in these costs or if the annual coststhat 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. WP&LWPL’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 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.

 

(i) Generating Facility Outages - - Operating expenses incurred during refueling outages at Kewaunee and the maintenance costs incurred during outages for WP&L’sWPL’s various other generating facilities are expensed as incurred. The timing of the Kewaunee refueling outages during 2001-20032002 to 2004 and anticipated refueling outages for 2004-20062005 to 2007 are as follows:

 

2001


2002


 

2003


 

2004


 

2005


 

2006


2007


FallNone

None Spring Fall None SpringFall

 

(j) Derivative Financial Instruments - - WP&LWPL uses derivative financial instruments to hedge exposures to fluctuations in certain commodity prices and volatility in a portion of natural gas sales volumes due to weather. WP&LWPL 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 some commodity purchase and sales contracts that have been designated, and qualify for, the normal purchase and sale exception and based 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 related to its derivative financial instruments. Refer to Note 10 for further discussion of WP&L’sWPL’s derivative financial instruments.

 

(k) Pension 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.

 

(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 indicated if the carrying value of an 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. The 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. The estimated fair value, less cost to sell assets held for sale, is compared each reporting period to their carrying values. Impairmentand impairment charges are recorded for assets held for sale if the carrying value of such asset exceeds the estimated fair value 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.values as well as assessing if a decline in fair value is temporary. If an impairment is indicated, a charge is recognized equal to the amount the carrying value exceeds the investment’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 Consolidated Statements of Income based on monthly payments for these agreements. Monthly capacity payments related to 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 February 2004, WP&L2005, WPL received approval from the PSCW to refund $5.3$12 million in 2005 to its natural gas customers as relates tofor gains realized from its annual performance under the gas performance incentive. The PSCW has not yet audited the refund calculation, but agreed with WP&L’s request to refund approximately 80% of the total refund amount at this time. This refund was completed in February 2004 and the remainder of the refund will be completed after the PSCW completes their audit and issues a ruling.incentive program. At Dec. 31, 2003, WP&L had reserves2004, WPL reserved for all amounts related to these refunds. Refer to Note 1(h) for further discussion of WP&L’sWPL’s fuel cost recovery.

 

(3) LEASES

WP&L’s

WPL’s operating lease rental expenses, which include certain purchased-powerpurchased power agreements, for 2004, 2003 and 2002 and 2001 were $25.9$63 million, $24.5$25 million and $23.4$23 million, respectively. Contingent rentals from operating leases that were excluded from these amounts were $0.4 million, $0.9 million and $1.1 million 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-powerpurchased 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 belowin the previous table includes $464$429 million and $69$56 million related to the Riverside plant tolling agreement and RockGen plants, respectively, in Wisconsin. Riverside is expectedplant purchased power agreement, respectively. Refer to be placed in service in 2004. WP&L continues to evaluate Riverside, RockGen and other tolling arrangements, renewable energy entities and any other non-special purpose entities, to determine if they require consolidation underNote 18 for additional information concerning the revised FIN 46 guidance issued by the FASB in December 2003. WP&L will apply the provisionsimpacts of the revised guidance asFinancial Accounting Standards Board (FASB) Interpretation No. 46R, “Consolidation of March 31, 2004. Variable Interest Entities” (FIN 46R), on these two agreements.

The synthetic leases in the previous table relate to the financing of utility railcars and a utility radio dispatch system. These leasesThe entities that lease these assets to WPL do not meet the consolidation requirements per FIN 46FIN46R and wereare not included on the Consolidated Balance Sheets. WP&LWPL has guaranteed the residual value of its synthetic leases totaling $13which total $8 million in the aggregate. The guarantees extend through the maturity of each respective underlying lease with remaining terms up to 1211 years. Residual value guaranteesguarantee amounts have been included in the future minimum lease payments noted in the following table (in millions):previous table.

   2004

  2005

  2006

  2007

  2008

  Thereafter

  Total

Certain purchased-power agreements

  $52.6  $69.5  $70.9  $72.2  $64.8  $235.0  $565.0

Synthetic leases

   7.9   7.9   7.8   6.8   2.6   22.8   55.8

Other

   2.1   1.7   1.3   1.1   1.0   1.4   8.6
   

  

  

  

  

  

  

   $62.6  $79.1  $80.0  $80.1  $68.4  $259.2  $629.4
   

  

  

  

  

  

  

(4) SALE OF ACCOUNTS RECEIVABLE

Utility customer accounts receivable, including unbilled revenues, arise primarily from electric and natural gas sales. At Dec. 31, 2004 and 2003, and 2002, WP&LWPL 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 WP&L and IP&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 special purpose entities. Corporate Services actsacted as a collection agent for the buyer and receivesreceived a fee for collection services. The agreement expires in April 2006 and is subject to annual renewal or renegotiation for a longer period thereafter. Under terms of the agreement, the third-party financial institution

purchases purchased 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 WP&LWPL. WPL had no receivables sold and IP&L.no short-term debt outstanding at the 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, 2004 and 2003, WPL had sold $0 and $50 million of utility customer accounts receivable, respectively. In 2004, 2003 and 2002, WP&L had sold $50WPL received $30 million, and $116 million of receivables, respectively. In 2003, 2002 and 2001, WP&L received $0.8 billion $1.2 billion and $1.1$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 in 2004, 2003 and $4.0 million in 2003, 2002, and 2001, 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,” which do not require consolidation per the guidelines of FIN 46. 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.

 

(5) INCOME TAXES

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

 

  2003

   2002

   2001

   2004

 2003

 2002

 

Current tax expense:

            

Federal

  $29.0   $42.8   $36.8   $45.2  $29.0  $42.8 

State

   15.7    9.7    11.2    13.3   15.7   9.7 

Deferred tax expense (benefit):

            

Federal

   22.8    (5.0)   (4.6)   9.7   22.8   (5.0)

State

   0.6    1.2    (0.4)   0.4   0.6   1.2 

Amortization of investment tax credits

   (1.6)   (1.8)   (1.8)   (1.6)  (1.6)  (1.8)

Research and development tax credits

   (0.7)   (2.2)   --      (0.7)  (0.7)  (2.2)
  


  


  


  


 


 


  $65.8   $44.7   $41.2   $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 WP&L,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. WP&LWPL realized net benefits of $1.2 million, $2.9 million $0 and $0 related to state apportionment and allocation of parent tax benefits in 2004, 2003 and 2002, and 2001, 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.

 

  2003

   2002

   2001

   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

  5.8   6.1   6.4   6.2  5.8  6.1 

Research and development tax credits

  (0.3)  (1.8)  --     (0.4) (0.3) (1.8)

Amortization of excess deferred taxes

  (0.5)  (1.4)  (1.5)  (0.5) (0.5) (1.4)

Amortization of investment tax credits

  (0.9) (0.9) (1.4)

Adjustment of prior period taxes

  (0.8)  (1.1)  (2.8)  (1.5) (0.8) (1.1)

Amortization of investment tax credits

  (0.9)  (1.4)  (1.6)

Other items, net

  (1.9)  0.2   0.4   (1.1) (1.9) 0.2 
  

  

  

  

 

 

Overall effective income tax rate

  36.4%  35.6%  35.9%  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):

 

  2003

 2002

   2004

 2003

 
  Deferred
Tax
Assets


 Deferred
Tax
Liabilities


  Net

 Deferred
Tax
Assets


 Deferred
Tax
Liabilities


  Net

   Deferred
Tax Assets


 Deferred Tax
Liabilities


  Net

 Deferred
Tax Assets


 Deferred Tax
Liabilities


  Net

 

Property related

  ($14.3) $216.0  $201.7  ($15.6) $216.8  $201.2 

Minimum pension liability

  (13.6) --    (13.6) (16.4) --    (16.4)

Property

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

Decommissioning

  (22.2) --    (22.2) (25.2) --    (25.2)  (23.5)  —     (23.5) (22.2)  —     (22.2)

Investment in American Transmission Co. LLC (ATC)

  —     14.0   14.0  —     7.9   7.9 

Other

  (6.6) 47.8  41.2  (8.5) 40.8  32.3   (8.0)  32.6   24.6  (20.2)  39.9   19.7 
  

 
  

 

 
  

  

 

  


 

 

  


Total

  ($56.7) $263.8  $207.1  ($65.7) $257.6  $191.9   ($44.7) $269.3  $224.6  ($56.7) $263.8  $207.1 
  

 
  

 

 
  

  

 

  


 

 

  


     2003

   2002

       2004     2003 

Current assets - Accumulated deferred income taxes

     ($6.6)   ($8.5)

Other long-term liabilities and deferred credits - Accumulated deferred income taxes

     213.7    200.4 
     


   


Other current assets

      ($8.0)    ($6.6)

Deferred income taxes

      232.6     213.7 
     

   

     


   


Total deferred tax (assets) and liabilities

     $207.1    $191.9      $224.6    $207.1 
     

   

     


   


 

(6) PENSION PLANS AND OTHER POSTRETIREMENT BENEFITS

Substantially all of WP&L’sWPL’s employees are covered by several non-contributory defined benefit pension plans. Benefits are based on the employees’ years of service and compensation. WP&LWPL also provides certain defined benefit postretirement health care and life benefits to eligible retirees. In general, the health care plans are contributory with participants’ contributions adjusted regularly and the life insurance plans are non-contributory. The weighted averageweighted-average assumptions at the measurement date of Sept.Sep. 30 were as follows:follows (N/A=Not Applicable):

 

  

Qualified

Pension Benefits


  

Other

Postretirement Benefits


  Qualified Pension Benefits

 Other Postretirement Benefits

 
  2003

  2002

  2001

  2003

  2002

  2001

  2004

 2003

 2002

 2004

 2003

 2002

 

Discount rate for benefit obligations

  6%  6.75%  7.25%  6%  6.75%  7.25%  6% 6% 6.75% 6% 6% 6.75%

Discount rate for net periodic cost

  6.75%  7.25%  8%  6.75%  7.25%  8%  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  9.5%  10.8%  12%  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 historical and 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

 
  2003

 2002

 2001

 2003

 2002

 2001

   2004

 2003

 2002

 2004

 2003

 2002

 

Service cost

  $4.0  $3.6   $2.8  $3.4  $2.4  $1.6   $5.0  $4.0  $3.6  $4.0  $3.4  $2.4 

Interest cost

   10.6   10.1   9.2   5.2   4.4   3.6    11.2   10.6   10.1   5.4   5.2   4.4 

Expected return on plan assets

   (13.5)  (12.2)  (13.7)  (1.4)  (1.6)  (1.7)   (15.9)  (13.5)  (12.2)  (1.7)  (1.4)  (1.6)

Amortization of:

   

Amortization of (*):

   

Transition obligation (asset)

   --     (1.7)  (2.1)  1.1   1.1   1.2    —     —     (1.7)  1.1   1.1   1.1 

Prior service cost

   0.4   0.4   0.5   --     --     --      0.6   0.4   0.4   —     —     —   

Actuarial loss (gain)

   3.5   1.5   --     0.8   0.1   (0.6)

Actuarial loss

   3.0   3.5   1.5   1.4   0.8   0.1 
  


 


 


 


 


 


  


 


 


 


 


 


  $5.0  $1.7  ($3.3) $9.1  $6.4  $4.1   $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 benefits costs shown previously (and in the following tables) represent only the pension benefits 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 Statements and are not reported previously. The pension benefits (income) costs for WP&L’sWPL’s non-bargaining employees who are now participants in other Alliant Energy plans were $0.5 million, $1.9 million and $0.3 million for 2004, 2003 and ($1.5) million for 2003, 2002, and 2001, respectively. In addition, Corporate Services provides services to WP&L.WPL. The allocated pension benefits costs associated with these services were $2.1 million, $2.0 million and $1.7 million for 2004, 2003 and $1.3 million for 2003, 2002, and 2001, respectively. The other postretirement benefits costs shown previously for each period (and in the following tables) represent the other postretirement benefits costs for all WP&LWPL employees. The allocated other postretirement benefits costs associated with Corporate Services for WP&LWPL were $1.6 million, $0.9 million and $0.5 million for 2004, 2003 and $0.3 million for 2003, 2002, and 2001, respectively.

 

The assumed medical trend rates are critical assumptions in determining the service and interest cost and accumulated postretirement benefit obligation related to postretirement benefits costs. A 1% change in the medical trend rates for 2003,2004, 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

  $0.9  ($0.8)  $1.2  ($1.1)

Effect on postretirement benefit obligation

   9.4   (8.3)  $9.7  ($8.7)

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

 

  Qualified
Pension
Benefits


 Other
Postretirement
Benefits


   Qualified Pension Benefits

 Other Postretirement Benefits

 
  2003

 2002

 2003

 2002

   2004

 2003

 2004

 2003

 

Change in projected benefit obligation:

      

Net projected benefit obligation at beginning of year

  $156.0  $139.2  $76.6  $60.5   $181.0  $156.0  $93.1  $76.6 

Service cost

   4.0   3.6  3.4  2.4    5.0   4.0   4.0   3.4 

Interest cost

   10.6   10.1  5.2  4.4    11.2   10.6   5.4   5.2 

Plan participants’ contributions

   --     --    1.5  1.5    —     —     1.6   1.5 

Plan amendments

   5.7   —     —     —   

Actuarial loss

   17.8   10.3  11.7  13.2    6.9   17.8   7.7   11.7 

Gross benefits paid

   (7.4)  (7.2) (5.3) (5.4)   (7.3)  (7.4)  (6.5)  (5.3)
  


 


 

 

  


 


 


 


Net projected benefit obligation at end of year

   181.0   156.0  93.1  76.6    202.5   181.0   105.3   93.1 
  


 


 

 

  


 


 


 


Change in plan assets:

      

Fair value of plan assets at beginning of year

   153.5   138.8  16.7  17.8    175.0   153.5   19.5   16.7 

Actual return on plan assets

   28.9   (8.1) 2.2  (1.4)   20.2   28.9   2.1   2.2 

Employer contributions

   --     30.0  4.4  4.2    5.0   —     4.0   4.4 

Plan participants’ contributions

   --     --    1.5  1.5    —     —     1.6   1.5 

Gross benefits paid

   (7.4)  (7.2) (5.3) (5.4)   (7.3)  (7.4)  (6.5)  (5.3)
  


 


 

 

  


 


 


 


Fair value of plan assets at end of year

   175.0   153.5  19.5  16.7    192.9   175.0   20.7   19.5 
  


 


 

 

  


 


 


 


Funded status at end of year

   (6.0)  (2.5) (73.6) (59.9)   (9.6)  (6.0)  (84.6)  (73.6)

Unrecognized net actuarial loss

   62.4   63.5  30.5  20.4    62.0   62.4   36.4   30.5 

Unrecognized prior service cost

   3.0   3.4  (0.1) (0.1)   8.1   3.0   (0.1)  (0.1)

Unrecognized net transition obligation

   --     --    10.3  11.5    —     —     9.2   10.3 
  


 


 

 

  


 


 


 


Net amount recognized at end of year

   $59.4   $64.4  ($32.9) ($28.1)  $60.5  $59.4   ($39.1)  ($32.9)
  


 


 

 

  


 


 


 


Amounts recognized on the Consolidated Balance Sheets consist of:

      

Prepaid benefit cost

   $59.4   $64.4  $1.5  $1.5   $60.5  $59.4  $1.6  $1.5 

Accrued benefit cost

   --     --    (34.4) (29.6)   —     —     (40.7)  (34.4)
  


 


 

 

  


 


 


 


Net amount recognized at measurement date

   59.4   64.4  (32.9) (28.1)   60.5   59.4   (39.1)  (32.9)
  


 


 

 

  


 


 


 


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

   --     --    0.4  1.0    —     —     0.6   0.4 
  


 


 

 

  


 


 


 


Net amount recognized at 12/31

   $59.4   $64.4  ($32.5) ($27.1)  $60.5  $59.4   ($38.5)  ($32.5)
  


 


 

 

  


 


 


 


 

In 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, 20032004 and 2002,2003, Corporate Services allocated an additionala minimum pension liability of $34.2$44 million and $41.3$34 million, respectively. Included in the following table are WP&L’sWPL’s accumulated benefit obligations, amounts applicable to qualified pension and other postretirement benefits with accumulated benefit obligations in excess of plan assets, as well as qualified pension plans with projected benefit obligations in excess of plan assets as of the measurement date of Sept.Sep. 30 (in millions):

 

  Qualified
Pension
Benefits


  Other
Postretirement
Benefits


  Qualified Pension Benefits

  Other Postretirement Benefits

  2003

  2002

  2003

  2002

  2004

  2003

  2004

  2003

Accumulated benefit obligation

  $165.7  $143.1  $93.1  $76.6  $181.8  $165.7  $105.3  $93.1

Plans with accumulated benefit obligations in excess of plan assets:

                        

Accumulated benefit obligation

   --     --     91.5   74.7

Accumulated benefit obligations

   —     —     103.6   91.5

Fair value of plan assets

   --     --     16.3   13.7   —     —     17.3   16.3

Plans with projected benefit obligations in excess of plan assets:

                        

Projected benefit obligations

   181.0   156.0   N/A   N/A   202.5   181.0   N/A   N/A

Fair value of plan assets

   175.0   153.5   N/A   N/A   192.9   175.0   N/A   N/A

WP&L’sWPL’s net periodic benefit cost is primarily included in “Other operation and maintenance” in the Consolidated Statements of Income. WP&LWPL 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 VEBAVoluntary 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 WP&L’sWPL’s qualified pension and other postretirement benefit plans at Sept.Sep. 30, 20032004 and 2002,2003, and the qualified pension plan target allocation for 20032004 were as follows:

 

  Qualified Pension Plans

   Other Postretirement Plans

  Qualified Pension Plans

 Other Postretirement Plans

 
  

Target

Allocation


   Percentage of Plan
Assets
at Sept. 30


   

Percentage of Plan

Assets

at Sept. 30


  

Target

Allocation


 

Percentage of Plan

Assets at Sep. 30,


 

Percentage of Plan

Assets at Sep. 30,


 

Asset Category


  2003

   2003

 2002

   2003

 2002

  2004

 2004

 2003

 2004

 2003

 

Equity securities

  50-65%     61% 55%   15% 16%  65-75% 73% 61% 10% 15%

Debt securities

  25-40%     33% 35%   33% 27%  20-35% 27% 33% 20% 33%

Other

  0-5%   6% 10%   52% 57%  0-5% —    6% 70% 52%
     
 
   
 
   

 

 

 

     100% 100%   100% 100%   100% 100% 100% 100%
     
 
   
 
   

 

 

 

 

WP&L’sWPL’s plan assets are managed by outside investment managers. WP&L’sWPL’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 balanced 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, private placements, unregistered or restricted stock, options and futures unless specifically approved, margin trading, oil and gas limited partnerships, commodities, short selling commercial mortgage obligations and securities of the managers’ firms or affiliate firms.

 

WP&LWPL estimates that funding for the qualified pension and postretirement benefit plans for 20042005 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 December 2003, the President signed into law the Medicare Prescription Drug, Improvement and Modernization Act of 2003 (the Act). The Act introduces a prescription drug benefit under Medicare Part D, as well as a federal subsidy to sponsors of retiree health care benefit plans, that provide a benefit that is at least

actuarially equivalent to Medicare Part D. As permitted by FSP2004, WPL adopted FASB Staff Position No. FAS 106-1,SFAS 106-2, “Accounting and Disclosure Requirements Related to the Medicare Prescription Drug, Improvement and Modernization Act of 2003,2003.WP&L has electedThe U.S. Department of Health and Human Services recently provided initial guidance regarding actuarial equivalence. Additional guidance and clarifications are expected to defer reflecting the effect of the Act on postretirement net periodic benefit cost and the accumulated postretirement benefit obligationbe provided in the Consolidated Financial Statements, since specific authoritative guidance onfuture. WPL believes that a substantial portion of its postretirement medical plans will be actuarially equivalent to the accountingMedicare Prescription Drug Plan. WPL anticipates continuing its current prescription drug coverage for currently covered retirees and therefore should be eligible for the federal subsidy is pending and that guidance, when issued, could require WP&L to change previously reported information. WP&L is currently evaluating the effect of the Act on itsavailable from Medicare. The estimated reductions in WPL’s 2004 other postretirement benefits expense.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 in 2004, 2003 and $1.0 million in 2003, 2002, and 2001, respectively. WP&LWPL has various life insurance policies that cover certain key employees and directors. At both Dec. 31, 20032004 and 2002,2003, the cash surrender value of these investments was $11 million and $10 million, respectively.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 $2.3 million, $2.1 million and $2.2 million in 2004, 2003 and $2.1 million in 2003, 2002, and 2001, respectively.

 

(7) COMMON AND PREFERRED STOCK

(a) Common Stock - - WP&LWPL has dividend payment restrictions based on its bond indentures, the terms of its outstanding preferred stock and state regulatory limitations. In its December 2003 rate order, the PSCW stated WP&LWPL may not pay annual common stock dividends, including pass-through of subsidiary dividends, in excess of $89 million to Alliant Energy if WP&L’sWPL’s actual average common equity ratio, on a regulatory financial basis, is or will fall below the authorized level of 54.01%. As of Dec. 31, 2003, WP&L2004, WPL was in compliance with all such dividend restrictions.

 

(b) Preferred Stock - - The carrying value of WP&L’sWPL’s cumulative preferred stock at both Dec. 31, 20032004 and 20022003 was $60 million. The fair market value, based upon the market yield of similar securities and quoted market prices, at Dec. 31, 2004 and 2003 and 2002 was $53$55 million and $48$53 million, respectively.

 

(8) DEBT

(a) Short-Term Debt - - To provide short-term borrowing flexibility and security for commercial paper outstanding, WP&LWPL maintains committed bank lines of credit, all of which require a fee. At Dec. 31, 2004, 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 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):

 

  2003

  2002

  2004

 2003

 

At Dec. 31:

         

Commercial paper outstanding

  $--    $60.0  $47.0  $—   

Discount rates on commercial paper

  N/A  1.6%

Average discount rates - commercial paper

   2.3%  N/A 

For the year ended:

         

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

  $29.8  $57.4

Average interest rates on short-term debt

  1.4%  1.8%

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 - - WP&L’sWPL’s First Mortgage Bonds are secured by substantially all of its utility plant. WP&LWPL also maintains indentures related to the issuance of unsecured debt securities. WP&L’sWPL’s debt maturities for 20042005 to 20082009 are $62 million, $88 million, $0, $105 million, and $60 million, and $0, respectively. The carrying value of WP&L’sWPL’s long-term debt (including current maturities and variable rate demand bonds) at Dec. 31, 2004 and 2003 and 2002 was $454$491 million and $523$454 million, respectively. The fair market value, based upon the market yield of similar securities and quoted market prices, at Dec. 31, 2004 and 2003 was $532 million and 2002 was $494 million, respectively. WPL’s unamortized debt issuance costs recorded in “Deferred charges and $574other” 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):

 

  2003

  2002

  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

  $137  $3  $131  $5  $21.0  $0.7  $136.9  $3.3

Equity securities

  97  19  93  5   51.3   13.0   96.8   18.6
  
  
  
  

Total

  $234  $22  $224  $10
  
  
  
  

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 - - At Dec. 31, 2003, $762004, $0.2 million, $37$3.1 million and $24$17.7 million of the debt securities mature in 2004-2010, 2011-20202005-2009, 2010-2019 and 2021-2040,2020-2040, 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. In 2003, netNet unrealized holding gains were recorded as part of regulatory liabilities or as an offset to regulatory assets related to AROs (recorded in 2002 as part of cost of removal obligations).AROs. The funds realized pre-tax gains (losses) from the sales of securities of ($6.2)$12 million, $10.3($6) million and $2.1$10 million in 2004, 2003 2002 and 2001,2002, respectively (cost of the investments based on specific identification was $333.9 million, $92.2$1.1 billion, $334 million and $147.4$92 million and pre-tax proceeds from the sales were $327.7 million, $102.5$1.1 billion, $328 million and $149.5$102 million, respectively). In January 2004, WP&LWPL liquidated all of the qualified decommissioning assets into money market funds as a result of the pendinganticipated Kewaunee sale.sale and at Dec. 31, 2004, the value of the qualified decommissioning assets was $171 million.

 

Investment in ATCUnconsolidated Equity Investments - - At Dec. 31, 2004 and 2003, WPL had $154 million and 2002, WP&L had$133 million of investments in equity method investees, respectively, consisting of a 24% ownership interestsinterest in ATC (carrying value of approximately 25% and 27%, respectively, and accounts for this investment under the equity method. At$141 million at Dec. 31, 20032004) and 2002, the carryinga 50% ownership interest in Wisconsin River Power Company (carrying value of WP&L’s investment in ATC was $121$13 million and $112 million,at Dec. 31, 2004), respectively. Summary financial information from the 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 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 $41.3WPL $48 million, $38.7$41 million and $36.4$39 million in 2004, 2003 and 2002, and 2001, respectively. WP&LWPL billed ATC $12.4$13 million, $18.1$12 million and $18.4$18 million in 2004, 2003 and 2002, respectively. At Dec. 31, 2004 and 2001, and recorded equity earnings2003, WPL owed ATC net amounts of $16.2 million, $14.3$2.9 million and $14.6$2.7 million, in 2003, 2002 and 2001, respectively.

 

Unconsolidated Equity InvestmentsNuclear Management Company, LLC (NMC) - Summary financial information WPL receives services from NMC for the financial statementsmanagement and operation of WP&L’s unconsolidated equity investmentsKewaunee. NMC billed WPL indirectly through Wisconsin Public Service Corporation (WPSC) $34 million, $33 million and $24 million in ATC, WRPC2004, 2003 and Alliant Energy SPE LLC is as follows (in millions):2002, respectively, for its allocated portion for Kewaunee.

   2003

    2002

    2001

Operating revenues

  $232.3    $211.7    $180.3

Operating income

   87.7     75.7     65.8

Net income

   72.1     59.5     55.9

As of Dec. 31:

                

Current assets

   41.5     44.7      

Non-current assets

   947.2     774.4      

Current liabilities

   67.9     50.8      

Non-current liabilities

   14.6     7.5      

(10) DERIVATIVE FINANCIAL INSTRUMENTS

(a) Accounting for Derivative Instruments and Hedging Activities - - WP&LWPL 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. At Dec. 31, 20032004 and 2002,2003, WP&L had $1.3$4.7 million and $2.7$1.3 million of derivative assets included in “Other current assets” and $3.6$6.7 million and $7.1$3.6 million of derivative liabilities included in “Other current liabilities” on itsthe Consolidated Balance Sheets, respectively.

 

In April 2003, the FASB issued SFAS 149, which amends and clarifies accounting for derivative instruments, including certain derivative instruments embedded in other contracts, and for hedging activities under SFAS 133. Although SFAS 149 is expected to result in more energy contracts at WP&L qualifying as derivatives, changes in the fair value of these derivatives are generally reported as changes in regulatory assets and liabilities rather than being reported currently in earnings, based on the regulatory treatment.

Cash Flow Hedging Instruments - During 2003 and/or 2002, WP&L held various derivative instruments designated as cash flow hedging instruments. WP&L utilized natural gas commodity financial swap arrangements to reduce the impact of price fluctuations on natural 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, some of which did not qualify for the normal purchase and sale exception, to manage the price of anticipated coal purchases and sales.

In 2003 and 2002, $0 and a net loss of $0.2 million, respectively, were recognized relating to the amount of hedge ineffectiveness in accordance with SFAS 133. In 2003 and 2002, WP&L did not exclude any components of the derivative instruments’ gain or loss from the assessment of hedge effectiveness and there was no earnings impact as a result of the discontinuance of hedges. At Dec. 31, 2003, WP&L did not have any cash flow hedging instruments outstanding.

Other Derivatives Not Designated in Hedge Relationships - WP&L’sWPL’s derivatives that were not designated in hedge relationships during 20032004 and/or 20022003 included coal and gas contracts. Coal 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 - - WP&LWPL uses weather derivatives to reduce the impact of weather volatility on its natural gas sales volumes. In 2004, 2003 and 2002, Corporate Services, as agent for 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

WPL’s ratepayers do not pay any 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. In 2003, fair value changes of these instruments did not impact net income aspremiums nor do they were recorded as equally offsetting changesshare in the investment in nuclear decommissioning trust funds and regulatory liabilities or, for AROs, as an offset to regulatory assets (in 2002 as an offset to cost of removal obligations).gains/losses realized from the weather hedges.

 

(11) COMMITMENTS AND CONTINGENCIES

(a) Construction and Acquisition Expenditures - - CertainWPL has made certain commitments have been made in connection with 2004its 2005 capital expenditures. During 2004, total construction and acquisition expenditures are estimated to be approximately $228 million (unaudited).

(b) Purchase Obligations - - Alliant Energy, through its subsidiaries Corporate Services, WP&LInterstate Power and IP&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 WP&L and IP&L. Such process considers factors such as resource mix, load growth and resource availability. However, for 2004, system-wide purchased-power contracts of $4.4 million (0.2 million MWh) have not yet been directly assigned to WP&L and IP&L since the specific needs of each utility are not yet known. Refer to Note 17 for additional information. Coal contract quantities are directly assigned to specific plants at WP&L and IP&L based on various factors including projected heat input requirements, combustion compatibility and efficiency. However, for 2004 to 2008, system-wide coal contracts of $78.7 million (10.7 million tons), $55.1 million (7.6 million tons), $34.0 million (5.4 million tons), $12.5 million (2.1 million tons) and $6.4 million (1.0 million tons), respectively, have not yet been directly assigned to WP&L and IP&L since the specific needs of each utility are 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 and WP&L expectexpects to supplement theirits coal and natural gas supplies with spot market purchases as needed. The table includes commitments for “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, 2003, 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

 Purchased power

 Coal

 Natural gas

  Dollars

  MWhs

  Dollars

  Tons

  Dollars

  Dths

 Dollars

 MWhs

 Dollars

 Tons

 Dollars

 Dths

2004

  $25.1  730  $8.2  --    $33.9  2

2005

   --    --     7.6  --     23.7  -- $6.0 —   $8.0 —   $114.4 15

2006

   --    --     7.6  --     22.5  --  3.2 —    8.0 —    50.0 4

2007

   --    --     7.6  --     20.2  --  3.2 —    8.0 —    20.9 —  

2008

   --    --     5.9  --     15.5  --  3.2 —    6.2 —    15.8 —  
2009  3.2 —    6.2 —    15.7 —  

Thereafter

   --    --     35.6  --     40.0  --  10.6 —    31.2 —    22.2 —  

Also, at DecemberDec. 31, 2003, WP&L’s2004, WPL’s other purchase obligations, which represent individual commitments incurred during the normal course of business which exceeded $1$1.0 million at Dec. 31, 2003,2004, were $6.0$9 million for 2004.2005. This excludes lease obligations which are included in Note 3.

 

(c) Legal 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 - - Refer to Note 3 for discussion of WP&L’sWPL’s residual value guarantees of its synthetic leases.

 

(e) Environmental 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


   2003

  2002

    2003

  2002

MGP sites

  $5.4  $6.9    $12.5  $13.0

NEPA

   2.0   2.5     2.4   3.1

Other

   --     --       1.3   2.9
   

  

    

  

   $7.4  $9.4    $16.2  $19.0
   

  

    

  

   2004

  2003

Manufactured gas plant (MGP) sites

  $5.2  $5.4

Other

   1.3   2.0
   

  

   $6.5  $7.4
   

  

 

MGP Sites - - WP&LWPL 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 six sites.

WP&L WPL 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 2003,2004, 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&L’sWPL’s sites to be $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 four-yearfive-year period effective withafter new rates set to recover such amounts.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.

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 uranium enrichment services provided in conjunction with prior nuclear fuel purchases. WP&L elected to pay its assessment in 15 annual installments. The costs associated with this assessment for WP&L is being recovered through fuel costs. The final installment payment is scheduled to be made in fall 2006. WP&L continues to pursue relief from this assessment through litigation.

(f) Decommissioning of Kewaunee - - Decommissioning expense is included in “Depreciation and amortization” in the Consolidated Statements of Income and the cumulative amount for 2003 is included in “Regulatory liabilities” or, for AROs, is netted in “Regulatory assets” on the Consolidated Balance Sheets. For 2002, the cumulative amount is included in “Cost of removal obligations.” The PSCW and FERC, in an orderorders effective Jan. 1, 2002 and Jan. 1, 2005, respectively, eliminated WP&L’sWPL’s recovery from retail customers for the cost to decommission Kewaunee, due to the trust fund being adequately funded.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 

(1)

Assumptions relatingInformation is related to current rate recovery amounts (per
WP&L’sWPL’s most recent FERC settlement):

WP&L’s shareorder (prior to the elimination 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%

Current annual rate recovery (FERC)

$2.9

External trust fund balance at Dec. 31, 2003

$233.7

After-tax losses on external trust funds in 2003

($4.7)for Kewaunee).

WP&L is funding all rate recoveriesThe earnings for decommissioning into external trust funds and funding on a tax-qualified basis to the extent possible. In 2003, 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 1516 for information regarding the pendingproposed sale of WP&L’sWPL’s interest in Kewaunee and Note 1617 for information related to the impact of SFAS 143.

 

(g) Credit Risk - - WP&LWPL has limited credit exposure from electric and natural gas sales and non-performance of contractual obligations by its counterparties. WP&LWPL 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.

 

(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, WP&LWPL 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’sWPL’s ownership interest in these facilities at Dec. 31, 20032004 was as follows (dollars in millions):

 

  

Fuel

Type


  

Ownership

Interest %


  

Plant in

Service


  

Accumulated

Provision for

Depreciation


  

Construction

Work In

Progress


  Fuel Type

  Ownership
Interest %


  Plant in
Service


  Accumulated
Provision for
Depreciation


  Construction
Work In
Progress


Edgewater Unit 5

  Coal  75.0  $237.0  $120.7   $0.8  Coal  75.0  $238.3  $127.7  $1.3

Columbia Energy Center

  Coal  46.2   192.5   118.5   2.5  Coal  46.2   195.5   121.0   9.6

Kewaunee

  Nuclear  41.0   175.8   127.6   7.7  Nuclear  41.0   204.4   145.7   12.5

Edgewater Unit 4

  Coal  68.2   66.8   39.5   1.7  Coal  68.2   71.1   41.9   0.9
        

  

  

        

  

  

        $672.1  $406.3  $12.7        $709.3  $436.3  $24.3
        

  

  

        

  

  

 

Refer to Note 1516 for information regarding the pendingproposed sale of WP&L’sWPL’s interest in Kewaunee.

(13) SEGMENTS OF BUSINESS

WP&L

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 2002 and 2001,2002, gas revenues included $20 million, $45 million $22 million and $21$22 million, respectively, for sales to the electric segment. All other intersegment revenues were not material to WP&L’sWPL’s operations and there was no single customer whose revenues were 10% or more of WP&L’sthe consolidated revenues. Certain financial information relating to WP&L’sWPL’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  Electric

  Gas

  Other

 Total

          

Operating revenues

  $910.1  $272.4  $34.5  $1,217.0   $910.1  $272.4  $34.5  $1,217.0 

Depreciation and amortization

  89.2  14.6  1.1  104.9    89.2   14.6   1.1   104.9 

Operating income

  163.8  25.5  2.3  191.6    163.8   25.5   2.3   191.6 

Interest expense, net of AFUDC

         33.8           33.9 

Equity income from unconsolidated investments

         (20.7)          (20.7)

Miscellaneous, net

         (2.2)

Interest income and other

          (2.3)

Income tax expense

         65.8           65.8 

Net income

         114.9           114.9 

Preferred dividends

         3.3           3.3 

Earnings available for common stock

         111.6           111.6 

Total assets

  1,950.5  306.2  212.6  2,469.3    1,950.5   306.2   212.6   2,469.3 

Investments in equity method subsidiaries

  133.3  --    --    133.3    133.3   —     —     133.3 

Construction and acquisition expenditures

  133.0  17.4  1.2  151.6    133.0   17.4   1.2   151.6 

2002

                  

Operating revenues

  787.7  179.1  22.7  989.5   $787.7  $179.1  $22.7  $989.5 

Depreciation and amortization

  91.7  15.9  1.1  108.7    91.7   15.9   1.1   108.7 

Operating income (loss)

  135.1  12.0  (1.5) 145.6    135.1   12.0   (1.5)  145.6 

Interest expense, net of AFUDC

         37.6           37.6 

Equity income from unconsolidated investments

         (17.0)          (17.0)

Miscellaneous, net

         (0.6)

Interest income and other

          (0.6)

Income tax expense

         44.7           44.7 

Net income

         80.9           80.9 

Preferred dividends

         3.3           3.3 

Earnings available for common stock

         77.6           77.6 

Total assets

  1,834.7  298.5  201.9  2,335.1    1,834.7   298.5   201.9   2,335.1 

Investments in equity method subsidiaries

  121.7  --    --    121.7    121.7   —     —     121.7 

Construction and acquisition expenditures

  144.6  10.6  1.7  156.9    144.6   10.6   1.7   156.9 

2001

         

Operating revenues

  753.5  206.9  33.3  993.7 

Depreciation and amortization

  104.0  15.8  1.3  121.1 

Operating income

  129.1  2.5  5.7  137.3 

Interest expense, net of AFUDC

         38.7 

Equity income from unconsolidated investments

         (15.5)

Miscellaneous, net

         (0.6)

Income tax expense

         41.2 

Net income

         73.5 

Preferred dividends

         3.3 

Earnings available for common stock

         70.2 

Total assets

  1,638.8  249.4  329.3  2,217.5 

Investments in equity method subsidiaries

  117.3  --    --    117.3 

Construction and acquisition expenditures

  127.9  16.8  2.3  147.0 

(14) SELECTED CONSOLIDATED QUARTERLY FINANCIAL DATA (UNAUDITED)

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

 

  2003

  2002

  2004

  2003

  March 31

  June 30

  Sept. 30

  Dec. 31

  March 31

  June 30

  Sept. 30

  Dec. 31

  March 31

  June 30

  Sep. 30

  Dec. 31

  March 31

  June 30

  Sep. 30

  Dec. 31

  (in millions)  (in millions)

Operating revenues

  $346.9  $254.8  $318.9  $296.3  $235.5  $220.6  $254.0  $279.4  $339.4  $270.7  $286.2  $313.5  $346.9  $254.8  $318.9  $296.3

Operating income

   18.1   35.7   77.8   60.1   30.1   25.7   34.9   54.9   38.9   51.3   55.0   37.6   18.1   35.7   77.8   60.1

Net income

   10.1   19.9   47.4   37.5   15.7   12.8   19.2   33.2   22.3   31.2   33.6   26.7   10.1   19.9   47.4   37.5

Earnings available for common stock

   9.3   19.0   46.6   36.7   14.9   12.0   18.3   32.4   21.5   30.4   32.7   25.8   9.3   19.0   46.6   36.7

 

(15) PENDINGASSETS 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 WP&L’SWPL’S INTEREST IN KEWAUNEE

WP&L

WPL has signed a definitive agreement to sell its 41% ownership interest in Kewaunee to Richmond, Va.-based Dominion Energy Kewaunee, Inc. (Dominion), a subsidiary of Dominion Resources, Inc. Joint owner of Kewaunee, WPSC, also agreed(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 its 59% ownership interest in Kewaunee to Dominion. Pending various regulatory approvals, includingWPL 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 NRC, the transaction is expected to be completed by fall 2004. WP&Lpetition was accepted in January 2005 on an expedited schedule. WPL anticipates that basedthe PSCW will issue a decision on an expected Nov. 1, 2004 closing date,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 has established to cover the eventual decommissioning of Kewaunee. The fund that WPL will be retainedretain had an after-tax value of $67.3$72 million onas of Dec. 31, 2003.2004. 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 gross cash proceeds, after certain transaction costs, from the sale are expected to slightly exceed WP&L’sWPL’s carrying value of the assets being sold. WP&LWPL 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, WP&LWPL does not expect this transaction will have a significant impact on its operating results. Dominion will assume responsibility forAs of Dec. 31, 2004, WPL’s share of the eventual decommissioning of Kewaunee and WP&L is required to provide qualified decommissioning trust assets of at least $160.7 million on an after-tax basis. The after-taxcarrying value of the qualified fundassets and liabilities included within the sale agreement was $166.3 million on Dec. 31, 2003. In January 2004, WP&L liquidated all of the qualified decommissioning assets into money market funds as a result of the pending Kewaunee sale. 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, WP&LWPL will enter into a long-term purchased-powerpurchased power agreement with Dominion to purchase energy and capacity equivalent to the amounts received had current ownership continued. The purchased-powerpurchased power agreement, which also will require regulatory approval, will extend through 2013 when the plant’sKewaunee’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.

 

(16)(17) ASSET RETIREMENT OBLIGATIONS (AROs)

WP&L

WPL adopted SFAS 143 on Jan. 1, 2003, which provides accounting and disclosure requirements for AROs associated with long-lived 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 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 assets including, but not limited to, active ash landfills, water intake facilities, underground storage tanks, groundwater wells, distribution equipment, easements, leases and the dismantlement of certain hydro facilities. Other than Kewaunee, WP&L’sWPL’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 WP&L’sthe AROs is depicted below (in millions):

 

Balance at Jan. 1, 2003

  $175

Accretion expense

   13
   

Balance at Dec. 31, 2003

  $188
   

If SFAS 143 had been adopted as of Jan. 1, 2001, WP&L would have recorded ARO SFAS 143 liabilities of $175 million at Dec. 31, 2002 and $161 million at Dec. 31, 2001. Refer to Note 15 for information regarding the pending sale of WP&L’s interest in Kewaunee.

Balance at Jan. 1, 2004

  $187.4

Accretion expense

   13.5
   

Balance at Dec. 31, 2004

  $200.9
   

 

At Dec. 31, 2002, prior to theUpon adoption of SFAS 143 WP&Lon Jan. 1, 2003, WPL recorded $163.2 millionAROs of legal AROs in “Cost of removal obligations” on the Consolidated Balance Sheet.$175.0 million.

 

(17)(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 of Dec. 31, 2003, 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 was 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 $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 evaluation.

(19) RELATED PARTIES

WP&L

WPL 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 (IP&L(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 $42.1$25 million, $26.9$42 million and $32.1$27 million for 2004, 2003 2002 and 2001,2002, respectively. The purchases allocated to WP&LWPL were $229.4$279 million, $205.8$229 million and $209.2$206 million for 2004, 2003 2002 and 2001,2002, 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 $125.1$129 million, $117.7$125 million and $107.0$118 million for 2004, 2003 2002 and 2001,2002, respectively, and consisted primarily of employee compensation, benefits and fees associated with various professional services. At Dec. 31, 2004 and 2003, and 2002, WP&LWPL had a net intercompany payable to Corporate Services of $36.4$31 million and $31.1$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. 72%71% of WP&L’sWPL’s individual preferred shareowners are Wisconsin residents.

 

Dividend Information- Preferred stock dividends paid per share for each quarter during 20032004 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 20042005 are as follows:

 

Record Date


  

Payment Date


February 2728

  March 15

May 2831

  June 15

August 31

  September 15

November 30

  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 Form 10-K 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

Erroll B. Davis, Jr., 59, was elected Chairman of the Board effective April 2000 and Chief Executive Officer effective April 1998.

William D. Harvey, 54, was elected Chief Operating Officer effective January 2004. He previously served as President since April 1998.

Barbara J. Swan, 52, was elected President effective January 2004. She previously served as Executive Vice President and General Counsel since October 1998.

Eliot G. Protsch, 50, was elected Chief Financial Officer effective January 2004. He previously served as Executive Vice President and Chief Financial Officer since September 2003 and Executive Vice President-Energy Delivery from October 1998 to September 2003.

Thomas L. Aller, 54, was elected Senior Vice President-Energy Delivery effective January 2004. He previously served as interim Executive Vice President-Energy Delivery since September 2003 and Vice President-Investments from 1998 to 2003 at Resources.

Thomas L. Hanson, 50, 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, 41, 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.

LOGO


LOGO

Wisconsin Power & Light Company

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

Erroll B. Davis, Jr., 60, was elected Chairman of the Board effective April 2000 and Chief Executive Officer 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 January 2004. She previously served as Executive Vice President and General Counsel since 1998.

Eliot G. Protsch, 51, was elected Chief Financial Officer effective January 2004. He previously served as Executive Vice President and Chief Financial Officer since September 2003 and Executive Vice President-Energy Delivery from 1998 to September 2003.

Thomas L. Aller, 55, was elected Senior Vice President-Energy Delivery effective January 2004. He previously served as interim Executive Vice President-Energy Delivery since September 2003 and Vice President-Investments at Resources from 1998 to 2003.

Thomas L. Hanson, 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, 42, was elected Vice President-Controller and Chief Accounting Officer effective October 2002. He previously served as Corporate Controller and Chief Accounting Officer since 2000.

Directors- Refer to WPL’s Proxy Statement for information on WPL’s board members.

LOGO

Wisconsin Power and 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

NomineeNominees for termterms ending in 2008:

Withhold For All Withhold For All For All Except(*)

ending in 2006:

(01) Ann K. Newhall

Nominees for terms ending in 2007:William D. Harvey

(02) Michael L. BennettSingleton B. McAllister

(03) Jack B. Evans

(04) David A. Perdue

(05) Judith D. Pyle

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

Signature Date Signature Date

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

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 20042005 Wisconsin Power and Light Company proxy card. Please read both sides of the Proxy 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 Wednesday, June 2, 2004,May 25, 2005, at 3:2:00 p.m. at the Alliant Energy Corporate Headquarters in the Nile Meeting Room at 4902 N. Biltmore Lane, Madison, Wisconsin.


LOGOLOGO

 

WISCONSIN POWER AND LIGHT COMPANY

PO BOX 2568

MADISON WI 53701-2568

WISCONSIN POWER AND LIGHT COMPANY

PO BOX 2568

MADISON, WI 53701-2568

ANNUAL MEETING OF SHAREOWNERS — JUNE 2, 2004MAY 25, 2005

The undersigned appoints Barbara J. Swan and 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 13, 2004,5, 2005, at the Annual Meeting of Shareowners of the Company to be held at 4902 N. Biltmore Lane, Madison, Wisconsin on June 2, 2004May 25, 2005 at 3:2:00 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 16, 2004 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 at 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.