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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¨ 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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Notes:

 

Reg. (S) 240.14a-101.

SEC 1913 (3-99)




YOUR VOTE IS IMPORTANT

Wisconsin

Power and Light

Company

NOTICEOF 20032006 ANNUAL MEETING

PROXY STATEMENTAND

20022005 ANNUAL REPORT




 

WISCONSIN POWER AND LIGHT COMPANY

 

ANNUAL MEETING OF SHAREOWNERS

 

DATE:

 

June 5, 2003Wednesday, May 24, 2006

TIME:

 

1:2:00 PM, Centralp.m. (Central Daylight Savings TimeTime)

LOCATION:

 

Wisconsin Power and Light Company

Seine ConferenceMississippi Meeting Room, (1R 440)1R600

4902 North Biltmore Lane

Madison, Wis.WI 53718

SHAREOWNER INFORMATION

LOCAL (Madison, Wis., area)(608) 458-3110
TOLL FREE(800) 356-5343

 

 

 

SHAREOWNER INFORMATION NUMBERS

LOCAL CALLS (Madison, Wis., Area)

608-458-3110

TOLL FREE NUMBER

800-356-5343


 

Wisconsin Power and Light Company

4902 North Biltmore Lane

P. O. Box 2568

Madison, WI 53701-2568

Phone: 608.458.3110

 

NOTICE OF ANNUAL MEETING AND PROXY STATEMENT

 

Dear Wisconsin Power and Light Company Shareowner:

 

On Thursday, June 5, 2003,Wednesday, May 24, 2006, Wisconsin Power and Light Company (the “Company”) will hold its 20032006 Annual Meeting of Shareowners at the officeoffices of Alliant Energy Corporation, 4902 North Biltmore Lane, SeineMississippi Meeting Room, Madison, Wis. The meeting will begin at 1:2:00 p.m. Central Daylight Savings Time.

 

Only the sole common stock shareowner, Alliant Energy Corporation, and preferred shareowners who owned stock at the close of business on April 15, 2003,10, 2006 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:will be asked to:

 

 1.Elect three Directorsdirectors for terms expiring at the 20062009 Annual Meeting of Shareowners;

2.Ratify the appointment of Deloitte & Touche LLP as the Company’s independent registered public accounting firm for 2006; and

 

 2.3.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 20022005 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 20022005 Annual Report, to ShareownersNotice of Annual Meeting and Proxy Statement may do so by calling the Company’s Shareowner Services Department at the Shareowner Information Numbersshareowner information numbers shown at the front of this proxy statement or writing to the Company at the address shown above.

 

By Order of the Board of Directors,

By Order of the Board of Directors,

LOGO

F. J. Buri

Corporate Secretary

 

Dated and mailed on or about April 22, 200313, 2006.

1


 

TABLE OF CONTENTS

 

Questions and Answers

 

1

Election of Directors

 

4

3

Meetings and Committees of the Board

 

7

5

Corporate Governance

7

Compensation of Directors

 

8

Ownership of Voting Securities

 

9

Compensation of Executive Officers

 

10

11

Stock Options

 

11

12

Long-Term Incentive Awards

 

12

13

Certain Agreements

 

13

Retirement and Employee Benefit Plans

 

14

15

Report of the Compensation and Personnel Committee on Executive Compensation

 

17

18

Report of the Audit Committee

 

20

22

Proposal for the Ratification of the Appointment of Deloitte & Touche LLP as the Company’s Independent Registered Public Accounting Firm

23

Section 16(a) Beneficial Ownership Reporting Compliance

 

21

24

Appendix A – Audit Committee Charter

A-1

Appendix B – Wisconsin Power and Light Company Annual Report

 

B-1


 


QUESTIONS AND ANSWERS

 

1.  Q:Q:Why am I receiving these materials?
A:The Board of Directors of Wisconsin Power and Light Company (the “Company”) is providing these proxy materials to you in connection with the Company’s Annual Meeting of Shareowners (the “Annual Meeting”), which will take place on Thursday, June 5, 2003.Wednesday, May 24, 2006. As a shareowner, you are invited to attend the Annual Meeting and are entitled to and requested to vote on the mattersproposals described in this proxy statement.

 

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

 

3.  Q:Q:Who is entitled to vote at the Annual Meeting?
A:Only shareowners of record at the close of business on April 15, 2003,10, 2006 are entitled to vote at the Annual Meeting. As of the record date, 13,236,601 shares of common stock (owned solely by AEC) and 1,049,225 shares of preferred stock, in seven series (representing 599,630 votes), were issued and outstanding. Each share of Company common stock and Company preferred stock, with the exception of the 6.50% Series, is entitled to one vote per share. The 6.50% Seriesseries of Company preferred stock is entitled to ¼ 1/4 vote per share.

 

4.  Q:Q:What may I vote on at the Annual Meeting?
A:You may vote on the election of three nominees to serve on the Company’s Board of Directors for terms expiring at the 2009 Annual Meeting of Shareowners inand the yearratification of the appointment of Deloitte & Touche LLP as the Company’s independent registered public accounting firm for 2006.

 

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.director nominees and FOR the ratification of the appointment of Deloitte & Touche LLP as the Company’s independent registered public accounting firm for 2006.

 

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 voting on the election of Directors,directors, you may vote FOR all of the Directordirector nominees or you may WITHHOLD your vote may be WITHHELD with respect to one or more nominees. In voting on the proposal to ratify Deloitte & Touche LLP as the Company’s independent registered public accounting firm for 2006, you may vote FOR, AGAINST or ABSTAIN. 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“FOR” all listed Director nominees.director nominees and “FOR” the proposal to ratify the appointment of Deloitte & Touche LLP as the Company’s independent registered public accounting firm for 2006.

 

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

 

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

 

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

 

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

 

1


10.  Q:Q:Who may attend the Annual Meeting?
A:All shareowners who owned shares of the Company’s common stock and preferred stock on April 15, 2003,10, 2006, may attend the Annual Meeting. You may indicate on the enclosed proxy card your intention to attend the Annual Meeting and return it with your signed proxy.

 

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

 

12.  Q:Q:Where and when will I be able to find the results of the voting?
A:The results of the voting will be announced at the Annual Meeting. You may also call ourthe Company’s Shareowner Services Department at the Shareowner Information Numbersshareowner information numbers shown at the front of this proxy statement for the results. The Company will also publish the final results in its Quarterly Report on Form 10-Q for the second quarter of 20032006 to be filed with the Securities and Exchange Commission (“SEC”).

13.  Q:Q:When are shareowner proposals for the 20032007 Annual Meeting due?
A:All shareowner proposals to be considered for inclusion in the Company’s proxy statement for the 20042007 Annual Meeting must be received at the principal office of the Company by Dec. 23, 2003.14, 2006. In addition, any shareowner who intends to present a proposal from the floor at the 20042007 Annual Meeting must submit the proposal in writing to the Corporate Secretary of the Company no later than March 8, 2004.Feb. 27, 2007.

 

14.  Q:Q:Who areis the independent auditorsregistered public accounting firm of the Company and how are theyis it appointed?
A:Deloitte & Touche LLP audited the financial statements of the Company for the year ended Dec. 31, 2002, and re-audited the financial statements of the Company for the years ended Dec. 31, 2001, and Dec 31, 2000.2005. Representatives of Deloitte & Touche LLP are not expected to be present at the meeting. The Audit Committee of the Board of Directors expects to appointrecommends the ratification of its appointment of Deloitte & Touche LLP as the Company’s independent auditorsregistered public accounting firm for 2003 later in the year.year ending Dec. 31, 2006.

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

 

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

 

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

 

17.  Q:Q:If more than one shareowner lives in my household, how can I obtain an extra copy of thisthe Company’s 2005 Annual Report and proxy statement and Annual Report?statement?
A:Pursuant to the rules of the SEC, services that deliver the Company’s communications to shareowners that hold their stock through a bank, broker or other holder of record may deliver to multiple shareowners sharing the same address a single copy of the Company’s 20022005 Annual Report and proxy statement. Upon written or oral request, the Company will delivermail a separate copy of the 20022005 Annual Report and proxy statement to any shareowner at a shared address to which a single copy of eachthe document was delivered. You may notify the Company of your request by calling or writing the Company’s Shareowner Services Department at the Shareowner Information Numbersshareowner information numbers shown at the front of this proxy statement or at the address of the Company.Company shown on the Notice of Annual Meeting.

2


ELECTION OF DIRECTORS

 

Three DirectorsAt the Annual Meeting, three directors will be elected this year for terms expiring in 2006.2009. The nominees for election as recommended by the Nominating and Governance Committee ofand selected by the Company’s Board of Directors are: Erroll B. Davis, Jr., Robert W. Schlutzare Ann K. Newhall, Dean C. Oestreich and Wayne H. Stoppelmoor.Carol P. Sanders. Each of the nominees is currently serving as a Directordirector of the Company. Each person elected as Directora director will serve until the Annual Meeting of Shareowners of the Company in 20062009, or until his or her successor has been duly electedqualified and qualified.elected.

 

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

 

Brief biographies of the Directordirector nominees and continuing Directorsdirectors follow. These biographies include their ageages (as of Dec. 31, 2002)2005), an account of their business experience and the names of publicly held and certain other corporations of which they are also Directors.directors. Except as otherwise indicated, each nominee and continuing Directordirector has been engaged in his or her present occupation for at least the past five years.

 

NOMINEES

 

LOGO

LOGO  

ERROLL B. DAVIS, JR.ANN K. NEWHALL

Age 54

  

Director Since 1984since 2003

Nominated Term expires in 2009

  

Age 58

Nominated Term ExpiresMs. Newhall is Executive Vice President, Chief Operating Officer, Secretary and a Director of Rural Cellular Corporation, a cellular communications corporation located in 2006

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

2003.

LOGO

LOGO  

ROBERT W. SCHLUTZDEAN C. OESTREICH

Age 53

  

Director Since 1998since 2005

Nominated Term expires in 2009

  

Age 66

Nominated Term Expires in 2006

Mr. Schlutz is President of Schlutz Enterprises, a diversified farming and retailing business in Columbus Junction, Iowa. Mr. SchlutzOestreich has served as President of Pioneer Hi-Bred International, Inc., a developer and supplier of advanced plant genetics, and a wholly-owned subsidiary of DuPont Corporation, located in Johnston, Iowa, since 2004. He previously served as Vice President and Business Director of North America from 2002 to 2004, Vice President and Director of Supply Management from 2001 to 2002 and Vice President and Director for Africa, Middle East, Asia and Pacific from 1999-2001. Mr. Oestreich was appointed a Director of the Company, AEC, IP&L (or predecessor companies) since 1989 and of AEC and AER since 1998. Mr. Schlutz is ChairpersonResources in July 2005. He was originally recommended as a nominee in 2005 by a third-party search firm acting on behalf of the Environmental, Nuclear, HealthNominating and SafetyGovernance Committee.

LOGO

LOGO  

WAYNE H. STOPPELMOORCAROL P. SANDERS

Age 38

  

Director Since 1998since 2005

Nominated Term expires in 2009

  

Age 68

Nominated Term ExpiresMs. Sanders has served as Chief Financial Officer and Corporate Secretary of Jewelers Mutual Insurance Company of Neenah, Wis., a nationwide insurer that specializes in 2006

Mr. Stoppelmoorprotecting jewelers and personal jewelry, since 2004. She previously served as Controller and Assistant Treasurer of Sentry Insurance located in Stevens Point, Wis. from 2001 to 2004. From 1999 to 2001, she served as Vice ChairmanPresident and Treasurer of the BoardAmerican Medical Security, Inc. located in Green Bay, Wis. Ms. Sanders was appointed a Director of the Company, AEC, IP&L and AEC from April 1998 until April 2000. Prior to 1998, heResources in November 2005. She was Chairman, President and Chief Executive Officer of Interstate Power Company, a predecessor to IP&L. He retired as Chief Executive Officer of Interstate Power Company in 1997. Mr. Stoppelmoor has servedoriginally recommended as a Directornominee in 2005 by a third-party search firm acting on behalf of IP&L (or predecessor companies) since 1986the Nominating and of AEC and AER since 1998.

Governance Committee.

 

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

3


CONTINUING DIRECTORS


 

LOGO

LOGO  

ALAN B. ARENDSMICHAEL L. BENNETT

Age 52

  

Director Since 1998since 2003

Term expires in 2007

  

Age 69

Term Expires in 2005

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

LOGO

JACK B. EVANS

Director Since 2000

Age 54

Term Expires in 2004

Mr. Evans is a Director and since 1996Bennett has served as President and Chief Executive Officer of The Hall-Perrine Foundation, a private philanthropic corporationTerra Industries Inc., an international producer of nitrogen products and methanol ingredients headquartered in Cedar Rapids, Iowa. Previously, Mr. EvansSioux City, Iowa, since April 2001. From 1997 to 2001, he was Executive Vice President and Chief Operating Officer of SCI Financial Group,Terra Industries Inc. He also serves as Chairman of the Board for Terra Nitrogen Corp., a regional financial services firm.subsidiary of Terra Industries Inc. Mr. Evans is a Director of Gazette Communications, the Federal Reserve Bank of Chicago and Nuveen Institutional Advisory Corp., and Vice Chairman and a Director of United Fire and Casualty Company. Mr. EvansBennett has served as a Director of AEC, IP&L (or predecessor companies) and AERResources since 2000.2003. Mr. EvansBennett is Chairperson of the Audit Committee.

LOGO

LOGO  

KATHARINE C. LYALLWILLIAM D. HARVEY

Age 56

  

Director Since 1986since 2005

Term expires in 2008

  

Age 61

Term Expires inMr. Harvey has served as Chairman of the Board of the Company, AEC, IP&L and Resources since February 2006. He has served as Chief Executive Officer of the Company, AEC, IP&L and Resources since July 2005

Ms. Lyall is and as President of Resources since January 2005. He previously served as President and Chief Operating Officer of AEC and Chief Operating Officer of the Company, IP&L and Resources since January 2004. He served as President of the University of Wisconsin System in Madison, Wis. In additionCompany and as Executive Vice President – Generation for AEC, IP&L and Resources from 1998 to her administrative position, she is a professor of economics at the University of Wisconsin-Madison. She serves on the Boards of Directors of the Kemper National Insurance Companies, M&I Corporation and the Carnegie Foundation for the Advancement of Teaching. Ms. Lyall has served as a Director of AEC and AER since 1994 and of IP&L (or predecessor companies) since 1998.

January 2004.

LOGO

LOGO  

SINGLETON B. McALLISTERMCALLISTER

Age 53

  

Director Sincesince 2001

Term expires in 2008

  

Age 50

Term Expires in 2005

Ms. McAllister ishas been a partner within the Washington D. C. law firm of Mintz, Levin, Cohn, Ferris, Glovsky and Popeo P. C. since July 2005. She previously served as the Corporate Diversity Counsel practice group chair and in the public law and policy strategies group of the Washington, D.C. law firm office of Sonnenschein, Nath & Rosenthal, LLP from 2003 to July 2005. She was previously a partner at Patton Boggs LLP, a Washington, D.C.-basedD.C. law firm.firm, from 2001 to 2003. From 1996 until early 2001, Ms. McAllister was General Counsel for the United States Agency for International Development. She was also a partner at Reed, Smith, Shaw and McClay where she specialized in government relations and corporate law.serves on the Board of Directors of United Rentals, Inc. Ms. McAllister has served as a Director of AEC, IP&L (or predecessor companies) and AERResources since 2001.

Ms. McAllister is Chairperson of the Compensation and Personnel Committee.

LOGO

LOGO  

DAVID A. PERDUE

Age 56

  

Director Sincesince 2001

Term expires in 2007

  

Age 53

Term ExpiresMr. Perdue is Chairman of the Board and Chief Executive Officer of Dollar General Corporation, a retail organization headquartered in 2004

Mr. PerdueGoodlettsville, Tenn. He was named Chief Executive Officer and a Director of Dollar General Corporation, a retail sales organization headquartered in Goodlettsville, Tenn., in April 2003 and elected Chairman of the Board in June 2003. PriorFrom July 2002 to this position,March 2003, he served aswas Chairman and Chief Executive Officer of Pillowtex Corporation, a textile manufacturing company located in Kannapolis, N. C.,N.C. Pillowtex filed for bankruptcy in July 2003 after emerging from Julya previous bankruptcy in May 2002. From 1998 to 2002, to March 2003. Prior to this position, he was employed by Reebok International Limited, where he served as President and Chief Executive Officer of the Reebok Brand for Reebok International Limited. Priorfrom 2000 to joining Reebok in 1998, he was Senior Vice President of Operations at Haggar, Inc.2002. Mr. Perdue has served as a Director of AEC, IP&L (or predecessor companies) and AERResources since 2001.

LOGO

LOGO  

JUDITH D. PYLE

Age 62

  

Director Sincesince 1994

Term expires in 2007

  

Age 59

Term Expires in 2004

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. Prior to assuming her current position, Ms. PyleShe previously served as Vice ChairmanChair and Senior Vice President of Corporate Marketing of Rayovac Corporation, (aa battery and lighting products manufacturer),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.

LOGO

LOGO  

ANTHONY R. WEILER

Age 69

  

Director Sincesince 1998

Term expires in 2008

  

Age 66

Term Expires in 2005

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

Committee and the Lead Independent Director.

4


MEETINGS AND COMMITTEES OF THE BOARD

 

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

 

Audit Committee

The Audit Committee held fournine joint meetings (the Company, AEC, IPL and AER) in 2002.2005. The Committee currently consists of J. B. EvansM. L. Bennett (Chair), A. B. Arends, K. C. Lyall, S. B. McAllister, andA. K. Newhall, D. A. Perdue.Perdue and C. P. Sanders. Each of the members of the Committee is independent as defined by the New York Stock Exchange (“NYSE”) listing standards and SEC rules. The Board of Directors has determined that Mr. Bennett and two additional Audit Committee members qualify as “audit committee financial experts” as defined by SEC rules. The Audit Committee is responsible for assisting Board oversight of: (1) the integrity of the Company’s financial statements,statements; (2) the Company’s compliance with legal and regulatory requirements,requirements; (3) the independent auditors’registered public accounting firm’s qualifications and independence,independence; and (4) the performance of the Company’s internal audit function and the independent auditors.registered public accounting firm. The Audit Committee is also directly responsible for the appointment, retention, termination, compensation and oversight of the Company’s independent auditors.registered public accounting firm.

 

Compensation and Personnel Committee

The Compensation and Personnel Committee held sixfive joint meetings in 2002.2005. The Committee currently consists of J.S. B. McAllister (Chair), M. L. Bennett, D. Pyle (Chair), A. B. Arends, J. B. EvansC. Oestreich and D. A. Perdue. Each of the members of the Committee is independent as defined by the NYSE listing standards and SEC rules. This Committee setsreviews 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 policy, administersand incentive programs and management development programs.

Nominating and Governance Committee

The Nominating and Governance Committee held three joint meetings in 2005. The Committee currently consists of A. R. Weiler (Chair), A. K. Newhall, J. D. Pyle and R. W. Schlutz. Each of the AEC Long-Term Incentive Program, reviewsmembers of the performance ofCommittee is independent as defined by the NYSE listing standards and approves salariesSEC rules. 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 certain officersdirectorships to be filled by the Board or shareowners; (2) identify and certain other management personnel, reviewsrecommend Board members qualified to serve on Board committees; (3) develop and recommendsrecommend to the Board a set of corporate governance principles; (4) oversee the evaluation of the Board and the Company’s management; and (5) advise the Board with respect to other matters relating to corporate governance of the Company.

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

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

have the ability to exercise sound business judgment;

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

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

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

5


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. 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.

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

 

Environmental, Nuclear, Health and Safety Committee

The Environmental, Nuclear, Health and Safety Committee held threetwo joint meetings in 2002.2005. The Committee currently consists of R. W. Schlutz (Chair), J. L. Hanes, J. D. Pyle, D. C. Oestreich, C. P. Sanders and A. R. Weiler. Each of the members of the Committee is independent as defined by the NYSE listing standards and SEC rules. The Committee’s responsibilities are to review environmental policy and planning issues of interest to the Company, including matters involving the Company before environmental regulatory agencies and compliance with air, water and waste regulations. In addition, the Committee reviews policies and operating issues related to the Company’s nuclear generating station investments including planning and funding for decommissioning of the plants. The Committee also reviews health and safety relatedsafety-related policies, activities and operational issues as they affect employees, customers and the general public.

Nominating and Governance In addition, the Committee

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

 

Capital Approval Committee

The Capital Approval Committee held no meetings in 2002.2005. The Committee currently consists of J. B. Evans, J.M. L. Bennett, D. PyleA. Perdue and A. R. Weiler. Mr. DavisHarvey is the Chair and a non-voting member of this Committee. The purpose of this Committee is the evaluation ofto evaluate certain investment proposals where (a)(1) an iterative bidding process is required, and/or (b)(2) the required timelines for such a proposal would not permit the proposal to be brought before a regular meeting of the Board of Directors and/or a special meeting of the full Board of Directors is not practical or merited.

 

Executive Committee

The Executive Committee held no meetings in 2005. The Committee currently consists of M. L. Bennett, S. B. McAllister, R. W. Schlutz and A. R. Weiler. Mr. Harvey is the Chair and a non-voting member of this Committee. The purpose of this Committee is to possess all the powers and authorities of the Board of Directors when the Board is not in session, except for the powers and authorities set forth in Section 180.0825 (5) (a-h) of the Wisconsin Business Corporation Law.

The Board of Directors held seven joint meetings during 2002.2005. Each Directordirector attended at least 85%75% of the aggregate number of meetings of the Board and Board committees on which he or she served.

 

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

Board members are not expected to attend the Company’s Annual Meeting. In 2005, none of the Board members were present for the Company’s Annual Meeting.

6


CORPORATE GOVERNANCE

Corporate Governance Principles

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

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

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

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

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

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

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

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

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

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

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

Lead Independent Director; Executive Sessions

The Corporate Governance Principles provide that the chairperson of the Nominating and Governance Committee shall be the designated “Lead Independent Director” and will preside as the chair at meetings or executive sessions of the independent directors. As the Chairperson of the Nominating and Governance Committee, Mr. Weiler is currently designated

7


as the Lead Independent Director. At every regular in-person meeting of the Board of Directors, the independent directors meet in executive session with no member of Company management present.

Communication with Directors

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

Ethical and Legal Compliance Policy

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

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

COMPENSATION OF DIRECTORS

 

No retainer fees are or were paid to Mr. Harvey or Erroll B. Davis, Jr., the Company’s former Chairman and CEO, for histheir service on the Company’s Board of Directors. In 2002,2005, all other Directorsdirectors (the “non-employee Directors”directors”), each of whom served on the Boards of the Company, AEC, IP&L and AER,Resources, received an annual retainer for service on all four Boards consisting of $30,000$85,000 in cash. Also, in 2005, the Chairperson of the Audit Committee received an additional $10,000 cash retainer and 1,000the Chairpersons of the Compensation and Personnel, Nominating and Governance, and Environmental, Nuclear, Health, and Safety Committees received an additional $5,000 cash retainer; other members of the Audit Committee received a $3,500 cash retainer; and the Lead Independent Director received an additional $15,000 cash retainer. Travel expenses incurred by the non-employee directors are paid for each meeting attended.

In 2006, the non-employee directors will each receive a cash retainer of $100,000. In 2006, 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 $20,000 cash retainer.

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

 

Director’s Deferred Compensation Plan

Under the AEC Director’s Deferred Compensation Plan Directors(“DDCP”), 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.Journal, provided that the return may not be greater than 12% or less than 6%. Amounts deposited to anthe AEC Stock Account whether the cash portion or the stock portion of the Director’s compensation, are treated as though invested in the common stock of AEC and will be credited with dividends,dividend equivalents, which will be treated as if reinvested. Annually, the DirectorThe director may elect that the AEC Deferred Compensation Account will be paid in a lump sum or in annual installments for up to 10 years beginning in the year of or one, two or three tax yearyears after retirement or resignation from the Board.Board of Directors of AEC.

Internal Revenue Code (the “Code”) Section 409A. Code Section 409A imposes restrictions on nonqualified deferred compensation arrangements that do not meet specified criteria as set forth in the statute and supporting guidance. If any of the arrangements provided under the DDCP fail to meet the criteria specified in Code Section 409A, or if the DDCP is not operated by AEC in accordance with such requirements, then a participant will recognize ordinary income at the time of deferral and may be liable for an excise tax on such amounts. AEC anticipates that the DDCP will meet the specified criteria set forth in the statute and the supporting guidance under Code Section 409A.

 

Director’s Charitable Award Program

AEC maintains a Director’s Charitable Award Program for thecertain members of its Board of Directors beginning after three years of service. The participants in this Program currently are E. B. Davis, S. B. McAllister, D. A. Perdue, J. D. Pyle and A. R. Weiler. K. C. Lyall, who retired as a director on May 19, 2005, is also a participant in the Program. The purpose of the

8


Program is to recognize the interest of the Company and its Directorsdirectors in supporting worthy institutions, and to enhance the Company’s Director benefit program so that the Company is able to continue to attract and retain Directors of the highest caliber.institutions. Under the Program, when a Directordirector dies, the Company and/or AEC will donate a total of $500,000 to one qualified charitable organization or divide that amount among a maximum of fourfive qualified charitable organizations selected by the individual Director.director. The individual Directordirector derives no financial benefit from the Program. All deductions for charitable contributions are taken by the Company and/or AEC, and the donations are funded by the Company or AEC through life insurance policies on the Directors.directors. Over the life of the Program, all costs of donations and premiums on the life insurancepolicies,insurance policies, including a return of the Company’s or AEC’s cost of funds, will be recovered through life insurance proceeds on the Directors.directors. The Program, over its life, will not result in any material cost to the Company or AEC. The Board of Directors of AEC has terminated this Program for all new directors who join the Board after Jan. 1, 2005.

 

Director’s Life Insurance Program

AEC maintains a split-dollar Director’s Life Insurance Program for non-employee Directors, beginning after three years of service, whichdirectors. The participants in this Program currently include J. D. Pyle and A. R. Weiler. K. C. Lyall, who retired as a director on May 19, 2005, is also a participant in the Program. The Program provides a maximum death benefit of $500,000 to each eligible Director.director. Under the split-dollar arrangement, Directorsdirectors are provided a death benefit only and do not have any interest in the cash value of the policies. The Life Insurance Program is structured to pay a portion of the total death benefit to AEC to reimburse AEC for all costs of the program,Program, including a return on its funds. The Life Insurance Program, over its life, will not result in any material cost to AEC. The imputed income allocations reported for each Directordirector in 20022005 under the Director’s Life Insurancethis Program were as follows: A. B. Arends—$50, J. L. Hanes—$50, K. C. Lyall—$448,Lyall — $566, J. D. Pyle—$20, W. H. Stoppelmoor—$948Pyle — $29, and A. R. Weiler—$50.Weiler — $50. In November of 2003, the Board of Directors of AEC terminated this insurance benefit for any director not already having the required vesting period of three years of service and for all new directors.

 

Pension Arrangements

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

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

OWNERSHIP OF VOTING SECURITIES

 

All of the common stock of the Company is held by AEC. None of the directors or officers of the Company own any shares of the Company’s preferred stock. Listed in the following table are the number of shares of AEC’s common stock beneficially owned by (1) the executive officers listed in the Summary Compensation Table, and(2) all director nominees and Directorsdirectors of AEC and the Company, as well as the number of shares owned by Directorsand (3) all director nominees, directors and executive officers of AEC and the Company as a group as of Feb. 28,2003.28, 2006. The Directorsdirectors and executive officers of AEC and the Company as a group owned 1.8%1% of the outstanding shares of AEC common stock on that date. No individual Directordirector or officer owned more than 1% of the outstanding shares of AEC common stock on that date. To the Company’s knowledge, no shareowner beneficially owned 5% or more of AEC’s outstanding common stock as of Dec. 31, 2002.

 

NAME OF BENEFICIAL OWNER


  

SHARES

BENEFICIALLY

SHARES BENEFICIALLY OWNED(1)


 

ExecutivesExecutive Officers(2)

    

William D. HarveyThomas L. Aller

  

135,155117,512

(3)

Eliot G. Protsch

139,443

(3)

Thomas M. Walker

91,639

(3)

Pamela J. Wegner

100,781

(3)

Director Nominees

Erroll B. Davis, Jr.

  

473,619971,906

(3)(4)

Robert W. Schlutz.Eliot G. Protsch

  

16,791250,967

(3)

Wayne H. StoppelmoorBarbara J. Swan

  

133,935153,267

(3)

DirectorsDirector Nominees

    

Alan B. Arends.Ann K. Newhall

  

9,4189,161

(3)

Jack B. EvansDean C. Oestreich

  

36,3633,994

(3)

Joyce L. Hanes(4)Carol P. Sanders

  

8,585826

(3)

Lee Liu(4)Directors

  

192,386

(3)

Katharine C. LyallMichael L. Bennett

  5,357(3)

14,540William D. Harvey

316,297(3)

Singleton B. McAllister

  

2,710

7,911

(3)

David A. Perdue

  

3,9588,853

(3)

Judith D. Pyle

  14,612

13,043Robert W. Schlutz

22,810(3)(5)

Anthony R. Weiler

  

15,40921,245

(3)

All ExecutivesExecutive Officers and Directors as a Group

2317 people, including those listed above.excluding Mr. Davis

  

1,710,8291,118,303

(3)

 

(1)Total shares of AEC common stock outstanding as of Feb. 28, 2003,2006 were 92,658,243.117,523,778.

9


 

(2)Stock ownership of Mr. DavisHarvey is shown with the Directors.directors.

 

(3)Included in the beneficially owned shares shown are indirect ownership interests with shared voting and investment powers: Mr. Davis—8,467,Harvey — 2,934, Mr. Evans—Aller — 1,000, Ms. Hanes—604, Mr. Liu—19,755, Mr. Weiler—1,389, Mr. Harvey—2,595Protsch — 845 and Mr. Protsch—783;Davis — 9,876 shares; shares of common stock held in deferred compensation plans: Mr. Arends—4,227,Bennett — 4,945, Mr. Davis—42,865,Harvey — 38,278, Ms. McAllister — 4,848, Ms. Newhall — 7,851, Mr. Evans—5,363,Oestreich – 2,994, Mr. Perdue — 8,853, Ms. Hanes—200,Sanders —726, Mr. Perdue—3,958,Schlutz — 10,898, Mr. Schlutz—6,252,Weiler — 10,064, Mr. Weiler—4,228,Protsch — 36,583, Mr. Harvey—26,479,Aller – 6,951, Mr. Protsch—32,388, Mr. Walker—17,437Davis — 52,686 and Ms. Wegner—17,884Swan — 22,350 (all executive officers and Directorsdirectors as a group—203,104)group including Mr. Davis — 222,254); and AEC stock options exercisable on or within 60 days of Feb. 28, 2003:2006: Mr. Davis—388,778,Harvey — 178,692, Mr. Liu—148,849,Protsch — 151,953, Mr. Stoppelmoor—119,201,Aller – 99,166, Mr. Harvey—87,403, Mr. Protsch—87,403, Mr. Walker—70,637Davis — 812,406 and Ms. Wegner—73,859Swan — 107,333 (all executive officers and Directorsdirectors as a group—1,231,041)group including Mr. Davis — 1,482,953).

 

(4)Ms. Hanes and Mr. LiuDavis retired from the Company effective Feb. 1, 2006.

(5)Mr. Schlutz will retire as Directors of the Companya director at AEC’s 2006 Annual Meeting on May 28, 2003.12, 2006.

 

None of the Directors or officers of the Company own any shares of the Company’s preferred stock. To the Company’s knowledge, no shareowner beneficially owned5%owned 5% or more of any class of the Company’s preferred stock as of Dec. 31, 2002.2005. The following table sets forth information, as of Dec. 31, 2005, regarding beneficial ownership by the only persons known to AEC to own more than 5% of AEC’s common stock. The beneficial ownership set forth below has been reported on Schedule 13G filings with the SEC by the beneficial owners.

 

Amount and Nature of Beneficial Ownership

  Voting Power Investment Power    

Name and Address of Beneficial Owner

 Sole Shared Sole Shared Aggregate Percent
of
Class

Barclays Global Investors, N. A.

(and certain affiliates)

45 Fremont Street

San Francisco, CA 94105

 

 8,088,178 0 8,980,537 0 8,980,537 7.68%

Franklin Resources, Inc.

(and certain affiliates)

One Franklin Parkway

San Mateo, CA 94403-1906

 

 7,422,770 0 7,424,370 0 7,424,370 6.40%

10


COMPENSATION OF EXECUTIVE OFFICERS

 

The following Summary Compensation Table sets forth the total compensation paid by the Company, AEC and AEC’s other subsidiaries to the Chief Executive Officer and the fourcertain other most highly compensated executive officers of the Company for all services rendered during 2002, 20012005, 2004 and 2000.2003.

 

SUMMARY COMPENSATION TABLE


 

Name and Principal Position

Year

Annual Compensation

Long-Term Compensation

All Other

Compensation(3)


Base

Salary

Bonus

Other

Annual

Compensation(1)

Awards

Payouts

    
Annual CompensationLong-Term Compensation 
     Awards(4)Payouts

Securities UnderlyingName and

Options

(Shares)(2)Principal Position

 

LTIPYear

Payouts

 


Base
Salary
Bonus

Other
Annual
Compensation(3)


Restricted
Stock
Awards(5)
Securities
Underlying
Options

(Shares)

LTIP
Payouts(6)

All Other
Compensation(7)

Erroll B. Davis, Jr.(1)

2005
2004
2003
$

775,702
749,019
685,000
$

0
375,197
0
$

78,129
74,987
14,949
$

618,706
300,453
0
0
234,732
151,687
$

2,788,617
0
0
$

168,040
138,719
45,253

William D. Harvey(2)

Chairman and

Chief Executive Officer

 

2002

2001

2000

2005
2004
2003
 

$



685,000

683,269

637,692

584,692
459,442
290,000
 

$



0

489,364

895,200


206,805
0
 

$



0

11,265

11,875

6,025
6,246
5,954
 

151,687

108,592

111,912



1,296,751
100,143
0
 

$

0

359,605

196,711


73,454
26,642
 

$



63,067

50,284

52,619


William D. Harvey

President

590,961
0
0
 

2002

2001

2000



282,500

274,616

264,615

0

161,233

206,541

0

4,061

4,234

26,642

21,798

21,063

0

92,209

47,474

25,307

42,944

42,230


84,173
48,896
15,562

Eliot G. Protsch

Executive Vice President

2002

2001

2000

282,500

274,616

264,615

0

143,688

214,942

0

893

1,423

26,642

21,798

21,063

0

92,209

47,474

22,448

38,372

38,058


Thomas M. Walker

Executive Vice President & Chief Financial Officer

 2005
2004
2003


412,758
364,539
290,000


106,000
142,167
0


5,960
6,014
4,825


693,504
149,981
0
0
40,996
26,642


590,961
0
0


62,468
43,611
15,605

2002Barbara J. Swan

2001

2000President

 

277,500

264,615

254,616

2005
2004
2003
 



0

133,852

190,026

312,694
298,674
265,000
 



73,000
110,791
0

0

0

 

25,673

21,005

20,268



5,627
5,255
0
 



124,933
100,143
0

88,597

47,474

 

0
32,026
24,705

44,841

6,207

6,166




537,224
0
0


23,875
18,843
14,536

Pamela J. WegnerThomas L. Aller

ExecutiveSenior Vice President

 

2002

2001

2000

2005
2004
2003
 



270,000

264,615

254,608

244,265
237,692
200,000
 



0

124,312

180,285

49,000
123,203
189,170
 



0

2,267

2,416


0
0
 

25,673

21,005

20,268



72,891
0
0
 

0

88,597

27,563


21,654
17,438
 



28,441

35,370

34,377

300,123
0
0



10,697
4,164
8,693

 

(1)Other Annual Compensation consists of income tax gross-ups for reverse split-dollar life insurance.Mr. Davis was Chairman and CEO from Jan. 1, 2005 until July 1, 2005 and served as Chairman from July 1, 2005 until his retirement on Feb. 1, 2006.

 

(2)Mr. Harvey was Chief Operating Officer from Jan. 1, 2005 until July 1, 2005 and has served as CEO since July 1, 2005. On Feb. 7, 2006, Mr. Harvey was also elected Chairman.

(3)Other Annual Compensation consists of income tax gross-ups for split-dollar life 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 Summary Compensation Table. The aggregate amount of such personal benefits for each such executive officer in each year reflected in the Summary Compensation 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.

(4)Awards made in 20022005 were in addition to performance share awards as described in the table entitled “Long-Term Incentive Awards in 2002.2005.

 

(3)(5)

The amounts in the Summary Compensation Table above for restricted stock granted in 2004 and 2005 represent the market value based on the closing price of AEC common stock on the date of the grants. Mr. Protsch was granted 2,008 shares of restricted stock on Jan. 3, 2004 that vested on Jan. 3, 2006. All other shares of restricted stock granted to the executive officers listed in 2004 were granted on Jan. 30, 2004 and vest three years after the date of grant. Mr. Harvey was granted 34,880 shares of restricted stock on July 11, 2005 that vest 20% on the third anniversary of the grant date, 40% on the fourth anniversary of the grant date and 40% on the fifth anniversary of the grant date. Mr. Protsch was granted 17,440 shares of restricted stock on July 11, 2005 that vest 20% on the third anniversary of the grant date, 30% on the fourth anniversary of the grant date and 50% on the fifth anniversary of the grant date. All other shares of restricted stock granted to the executive officers listed in 2005 vest subject to meeting certain performance criteria. The shares vest if for the second, third or fourth year of the performance period, AEC’s annual Earnings Per Average Common Share from Continuing Operations (“EPS”) is at least 116% of EPS for the year ending immediately prior to the beginning of the performance period. More specifically, the performance contingency is satisfied if on Dec. 31,

11


2006, 2007 or 2008 AEC’s EPS is at least 116% of the EPS for the year ending 2004. As of Dec. 31, 2005, the total number of shares of restricted common stock (and their market value based on the closing price of AEC common stock on Dec. 30, 2005, the last trading day of the year) held by each executive officer listed in the Summary Compensation Table above were as follows: Mr. Davis, 33,623 shares ($942,789); Mr. Harvey, 49,122 shares ($1,377,381); Mr. Protsch, 30,109 shares ($844,256); Ms. Swan, 8,314 shares ($233,125); and Mr. Aller, 2,594 shares ($72,736). Holders of restricted stock are entitled to receive all dividends on such shares of restricted stock prior to vesting. Such dividends are reinvested into AEC common stock and are subject to the same vesting schedule as the restricted stock on which they are earned.

(6)Executive officers receiving a payout of their performance shares awarded in 2003 for the performance period ending Dec. 31, 2005 could elect to receive their award in cash, in shares of AEC common stock, or partially in cash and partially in AEC common stock. All of the named officers elected to receive their awards 100% in cash, with the exception of Ms. Swan, who received 440 shares of AEC common stock on Jan. 23, 2006 and received the remaining value of her award in cash.

(7)The table below shows the components of the compensation reflected under this column for 2002:2005:

 


    

Erroll B. Davis, Jr.

    

William D. Harvey

    

Eliot G. Protsch

    

Thomas M. Walker

    

Pamela J. Wegner



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

A.

    

$

20,550

    

$

7,825

    

$

8,475

    

$

5,500

    

$

6,850

 $23,271 $9,923 $9,064 $6,300 $6,300

B.

    

 

37,568

    

 

16,469

    

 

13,312

    

 

37,486

    

 

19,793

  99,652  36,316  28,902  7,398  0

C.

    

 

4,949

    

 

1,013

    

 

661

    

 

1,855

    

 

1,798

  8,808  4,205  1,560  1,156  1,634

D.

  36,309  33,729  22,942  9,021  2,763

Total

    

$

63,067

    

$

25,307

    

$

22,448

    

$

44,841

    

$

28,441

 $168,040 $84,173 $62,468 $23,875 $10,697

 

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 2005 on restricted stock

STOCK OPTIONS

 

The following table sets forth certain information concerningAEC did not grant any stock options granted during 2002 to the executives named below:in 2005.

STOCK OPTION GRANTS IN 2002



  

Individual Grants

 

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

 

Name

 

Number of Securities

Underlying

Options Granted(1)

  

% of Total Options Granted to Employees in Fiscal Year

  

Exercise or Base Price

($/Share)

 

Expiration

Date

 

5%

 

10%


Erroll B. Davis, Jr.

 

151,687

  

16.0

%

 

$

27.79

 

5/16/12

 

$

6,866,870

 

$

10,935,116


William D. Harvey

 

26,642

  

2.8

%

 

 

27.79

 

5/16/12

 

 

1,206,083

 

 

1,920,622


Eliot G. Protsch

 

26,642

  

2.8

%

 

 

27.79

 

5/16/12

 

 

1,206,083

 

 

1,920,622


Thomas M. Walker

 

25,673

  

2.7

%

 

 

27.79

 

5/16/12

 

 

1,162,217

 

 

1,850,767


Pamela J. Wegner

 

25,673

  

2.7

%

 

 

27.79

 

5/16/02

 

 

1,162,217

 

 

1,850,767


(1)Consists of non-qualified stock options to purchase shares of AEC common stock granted pursuant to the AEC’s Equity Incentive Plan. Options were granted on May 16, 2002, and have a three-year vesting schedule pursuant to which one-third of the options become exercisable on each of Jan. 1, 2003; Jan. 1, 2004; and Jan. 1, 2005. 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.

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

 

The following table provides information for the executives named below regarding options exercised in 2005 and the number and value of exercisable and unexercisedunexercisable options. None of the executives exercised options in fiscal year 2002.

 

AGGREGATE OPTION EXERCISES IN 2005 AND OPTION VALUES AT DEC. 31, 20022005


 


    

Number of Securities Underlying

Unexercised Options at Fiscal Year End

    

Value of Unexercised

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


 

Shares
Acquired

on Exercise

 

Value
Realized

($)

 Number of Securities
Underlying Unexercised
Options at Fiscal Year End
 

Value of Unexercised

In-the-Money Options

at Year End(1)

Name

    

Exercisable

    

Unexercisable

 

Shares
Acquired

on Exercise

 

Value
Realized

($)

 Exercisable Unexercisable  Exercisable  Unexercisable

Erroll B. Davis, Jr.

    

264,715

    

261,385

    

$

0

    

$

0


Erroll B. Davis, Jr.(2)

 0 $0 667,564 157,442 $1,335,742 $893,706

William D. Harvey

    

64,235

    

48,195

    

 

0

    

 

0

 0  0 149,975 57,851  275,089  237,949

Eliot G. Protsch

    

64,235

    

48,195

    

 

0

    

 

0

 0  0 139,156 36,212  245,449  178,668

Thomas M. Walker

    

48,322

    

46,432

    

 

0

    

 

0


Pamela J. Wegner

    

51,544

    

46,432

    

 

0

    

 

0


Barbara J. Swan

 0  0 110,644 29,585  130,857  156,959

Thomas L. Aller

 0  0 86,135 20,249  156,466  108,568

 

(1)Based on the closing per share price of AEC’sAEC common stock on Dec. 31, 2002.30, 2005 (the last trading day of the year) of $28.04.

 

(2)Pursuant to the terms of his stock option award agreements, all of Mr. Davis’ unvested stock options vested immediately upon his retirement on Feb. 1, 2006, and he has three years from such date to exercise his vested stock options.

12


LONG-TERM INCENTIVE AWARDS

 

The following table provides information concerning long-term incentive awards made to the executives named below in 2002.2005.

 

LONG-TERM INCENTIVE AWARDS IN 20022005


 


Name

    

Number of

Shares,

Units or

Other Rights

(#)(1)

    

Performance

or Other

Period Until

Maturation

or Payout

  

Estimated Future Payouts Under

Non-Stock Price-Based Plans

  Number of
Shares, Units

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

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

Threshold

(#)

  

Target

(#)

  

Maximum

(#)


Erroll B. Davis, Jr.

    

29,579

    

1/01/05

  

14,790

  

29,579

  

59,158


Erroll B. Davis, Jr.(2)

  33,027  1/1/2008  16,514  33,027  66,054

William D. Harvey

    

5,937

    

1/01/05

  

2,969

  

5,937

  

11,874

  15,561  1/1/2008  7,781  15,561  31,122

Eliot G. Protsch

    

5,937

    

1/01/05

  

2,969

  

5,937

  

11,874

  9,509  1/1/2008  4,755  9,509  19,018

Thomas M. Walker

    

5,721

    

1/01/05

  

2,861

  

5,721

  

11,442


Pamela J. Wegner

    

5,721

    

1/01/05

  

2,861

  

5,721

  

11,442


Barbara J. Swan

  6,669  1/1/2008  3,335  6,669  13,338

Thomas L. Aller

  3,458  1/1/2008  1,729  3,458  6,916

 

(1)Consists of performance shares awarded underas part of AEC’s Long-Term Equityannual Long Term Incentive Plan.(“LTI”) grant. The payout from the performance shares is based on two equally-weighted performance components: AEC’s three-year Total Shareowner Return (TSR)(“TSR”) relative to an investor-owned utilitya peer group and annualized earnings per share growth versus internally set performance hurdles contained in(defined as those companies comprising the Alliant Energy Strategic PlanStandard & Poor’s (“S&P”) Midcap Utilities Index) during the three-year performance cycle ending Dec. 31, 2004.2007. 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, cash or a combination of AEC common stock and cash.

(2)Pursuant to the terms of his performance share award agreement, Mr. Davis’ shares are to be prorated based upon the number of months he was actively working during the performance period, provided that the performance criteria are satisfied and there is a payout at all.

CERTAIN AGREEMENTS

 

Mr. Davis hasDavis’ position as Chairman of the Board was subject to an employment agreement with AEC, pursuant to which he willwould serve as the Chairman President and Chief Executive Officer of AEC until the expiration of the current term of the agreement on April 21, 2004. Thereafter,the date of AEC’s 2006 Annual Meeting, but no later than May 30, 2006. In addition, he was to serve as the Chief Executive Officer of AEC during the term of the agreement will automatically renew for successive one-year terms, unless eitherotherwise determined by the Board of Directors. Under the employment agreement, Mr. Davis or AEC gives prior written notice of his or its intent to terminate the agreement. Mr. Davis willwould also serve as the Chief Executive Officer of the Company, IP&L and a DirectorResources as long as he held the same position for AEC. On July 1, 2005, AEC’s Board of each subsidiaryDirectors appointed Mr. Harvey as the Chief Executive Officer and President of AEC includingand the Company’s Board of Directors appointed Mr. Harvey as the Chief Executive Officer of the Company. Mr. Davis remained Chairman of the Board of AEC, the Company, during the term of his employment agreement.IP&L and Resources. Pursuant to Mr. Davis’the employment agreement, he isMr. Davis was paid an annual base salary of not less than $450,000.$750,000. Mr. Davis’ current salary underDavis retired and resigned from his position as Chairman of the Board effective Feb. 1, 2006. Under the employment agreement, is $685,000. Mr. Davis also haswas afforded the opportunity to earn short-term and long-term incentive compensation (including stock options, restricted stock and other long-term incentive compensation) at least equal to other executive officers and receive supplemental retirement benefits (including continued participation in the Company’sAlliant Energy Corporation Executive Tenure Compensation Plan) and life insurance providing a death benefit of three times his annual salary. IfIn conjunction with Mr. Davis’ retirement, 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), no bonus for 2005, and a pro-rata bonus of $104,000 for 2006, which has been deemed to be the estimated target award. 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. 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 determined to treat Mr. Davis as an eligible retiree at the termination of his employment, regardless of the circumstances other than death. The voluntary retirement of Mr. Davis is terminatedwas considered a termination of employment without cause (as defined in the employment agreement) or if Mr. Davis terminates his employment for good reason (as defined in the employment agreement), AEC or its affiliates will continueprior to provide the compensation and benefits called for by the employment agreement through the end of the term of suchthe employment agreement (with incentive compensation based on the maximum potential awards and with any stock compensationagreement. Therefore, AEC paid in cash), and all unvested stock compensation will vest immediately. If Mr. Davis dies or becomes disabled, or terminates his employment without good reason, during the term of his respective employment agreement, AEC or its affiliates will pay to Mr. Davis or his beneficiaries or estate all compensation earned through the date of death, disability or such terminationFeb. 1, 2006 (including previously deferred compensation

13


and pro rata short-term incentive compensation of $104,000 based upon the maximum potential awards)award). If Mr. Davis is terminatedalso eligible for cause, AEC or its affiliates will pay his base salary through the date of termination plus any previously deferred compensation. Under Mr. Davis’ employment agreement, if any payments thereunder constitute an excess parachute paymentbenefits he has accrued under the Internal Revenue Code (the “Code”), AEC will pay to Mr. Davisapplicable retirement plans, including the amount necessary to offsetbenefits under the excise taxSupplemental Executive Retirement Plan and any applicable taxes on this additional payment.the Executive Tenure Compensation Plan.

 

AEC currently has in effect key executive employment and severance agreements (the “KEESAs”) with certainits executive officers and certain key employees of AEC (including Messrs. Davis, Harvey, Protsch Walkerand Aller and Ms. Wegner)Swan). The KEESAs provide that each executive officer who is a party thereto is entitled to benefits if, within a period of up to three years (depending on which executive is involved) after a change in control of AEC (as defined in the KEESAs) (the “Employment Period”), the officer’s employment is ended through (a) termination by AEC, other than by reason of death or disability or for cause (as defined in the KEESAs); or (b) termination by the officer due to a breach of the agreement by AEC or a significant change in the officer’s responsibilities; or (c) in the case of Mr. Davis’ agreement, termination by Mr. Davis following the first anniversary of the change of control. Theresponsibilities.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 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 Chairman, Chief Executive Officer, and thePresident, Senior Executive Vice PresidentsPresident, Executive Vice President and Senior Vice President (including Messrs. Davis, Harvey, Protsch Walkerand Aller and Ms. Wegner)Swan) provide that if any payments thereunder or otherwise constitute an excess parachute payment, AEC will pay to the appropriate officer the amount necessary to offset the excise tax and any additional taxes on this additional payment. Mr. Davis’ employment agreement as described above limits benefits paid thereunder to the extent that duplicate payments would be provided to him under his KEESA.KEESA terminated on Feb. 1, 2006.

 

14


 

RETIREMENT AND EMPLOYEE BENEFIT PLANS

 

Alliant Energy Cash Balance Pension Plan

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

 

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

 

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

 

Company Plan A Prior Formula.

One of the applicable prior plan formulas provided retirement income based on years of credited service and final average compensation for the 36 highest consecutive months, with a reduction for Social Security offset. The individuals listed in the Summary Compensation Table covered by this formula are Messrs. Davis, Harvey and Protsch and Ms. Wegner.Swan. The following table illustrates the estimated annual benefits payable upon retirement at age 65 under the prior plan formula based on average annual compensation and years of service. 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., 2326 years; William D. Harvey, 1518 years; Eliot G. Protsch, 2326 years; and PamelaBarbara J. Wegner, 8Swan, 17 years.

 

IES Industries Pension Plan Prior Formula.

Another of the The other applicable prior plan formulasformula provided retirement income based on years of service and final average compensation for the highest consecutive 36 months outcompensation. Mr. Aller has a frozen benefit of the last 10 years of employment. The only individual listed in the Summary Compensation Table covered by$7,608 annually under this prior formula which is Mr. Walker. The benefits would be as follows:payable at age 65.

 

IES Industries Pension Plan Prior Formula Table15

Average Annual

Compensation


  

Annual Benefit After Specified Years in Plan


  

15


  

20


  

25


  

30


  

35


$200,000

  

$

43,541

  

$

58,056

  

$

72,570

  

$

87,083

  

$

101,597

300,000

  

 

66,792

  

 

89,056

  

 

111,320

  

 

133,583

  

 

155,847

400,000

  

 

90,042

  

 

120,056

  

 

150,070

  

 

180,083

  

 

210,097

500,000

  

 

113,292

  

 

151,056

  

 

188,820

  

 

226,583

  

 

264,347

600,000

  

 

136,542

  

 

182,056

  

 

227,569

  

 

273,083

  

 

318,597

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. Walker has six years of credited service under the Pension Plan.


 

Unfunded Excess Plan—Alliant Energy

Corporate Services maintains an Unfunded Excess Plan that provides funds for payment of retirement benefits above the limitations on payments from qualified pension plans in those cases where an employee’s retirement benefits exceed the qualified plan limits. The Unfunded Excess Plan provides an amount equal to the difference between the actual pension benefit payable under the Pension Plan and what such pension benefit would be if calculated without regard to any limitation imposed by the Code on pension benefits or covered compensation. Upon Mr. Davis’ retirement on Feb. 1, 2006, his vested benefit had a lump sum value of $3,003,018. A portion of Mr. Davis’ benefit was paid on Feb. 1, 2006, and the remaining balance is payable on Aug. 1, 2006.

 

Unfunded Executive Tenure Compensation Plan—Alliant Energy

Corporate Services maintains an Unfunded Executive Tenure Compensation Plan to provide incentive for selected key executives to remain in the service of AEC by providing additional compensation that is payable only if the executive remains with AEC until retirement (orother termination if approved by the Board of Directors). In the caseDirectors of the Chief Executive Officer only, in the event that the Chief Executive Officer (a) is terminated under his employment agreement with AEC as described above other than for cause, death or disability (as those terms are defined in the employment agreement); (b) terminates his employment under the employment agreement for good reason (as such term is defined in the employment agreement); or (c) is terminated as a result of a failure of the employment agreement to be renewed automatically pursuant to its terms (regardless of the reason for such non-renewal), then for purposes of the Plan, the Chief Executive Officer shall be deemed to have retired at age 65 and shall be entitled to benefits under the Plan.AEC). Any participant in the Plan must be approved by the Board of Directors. Mr. Davis was the only active participant in the Plan as of Dec. 31, 2002.2005. The Plan provides for monthly payments to a participant after retirement (at or after age 65, or with AEC 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 would be$184,620 are payable to Mr. Davis upon retirement, assuming he continues in Alliant Energy Corporate Services’ service until retirement at the same salary as was in effectcommencing on Dec. 31, 2002.Sept. 1, 2006.

 

Supplemental Executive Retirement Plan

AEC maintains an unfunded Supplemental Executive Retirement Plan (“SERP”) to provide incentive for key executives to remain in the service of AEC by providing additional compensation that is payable only if the executive remains with AEC until retirement, disability or death. While the SERP provides different levels of benefits depending on the executive covered, this summary reflects the terms applicable to all of the individuals listed in the Summary Compensation Table. Participants in the SERP must be approved by the Compensation and Personnel Committee of the Board. The

For Messrs. Davis, Harvey and Protsch, and Ms. Swan, the SERP provides for payments of 60% of the participant’s average annual earnings (base salary and bonus) for the highest paid three years out of the last 10 years of the participant’s employment reduced by the sum of benefits payable to the officer from the officer’s defined benefit plan and the Unfunded Excess Plan. The normal retirement date under the SERP is age 62 with at least 10 years of service and early retirement is at age 55 with at least ten10 years of service. If a participant retires prior to age 62, the 60% payment under the SERP isreducedis reduced by 3% per year for each year the participant’s retirement date precedes his or his/her normal retirement date. The actuarial reduction factor will be waived for participants who have attained age 55 and have a minimum of 10 years of service in a senior executive position with AEC after April 21, 1998. At the timely election of the participant, benefits under the SERP will be made in a lump sum, in installments over a period of up to 10 years, or for the lifetime of the participant. If the lifetime benefit is selected and the participant dies prior to receiving 12 years of payments, payments continue to any surviving spouse or dependent children of a deceased participant who dies while still employed by AEC, payable for a maximum of 12 years. A post-retirement death benefit of one times the participant’s final average earnings at the time of retirement will be paid to the designated beneficiary. Messrs. Davis, Harvey, Protsch, Walker and Ms. 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.

16


Upon Mr. Davis’ retirement on Feb. 1, 2006, his benefit had a lump sum value of $5,517,280, payable on January 1, 2007.

For Mr. Aller, the SERP provides for payments of 50% 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 10 years of service and five or more years of continuous SERP employment. If a participant retires prior to age 62, the 50% payment under the SERP is reduced by 5% per year for each year the participant’s retirement date precedes his/her normal retirement date. At the timely election of the participant, benefits under the SERP will be made in a lump sum, in annual installments over a period of up to 10 years, or in monthly installments for 18 years. If the monthly installment option is selected and the participant dies prior to receiving 12 years of payments, payments continue to any surviving spouse or dependent children of a deceased participant who dies while still employed by AEC, payable for a maximum of 12 years. 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

  <10 Years

  >10 Years*

$   200,000

  0  $100,000

     300,000

  0   150,000

     400,000

  0   200,000

     500,000

  0   250,000

     600,000

  0   300,000

     700,000

  0   350,000

     800,000

  0   400,000

     900,000

  0   450,000

  1,000,000

  0   500,000

  1,100,000

  0   550,000

* 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 (“KEDCP”) 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.KEDCP. 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;the KEDCP; 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 AECa Company Stock Account. Deferrals and matching contributions to the Interest Account receive an annualreturn based on the A-Utility Bond Rate with a minimum return no less than the prime interest rate published inThe Wall Street Journal, provided that the return may not be greater than 12% or less than 6%. Deferrals and matching contributions credited to the AEC Stock Account are treated as though invested in AECthe common stock of AEC and will be credited with dividends,dividend equivalents, which will be treated as if reinvested. The shares of common stock identified as obligations under the PlanKEDCP are held in a rabbi trust. Payments from the PlanKEDCP may be made in a lump sum or in annual installments for up to 10 years at the election of the participant. Participants are selected by the Chief Executive Officer of Alliant Energy Corporate Services. Messrs. Davis, Harvey, Protsch Walkerand Aller, and Ms. WegnerSwan are participants in the Plan.KEDCP. Prior to his retirement, Mr. Davis was a participant in the KEDCP and he will receive distributions from the KEDCP in accordance with his prior elections.

17


REPORT OF THE COMPENSATION AND PERSONNEL

COMMITTEE ON EXECUTIVE COMPENSATION

 

To Our Shareowners:

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

 

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

 

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

 

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

 

·Total compensation should enhance the Company’s ability to attract, retain and encourage the development of exceptionally knowledgeable and experienced executives, upon whom, in large part, the successful operation and management of the Company depends.
Total compensation should enhance the Company’s ability to attract, retain and encourage the development of exceptionally knowledgeable and experienced 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 executives of comparable companies. Specifically, the Committee targets the median (50th) percentile of base salaries paid by a selected group of utility and general industry companies.
Base salary levels should be targeted at a competitive market range of base salaries paid to executive officers of comparable companies. Specifically, the Company 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 meetingpredetermined corporate, subsidiary, business unit and individual performance goals. In addition, the Committee targets incentive levels at the median (50th percentile) of incentive compensation paid by a selected group of utility and general industry companies.
Incentive compensation programs should strengthen the relationship between pay and performance by emphasizing variable at-risk compensation that is consistent with meeting predetermined Company, subsidiary, business unit and individual performance goals. The Committee targets incentive levels at the median (50th percentile) of incentive compensation paid by companies of similar revenue base within the utility and general industries.

 

Components of Compensation

The major elements of theAEC’s executive compensation program are base salary, short-term (annual) incentives, and long-term (equity) incentives.incentives and other benefits. These elements are addressed separately below. In 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. For 2005, the Committee has determined that total executive compensation at target levels including that for Mr. Davis, iswere in line with competitive compensation rates at comparable 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 comparison groupsecond to last Committee meeting of companies.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 in 2005 for assessing compensation includes, but is somewhat broader than, the industry index used in the cumulative total shareowner return graph in this proxy statement. The Committee annually adjusts base salaries to recognize changes in

18


the market, AEC performance, varying levels of responsibility, and the 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, although the Committee does not consideralso considers individual performance factors in setting base salaries. The Committee reviewed executive salaries for market comparability using utility and general industry data contained in compensation surveys published by Edison Electric Institute, American Gas Association and several compensation consulting firms. Based on the foregoing and market conditions, the Committee established the annual salary for Mr. Davis at $685,000 for the 2002 fiscal year.

 

In consideration of industry conditionsBased on this data and corporate performance,consultation with the independent executive compensation consultant, the Committee determined that the Chief Executive Officer and the Executive Vice Presidents would not receive aapproved base salary increaseincreases for 2003.the Company’s executive officers in 2005.

 

Short-Term Incentives

TheAEC’s short-term (annual) incentive program promotes the Committee’s pay-for-performance philosophy by providing executivesexecutive officers with direct financial incentives in the form of annual cash bonuses tied to the achievement of corporate, subsidiary, business unitAEC financial goals 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 on an annual basis reviews and approves the program’s performance goals on an annual basis, the relative weight assigned to each goal and the targeted and maximum award levels. A description of the short-term incentive programsprogram available during 20022005 to executive officers follows.

 

Alliant Energy Corporation Management Incentive Compensation PlanIn 2002,2005, the Alliant Energy Corporation Management Incentive Compensation Plan (the “MICP”) covered executivesexecutive officers and was based on achieving annual targets in corporate performance that included earnings per share (“EPS”), safety, diversity and environmental targets for the utility businesses,AEC’s financial and business unit performance. AEC financial performance was gauged on EPS and individualcash flows from continuing operations and was used to determine an overall pool of available incentive dollars under the MICP. If a pre-determined EPS target is not met, there is no funding for the plan and no bonus payment associated with the MICP, unless the Committee determines otherwise. If that threshold is met, the pool of dollars available for awards is allocated to executive officers on a pro forma basis (base salary x target incentive percent x corporate performance goals.modifier). Executive officers’ pro forma awards are then subject to adjustment upward or downward based on each individual’s achievement on financial and operational measures specific to his or her business unit such as safety, reliability and customer service. Adjustments are made at the discretion of the CEO and are reviewed and approved by the Committee. Target and maximum bonus awards under the MICP in 20022005 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 EPS 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 percentageMICP targets ranged from 80% of base salary paid asfor Messrs. Davis and Harvey to 30-65% of base salary for other executive officers, with a bonus, within the allowable range, is equal to the weighted average percent achievementmaximum possible payout for all the performance categories. Potential MICP awards range from 0% to 100%

of annual salary for eligible executives other than Mr. Davis.two times their target percentage.

 

In 2002, Mr. Davis was covered by the MICP. Awards for Mr. DavisFor 2005, AEC’s EPS minimum target under the MICP in 2002 were based on corporate and strategic goal achievement in relation to predetermined goals. For each plan year,was not met. However, the Committee determinesassessed the performance apportionment for Mr. Davis. In 2002, that apportionment was 80% for corporate performance and 20% for strategic goal performance. Corporate performance is measured based on corporate-wide EPS, environmental, diversity and safety targets established at the beginningnegative impact of the year. Strategic goals are measured basedBrazil business on overall AEC EPS relative to the achievement of certain specific goals, which included strategy developmentCompany’s and implementation, established for Mr. Davis by the Committee. The 2002 MICP award range for Mr. Davis was from 0% to 150% of annual salary.

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

Due to industry and market conditions and overall corporate performance,IP&L’s strong utility performance. Based on that review, the Committee determined in February 2006 that the Chief Executive Officerbonus payments for 2005 MICP plan year performance were warranted for certain executive officers. Actual payments were approximately 55% of target for named officers, except that Messrs. Davis and Executive Vice Presidents will participate in the MICP, but willHarvey did not receive MICP awards, if earned, for 2003 plan year performance.any payment.

 

Long-Term Incentives

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

Alliant Energy Corporation Long-Term Incentive Program—The Alliant Energy Corporation Long-Term Incentive Program covered executives and consisted of the following components in 2002: non-qualified stock options and performance shares. Non-qualified stock options provide a reward that is directly tied to the benefit shareowners receive from increases in the price of AEC’s common stock. The payout from the performance shares is based on two equally-weighted performance components: AEC’s three-year total return to shareowners relative to an investor-owned utility peer group (TSR), and annualized EPS growth versus internally set performance hurdles contained in the Alliant Energy Strategic Plan. Thus, the two components of the Long-Term Incentive Program (i.e., stock options and performance shares) provide incentives for management to produce superior shareowner returns on

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

 

In determining actual award levels under the Alliant Energy Corporation Long-Term Incentive Program (“LTIP”), the Committee was primarily concerned with providing asought to provide competitive total compensation opportunity levelopportunities to officers.executive officers while also taking performance factors into account. As such, award levels (including awards made to Mr. Davis)for 2005 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, as well as the competitiveness of the total compensation package. The Committee then established award rangespackage 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.Company 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 to executive officers during 2005 is set forth below.

LTIP –The Committee did not consider the amountsLTIP for 2005 consisted of optionsgrants of performance-contingent restricted stock and performance shares already outstanding or previouslyto all executive officers, including Messrs. Davis, Harvey, Protsch and Aller, and Ms. Swan. The Committee also granted when making awards for 2002. Mr. Davis’ awardsMessrs.

19


Harvey and Protsch time-based restricted stock to recognize their strong performance and to help ensure that they will be members of the Company’s management team in 2002 underthe future.

The vesting of the performance-contingent restricted stock granted in 2005 is based on AEC’s EPS growth. Specifically, the stock vests if AEC achieves a 16% growth in EPS within four years. In no case may the stock vest earlier than two years, and all shares will be forfeited if the EPS target is not met at the four-year mark.

Payout of performance shares granted in 2003, 2004 and 2005 is based on AEC’s three-year Total Shareowner Return (TSR) relative to a defined peer group. For 2003 and 2004, the peer group was all major publicly traded utilities. For 2005, the peer group is companies comprising the S&P Midcap Utilities Index. Thus, the Committee believes the two components of the Long-Term Incentive Program are shown in the tables under “Stock Option Grants in 2002”(i.e., performance-contingent restricted stock and “Long-Term Incentive Awards in 2002.”performance shares) provide incentives for management to create value and produce superior shareowner returns on both an absolute and relative basis.

 

Due to the corporate EPS and TSR goals notgoal being achieved, there was noa performance share payout of 175% of target for the 2003 grant which had a three-year cycle ending in December 2005. The Committee approved the awards in January 2006 and paid them out in that same month.

In addition to performance-contingent restricted stock and performance share portionshares, the Committee awarded Messrs. Harvey and Protsch grants of time-based restricted stock in July 2005. Mr. Harvey’s award consisted of 34,880 shares of restricted stock valued at $1,000,000, vesting as follows: 20% on the third anniversary of the Long-Termgrant date; 40% on the fourth anniversary of the grant date; and 40% on the fifth anniversary of the grant date. Mr. Protsch’s award consisted of 17,440 shares of restricted stock valued at $500,000, vesting as follows: 20% on the third anniversary of the grant date; 30% on the fourth anniversary of the grant date; and 50% on the fifth anniversary of the grant date. These grants coincided with the promotions of Messrs. Harvey and Protsch to their respective new roles. The Committee decided to grant the awards for the purpose of recognizing and retaining these key individuals and bringing their compensation closer in line with competitive market rates.

Performance-contingent restricted stock and performance shares will comprise the total long-term incentive target award for 2006 as well.

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, SERP and KEDCP – all as described in the Retirement and Employee 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. In 2006, executive officers were moved into AEC’s broad-based Employee Health Care Plan.

Certain executive officers receive individually owned life insurance policies. Premiums paid by AEC for this insurance were taxed as bonuses to the individual officers in 2005.

Compensation of the Chief Executive Officer

When determining the compensation package of the CEO, the Committee follows the same general policies that guide compensation decisions for other executive officers. Thus, the Committee based Mr. Harvey’s award levels on an analysis of similarly sized utility and general industry companies that took into consideration the competitiveness of the total compensation package, as well as AEC performance.

As was the case for other executive officers, Mr. Harvey – Chief Operating Officer at the beginning of 2005 – received a base salary increase in February 2005 to $490,000 from his previous level of $475,000, which had been in effect for 2004. The Committee approved the salary increase based on its evaluation of Mr. Harvey’s performance and on a review of competitive data for his position at that time. Upon Mr. Harvey being named CEO in July 2005, he received a base salary increase to $700,000, with the Committee again approving the increase based on a review of competitive data and taking into account Mr. Harvey was new to the CEO position.

For 2005, Mr. Harvey’s target long-term incentive percentage was increased with his appointment to CEO from 150% of base salary to 200% of base salary, with the total award comprising performance shares and performance-contingent restricted stock. In addition to these grants, the Committee also approved a grant of time-based restricted stock for recognition and retention purposes, as described in “Long-Term Incentives” above. All of Mr. Harvey’s 2005 awards under the long-term incentive program are also shown in the table under “Long-Term Incentive Program’s three-year cycleAwards in 2005.”

20


For 2005, Mr. Harvey’s target short-term incentive percentage was increased with his appointment to CEO from 65% of base salary to 80% of base salary. As was noted earlier, however, while the Committee made other executive officers eligible for short-term incentive payouts under the 2005 MICP, Mr. Harvey did not receive an award, based on AEC’s performance on the corporate financial goals described above, specifically EPS.

Compensation of the Chairman of the Board (formerly Chairman and CEO)

Mr. Davis – Chairman and CEO at the beginning of 2005 – received a base salary increase in February 2005 to $780,000 from his previous level of $750,000, which had been in effect for 2004. The Committee approved the salary increase based on its evaluation of Mr. Davis’ performance and on a review of competitive data for his position at that endedtime.

Upon Mr. Davis’ transition out of the CEO role into strictly the Chairman role, the Committee determined that no changes to his compensation would be made at that time. As described in Dec. 2002.the “Certain Agreements” section of this proxy statement, Mr. Davis already had an employment agreement with AEC in place to cover his compensation in the event of various contingencies and pending his retirement.

For 2005, Mr. Davis’ target long-term incentive percentage was maintained at 200% of base salary, the same as it had been for 2004, with the total award comprising performance shares and performance-contingent restricted stock. All of Mr. Davis’ 2005 awards under the long-term incentive program are shown in the table under “Long-Term Incentive Awards in 2005.”

For 2005, Mr. Davis’ target short-term incentive percentage was also maintained at the 2004 level of 80% of base salary. Based on AEC’s performance on the corporate financial goals, specifically EPS, Mr. Davis did not receive a 2005 short-term incentive award.

Share Ownership Guidelines

AEC has established share ownership guidelines for executive officers as a way to better align the financial interests of its officers with those of its shareowners. Under these guidelines, the requisite ownership numbers are 85,000 shares for the Chief 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 five-year period from the effective date of becoming an officer. The Chief Executive Officer retains the right to grant special dispensation for hardship, promotions or new hires.

 

Policy with Respect to the $1 Million Deduction Limit

Section 162(m) of the Code generally limits the corporate deduction for compensation paid to executive officers named in the proxy statement to $1 million, unless such compensation is based upon performance objectives meeting certain regulatory criteria or is otherwise excluded from the limitation. Based on the Committee’s commitment to link compensation with performance as described in this report, the Committee intends to qualify future compensation paid to the Company’s executive officers for deductibility by the Company under Section 162(m) except in limited appropriate circumstances. All taxable income for 2005 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. ArendsMichael L. Bennett

Jack B. EvansDean C. Oestreich

David A. Perdue

21


REPORT OF THE AUDIT COMMITTEE

 

To Our Shareowners:

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

 

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

 

The Company’s independent auditors haveregistered public accounting firm has 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 theirregistered public accounting firm its independence.

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

 

The principal accounting fees that were billed to the Company by its independent registered public accounting firm for work performed on behalf of the Company and AEC paid to its independent auditorssubsidiaries for 20012004 and 2002 for the Company and AEC2005 were as follows:

 

   

2001


  

2002


 

Audit Fees

  

$

1,194,000

  

$

2,843,000

(1)

Audit Related Fees(2)

  

 

146,000

  

 

19,000

 

Tax Fees(3)

  

 

491,000

  

 

1,125,000

 

All Other Fees(4)

  

 

36,000

  

 

297,000

 


(1)Includes approximately $1.4 million for 2000 and 2001 re-audit fees.
   2004

  2005

Audit Fees

  $        987,000  $        892,000

Audit-Related Fees

   348,000   33,000

Tax Fees

   70,000   77,000

All Other Fees

   22,000   25,000

 

Audit Fees consisted of the fees billed for the audit of (i) the consolidated financial statements of the Company and its subsidiaries, (ii) management’s assessment of the effectiveness of AEC’s internal controls over financial reporting; and (iii) the effectiveness of AEC’s internal controls over financial reporting, reviews of financial statements included in Form 10-Q filings and services normally provided in connection with statutory and regulatory filings such as financial transactions.

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

 

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

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

 

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

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

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


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

 

The Committee discussed with the Company’s internal auditor and independent auditorsregistered public accounting firm the overall scopes and plans for their respective audits. The Committee meets with the internal auditor and independent auditors,registered public accounting firm, 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 auditorsauditor and the independent auditorsregistered public accounting firm referred to above, the Committee recommended to the Board of Directors that the audited consolidated financial statements be included in the Company’s Annual Report on Form 10-K for the year ended Dec. 31, 2002,2005, for filing with the SEC.

 

AUDIT COMMITTEE

Jack B. EvansMichael L. Bennett (Chairperson)

Alan B. Arends

Katharine C. Lyall

Singleton B. McAllister

Ann K. Newhall

David A. Perdue

Carol P. Sanders

22


PROPOSAL FOR THE RATIFICATION OF THE APPOINTMENT

OF DELOITTE & TOUCHE LLP AS THE COMPANY’S

INDEPENDENT REGISTERED PUBLIC ACCOUNTING FIRM

In accordance with its charter, the Audit Committee of the Board of Directors appointed the firm of Deloitte & Touche LLP, independent registered public accounting firm, to audit the consolidated financial statements of the Company and its subsidiaries for the year ending Dec. 31, 2006 and is requesting that its shareowners ratify such appointment.

Representatives of Deloitte & Touche LLP are not expected to attend the annual meeting. Further information about the services of Deloitte & Touche LLP, including the fees paid in 2004 and 2005, is set forth in the “Report of the Audit Committee.”

Vote Required

The affirmative vote of a majority of the votes cast on the proposal at the Annual Meeting (assuming a quorum is present) is required to ratify the appointment of Deloitte & Touche LLP as the Company’s independent registered public accounting firm. For purposes of determining the vote required for this proposal, abstentions and broker nonvotes will have no impact on the vote. The votes represented by proxies will be voted FOR ratification of the appointment of Deloitte & Touche LLP as the Company’s independent registered public accounting firm, unless a vote against such approval or to abstain from voting is specifically indicated on the proxy. If the appointment is not ratified by a majority of the votes cast, the adverse vote will be considered as an indication to the Audit Committee that it should consider selecting another independent registered public accounting firm for the following fiscal year. Even if the appointment is ratified, the Audit Committee, in its discretion, may select a new independent registered public accounting firm at any time during the year if it feels that such a change would be in the best interest of the Company.

The Board of Directors recommends that shareowners vote FOR the ratification of the appointment of Deloitte & Touche LLP as the Company’s independent registered public accounting firm for 2006.

23


SECTION 16(a) BENEFICIAL OWNERSHIP

REPORTING COMPLIANCE

 

TheSection 16(a) of the Securities Exchange Act of 1934 requires the Company’s Directors, its executive officersdirectors and certain other officers are required to report theirfile reports of ownership and changes in ownership of the Company’s Preferredpreferred stock with the SEC. As a matter of practice, the Company’s Shareowner Services Department assists the Company’s reporting persons in preparing initial reports of ownership and anyreports of changes in that ownership and files those reports on their behalf. The Company is required to disclose in this proxy statement the SEC and the New York Stock Exchange. To the bestfailure of the Company’s knowledge, all requiredfilings in 2002 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 reporting persons involved and on copies of theirthe reports filed with the SEC.SEC, the Company believes that all reporting persons of the Company satisfied these filing requirements in 2005.

 

By Order of the Board of Directors,

LOGO

F. J. Buri

Corporate Secretary

 

24


APPENDIX A – AUDIT COMMITTEE CHARTER

Purposes and Role of Committee

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

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

Committee Membership

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

Committee Structure and Operations

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

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

Committee Duties

The duties of the Committee are to:

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

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

3.

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

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

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

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

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

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

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

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

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

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

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

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

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

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

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

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

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

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

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

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

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

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

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

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

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

Committee Reports

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

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

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

Resources and Authority of the Committee

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

APPENDIX B – WISCONSIN POWER AND LIGHT COMPANY

ANNUAL REPORT

For the Year Ended December 31, 20022005

 

Contents


Page


DefinitionsContents

  

B-2

Page

The Company

  

B-3

A-2

Selected Financial Data

  

B-3

A-2

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

  

B-4

A-3

Report of Independent Auditors’ ReportRegistered Public Accounting Firm

  

B-15

A-20

Consolidated Financial Statements

  A-21

Consolidated Statements of Income

  

B-17

A-21

Consolidated Balance Sheets

  

B-18

A-22

Consolidated Statements of Cash Flows

  

B-20

A-24

Consolidated Statements of Capitalization

  

B-21

A-25

Consolidated Statements of Changes in Common Equity

  

B-22

A-26

Notes to Consolidated Financial Statements

  

B-23

A-27

Shareowner Information

  

B-37

A-47

Executive Officers and Directors

  

B-37

A-48

 

DEFINITIONSA-1


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

Abbreviation or Acronym


Definition


AFUDC

Allowance for Funds Used During Construction

Alliant Energy

Alliant Energy Corporation

ATC

American Transmission Company, LLC

CAA

Clean Air Act

Corporate Services

Alliant Energy Corporate Services, Inc.

DNR

Department of Natural Resources

Dth

Dekatherm

EPA

U.S. Environmental Protection Agency

FASB

Financial Accounting Standards Board

FERC

Federal Energy Regulatory Commission

FIN

FASB Interpretation No.

FIN 45

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

FIN 46

Consolidation of Variable Interest Entities

GAAP

Accounting Principles Generally Accepted in the U.S.

ICC

Illinois Commerce Commission

IES

IES Industries Inc.

IESU

IES Utilities Inc.

IPC

Interstate Power Company

IP&L

Interstate Power and Light Company

Kewaunee

Kewaunee Nuclear Power Plant

KWh

Kilowatt-hour

MD&A

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

MGP

Manufactured Gas Plants

Moody’s

Moody’s Investors Service

MW

Megawatt

MWh

Megawatt-hour

NEPA

National Energy Policy Act of 1992

PSCW

Public Service Commission of Wisconsin

PUHCA

Public Utility Holding Company Act of 1935

Resources

Alliant Energy Resources, Inc.

SEC

Securities and Exchange Commission

SFAS

Statement of Financial Accounting Standards

SFAS 115

Accounting for Certain Investments in Debt and Equity Securities

SFAS 133

Accounting for Derivative Instruments and Hedging Activities

SFAS 143

Accounting for Asset Retirement Obligations

South Beloit

South Beloit Water, Gas and Electric Company

TBD

To Be Determined

U.S.

United States of America

WP&L

Wisconsin Power and Light Company

WPLH

WPL Holdings, Inc.

WP&LLight Company (WPL) filed a combined Form 10-K for 20022005 with the SEC;Securities and Exchange Commission (SEC); 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 COMPANY

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

WP&LOverview - WPL was incorporated in Wisconsin1917 in 1917Wisconsin as Eastern Wisconsin Electric Company andCompany. WPL is a public utility engaged principally in the generation, distribution and sale of electric energy; and the purchase, distribution, transportation and sale of natural gas; and the provision of water servicesgas in selective markets. Nearly all of WP&L’sWPL’s customers are located in south and central Wisconsin. WP&LWPL operates in municipalities pursuant to permits of indefinite duration, which are regulated by Wisconsin law. At Dec. 31, 2002, WP&L2005, WPL supplied electric and gas service to 430,406452,679 and 170,123179,289 (excluding transportation and other) customers, respectively. WP&LWPL also had 19,527 water customers.provides various other energy-related products and services. In 2002, 20012005, 2004 and 2000, WP&L2003, WPL had no single customer for which electric, gas and/or waterother sales accounted for 10% or more of WP&L’sWPL’s consolidated revenues. WPL Transco LLC is a wholly-owned subsidiary of WP&LWPL and holds WP&L’sWPL’s investment in ATC. WP&LAmerican Transmission Company LLC (ATC). WPL also owns all of the outstanding capital stock of South Beloit Water, Gas and Electric Company (South Beloit), which was incorporated in 1908. South Beloit is a public utility supplying electric, gas and water service, principally in Winnebago County, Illinois, and 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.WPL is divesting.

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

WPL is also subject, but not limited, to regulation by the Illinois Commerce Commission, the Federal Energy Regulatory Commission (FERC) and the United States of America (U.S.) Environmental Protection Agency (EPA).

Electric Utility Operations - As of Dec. 31, 2002, WP&L2005, WPL provided retail electric service to 428,390450,628 retail, 31 wholesale and 2,020 other customers 602 communities and 30 wholesale customers. 2002in 610 communities. 2005 electric utility operations accounted for 81%76% of operating revenues and 90%84% of operating income. Electric sales are seasonal to some extent with the annual peak normally occurring in the summer months. In 2002,2005, the maximum peak hour demand for WP&LWPL was 2,674 MW2,854 megawatts (MW) and occurred on Aug. 1, 2002.9, 2005.

Gas Utility Operations - As of Dec. 31, 2002, WP&L2005, WPL provided retail natural gas service to 170,123179,289 (excluding 253 transportation and other) customers in 233246 communities. 20022005 gas utility operations accounted for 18%23% of operating revenues and 9%19% of operating income, which includedinclude providing gas services to retail and transportation customers. WP&L’sWPL’s gas sales follow a seasonal pattern. There is an annual base load of gas used for cooking, heating and other purposes, with a large heating peak occurring during the winter season.

SELECTED FINANCIAL DATA

 

  

2002


  

2001


  

2000


  

1999


  

1998


  2005 (1)  2004 (1)  2003 (1)  2002  2001
  

(in thousands)

  (in millions)

Operating revenues

  

$

972,078

  

$

965,353

  

$

862,381

  

$

752,505

  

$

731,448

  $1,409.6  $1,209.8  $1,217.0  $989.5  $993.7

Earnings available for common stock

  

 

77,614

  

 

70,180

  

 

68,126

  

 

67,520

  

 

32,264

   101.8   110.4   111.6   77.6   70.2

Cash dividends declared on common stock

  

 

59,645

  

 

60,449

  

 

—  

  

 

58,353

  

 

58,341

   89.8   89.0   70.6   59.6   60.4

Cash flows from operating activities

   176.6   199.3   138.5   223.9   135.9

Total assets

  

 

1,984,597

  

 

1,875,800

  

 

1,857,024

  

 

1,766,135

  

 

1,685,150

   2,667.6   2,656.1   2,469.3   2,335.1   2,217.5

Long-term obligations, net

  

 

523,308

  

 

523,183

  

 

569,309

  

 

471,648

  

 

471,554

   403.7   491.3   453.5   523.3   523.2

 

(1)Refer to “Results of Operations” in MDA for a discussion of the 2005, 2004 and 2003 results of operations.

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

 

A-2


MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL

CONDITION AND RESULTS OF OPERATIONS (MDA)

FORWARD-LOOKING STATEMENTS

Statements contained in this report that are not of historical fact are forward-looking statements intended to qualify for the safe harbors from liability established by the Private Securities Litigation Reform Act of 1995. Such forward-looking statements are subject to certain risks and uncertainties that could cause actual results to differ materially from those expressed in, or implied by, such statements. Some, but not all, of the risks and uncertainties include: factors listed in “Other Matters—Other Future Considerations;” weather effects on sales and revenues;results of operations; economic and political conditions in WP&L’sWPL’s service territories; federal and state regulatory or governmental actions, including the impact of the Energy Policy Act of 2005 (EPAct 2005) and other energy-related legislation in Congress and federal tax legislation; the ability to obtain adequate and timely rate relief includingto allow for, among other things, the recovery of operating costs and deferred expenditures, the earning of reasonable rates of return;return in current and future rate proceedings and the payment of expected levels of dividends; unanticipated construction and acquisition expenditures; unanticipated issues in connection with WPL’s construction of new generating facilities; issues related to the supply of fuel and purchased electricity and price thereof, including the ability to recover purchased-powerpurchased power, fuel and fuel-related costs through rates in a timely manner; the impact higher fuel and fuel-related prices may have on customer demand for utility services, customers’ ability to pay utility bills and WPL’s ability to collect unpaid utility bills; unplanned outages at WPL’s generating facilities and risks related to recovery of increased costs through rates; risksissues related to electric transmission, including operating in the operationsnew Midwest Independent System Operator (MISO) energy market, the impact of Kewaunee;potential future billing adjustments from MISO, recovery of costs incurred, and federal legislation and regulation affecting such transmission; impact of weather hedges on WPL’s earnings; costs associated with WP&L’sWPL’s environmental remediation efforts and with environmental compliance generally; unanticipated issues related to the Calpine Corporation (Calpine) bankruptcy that could adversely impact WPL’s purchased power agreements; developments that adversely impact WP&L’sWPL’s ability to implement its strategic plan; no material permanent declines in the fair market value of, or expected cash flows from, WP&L’sWPL’s investments; continued access to the capital markets; WP&L’sWPL’s ability to continue cost controls and operational efficiencies; WP&L’sWPL’s ability to identify and successfully complete proposedpotential acquisitions and/or development projects; WPL’s ability to complete its proposed or potential divestitures of various businesses and investments on a timely basis and for anticipated proceeds; access to technological developments; employee workforce factors, including changes in key executives, collective bargaining agreements or work stoppages; and changescurrent or future litigation, regulatory investigations, proceedings or inquiries; the direct or indirect effect resulting from terrorist incidents or responses to such incidents; the effect of accounting pronouncements issued periodically by standard-setting bodies; continued access to the capital markets; the ability to utilize any tax capital losses that may be generated in the rate of inflation. WP&Lfuture; the ability to successfully complete ongoing tax audits and appeals with no material impact on WPL’s earnings and cash flows; inflation and interest rates; and factors listed in “Other Matters - Other Future Considerations.” WPL assumes no obligation, and disclaims any duty, to update the forward-looking statements in this report.

EXECUTIVE SUMMARY

STRATEGIC ACTIONSDescription of Business - WPL is a public utility engaged principally in the generation, distribution and sale of electric energy; and the purchase, distribution, transportation and sale of natural gas in selective markets in Wisconsin, as well as the utility operations of Illinois properties that WPL is divesting. WPL owns a portfolio of electric generating facilities with a diversified fuel mix including coal, natural gas and renewable resources. The output from these generating facilities, supplemented with purchased power, is used to provide electric service to approximately 453,000 electric customers in the upper Midwest. WPL also procures natural gas from various suppliers to provide service to approximately 179,000 gas customers in the upper Midwest. 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 2005, 2004 and 2003, WPL’s earnings available for common stock were $101.8 million, $110.4 million and $111.6 million, respectively. Refer to “Results of Operations” for details regarding the various factors impacting earnings during 2005, 2004 and 2003.

 

In November 2002, Alliant Energy’s Board of Directors approved certain strategic actions designedA-3


STRATEGIC OVERVIEW

Summary - WPL is committed to maintainmaintaining sustained, long-term strong financial performance with a strong credit profile for Alliant Energy (including WP&L), strengthen its (including WP&L’s) balance sheet and positioninvestment grade credit ratings. The strategic plan for WPL is concentrated on: 1) building and maintaining the generation and infrastructure necessary to provide WPL’s utility customers with safe, reliable and environmentally sound energy service; 2) earning returns authorized by its regulators; and 3) controlling costs to mitigate potential rate increases. WPL is utilizing a comprehensive Lean Six Sigma program to assist it in generating cost savings and operational efficiencies.

Progressive legislation passed in Wisconsin provides companies with the necessary rate making principles - and resulting increased regulatory and investment certainty - prior to making certain generation investments. These changes have enabled WPL to pursue additional generation investments to serve its customers and to provide WPL with greater certainty regarding the returns on these investments. Refer to “Generation Plan” and “Liquidity and Capital Resources - Cash Flows used for Investing Activities - Construction and Acquisition Expenditures” for additional information.

Generation Plan - WPL’s current generation plan for the 2006 to 2013 time period reflects the need to increase base-load generation in Wisconsin. The proposed new generation is expected to meet increasing customer demand, reduce reliance on purchased power agreements and mitigate the impacts of potential future plant retirements. WPL will continue to purchase energy and capacity in the market and intends to remain a net purchaser of both, but at a reduced level assuming the successful completion of these generation projects. The plan also reflects continued commitments to WPL’s energy efficiency and environmental protection programs. WPL currently expects to add approximately 350 MW of owned-generation between 2006 and 2013, which includes approximately 250 MW of clean-coal technology generation in 2012 and up to 100 MW of wind generation in 2007 or 2008. The addition of such generation is expected to require approximately $550 million in capital expenditures, excluding allowance for funds used during construction, from 2006 to 2013. WPL’s previous plans to pursue a 500 MW jointly-owned base-load electric plant with Wisconsin Public Service Corporation have changed and WPL now plans to pursue additional options for its 250 MW of clean-coal technology generation in 2012.

WPL’s generation plan also assumes it will enter into purchased power agreements to add approximately 20 anaerobic digesters in Wisconsin. In addition, Alliant Energy for improved long-term financial performance (including WP&L). The strategic actions signaled a shiftexpects to less aggressive growth targets driven primarily by Alliant Energy’s utility operations.either own or enter into purchased power agreements to add 350 MW of wind generation. In July 2005, Alliant Energy announced that it signed a purchased power agreement to proceed with an Iowa-based wind energy farm to develop up to 150 MW of renewable energy by the end of 2007. Allocation of the energy from the Iowa facility to IPL and WPL will be determined at a later date. WPL continues to monitor developments related to state and federal renewable portfolio standards and federal and state tax incentives. WPL reviews and updates, as deemed necessary and in accordance with regulatory requirements, its generation requirements and expects to adjust its plans as needed to meet any of these standards or to react to any market factors increasing or decreasing the availability or cost effectiveness of the various renewable energy technologies.

Alliant Energy currently has agreements with Calpine subsidiaries related to the purchase of energy and capacity from the 466 MW RockGen Energy Center in Christiana, Wisconsin and the 603 MW (Alliant Energy leases 481 MW of this total capacity under its current purchased power agreement) Riverside Energy Center in Beloit, Wisconsin and has the option to purchase these two facilities in 2009 and 2013, respectively. WPL is continuingcurrently unable to determine what impacts Calpine’s recent bankruptcy filing will have on these two purchased power agreements. Refer to Note 18 of the “Notes to Consolidated Financial Statements” and “Other Matters - Other Future Considerations - Calpine Bankruptcy” for additional information.

The 300 MW, simple-cycle, natural gas-fired Sheboygan Falls Energy Facility (SFEF) near Sheboygan Falls, Wisconsin began commercial operation at the beginning of June 2005, ahead of schedule and under budget. In May 2005, the PSCW approved the lease of this facility to WPL under the Wisconsin leased generation law. Resources’ Non-regulated Generation business owns SFEF and leases it to WPL for an initial period of 20 years, with an option for two lease renewal periods thereafter. WPL is responsible for the operation and fuel supply of SFEF and has exclusive rights to its output. Refer to Note 3(b) of the “Notes to Consolidated Financial Statements” for further discussion.

Business Divestitures - In July 2005, WPL completed the sale of its interest in the Kewaunee Nuclear Power Plant (Kewaunee) to a subsidiary of Dominion Resources, Inc. WPL received $75 million at closing, which it used for debt reduction. Refer to Note 16 of the “Notes to Consolidated Financial Statements” for additional information.

In June 2005, WPL signed a definitive agreement for the sale of its effortselectric and gas distribution properties in Illinois for approximately $20 million. In June 2005, WPL reached an agreement on the sale of its water utility in South Beloit, Illinois for approximately $4 million. Pending all regulatory approvals, these sales are expected to implement these strategic actions. The actions that directly impact WP&L are as follows:close in 2006. In July 2005, WPL completed the sale of its Ripon water utility for approximately $5 million.

 

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

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


As of Dec. 31, 2005, all of these businesses have been reported as assets held for sale, and none of them have been reported as discontinued operations. Refer to Note 15 of the “Notes to Consolidated Financial Statements” for additional information.

RATES AND REGULATORY MATTERS

Overview—WP&L - WPL has one utility subsidiary, South Beloit. As a public utility holding company with significant utility assets, WP&L competes in an ever-changing utility industry. Electric energy generation, transmission and distribution are in a period of fundamental change resulting from legislative, regulatory, economic and technological changes. These changes impact competition in the electric wholesale and retail markets as customers of electric utilities are being offered alternative suppliers. Such competitive pressures could result in electric utilities losing customers and incurring stranded costs (i.e., assets and other costs rendered unrecoverable as the result of competitive pricing), which would be borne by security holders if the costs cannot be recovered from customers.

WP&LWPL is currently subject to federal regulation by FERC, which has jurisdiction over wholesale electric rates, electric transmission and certain natural gas facilities, and state regulation in Wisconsin and Illinois. FERC regulates competition in the electric wholesale powerIllinois for retail utility rates and standards of service. Such regulatory oversight also covers WPL’s plans for construction and financing of new generation marketfacilities and each state regulates whether to permit retail competition, the termsrelated activities.

Recent Rate Case Developments - Details of such retail competitionWPL’s rate cases impacting its historical 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 orfuture results of operations but does believe it is well-positioned to compete in a deregulated competitive market. Although WP&L ultimately believes that the electric industry will be deregulated, the pace of deregulation in its primary retail electric service territories has been delayed due to more recent developments in the industry.

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

WP&L’s merger-related price freezes expired in April 2002 and it is currently addressing the recovery of its cost increases through numerous rate filings. WP&L has received final orders in two of its rate cases and currently has two other rate cases pending. Details of these rate cases are as follows (dollars in millions)millions; Electric (E); Gas (G); Water (W); To Be Determined (TBD); Not Applicable (N/A); Fuel-Related (F-R); Fourth Quarter (Q4)):

 

Case


  

Utility Type


  

Filing

Date


  

Increase Requested


  

Interim Increase Granted (1)


  

Interim Effective Date


  

Final Increase Granted


  

Final

Effective

Date


  

Expected

Final

Effective

Date


  

Notes


2002 retail

  

E/G/W

  

Aug. 2001

  

$

  104

  

$

49

  

April 2002

  

$

82

  

Sept. 2002

  

N/A

  

(2)

2003 retail

  

E/G/W

  

May 2002

  

 

101

  

 

TBD

  

TBD

  

 

TBD

  

TBD

  

April 2003

   

2004 retail

  

E/G/W

  

March 2003

  

 

65

  

 

TBD

  

TBD

  

 

TBD

  

TBD

  

Jan. 2004

   

Wholesale

  

E

  

Feb. 2002

  

 

6

  

 

6

  

April 2002

  

 

3

  

Jan. 2003

  

N/A

  

(3)

         

  

     

         

Total

        

$

276

  

$

55

     

$

85

         
         

  

     

         

Case

  Utility
Type
  Filing
Date
  Increase
Requested
  Interim
Increase
Granted (1)
  Interim
Effective
Date
  Final
Increase
Granted (1)
  Final
Effective
Date
  Expected
Final
Effective
Date
  Return on
Common
Equity
 Notes

2003 retail

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

2004 retail

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

2005/2006 retail

  E/G  9/04   63   N/A  N/A   21  7/05  N/A  11.50% (2)(3)

2004 retail (F-R)

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

2004 retail (F-R)

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

2005 retail (F-R)

  E  3/05   26   26  4/05   26  7/05  N/A  N/A 

2005 retail (F-R)

  E  8/05   96   96  Q4 ‘05   TBD  TBD  5/06  N/A (5)

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

Wholesale

  E  8/04   12   12  1/05   TBD  TBD  3/06  N/A (6)

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

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

(3)In May 2005, WPL received approval from the fourth quarterPSCW to lease SFEF from Resources’ Non-regulated Generation business. The 20-year lease includes initial monthly lease payments of 2002, WP&Lapproximately $1.3 million. WPL’s 2005/2006 retail rate case order, effective in July 2005, included recovery of these initial monthly lease payments. Refer to Note 3(b) of the “Notes to Consolidated Financial Statements” for further discussion.

(4)In April 2005, the PSCW issued the final written order denying WPL’s request for a rate increase in this proceeding. In June 2005, the PSCW denied WPL’s request for rehearing. In July 2005, WPL filed a lawsuit in state circuit court challenging the PSCW’s ruling and its interpretation of the fuel rules. In December 2005, the circuit court ruled that the PSCW acted lawfully in denying WPL’s requested rate increase. WPL has initiated the appeal process of the circuit court’s decision.

(5)In August 2005, WPL filed for a fuel-related rate increase of $41 million with the PSCW and an interim increase of such amount was granted and effective in early October 2005. In November 2005, WPL revised its filing to request a $96 million increase as the result of continued increases in fuel-related costs since the initial filing. The PSCW authorized the increase in interim rates to $96 million effective in December 2005. Fuel-related costs have decreased in early 2006 which could lead to final rates granted being lower than interim rates and a resulting customer refund.

(6)In June 2005, WPL reached a settlement agreementin principle with certainits wholesale customers for an $8 million annual revenue increase effective Jan. 1, 2005. The settlement agreement is expected to be filed with FERC in the first quarter of $3 million2006 and a refund of amounts previouslyfinal rates will be applied to all service rendered on and after Jan. 1, 2005. Any amount collected in excess of the settlement. The settlement agreement was approved by FERC in January 2003. Atfinal rates will be refunded to customers, with interest, and has been fully reserved at Dec. 31, 2002, WP&L had reserved all amounts related to the anticipated refund.2005.

 

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With the exception of additions to WPL’s infrastructure, a significant portion of the rate increases included in the previousabove table reflect the recovery of anticipated increased costs incurred or expected to be incurred by WP&L, or costs it expects to incur, thusWPL. The major drivers in WPL’s base rate and fuel-related rate cases for 2005 are both fixed and variable fuel and purchased power costs. Thus, the potential increase in revenues related to these cost increases wouldrate increase requests is not expected to result in a correspondingmaterial increase in net income. WP&LRefer to “Other Matters - Market Risk Sensitive Instruments and South BeloitPositions - Commodity Price Risk” for further discussion of the impact of increased fuel and purchased power costs on results of operations.

Recent Regulatory-related Legislative Developments - In August 2005, the EPAct 2005 was enacted. In general, the legislation is intended to improve reliability and market transparency, provide incentives to promote the construction of needed energy infrastructure and foster development of a wide range of energy options that promote economic growth and greater energy independence. Among other things, the legislation provides for shorter recovery periods for certain electric transmission and gas distribution lines, extends the renewable energy production tax credit through 2007, provides a seven-year recovery period for certain certified pollution control facilities and provides for the repeal of the Public Utility Holding Company Act of 1935 (PUHCA 1935) and the Public Utility Regulatory Policy Act of 1978. In December 2005, FERC issued final rules, effective February 2006, to effectuate the repeal of PUHCA 1935 and FERC’s new authority to regulate public utility holding companies under the Public Utility Holding Company Act of 2005 (PUHCA 2005) which was enacted as part of the EPAct 2005. These rules provide detail on the authority of FERC to address and review various issues, including affiliate transactions, public utility mergers, acquisitions and dispositions, and books and records requirements.

In May 2005, a new law impacting rate making was signed by the Governor in Wisconsin. The new law allows a public utility that proposes to purchase or construct an electric generating facility to apply to the PSCW for an order that specifies in advance the rate making principles that the PSCW will apply to the electric generating facility costs in future rate making proceedings. These changes are currentlydesigned to give Wisconsin utilities more regulatory certainty, including providing utilities with a fixed rate of return on these investments, when financing electric generation projects. The new law requires the PSCW to establish rules to administer the requirements of such law. In December 2005, the PSCW issued a proposed final rule which is anticipated to become effective in the processfirst quarter of determining what other rate case filings may be necessary in 2003.2006.

Other Recent Regulatory Developments -

WP&L’sUtility Fuel Cost Recovery - WPL’s retail electric rates are based on annualforecasts of forward-looking test year periods and include estimates of future monthly fuel costs (includes fuel and purchased energy costs) anticipated during the test year. During each electric retail rate proceeding, the PSCW sets fuel monitoring ranges based on the forecasted fuel and purchased-power costs. Under PSCW rules, WP&L can seek emergency rate increases if the annual costs are more than 3% higher than the estimated costs used to establishdetermine rates in such proceeding. If WPL’s actual fuel costs fall outside these fuel monitoring ranges during the test year period, the PSCW can authorize an adjustment to future retail electric rates. For 2001

The fuel monitoring ranges set by the PSCW include three different ranges based on monthly costs, annual costs and 2002,cumulative costs during the test year. In order for WPL to be authorized to file for a proceeding to increase rates related to increased fuel costs during the test year period, WPL must demonstrate first that (1) any collections in excess ofactual monthly costs incurredduring the test year period exceed the monthly range or (2) the actual cumulative costs to date during the test year period exceed the cumulative range. In addition, the annual projected costs (that include cumulative actual costs) for the test period must be refunded, with interest. Accordingly, WP&L has establishedalso exceed the annual range. Any affected party, including WPL or the PSCW, may initiate a reserveproceeding to decrease rates due to overcollection of pastdecreases in fuel and purchased-power costs and expects to refund such amount in 2003. The final ruling fromduring the PSCW could result intest year period based on the same criteria as required for an increase or decrease toin rates, except the reserve that has been recorded.

ranges are smaller for decreases than for increases. The PSCW has issued newattempts to authorize, after a required hearing, interim fuel-related rate increases within 21 days of notice to customers. Any such change in rates would be effective prospectively and 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. Rate decreases due to decreases in fuel-related costs can be implemented without a hearing. The rules relating to the collection of fuel and purchased-power costs byalso include a process whereby Wisconsin utilities, including WP&L. The new rules and related procedures are intended, among other things, to significantly reduce regulatory lag for the utilities and customers related to the timing of the recovery of increased or decreased fuel and purchased-power costs. Purchased-power capacity costs will now be included in base rates. A process will also exist whereby the utilities can seek deferral treatment of capacity, transmission and emergency changes in fuel-related costs between fuel-related or base rate cases. Such deferrals would be subject to review, approval and recovery in future fuel-related or base rate cases.

In February 2006, the PSCW approved the issuance of an order changing WPL’s fuel cost monitoring ranges to plus 8% or minus 2% for the monthly range; plus 2% or minus 0.5% for the annual range; and for the cumulative range, plus 8% or minus 2% for the first month, plus 5% or minus 1.25% for the second month, and plus 2% or minus 0.5% for the remaining months of the monitoring period.

The newPSCW has initiated a general docket requesting comments by the affected utilities and other interested parties to be filed by March 3, 2006 on whether revisions to the fuel rules are expectedneeded and the scope of those proposed changes prior to initiating a formal administrative code revision proceeding. WPL is working with the PSCW staff, other affected utilities and other interested parties in developing a consensus position on the scope and details of potential changes.

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Coal Delivery Disruption - In July 2005, WPL announced plans to seek recovery of incremental purchased energy costs associated with coal conservation efforts currently underway at WPL due to coal delivery disruptions. In August 2005, WPL received approval from the PSCW to defer these incremental costs associated with WPL’s retail service, then estimated at $14 million to $22 million. WPL currently charges wholesale customers these incremental costs through the fuel adjustment clause. Refer to Note 1(c) of the “Notes to Consolidated Financial Statements” and “Other Matters - Other Future Considerations - Coal Delivery Disruptions” for further discussion.

Proposed Generating Facility - In June 2005, WPL received approval from the PSCW to defer incremental pre-certification and pre-construction costs as a result of siting and building its proposed base-load power plant discussed in further detail in “Strategic Overview - Generation Plan.”

Reduction in Workforce - In May 2005, Alliant Energy announced plans to reduce certain corporate and operations support positions. The net impacts of this reduction in workforce on WPL have been estimated to be implemented for WP&L with its pending 2003minimal in 2005 and to result in a reduction in costs in 2006. Because WPL’s 2005/2006 retail rate case was pending approval at the time of this announcement, and the impacts of this reduction in workforce were not addressed in this retail rate case, WPL received approval from the PSCW in August 2005 to defer all costs/benefits incurred/realized by WPL related to the reduction in workforce until its next rate case.

Kewaunee Outage -WPL received approval from the PSCW to defer incremental fuel-related costs, beginning April 15, 2005, associated with the extension of the unplanned outage at Kewaunee prior to its sale in July 2005. Deferral of incremental operation and maintenance costs related to the unplanned outage was also approved by the PSCW. Refer to Notes 1(c) and 16 of the “Notes to Consolidated Financial Statements” for additional information.

MISO -On April 1, 2005, WPL began participation in the restructured wholesale energy market operated by MISO. The implementation of this restructured market marked a significant change in the way WPL buys and sells wholesale electricity, obtains transmission services and schedules generation. In March 2005, the PSCW approved the deferral of certain incremental costs incurred by WPL to participate in this market, which will be effective until WPL files its next base rate case with the PSCW. WPL is currently working through the regulatory process to establish long-term recovery mechanisms for these costs.

RESULTS OF OPERATIONS

Overview—WP&L’s -WPL’s earnings available for common stock increased $7.4 million and $2.1decreased $8.6 million in 20022005 and 2001, respectively.$1.2 million in 2004. The 2002 increase2005 decrease was primarily due to lower electric margins and higher electric and gas margins,interest expense, partially offset by increaseddecreased operating expenses. The 2001 increase2004 decrease was primarily due to increased operating expenses, largely offset by higher electric margins.

Electric Margins -Electric margins and a lower effective income tax rate,megawatt-hour (MWh) sales for WPL were as follows:

   Revenues and Costs (in millions)  MWhs Sold (in thousands) 
   2005  2004  *  2003  **  2005  2004  *  2003  ** 

Residential

  $369.5  $327.8  13% $316.9  3% 3,599  3,375  7% 3,410  (1%)

Commercial

   197.4   180.0  10%  170.3  6% 2,274  2,215  3% 2,167  2%

Industrial

   288.2   262.6  10%  243.8  8% 4,825  4,769  1% 4,595  4%
                          

Total from retail customers

   855.1   770.4  11%  731.0  5% 10,698  10,359  3% 10,172  2%

Sales for resale

   197.9   144.1  37%  155.6  (7%) 4,371  3,797  15% 4,196  (10%)

Other

   20.9   25.3  (17%)  23.5  8% 75  80  (6%) 82  (2%)
                          

Total revenues/sales

   1,073.9   939.8  14%  910.1  3% 15,144  14,236  6% 14,450  (1%)
                    

Electric production fuel and purchased power expense

   600.8   431.5  39%  409.7  5%        
                       

Margins

  $473.1  $508.3  (7%) $500.4  2%        
                       

*Reflects the % change from 2004 to 2005. ** Reflects the % change from 2003 to 2004.

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   Actual   
   2005  2004  2003  Normal

Cooling degree days*:

        

Madison

  421  138  224  242

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

Electric margins decreased $35 million, or 7%, in 2005, largely due to the impact of higher purchased power capacity costs of $49 million, higher than anticipated fuel and purchased power energy costs and $3.5 million of charges incurred in 2005 related to WPL’s electric weather derivative. These items were partially offset by increased operating expensesthe impact of rate increases implemented in 2005 and lower gas margins.

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

   

Revenues and Costs


   

MWhs Sold


 
   

2002


  

2001


  

*


   

2000


  

**


   

2002


  

2001


  

*


   

2000


  

**


 

Residential

  

$

271,875

  

$

248,128

  

10

%

  

$

229,668

  

8

%

  

3,432

  

3,318

  

3

%

  

3,151

  

5

%

Commercial

  

 

146,726

  

 

138,269

  

6

%

  

 

127,199

  

9

%

  

2,150

  

2,122

  

1

%

  

2,031

  

4

%

Industrial

  

 

211,310

  

 

207,791

  

2

%

  

 

190,085

  

9

%

  

4,454

  

4,538

  

(2

)%

  

4,688

  

(3

)%

   

  

      

      
  
      
    

Total from ultimate customers

  

 

629,911

  

 

594,188

  

6

%

  

 

546,952

  

9

%

  

10,036

  

9,978

  

1

%

  

9,870

  

1

%

Sales for resale

  

 

125,822

  

 

131,187

  

(4

)%

  

 

115,715

  

13

%

  

3,654

  

3,524

  

4

%

  

3,228

  

9

%

Other

  

 

31,947

  

 

28,075

  

14

%

  

 

29,524

  

(5

)%

  

94

  

61

  

54

%

  

63

  

(3

)%

   

  

      

      
  
      
    

Total revenues/sales

  

 

787,680

  

 

753,450

  

5

%

  

 

692,191

  

9

%

  

13,784


  

13,563


  

2

%

  

13,161


  

3

%

Electric production fuels expense

  

 

132,492

  

 

120,722

  

10

%

  

 

113,208

  

7

%

                 

Purchased-power expense

  

 

217,209

  

 

217,306

  

 

  

 

146,939

  

48

%

                 
   

  

      

                     

Margin

  

$

437,979

  

$

415,422

  

5

%

  

$

432,044

  

(4

)%

                 
   

  

      

                     

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

Due2004, warmer weather conditions in 2005 compared to the formationmild weather in 2004, and a 2% increase in weather-normalized sales in 2005. Before giving consideration to the aforementioned impact of ATCthe electric weather derivative, WPL estimates that warmer than normal weather conditions had a positive impact of approximately $7 million on Jan. 1, 2001,its electric margins in 2005 compared to normal weather. WPL estimates the wheeling expenses from ATC includedimpact of weather reduced electric margins by approximately $10 million in 2004 compared to normal weather. Refer to Note 10(b) of the “Notes to Consolidated Financial Statements” for additional information regarding the electric marginweather derivative.

The higher purchased power capacity costs were largely due to the Kewaunee and Riverside agreements which began in 2002July 2005 and 2001 wereJune 2004, respectively. $30 million of this increase was related to the Kewaunee agreement but this was substantially offset by equity income (WP&L accounts for its investment in ATC under the equity method), reducedlower other operation and maintenance expenses and lower depreciation expense, resultingexpenses. WPL’s increase in no significant net incomefuel and purchased power energy costs was largely a result of an escalation in natural gas costs, an unplanned outage at Kewaunee during 2005 and the impact dueof coal supply constraints from the Powder River Basin in 2005. WPL estimates that the under-recovered portion of retail fuel and purchased power energy costs reduced its electric margins in 2005 by approximately $40 million. Refer to “Other Matters - Market Risk Sensitive Instruments and Positions - Commodity Price Risk” for discussion of risks associated with increased fuel and purchased power costs on WPL’s electric margins. Refer to Note 16 of the formation“Notes to Consolidated Financial Statements” for information regarding the sale of ATC. On a comparable basis, electric marginWPL’s interest in Kewaunee.

Sales for resale revenues increased $22.6 million, or 5%, and $13.8 million, or 3%, during 2002 and 2001, respectively. The 2002 increase wasin 2005 compared to 2004 primarily due to the impacts of higher fuel cost recovery revenues from wholesale customers at WPL and the implementation of the restructured wholesale energy market operated by MISO on April 1, 2005. These increased revenues were largely offset by increased electric production fuel and purchased power expense and therefore did not have a significant impact on electric margins.

Electric margins increased $7.9 million, or 2%, in 2004, primarily due to the impact of various rate increases in 2002, continued modest retail customer2004 and 2003, which included increased revenues to recover a significant portion of higher operating expenses, and weather-normalized sales growth and more favorable weatherof 3%, including increased industrial sales of 4% which reflects improving economic conditions in 2002 compared to 2001,WPL’s service territory. These items were partially offset by the sluggish economy.impact of the extremely mild weather conditions in 2004, $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. Alliant Energy estimates that mild weather conditions reduced electric margins by approximately $3 million in 2003 compared to normal weather. The 2001 increase wasreduced energy conservation revenues were largely offset by lower energy conservation expenses.

Gas Margins -Gas margins and dekatherm (Dth) sales for WPL were as follows:

   Revenues and Costs (in millions)  Dths Sold (in thousands) 
   2005  2004  *  2003  **  2005  2004  *  2003  ** 

Residential

  $156.4  $136.4  15% $137.1  (1%) 12,068  12,456  (3%) 12,797  (3%)

Commercial

   89.3   76.8  16%  74.6  3% 8,187  8,585  (5%) 8,539  1%

Industrial

   10.0   8.1  23%  9.6  (16%) 978  1,098  (11%) 1,182  (7%)

Transportation/other

   66.6   32.5  105%  51.1  (36%) 31,648  20,684  53% 19,796  4%
                          

Total revenues/sales

   322.3   253.8  27%  272.4  (7%) 52,881  42,823  23% 42,314  1%
                    

Cost of gas sold

   231.9   165.8  40%  186.3  (11%)     
                       

Margins

  $90.4  $88.0  3% $86.1  2%     
                       

*Reflects the % change from 2004 to 2005. ** Reflects the % change from 2003 to 2004.

A-8


   

Actual

   
   2005  2004  2003  Normal

Heating degree days*:

        

Madison

  6,796  6,831  7,337  7,485

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

Gas revenues and cost of gas sold were significantly higher in 2005 compared to 2004 due to increased natural gas prices. These increases alone had little impact on WPL’s gas margins given its rate recovery mechanism for gas costs. Gas margins increased $2.4 million, or 3%, in 2005, primarily due to lower purchased-power$3 million of improved results from WPL’s performance-based gas cost recovery program (benefits are shared by ratepayers and fuel costs impacting margin, increased residentialshareowners), the impact on margins from higher transportation/other sales and commercial sales due to more favorable weather conditions in 2001 compared to 2000 and continued retail customer growth. These items were partially offset by $10 million of income recorded in 2000 for a change in estimate of utility services rendered but unbilled at month-end due to the implementation of a refined estimation process and lower industrial sales, largely due to impacts of a slowing economy.

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

   

Revenues and Costs


   

Dths Sold


 
   

2002


  

2001


  

*


   

2000


  

**


   

2002


  

2001


  

*


   

2000


  

**


 

Residential

  

$

94,509

  

$

107,673

  

(12

)%

  

$

96,204

  

12

%

  

12,863

  

11,754

  

9

%

  

12,769

  

(8

)%

Commercial

  

 

50,121

  

 

58,658

  

(15

)%

  

 

54,512

  

8

%

  

8,574

  

7,572

  

13

%

  

8,595

  

(12

)%

Industrial

  

 

6,980

  

 

8,907

  

(22

)%

  

 

8,581

  

4

%

  

1,303

  

1,197

  

9

%

  

1,476

  

(19

)%

Transportation/other

  

 

27,481

  

 

31,625

  

(13

)%

  

 

5,855

  

440

%

  

18,572

  

16,866

  

10

%

  

13,680

  

23

%

   

  

      

      
  
      
    

Total revenues/sales

  

 

179,091

  

 

206,863

  

(13

)%

  

 

165,152

  

25

%

  

41,312


  

37,389


  

10

%

  

36,520


  

2

%

Cost of gas sold

  

 

110,119

  

 

153,823

  

(28

)%

  

 

107,131

  

44

%

                 
   

  

      

                     

Margin

  

$

68,972

  

$

53,040

  

30

%

  

$

58,021

  

(9

)%

                 
   

  

      

                     

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

Gas revenues and cost of gas sold were unusually high in 2001 due to the large increase in natural gas prices in the first half of 2001. Due to WP&L’s rate recovery mechanisms for gas costs, these increases alone had little impact on gas margin. Gas

margin increased $15.9 million, or 30%, and decreased $5.0 million, or 9%, during 2002 and 2001, respectively. The 2002 increase was largely due to the implementation of a rate increase in 2002, improved results from WP&L’s performance-based commodity cost recovery program, continued modest retail customer growth and the negative impact high gas prices in early 2001the fourth quarter of 2005 had on gas consumptionsales during that period. The 2001 decrease was largely dueIndustrial sales volume decreases in 2005 reflect a reduction in agricultural demand attributable to lower retail sales primarily related to unusually high gas prices earlierdrier weather conditions during the fall harvest in 2001 as some customers either chose alternative fuel sources or used less natural gas,2005 and the impact of the slowing economyincreases in natural gas prices. Transportation/other sales increased in 2005 due to greater demand from natural gas-fired electric generating facilities, including Riverside and lowerSFEF being placed in service in June 2004 and June 2005, respectively. The impact of these higher transportation/other sales increased gas margins by approximately $3 million in 2005.

Gas margins increased $1.9 million, or 2%, in 2004, primarily due to improved results of $4 million from WP&L’sWPL’s performance-based gas commodity cost recovery program.

program, partially offset by lower sales to retail customers due to milder weather conditions in 2004 compared to 2003.

Refer to “Rates and Regulatory Matters” for discussion of various electric and gas rate filings. Refer to “Rates and Regulatory Matters” and Note 1(i)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™ due to decreased demand. This decrease was largely offset by lower operating expenses related to this business.

Other Operating Expenses - Other operation and maintenance expenses decreased $23 million in 2005, primarily due to lower nuclear generation, incentive compensation and transmission and distribution expenses in 2005. These items were partially offset by a regulatory-related charge recorded in 2005 and higher fossil-fuel generation expenses. The lower nuclear generation-related expenses were primarily due to WPL’s sale of its interest in Kewaunee in July 2005. In the second half of 2004, WPL incurred approximately $26 million of other operation and maintenance expenses related to Kewaunee that have been replaced with Kewaunee’s purchased power capacity costs included in WPL’s electric margins in the second half of 2005. 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 expense decreased $3.1 million in 2005, primarily due to lower nuclear depreciation as a result of the Kewaunee sale in July 2005 and lower software amortization, partially offset by the impact of property additions including SFEF. 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.

Refer to “Rates and Regulatory Matters” for discussion of the interplay between utility operating expenses and utility margins given their impact on WPL’s utility rate activities. Refer to Note 216 of the “Notes to Consolidated Financial Statements” and “Rates and Regulatory Matters” for further discussion of WP&L’s rate filings.

the Kewaunee sale.

Other Operating Expenses—Due to the formation of ATC in 2001, WP&L incurred $10 million of operationInterest Expense and maintenance expenses in 2000 that were not incurred in 2001. On a comparable basis, other operation and maintenance expensesOther - Interest expense increased $29.2$6.9 million and $7.6decreased $4.4 million for 20022005 and 2001,2004, respectively. The 2002 increase was largely due to higher fossil generation, employee benefit, energy conservation, and energy delivery expenses. The 20012005 increase was primarily due to higher nuclear operating costs (partially dueaffiliated interest expense associated with the SFEF capital lease. Refer to a planned refueling outage at Kewaunee inNote 3(b) of the fourth quarter of 2001), higher uncollectible customer account balances largely due“Notes to the unusually high gas prices earlier in the year and higher other administrative and general costs. These items were partially offset by decreased fossil plant maintenance expenses.

Depreciation and amortization expenses increased $7.1 million and decreased $10.8 millionConsolidated Financial Statements” for 2002 and 2001, respectively.additional information on this capital lease. The 2002 increase was largely due to higher regulatory and software amortizations. Increased earnings on the nuclear decommissioning trust fund were largely offset by lower decommissioning expense based on reduced retail funding levels. The 20012004 decrease was primarily due to the impact of the formation of ATC and decreased earnings on the nuclear decommissioning trust fund, partially offset by increased expense due to property additions. The accounting for earnings on the nuclear decommissioning trust funds results in no net income impact. Interest income is increased for earnings on the trust fund, which is offset in depreciation expense.

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

Interest Expense and Other—Interest expense decreased $3.3 million in 2002 due to lower average interest rates on the outstanding borrowings. Interest income increased $13.5 million and decreased $5.0 million in 2002 and 2001, respectively, due to differences in earnings on the nuclear decommissioning trust fund.borrowings outstanding. Equity income from unconsolidated investments increased $15.0$1.3 million in 2001, largely due to ATC beginning operations on Jan. 1, 2001. Miscellaneous, net income decreased $7.3and $4.3 million in 2002for 2005 and 2004, respectively, primarily due to lower incomehigher earnings at ATC resulting from sales of non-commodity products and services and income realized from weather hedges in 2001.rate increases.

 

A-9


Income Taxes -The effective income tax rates were 35.6%36.7%, 35.9%36.8%, and 37.5%36.4% in 2002, 20012005, 2004 and 2000,2003, respectively. Refer to Note 5 of the “Notes to Consolidated Financial Statements” for additional information.

LIQUIDITY AND CAPITAL RESOURCES

Overview—WP&L’s recent - WPL believes it has a strong liquidity position and future financing activities have been and will be undertaken against a backdropexpects to maintain this position over its planning period of increased market concerns about general economic conditions and corporate governance issues2006 to 2010 as well as risks associated with particular sectors of the economy, including the energy industry. As a result of these factors, capital markets have become more restrictive. The commercial paper market, for example, has become more limited for many companies in terms of the amounts ofits available capitalcapacity under its revolving credit facility and the corresponding maturities. Medium- and long-term debt markets have become sensitive to increased credit ratings volatility and to a heightened perception of liquidity risk in the energy sector. As a result, investors have become more selective and have differentiated among otherwise comparable issuers in a way that has made the financing process more challenging. In response to these changing market conditions, WP&L is working closely with its financial advisors and others to access the capital it needs to operate its business.operating cash flows. Based on WP&L’sits strong cash flows coupled with actions Alliant Energy expects to take to strengthen itsliquidity position and WP&L’s balance sheet, WP&L currentlycapital structure, WPL believes it will be able to secure theadditional capital it requiresrequired to implement its strategic plan. WP&L anticipatesplan through the 2006 to 2010 planning period. WPL believes its ability to secure additional capital has been significantly enhanced by its actions during the last several years to strengthen its balance sheet as is evidenced by, among other items, WPL’s current debt-to-total capitalization ratio of 31% compared to 41% in early 2003. Total capitalization, for the purposes of this calculation, includes common equity, preferred stock and short- and long-term debt.

WPL continually reviews its capital structure and plans to maintain an adjusted consolidated debt-to-total capitalization ratio consistent with an investment grade credit rating. Important capital structure considerations include financing flexibility for the generation growth plans discussed in “Strategic Overview,” debt imputed by rating agencies and state regulations. The most stringent imputations include attributed debt for a portion of the RockGen and Riverside long-term capacity agreements and the Kewaunee long-term purchased power agreement.

Primary Sources and Uses of Cash - WPL’s most significant source of cash is electric and gas sales to its constructionutility 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 rate base assets required to provide such services. Operating cash flows are expected to substantially cover WPL’s utility maintenance capital expenditures during 2003-2005and dividends paid to Alliant Energy. The capital requirements needed to retire debt and pay capital expenditures associated with growing the rate base, including new generation plants, are expected to be financed primarily through external financings, supplemented by internally generated funds supplemented, when necessary, by outside financing.funds. In order to maintain its planned consolidated capitalization ratios, WPL may periodically issue additional debt to fund such capital requirements.

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

 

  

2002


   

2001


   

2000


   2005 2004 2003 

Cash flows from (used for):

             

Operating activities

  

$ 223,750

 

  

$ 135,886

 

  

$ 174,060

 

  $176.6  $199.3  $138.5 

Investing activities

   (42.9)  (214.3)  (108.4)

Financing activities

  

(27,685

)

  

(19,176

)

  

987

 

   (133.8)  (12.0)  (11.6)

Investing activities

  

(187,795

)

  

(116,832

)

  

(174,880

)

Cash Flows from Operating Activities -

Historical Changes in Cash Flows from Operating Activities - In 2002, WP&L’s2005, WPL’s cash flows from operating activities decreased $23 million primarily due to higher income tax payments and higher purchased power and fuel expenditures, partially offset by changes in the level of accounts receivable sales. In 2004, WPL’s cash flows from operating activities increased $61 million primarily due to changes in working capital;capital caused largely by the timing of tax payments and refunds.

Cash Flows used for Investing Activities -

Historical Changes in Cash Flows used for Investing Activities - In 2005, WPL’s cash flows used for investing activities decreased $171 million primarily due to proceeds received from WPL’s sale of its interest in Kewaunee and related liquidation of a portion of nuclear decommissioning trust fund assets in 2005. 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 received from the transfersale of WP&L’s transmission assetsWPL’s water utility serving the Beloit area.

A-10


Construction and Acquisition Expenditures - Capital expenditures, investments and financing plans are continually reviewed, approved and updated as part of WPL’s ongoing strategic planning and budgeting processes. In addition, material capital expenditures and investments are subject to ATCa rigorous cross-functional review prior to approval. Changes in 2001.WPL’s anticipated construction and acquisition expenditures may result from a number of reasons including, but not limited to, economic conditions, regulatory requirements, ability to obtain adequate and timely rate relief, the level of WPL’s profitability, WPL’s desire to maintain investment-grade credit ratings and reasonable capitalization ratios, variations in sales, changing market conditions and new opportunities. WPL currently anticipates construction and acquisition expenditures during 2006 and 2007 as follows (in millions):

   2006  2007

Distribution (electric and gas) and transmission (gas only)

  $90  $95

Generation - new facilities

   30   110

Generation - existing facilities

   30   35

Environmental

   15   25

Contributions to ATC

   12   11

Other miscellaneous utility property

   38   39
        
  $215  $315
        

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” and “Environmental” for further discussion.

Proceeds from Asset Sales - Refer to “Strategic Overview” for discussion of WPL’s recent asset divesture activities. Proceeds from asset divestitures have been and will be used primarily for debt reduction and general corporate purposes.

Cash Flows used for Financing Activities -

Historical Changes in Cash Flows used for Financing Activities - In 2001, WP&L’s cash flows from operating activities decreased due to changes in working capital;2005, WPL’s cash flows used for financing activities increased $122 million primarily due to common stock dividends paidchanges in 2001 as no dividends were declared in 2000 due to managementthe amount of WP&L’s capital structure, partially offset by a capital contribution of $35 million by Alliant Energy and changes in debt issued and retired;retired. In 2004, WPL’s cash flows used for investingfinancing activities decreased in 2001increased slightly primarily due to proceeds receiveda capital contribution from Alliant Energy in 2003 and higher common stock dividends, largely offset by changes in the transferamount of WP&L’s transmission assets to ATC.

debt issued and retired.

Common Equity—The PSCWState Regulatory Agency Financing Authorizations - WPL has indicated it will requireauthorization for short-term borrowings of $250 million, $211 million for general corporate purposes and an additional equity infusion by$39 million to redeem its variable rate demand bonds.

Shelf Registrations - WPL’s current SEC shelf registration 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, 2005.

Common Stock Dividends - In its July 2005 rate order, the PSCW stated WPL may not pay annual common stock dividends, including pass-through of subsidiary dividends, in excess of $92 million to Alliant Energy into WP&L during 2003. WP&L anticipatesif WPL’s actual average common equity ratio, on a financial basis, is or will fall below the final PSCW order, which is expected to be issued in the second quartertest year authorized level of 2003, will53.14%. WPL’s dividends are also include a customer refund provision if the timing and/or amount of the equity infusion differs from the assumptions included in the WP&L rate case.

Debt—Alliant Energy discontinued the use of its utility money pool in 2002 and WP&L is now meeting any short-term borrowing needs by issuing commercial paper.

WP&L is party to various credit facilities and other borrowing arrangements, some of which are summarized below. In additionrestricted to the specific covenants detailed below underextent that such dividend would reduce the 364-day revolving credit agreement, WP&L’s facilities and borrowing arrangements contain various customary terms and conditions, including required capitalization, net worth and interest coverage requirements, maintenance requirements relatedcommon stock equity ratio to bonded property and cross-default provisions.less than 25%. At Dec. 31, 2002, WP&L2005, WPL was in compliance with the financial ratiosall such dividend restrictions.

Short- and covenant requirements under its credit facilities and borrowing arrangements.

Long-term Debt - In October 2002, WP&L2005, WPL completed the syndicationre-syndication of a 364-dayits revolving credit facility totaling $150 million, availableand extended the term of the facility to August 2010. Refer to “Creditworthiness” for directdiscussion of the various restrictive covenants and other provisions of the new credit facility. The credit facility backstops commercial paper issuances used to finance short-term borrowing orrequirements, which fluctuate based on seasonal corporate needs, the timing of long-term financings and capital market conditions. Information regarding commercial paper borrowings under the credit facility at Dec. 31, 2005 was as follows (dollars in millions):

Amount outstanding

  $93.5 

Weighted average maturity

   3 days 

Discount rates

   4.3-4.45%

Available capacity

  $156.5 

Refer to support commercial paper. The newNote 8 of the “Notes to Consolidated Financial Statements” for additional information regarding short- and long-term debt.

A-11


Creditworthiness -

Credit Facilities -WPL’s credit facility agreement contains various covenants, includinga financial covenant requiring a debt-to-capital ratio of less than 58%. At Dec. 31, 2002, WP&L’s2005, WPL’s debt-to-capital ratio was 40.7%37%.

The debt component of the capital ratio includes long- and short-term debt (excluding non-recourse debt, trade payables)payables and imputed debt for certain purchased power agreements), 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).

The credit agreement contains negative pledge provisions, which generally prohibit placing liens on any of WPL’s property with certain exceptions for, including among others, the issuance of secured debt under first mortgage bond indentures by WPL, non-recourse project financing, and purchase money liens.

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

The credit agreement contains customary events of default. If an event of default under the credit agreement occurs and is continuing, then the lenders may declare any outstanding obligations under the credit agreement immediately due and payable. In addition, if any order for relief is entered under bankruptcy laws with respect to WPL, then any outstanding obligations under the respective credit agreement would be immediately due and payable.

A material adverse change representation is not required for borrowings under the credit agreement.

At Dec. 31, 2002, WP&L had $60 million of commercial paper outstanding,2005, WPL was in compliance with a weighted average maturity of 34 daysall covenants and discount rate of 1.6%. There were no bank facility borrowings at Dec. 31, 2002.

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 financing and capital market conditions. At Dec. 31, 2002, WP&L was authorized by the applicable federal or state regulatory agencies to issue short-term debt of $240 million, which includes $85 million for general corporate purposes, an additional $100 million should it no longer sell its utility receivables and an additional $55 million should it need to repurchase its variable rate demand bonds.

At Dec. 31, 2002, WP&L had $255 million of long-term debt that will mature prior to Dec. 31, 2007. Depending upon market conditions, it is currently anticipated that a majorityother provisions of the maturing debt will be refinanced with the issuance of long-term securities.credit facility.

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

 

   

Standard & Poor’s
Ratings Services (S&P)


  

Moody’s Investors
Service


SecuredSenior secured long-term debt

  

A

-
  

A1

UnsecuredSenior unsecured long-term debt

  

BBB+

A -
  

A2

Commercial paper

  A-2P-1

A-2Corporate/issuer

  

P-1

Corporate

A -
  

A-

A2

Outlook

  

Negative

Stable
  

Stable

In January 2006, S&P upgraded the rating of WPL’s senior unsecured long-term debt to A- from BBB+. At the same time, S&P also changed the outlook on all of WPL’s rated debt to stable from negative.

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

 

Sale of Accounts Receivable—Refer to Note 4 of the “Notes to Consolidated Financial Statements” for information on WP&L’s sale of accounts receivable program.A-12


Off-Balance Sheet Arrangements—WP&L - WPL utilizes off-balance sheet synthetic operating leases that relate to financethe financing of certain utility railcars and a utility radio dispatch system. Synthetic leases provide favorable financing rates to WP&LWPL while allowing it to maintain operating control of its leased assets. SeveralRefer to Note 3(a) of WP&L’s synthetic leases involve the use of unconsolidated structured finance or variable interest entities. WP&L has guarantees outstanding related“Notes to theConsolidated Financial Statements” for future minimum lease payments under, and residual value guarantees by WPL of, these synthetic leases. WP&L does not currently anticipateWPL’s credit facility agreement prohibits it from entering into any additional synthetic leases. WP&L also uses variable interestleases without the consent of a majority of the lenders to the credit facility. WPL has reviewed these entities during its implementation of revised Financial Accounting Standards Board Interpretation No. (FIN) 46, “Consolidation of Variable Interest Entities,” (FIN 46R), and determined that consolidation of these entities is not required. Refer to Note 18 of the “Notes to Consolidated Financial Statements” for its utility sale of accounts receivable program whereby WP&L uses proceeds fromadditional information regarding FIN 46R.

Guarantees and Indemnifications - WPL has indemnifications outstanding related to the sale of the accounts receivable and unbilled revenues to maintain flexibilityits interest in its capital structure, take advantage of favorable short-term interest rates and finance a portion of its long-term cash needs. The sale of accounts receivable generates a significant amount of short-term financing for WP&L. If this financing alternative were not available, WP&L anticipates it would have enough short-term borrowing capacity to compensate.Kewaunee. Refer to “Ratings Triggers”Notes 11(d) and 16 of the “Notes to Consolidated Financial Statements” for the impactadditional information.

Credit Risk - WPL has credit exposure from electric and natural gas sales and non-performance of contractual obligations by its counterparties. WPL maintains credit rating downgradesrisk oversight and sets limits and policies, which management believes minimizes its overall credit risk exposure. However, there is no assurance that such policies will protect WPL against all losses from non-performance by counterparties. Refer to “Other Matters - Other Future Considerations - Calpine Bankruptcy” for more information on WP&LWPL’s risks related to these synthetic leases and accounts receivable sales program.Calpine’s recent bankruptcy filing.

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

Certain Financial Commitments -

Contractual Obligations—WP&L’s - WPL’s long-term contractual cash obligations as of Dec. 31, 20022005 were as follows (in millions):

 

   

2003


  

2004


  

2005


  

2006


  

2007


  

Thereafter


  

Total


Long-term debt (Note 8)

  

$—  

  

$62

  

$88

  

$—  

  

$105

  

$269

  

$524

Operating leases (Note 3)

  

27

  

61

  

75

  

   76

  

76

  

335

  

650

Purchase obligations (Note 11(b))

  

   86

  

47

  

26

  

15

  

15

  

27

  

216

   
  
  
  
  
  
  
   

$113

  

$170

  

$189

  

$91

  

$196

  

$631

  

$1,390

   
  
  
  
  
  
  

   2006  2007  2008  2009  2010  Thereafter  Total

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

  $—    $105  $60  $—    $100  $139  $404

Interest - long-term debt obligations

   26   22   19   15   12   156   250

Capital leases (Note 3(b))

   15   15   15   15   15   218   293

Operating leases (Note 3(a))

   86   86   75   66   62   141   516

Purchase obligations (Note 11(b)):

              

Purchased power and fuel commitments

   286   118   103   109   104   261   981

Other

   3   1   1   —     —     —     5
                            
  $416  $347  $273  $205  $293  $915  $2,449
                            

At Dec. 31, 2002,2005, long-term debt and capital lease obligations as noted in the previousabove table waswere included on the Consolidated Balance Sheets.Sheet. Included in WPL’s long-term debt obligations was variable rate debt of $39 million, which represented 10% of total long-term debt outstanding. The long-term debt amounts exclude reductions related to unamortized debt discounts. Interest on variable rate debt in the above table was calculated using rates as of Dec. 31, 2005. Purchased power and fuel commitments represent normal business contracts used to ensure adequate purchased power, coal and natural gas supplies and to minimize exposure to market price fluctuations. Alliant Energy has entered into various purchased power commitments that have not yet been directly assigned to IPL and WPL. Such commitments are not included in WPL’s purchase obligations. Other purchase obligations represent individual commitments incurred during the normal course of business which exceeded $1.0 million at Dec. 31, 2005. In connection with its construction and acquisition program, WPL also enters into commitments related to such program on an ongoing basis which are not reflected in the above table. Refer to “Cash Flows used for Investing Activities - Construction and Acquisition Expenditures” for additional information. In addition, at Dec. 31, 2002,2005, there were various other long-term liabilities and deferred credits included on the Consolidated Balance SheetsSheet that, due to the nature of the liabilities, the timing of payments cannot be estimated and are therefore excluded from the tables. Operating leasesabove table. Refer to Note 6 of the “Notes to Consolidated Financial Statements” for anticipated pension and purchase obligationsother postretirement benefit funding amounts, which are amounts committed under contract which were not recorded onincluded in the Consolidated Balance Sheets at Dec. 31, 2002, in accordance with GAAP. Purchase obligations represent normal business contracts used to ensure adequate purchased-power, coal and natural gas supplies and to minimize exposure to market price fluctuations.In connection with WP&L’s construction and acquisition program, WP&L also enters into commitments related to such program on an ongoing basis.above table.

 

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Credit Risk—Credit risk is inherent in WP&L’s operations and relates to the risk of loss resulting from non-performance of contractual obligations by a counterparty. WP&L 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&L against all losses from non-performance by counterparties.Environmental -

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

WP&L’s facilities are subject tofederal, state and federal requirementslocal environmental rulemakings on its operations. While the final outcome of these rule makings cannot be predicted, WPL believes that required capital investments and/or modifications resulting from them could be significant, but expects that prudent expenses incurred by WPL likely would be recovered in rates from its customers. Given the dynamic nature of the CAA, including meeting ambient air quality standards.utility environmental and other related regulatory requirements, WPL has an integrated planning process that includes the determination of new generation, environmental compliance requirements and other operational needs. As a resultpart of a new rate-of-progress rule developedWPL’s planning process, significant investments for environmental requirements are approved by the Wisconsin DNR, and based on existing technology, WP&L estimates the total aggregate capital investments necessary to comply with the new rules will be approximately $19 million in 2003 through 2007. WP&L is also currently addressing various other potential federal and stateWPL’s Board of Directors. The following are major environmental rulemakings and activities, including: 1) proposed revisions to the Wisconsin Administrative Code concerning the amount of heatissues that WP&L’s generating stations can discharge into Wisconsin waters which could potentially have a significant impact on WP&L’s operationWPL’s financial condition and results of its Wisconsinoperations. Refer to “Cash Flows used for Investing Activities - Construction and Acquisition Expenditures” for information on WPL’s anticipated 2006 and 2007 environmental capital expenditures.

Air Quality - The 1990 Clean 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 March 2005, the EPA finalized the Clean Air Interstate Rule (CAIR), which requires emission control upgrades to existing electric generating facilities; 2) potential new rulesunits with greater than 25 MW capacity. This rule will cap emissions of sulfur dioxide (SO2) and nitrogen oxides (NOx) in 28 states (including Wisconsin) in the eastern U.S and, when fully implemented, reduce SO2 and NOx emissions in these states by over 70% and 60% from 2003 levels, respectively. The specific reductions for WPL will be determined by state-specific implementation plans, which could be more or less stringent than the noted 70% and 60% reductions. The first phase of compliance for SO2 and NOx is required by 2010 and 2009, respectively, and the second phase of compliance for both SO2 and NOx is required by 2015. This federal rule allows that additional reduction requirements may also be imposed at the state level for those areas that are in non-attainment with National Ambient Air Quality Standards (NAAQS). WPL has existing electric generating units located in non-attainment areas for the 8-hour ozone standard and may be pursued bysubject to additional NOx emissions reductions.

In March 2005, the EPA also finalized the Clean Air Mercury Rule (CAMR) which requires mercury emission control upgrades for coal-fired generating units with greater than 25 MW capacity. When fully implemented, this rule will reduce U.S. utility (including WPL) mercury emissions by approximately 70% in a two-phased reduction approach. The first phase of compliance is required by 2010 and the statessecond phase by 2018.

The final CAIR and CAMR rules were effective in May 2005 and each state must submit enforceable plans to the EPA for approval, which comply with the requirements of these rules, by September and November 2006, respectively. WPL is actively participating in the WP&L service territory relateddevelopment of the state implementation plans. Although the federal rulemakings were anticipated, specific compliance plans cannot be completed until state implementation plans are finalized.

WPL has completed a preliminary evaluation of CAIR and CAMR rulemakings based on the EPA model rule framework that states may adopt using multi-state cap and trade programs to various air emissions; 3)meet the required emissions reductions in a flexible and cost-effective manner. WPL’s estimated capital expenditures for 2006 through 2010 associated with the first phase of compliance for CAIR and CAMR are anticipated to be $100 million to $140 million. WPL expects additional capital investments for the second phase compliance with CAIR and CAMR to be significant and material. Based on WPL’s most recent planning scenario, its initial estimates for capital expenditures for 2011 through 2018 required for phase two compliance with these rules are $150 million to $200 million. These estimates are based on today’s costs of current technologies and information currently available regarding the EPA final rules. The costs may change depending on the requirements of the final state rules. In addition, there will also be recurring costs for operating and maintaining the emissions control equipment associated with these capital expenditures. Pending the states’ adoption of EPA rules, it is possible that emissions reduction requirements may be achieved through market-based trading of SO2, NOx and mercury emissions allowances. Emissions allowances markets may be used by WPL to achieve compliance, with the potential to increase (or decrease) expenses associated with allowances purchases (or sales). These costs will depend upon actual emissions levels resulting from generation during this period, performance of emissions control equipment and market prices for emissions allowances.

In addition, WPL is aware that certain citizen groups have begun pursuing claims against utility generating stations regarding excess emissions, including opacity emissions. WPL continues to monitor its emissions closely to determine whether additional controls will be required. The additional capital investments for CAIR and CAMR compliance, as discussed above, will also contribute to improvements in opacity emissions. However, should more stringent opacity limits be required, the timing of investments and control equipment options to comply with these multiple regulatory requirements will need further evaluation.

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WPL previously responded confidentially to multiple data requests WP&L has received from the EPA related to the historical operation of WP&L’sand associated air permitting for certain major Wisconsin coal-fired generating units, which requestsunits. In 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. In October 2005, the EPA issued a memorandum with revised federal policy guidance on New Source Review enforcement pertaining to pre-construction air permitting requirements. As a result, WPL anticipates no further action from the EPA resulting from these prior requests.

There have been instances where citizen groups have pursued claims against utilities for alleged air permitting violations. While WPL has not received any such claims to date, WPL is aware that certain public comments have been submitted to the precursorWisconsin Department of Natural Resources (DNR) regarding the renewal of an air operating permit for one of WPL’s generating stations. WPL is unable to penaltiespredict what actions, if any, the Wisconsin DNR or the public commenters may take in response to these public comments.

WPL is also currently monitoring various other potential federal, state and additional capital requirements in some cases involving similar requestslocal environmental rulemakings and activities, including, but not limited to: litigation of various federal rules issued under the statutory authority of the Clean Air Act Amendments; revisions to other electric generating facilities; 4) the New Source Review, reforms published byand Prevention of Significant Deterioration permitting programs; Regional Haze evaluations for Best Available Retrofit Technology; revisions to the EPA in December 2002; 5)NAAQS including particulate matter, and several other legislative and regulatory proposals regarding the control of emissions of air pollutants and greenhouse gases from a variety of sources, including generating facilities;facilities.

Water Quality - The EPA regulation under the Clean Water Act referred to as “316(b)” became effective in 2004. This regulation requires existing large power plants with cooling water intake structures to apply technology to minimize adverse environmental impacts to fish and 6)other aquatic life. WPL is currently studying such impacts and will have compliance plans in place by the July 2002 request from the Wisconsin DNR that WP&L submit a written plan for facility closurerequired date of the Rock River Generating Station landfillJanuary 2008. WPL is investigating compliance options and clean-up of its support ponds and all areas where coal combustion waste is present. WP&L cannot presentlyunable to predict the final outcome, of these proposals or actions, but believes that required capital investments and/or modifications resulting from themthis regulation could be significant. WP&L

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

In 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 passages and to install an agency-approved fish-protective device within one year, and within three years to install an agency-approved fish passage. WPL is working with the appropriate federal and state agencies to comply with these provisions and research solutions. In September 2005, WPL filed a one-year extension request with FERC for the detailed engineering and biological evaluation of potential fish passages and installation of an agency-approved fish-protective device. The due date for the submittal of this evaluation has been extended to October 2006. WPL believes that required capital investments and/or modifications resulting from this issue could be significant.

Land and Solid Waste - WPL is monitoring various 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 biphenyls (PCB) Fix-it Rule/Persistent Organic Pollutants Treaty could possibly require replacement of all electrical equipment containing PCB insulating fluid which is a substance known to be harmful to human health. The Wisconsin Department of Commerce is proposing new rules related to flammable, combustible and hazardous liquids stored in above-ground storage tanks in which the primary financial impact would be recovered in rates from its customers. a secondary containment requirement for all hazardous materials tanks and for hazardous material unloading areas. WPL is unable to predict the outcome of these possible regulatory changes at this time, but believes that the 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 “Cash Flows used for Investing Activities—Construction and Acquisition Expenditures” for further discussion of environmental matters.

 

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

WP&L currently anticipates construction and acquisition expenditures for utility infrastructure and reliability investments to be $160 million in 2003 and $410 million in 2004-2005. WP&L has not entered into contractual commitments relating to the majority of its anticipated capital expenditures. As a result, WP&L does have discretion as to the eventual level of capital expenditures incurred and it closely monitors and updates such estimates on an ongoing basis based on numerous economic and other factors.A-15


OTHER MATTERS

Market Risk Sensitive Instruments and Positions—WP&L’s - WPL’s primary market risk exposures are associated with commodity prices, 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.

Commodity Price Risk - WPL 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. WPL employs established policies and procedures to mitigate its risks associated with these market fluctuations including the use of various commodity derivatives and contracts of various duration for the forward sale and purchase of electricity and natural gas. WPL’s exposure to commodity price risks is also significantly mitigated by the current rate making structures in place for recovery of its electric fuel and purchased energy costs (fuel-related costs) as well as its cost of natural gas purchased for resale.

Current and forecasted prices of electric and natural gas commodities increased significantly in 2005 due, in part, to the natural gas supply disruption caused by the hurricane activity in the Gulf of Mexico in the third quarter of 2005. The significant increases in the cost of natural gas commodities are not expected to have a significant impact on WPL’s gas margins due to the timely recovery of increased costs under its current rate making structure. However, increased prices of electric power and/or natural gas may result in reduced usage by WPL’s customers, including the potential for larger customers to switch to alternative fuel sources, and/or higher bad debt expense.

WPL’s electric margins are more exposed to the impact of these increased commodity prices due largely to the retail rate recovery mechanisms in place in Wisconsin for fuel-related costs. WPL’s retail electric rates are based on forecasts of forward-looking test year periods and include estimates of future fuel and purchased energy costs anticipated during the test year. During each electric retail rate proceeding, the PSCW sets fuel monitoring ranges based on the forecasted fuel costs used to determine rates. If WPL’s actual fuel costs fall outside these fuel monitoring ranges during the test year period, WPL can request and the PSCW can authorize an adjustment to future retail electric rates. Refer to “Rates and Regulatory Matters -Other Recent Regulatory Developments—Utility Fuel Cost Recovery” for discussion of recent changes to the fuel monitoring ranges. The PSCW may authorize an interim rate increase, however if the final rate increase is less than the interim rate increase, WPL would refund the excess collection to customers at the current authorized return on equity rate. Recovery of capacity-related charges associated with WPL’s purchased power costs and network transmission charges are recovered from electric customers through changes in base rates.

WPL experienced extraordinary increases in its fuel-related costs in 2005 which met the requirements to file for additional fuel-related rate relief. However, WPL estimates it under-collected fuel-related costs in 2005 by approximately $40 million from its retail electric customers given the regulatory process and resulting lag in obtaining approved rate relief. Given the prospective nature of the rate changes, amounts under-collected in this process are costs for which WPL will not be afforded the opportunity for recovery from rate payers in the future. In addition, the fuel-related rates that are established are based on test year average costs, thus once rates are set there is a natural under/over recovery during certain months based on the differences in the estimated average test year costs and the actual monthly costs. WPL is unable to determine the anticipated impact of these increases in fuel-related costs on its future results of operations given the uncertainty of how future costs will correlate with the rates in place, the timing and uncertainty of the necessary PSCW approvals to implement requested fuel-related rate increases and uncertainties regarding future sales volumes. Refer to “Rates and Regulatory Matters” for additional details of the recent fuel-related retail cases filed by WPL.

WPL’s retail gas tariffs provide for subsequent adjustments to its natural gas rates for changes in the current monthly natural gas commodity price index. Also, WPL has a gas performance incentive which includes a sharing mechanism whereby 50% of all gains and losses relative to current commodity prices, as well as other benchmarks, are retained by WPL, with the remainder refunded to or recovered from customers. Such rate mechanisms combined with commodity derivatives discussed above significantly reduce commodity risk associated with WPL’s cost of natural gas.

 

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Interest Rate RiskWP&L - WPL is exposed to risk resulting from changes in interest rates as a result of its issuance of variable-rate debt utility customer accounts receivable sale program and variable-rate leasing agreements. WP&LWPL manages its interest rate risk by limiting its variable interest rate exposure and by continuously monitoring the effects of market changes on interest rates. WP&L has also historically used interest rate swap and interest rate forward agreements to assist in the management of its interest exposure. In the event of significant interest rate fluctuations, management would take actions to minimize the effect of such changes on WP&L’sWPL’s results of operations and financial condition. Assuming no change in WP&L’sWPL’s consolidated financial structure, if variable interest rates were to average 100 basis points higher (lower) in 20032006 than in 2002, interest2005, expense and pre-tax earnings would increase (decrease) by approximately $2.5$1.4 million. These amounts wereThis amount was determined by considering the impact of a hypothetical 100 basis point increase (decrease) in interest rates on WP&L’sWPL’s consolidated variable-rate debt held the amount outstanding under the utility customer accounts receivable sale program and variable-rate lease balances at Dec. 31, 2002.2005.

Commodity Risk—Non-trading—WP&L is exposed to the impact of market fluctuations in the commodity price and transportation costs of electricity and natural gas products it markets. WP&L employs established policies and procedures to manage its risks associated with these market fluctuations including the use of various commodity derivatives. WP&L’s exposure to commodity price risks is 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(i) of the “Notes to Consolidated Financial Statements” for further discussion.

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

Equity Price Risk—RiskWP&L maintains - WPL is exposed to equity price risk as a trust fund to fundresult of its anticipated nuclear decommissioning costs. At Dec. 31, 2002investments in debt and 2001, this fund was invested primarily in domestic equity securities, including securities held by its pension and debt instruments. Fluctuations in equity prices or interest rates will not affect WP&L’s consolidated results of operations as such fluctuations are recorded in equally offsetting amounts of investment income and depreciation when they are realized. In 2001, WP&L entered into a four-year hedge on equity assets in its nuclear decommissioning trust fund. Refer to Note 10(c) of the “Notes to Consolidated Financial Statements” for further discussion. Refer to Notes 1(l) and 10 of the “Notes to Consolidated Financial Statements” for further discussion of WP&L’s derivative financial instruments.other postretirement benefit plans.

New Accounting Pronouncements—In November 2002, the FASB issued - Other than FIN 45 which requires disclosures by a guarantor about its obligations under certain guarantees that it has issued. FIN 45 also requires recognizing, at the inception47, “Accounting for Conditional Asset Retirement Obligations—an interpretation of a guarantee, a liabilityStatement of Financial Accounting Standards (SFAS) 143, “Accounting for the fair value of the obligation undertaken in issuing the guarantee. The recognition and measurement provisions of FIN 45 are effective on a prospective basis for guarantees issued or modified after Dec. 31, 2002. The disclosure requirements of FIN 45 are effective for financial statements of interim or annual periods ending after Dec. 15, 2002. WP&LAsset Retirement Obligations”,” WPL does not anticipate FIN 45 willexpect the other various new accounting pronouncements that were effective in 2005 to have a material impact on its financial condition or results of operations. Refer to Note 11(d) of the “Notes to Consolidated Financial Statements” for additional information on guarantees.

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

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

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

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

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

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

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

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

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

Regulatory Assets and Liabilities—LiabilitiesWP&L - WPL is regulated by various federal and state regulatory agencies. As a result, WP&Lit qualifies for the application of SFAS 71, which“Accounting for the Effects of Certain Types of Regulation” (SFAS 71). SFAS 71 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 and amounts collected in rates for various reasons.which the related costs have not yet been incurred.

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

Asset Valuations -

Asset Valuations—

Investments—The Consolidated Balance Sheets include investments in available-for-sale securities accountedLong-Lived Assets Held for in accordance with SFAS 115. WP&L monitors any unrealized losses from such investments to determineSale - WPL’s assets held for sale are reviewed for possible impairment each reporting period and impairment charges are recorded if the losscarrying value of such assets exceeds the estimated fair value less cost to sell. The fair values of WPL’s assets held for sale are generally determined based upon current market information including information from recently negotiated deals and bid information received from potential buyers when available. If current market information is considerednot available, WPL estimates the fair value of its assets held for sale utilizing appraisals or valuation techniques such as expected discounted future cash flows. WPL must make assumptions regarding these estimated future cash flows and other factors to be a temporary or permanent decline. The determination as to whether the investment is temporarily versus permanently impaired requires considerable judgment. When the investment is considered permanently impaired, the previously recorded unrealized loss would be recorded directly to the income statement as a realized loss. The Consolidated Balance Sheets also contain various other investments that are evaluated for recoverability when indicators of impairment may exist.

Derivative Financial Instruments—WP&L uses derivative financial instruments to hedge exposures to fluctuations in interest rates, certain commodity prices, volatility in a portion of natural gas sales volumes due to weather and to mitigate the equity price volatility associated with certain investments in equity securities. WP&L does not use such instruments for speculative purposes. To account for these derivative instruments in accordance with the applicable accounting rules, WP&L must determine the fair value of its derivatives. In accordance with SFAS 133, the fair value of all derivative instruments are recognized as either assets or liabilities in the balance sheet with the changes in their value recognized in earnings for the non-regulated businesses, unless specific hedge accounting criteria are met. For WP&L, changes in the derivatives fair values are generally recorded as regulatory assets or liabilities. If an established, quoted market exists for the underlying commodityrespective assets. Refer to Note 15 of the derivative instrument, WP&L uses the quoted market price“Notes 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 contractsConsolidated Financial Statements” for the purchase and sale of non-financial assets to assess whether the contracts meet the definition of a derivative and the requirements to follow hedge accounting as allowed by the applicable accounting rules. The determination of derivative status and valuations involves considerable judgment. Based on the fuel and natural gas cost recovery mechanisms in place, as well as other specific regulatory authorizations, changes in fair market values of derivatives generally have no impact on WP&L’s results of operations.additional information.

 

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

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

and reasonable projections and are reviewed annually with an outside actuary firm and an investment consulting firm. As of Dec. 31, 2002, WP&L was usingSep. 30, 2005 (WPL’s measurement date), WPL’s future assumptions included a 6.75%5.5% discount rate to calculate benefit obligations and a 9%8.5% annual rate of return on investments. In selecting an assumed discount rate, WP&LWPL reviews various corporate Aa bond indices. The 9%8.5% 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.

Income Taxes - WPL accounts for income taxes under SFAS 109, “Accounting for Income Taxes.” Under these rules, certain assumptions are made which represent significant estimates. There are many factors involved in determining an entity’s income tax assets, liabilities, benefits and expense each period. These factors include assumptions regarding WPL’s future taxable income as well as the impacts from the completion of audits of the tax treatment of certain transactions. WPL’s assumptions are supported by historical data and reasonable projections and are reviewed quarterly by management. Significant changes in these assumptions could have a material impact on WPL’s financial condition and results of operations. Refer to Note 5 of the “Notes to Consolidated Financial Statements” for further discussion.

Accounting for Costs Related to the MISO Wholesale Energy Market - Effective April 1, 2005, MISO implemented the MISO Midwest Market, a bid-based energy market. The market requires that all market participants submit day-ahead and/or real-time bids and offers for energy at locations across the MISO region. MISO then calculates the most efficient solution for all the bids and offers made in the market that day, and determines a locational marginal price which reflects the market price for energy. As a participant in the new MISO Midwest Market, WPL is required to follow MISO’s instructions when dispatching generating units to support MISO’s responsibility for maintaining stability of the transmission system.

As a participant in MISO, WPL offers its generation and bids its demand into the market on an hourly basis, resulting in net receipt from or net obligation to MISO for each hour of each day. MISO aggregates these hourly transactions and currently provides updated settlement statements to market participants seven, 14, 55, 105, and 155 days after each operating day. MISO also indicated that it will begin performing a 365-day settlement run on April 1, 2006. The 365-day settlement statements are expected to continue until all operating day transactions from April 1, 2005 through Aug. 31, 2005 have been resettled. These updated settlement statements may reflect billing adjustments, resulting in an increase or decrease to the net receipt from or net obligation to MISO, which may or may not be recovered through the rate recovery process. These updated settlement statements and charges may be disputed by market participants, including WPL, in the MISO market. MISO and its participants also have the ability to file with the FERC for settlement periods which may extend beyond 365 days.

At the end of each month, the amount due from or payable to MISO for the last seven days of the month is estimated, thus significant changes in the estimates and new information provided by MISO in subsequent settlement statements could have a material impact on WPL’s results of operations.

 

A-18


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

Coal Delivery Disruptions - In May 2005, Burlington Northern Santa Fe (BNSF) and Union Pacific railroad train derailments in Wyoming caused damage to heavily-used joint railroad lines that supply coal to numerous generating facilities in the U.S., including facilities owned by WPL. These railroads invoked their force majeure rights to stop performing under coal delivery contracts serving WPL following the derailments. BNSF and Union Pacific discontinued their force majeure effective June 3, 2005 and Nov. 23, 2005, respectively. Repair of the damaged lines has been suspended during the winter months and is expected to resume again in spring 2006 with anticipated congestion and delays of coal delivery throughout 2006. The damaged railroad lines limited coal deliveries from the Powder River Basin to certain generating facilities owned by WPL. Winter weather and other operational issues have prevented the railroads from increasing delivery rates on a consistent basis beyond the levels experienced during the force majuere. As a result of the ongoing conservation efforts, coal inventories were approaching normal levels at Dec. 31, 2005, allowing operations at most plants to resume to normal dispatch levels. WPL continues to closely monitor the delivery rates and will continue to take proactive fuel management actions to conserve coal when necessary to preserve reliability of its plants by reducing coal-fired generation during weekday off-peak hours and weekends and when replacement costs are more economical. These actions result in increased energy production and purchase costs for the system. Refer to Note 1(c) of the “Notes to Consolidated Financial Statements” and “Rates and Regulatory Matters” for additional information regarding regulatory recovery of costs associated with these coal delivery disruptions.

Retirement Benefits—Depreciation StudyWP&L’s qualified pension - WPL will begin conducting an updated depreciation study related to its utility plant in service in 2006 and other postretirement benefit expensesis unable to determine whether the impacts will result in a material impact on its financial condition or results of operations.

Calpine Bankruptcy - In December 2005, Calpine filed voluntary petitions to restructure under Chapter 11 of the U.S. Bankruptcy Code. WPL has purchased power agreements with Calpine subsidiaries related to the RockGen and Riverside generating facilities. The RockGen facility is part of the bankruptcy proceedings but the Riverside facility is excluded. WPL utilizes the RockGen facility primarily for 2003 arecapacity. WPL is currently expectedevaluating its options should the purchased power agreement be terminated by the bankruptcy trustees. While WPL is unable to be approximately $7 million higher than in 2002, primarily dueprovide any assurances at this time, it does not expect the Calpine bankruptcy to unfavorable asset returns,have a reduction in the discount rate used to value plan benefit obligations and expected increases in retiree medical costs. WP&L will pursue the possible recoverymaterial adverse impact on its future financial condition or results of these cost increases in any rate filings it has.operations.

 

Enterprise Resource Planning (ERP) System—Alliant Energy implemented a new ERP system in October 2002 which will result in annual amortization expense of approximately $11 million (approximately $5 million for WP&L) for five years. Alliant Energy is seeking rate recovery of the utility portion of the amortized expenses which represents a significant majority of the amortized expenses.A-19


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, 20022005 and 2001,2004, and the related consolidated statements of income, cash flows, and changes in common equity for each of the three years in the period ended December 31, 2002.2005. These financial statements are the responsibility of the Company’s management. Our responsibility is to express an opinion on thesethe 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, 20022005 and 2001,2004, and the results of its operations and its cash flows for each of the three years in the period ended December 31, 20022005, in conformity with accounting principles generally accepted in the United States of America.

DELOITTE & TOUCHE LLP

Milwaukee, Wisconsin

March 18, 2003

1, 2006

 

(THIS PAGE INTENTIONALLY LEFT BLANK)

A-20


CONSOLIDATED FINANCIAL STATEMENTS

CONSOLIDATED STATEMENTS OF INCOME

 

   

Year Ended December 31,


 
   

2002


   

2001


   

2000


 
   

(in thousands)

 

Operating revenues:

               

Electric utility

  

$

787,680

 

  

$

753,450

 

  

$

692,191

 

Gas utility

  

 

179,091

 

  

 

206,863

 

  

 

165,152

 

Water

  

 

5,307

 

  

 

5,040

 

  

 

5,038

 

   


  


  


   

 

972,078

 

  

 

965,353

 

  

 

862,381

 

   


  


  


Operating expenses:

               

Electric production fuels

  

 

132,492

 

  

 

120,722

 

  

 

113,208

 

Purchased power

  

 

217,209

 

  

 

217,306

 

  

 

146,939

 

Cost of gas sold

  

 

110,119

 

  

 

153,823

 

  

 

107,131

 

Other operation and maintenance

  

 

215,689

 

  

 

186,477

 

  

 

188,967

 

Depreciation and amortization

  

 

136,232

 

  

 

129,098

 

  

 

139,911

 

Taxes other than income taxes

  

 

32,874

 

  

 

32,504

 

  

 

29,163

 

   


  


  


   

 

844,615

 

  

 

839,930

 

  

 

725,319

 

   


  


  


Operating income

  

 

127,463

 

  

 

125,423

 

  

 

137,062

 

   


  


  


Interest expense and other:

               

Interest expense

  

 

40,202

 

  

 

43,483

 

  

 

44,644

 

Interest income

  

 

(21,590

)

  

 

(8,109

)

  

 

(13,143

)

Equity income from unconsolidated investments

  

 

(17,022

)

  

 

(15,535

)

  

 

(552

)

Allowance for funds used during construction

  

 

(2,639

)

  

 

(4,753

)

  

 

(5,365

)

Miscellaneous, net

  

 

2,864

 

  

 

(4,391

)

  

 

(2,841

)

   


  


  


   

 

1,815

 

  

 

10,695

 

  

 

22,743

 

   


  


  


Income before income taxes

  

 

125,648

 

  

 

114,728

 

  

 

114,319

 

   


  


  


Income taxes

  

 

44,724

 

  

 

41,238

 

  

 

42,918

 

   


  


  


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

  

 

80,924

 

  

 

73,490

 

  

 

71,401

 

   


  


  


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

  

 

—  

 

  

 

—  

 

  

 

35

 

   


  


  


Net income

  

 

80,924

 

  

 

73,490

 

  

 

71,436

 

   


  


  


Preferred dividend requirements

  

 

3,310

 

  

 

3,310

 

  

 

3,310

 

   


  


  


Earnings available for common stock

  

$

77,614

 

  

$

70,180

 

  

$

68,126

 

   


  


  


   Year Ended December 31, 
   2005  2004  2003 
   (in millions) 

Operating revenues:

    

Electric utility

  $1,073.9  $939.8  $910.1 

Gas utility

   322.3   253.8   272.4 

Other

   13.4   16.2   34.5 
             
   1,409.6   1,209.8   1,217.0 
             

Operating expenses:

    

Electric production fuel and purchased power

   600.8   431.5   409.7 

Cost of gas sold

   231.9   165.8   186.3 

Other operation and maintenance

   259.1   282.1   292.6 

Depreciation and amortization

   107.9   111.0   104.9 

Taxes other than income taxes

   35.3   36.6   31.9 
             
   1,235.0   1,027.0   1,025.4 
             

Operating income

   174.6   182.8   191.6 
             

Interest expense and other:

    

Interest expense

   40.4   33.5   37.9 

Equity income from unconsolidated investments

   (26.3)  (25.0)  (20.7)

Allowance for funds used during construction

   (3.3)  (4.5)  (4.0)

Interest income and other

   (2.2)  (1.2)  (2.3)
             
   8.6   2.8   10.9 
             

Income before income taxes

   166.0   180.0   180.7 
             

Income taxes

   60.9   66.3   65.8 
             

Net income

   105.1   113.7   114.9 
             

Preferred dividend requirements

   3.3   3.3   3.3 
             

Earnings available for common stock

  $101.8  $110.4  $111.6 
             

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

 

A-21


CONSOLIDATED BALANCE SHEETS

 

   

December 31,


 

ASSETS


  

2002


   

2001


 
   

(in thousands)

 

Property, plant and equipment:

          

Electric plant in service

  

$

1,843,834

 

  

$

1,779,593

 

Gas plant in service

  

 

286,652

 

  

 

280,881

 

Water plant in service

  

 

33,062

 

  

 

32,497

 

Other plant in service

  

 

242,329

 

  

 

243,121

 

Accumulated depreciation

  

 

(1,410,036

)

  

 

(1,328,111

)

   


  


Net plant

  

 

995,841

 

  

 

1,007,981

 

Construction work in progress

  

 

96,746

 

  

 

37,828

 

Other, net

  

 

17,811

 

  

 

18,085

 

   


  


   

 

1,110,398

 

  

 

1,063,894

 

   


  


Current assets:

          

Cash and temporary cash investments

  

 

8,577

 

  

 

307

 

Accounts receivable:

          

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

  

 

7,977

 

  

 

33,190

 

Associated companies

  

 

21,484

 

  

 

3,676

 

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

  

 

18,191

 

  

 

16,571

 

Production fuel, at average cost

  

 

18,980

 

  

 

17,314

 

Materials and supplies, at average cost

  

 

22,133

 

  

 

20,669

 

Gas stored underground, at average cost

  

 

16,679

 

  

 

22,187

 

Regulatory assets

  

 

27,999

 

  

 

5,163

 

Prepaid gross receipts tax

  

 

27,388

 

  

 

25,673

 

Other

  

 

8,599

 

  

 

7,855

 

   


  


   

 

178,007

 

  

 

152,605

 

   


  


Investments:

          

Nuclear decommissioning trust funds

  

 

223,734

 

  

 

215,794

 

Investment in ATC and other

  

 

133,043

 

  

 

127,941

 

   


  


   

 

356,777

 

  

 

343,735

 

   


  


Other assets:

          

Regulatory assets

  

 

102,674

 

  

 

109,864

 

Deferred charges and other

  

 

236,741

 

  

 

205,702

 

   


  


   

 

339,415

 

  

 

315,566

 

   


  


Total assets

  

$

1,984,597

 

  

$

1,875,800

 

   


  


   December 31, 
   2005  2004 
   (in millions) 

ASSETS

   

Property, plant and equipment:

   

Electric plant in service

  $2,047.1  $1,905.4 

Gas plant in service

   319.4   304.1 

Other plant in service

   222.0   250.5 

Accumulated depreciation

   (1,054.6)  (1,037.6)
         

Net plant

   1,533.9   1,422.4 

Leased Sheboygan Falls Energy Facility, less accumulated amortization of $3.6

   120.2   —   

Construction work in progress

   53.0   62.2 

Other, less accumulated depreciation of $0.5 and $0.3

   1.4   1.4 
         
   1,708.5   1,486.0 
         

Current assets:

   

Cash and temporary cash investments

   —     0.1 

Accounts receivable:

   

Customer, less allowance for doubtful accounts of $2.1 and $1.1

   167.5   139.7 

Other, less allowance for doubtful accounts of $0.6 and $—

   40.0   30.5 

Production fuel, at average cost

   20.2   15.9 

Materials and supplies, at average cost

   18.2   20.5 

Gas stored underground, at average cost

   40.2   30.3 

Regulatory assets

   32.7   21.1 

Prepaid gross receipts tax

   31.8   33.0 

Assets held for sale

   26.1   308.9 

Other

   33.7   18.6 
         
   410.4   618.6 
         

Investments:

   

Investment in American Transmission Company LLC

   152.4   141.5 

Other

   44.6   95.9 
         
   197.0   237.4 
         

Other assets:

   

Regulatory assets

   168.9   114.2 

Deferred charges and other

   182.8   199.9 
         
   351.7   314.1 
         

Total assets

  $2,667.6  $2,656.1 
         

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

 

A-22


CONSOLIDATED BALANCE SHEETS (Continued)

 

   

December 31,


 

CAPITALIZATION AND LIABILITIES


  

2002


   

2001


 
   

(in thousands)

 

Capitalization (See Consolidated Statements of Capitalization):

          

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

  

$

66,183

 

  

$

66,183

 

Additional paid-in capital

  

 

325,603

 

  

 

264,603

 

Retained earnings

  

 

399,302

 

  

 

381,333

 

Accumulated other comprehensive loss

  

 

(24,108

)

  

 

(10,167

)

   


  


Total common equity

  

 

766,980

 

  

 

701,952

 

   


  


Cumulative preferred stock

  

 

59,963

 

  

 

59,963

 

Long-term debt (excluding current portion)

  

 

468,208

 

  

 

468,083

 

   


  


   

 

1,295,151

 

  

 

1,229,998

 

   


  


Current liabilities:

          

Variable rate demand bonds

  

 

55,100

 

  

 

55,100

 

Commercial paper

  

 

60,000

 

  

 

—  

 

Notes payable to associated companies

  

 

—  

 

  

 

90,816

 

Accounts payable

  

 

90,869

 

  

 

94,091

 

Accounts payable to associated companies

  

 

43,276

 

  

 

25,231

 

Accrued taxes

  

 

19,353

 

  

 

2,057

 

Regulatory liabilities

  

 

16,938

 

  

 

7,619

 

Other

  

 

29,064

 

  

 

25,543

 

   


  


   

 

314,600

 

  

 

300,457

 

   


  


Other long-term liabilities and deferred credits:

          

Accumulated deferred income taxes

  

 

191,894

 

  

 

206,245

 

Accumulated deferred investment tax credits

  

 

23,241

 

  

 

24,907

 

Pension and other benefit obligations

  

 

58,921

 

  

 

18,175

 

Customer advances

  

 

36,555

 

  

 

34,178

 

Other

  

 

64,235

 

  

 

61,840

 

   


  


   

 

374,846

 

  

 

345,345

 

   


  


Commitments and contingencies (Note 11)

          

Total capitalization and liabilities

  

$

1,984,597

 

  

$

1,875,800

 

   


  


   December 31, 
   2005  2004 
   

(in millions, except per

share and share amounts)

 

CAPITALIZATION AND LIABILITIES

   

Capitalization (Refer to Consolidated Statements of Capitalization):

   

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

  $66.2  $66.2 

Additional paid-in capital

   525.8   525.7 

Retained earnings

   473.7   461.7 

Accumulated other comprehensive loss

   (3.1)  (2.7)
         

Total common equity

   1,062.6   1,050.9 
         

Cumulative preferred stock

   60.0   60.0 

Long-term debt, net (excluding current portion)

   364.3   364.2 
         
   1,486.9   1,475.1 
         

Current liabilities:

   

Current maturities

   —     88.0 

Variable rate demand bonds

   39.1   39.1 

Commercial paper

   93.5   47.0 

Accounts payable

   122.3   91.0 

Accounts payable to associated companies

   29.7   20.3 

Regulatory liabilities

   86.2   23.8 

Liabilities held for sale

   2.2   196.1 

Other

   51.5   39.4 
         
   424.5   544.7 
         

Other long-term liabilities and deferred credits:

   

Deferred income taxes

   224.8   232.6 

Deferred investment tax credits

   17.8   19.9 

Regulatory liabilities

   191.9   221.5 

Capital lease obligations - Sheboygan Falls Energy Facility

   120.8   —   

Pension and other benefit obligations

   101.8   85.7 

Other

   99.1   76.6 
         
   756.2   636.3 
         

Commitments and contingencies (Note 11)

   

Total capitalization and liabilities

  $2,667.6  $2,656.1 
         

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

 

A-23


CONSOLIDATED STATEMENTS OF CASH FLOWS

 

   

Year Ended December 31,


 
   

2002


   

2001


   

2000


 
   

(in thousands)

 

Cash flows from operating activities:

               

Net income

  

$

80,924

 

  

$

73,490

 

  

$

71,436

 

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

               

Depreciation and amortization

  

 

136,232

 

  

 

129,098

 

  

 

139,911

 

Amortization of nuclear fuel

  

 

6,486

 

  

 

4,554

 

  

 

5,066

 

Amortization of deferred energy efficiency expenditures

  

 

21,179

 

  

 

14,361

 

  

 

14,361

 

Deferred tax benefits and investment tax credits

  

 

(5,562

)

  

 

(6,791

)

  

 

(12,077

)

Equity income from unconsolidated investments, net

  

 

(17,022

)

  

 

(15,535

)

  

 

(552

)

Distributions from equity method investments

  

 

13,199

 

  

 

8,450

 

  

 

992

 

Other

  

 

(22,160

)

  

 

(10,539

)

  

 

(15,451

)

Other changes in assets and liabilities:

               

Accounts receivable

  

 

5,785

 

  

 

14,408

 

  

 

(29,733

)

Accounts payable

  

 

(11,676

)

  

 

(20,549

)

  

 

36,265

 

Accrued taxes

  

 

17,296

 

  

 

(1,225

)

  

 

(3,257

)

Other

  

 

(931

)

  

 

(53,836

)

  

 

(32,901

)

   


  


  


Net cash flows from operating activities

  

 

223,750

 

  

 

135,886

 

  

 

174,060

 

   


  


  


Cash flows from (used for) financing activities:

               

Common stock dividends

  

 

(59,645

)

  

 

(60,449

)

  

 

—  

 

Preferred stock dividends

  

 

(3,310

)

  

 

(3,310

)

  

 

(3,310

)

Capital contribution from parent

  

 

61,000

 

  

 

35,000

 

  

 

—  

 

Proceeds from issuance of long-term debt

  

 

—  

 

  

 

—  

 

  

 

100,000

 

Reductions in long-term debt

  

 

—  

 

  

 

(47,000

)

  

 

(1,875

)

Net change in short-term borrowings

  

 

(30,816

)

  

 

61,572

 

  

 

(96,505

)

Other

  

 

5,086

 

  

 

(4,989

)

  

 

2,677

 

   


  


  


Net cash flows from (used for) financing activities

  

 

(27,685

)

  

 

(19,176

)

  

 

987

 

   


  


  


Cash flows used for investing activities:

               

Utility construction expenditures

  

 

(156,921

)

  

 

(147,032

)

  

 

(131,640

)

Nuclear decommissioning trust funds

  

 

(16,092

)

  

 

(16,092

)

  

 

(16,092

)

Proceeds from formation of ATC and other asset dispositions

  

 

—  

 

  

 

75,600

 

  

 

961

 

Other

  

 

(14,782

)

  

 

(29,308

)

  

 

(28,109

)

   


  


  


Net cash flows used for investing activities

  

 

(187,795

)

  

 

(116,832

)

  

 

(174,880

)

   


  


  


Net increase (decrease) in cash and temporary cash investments

  

 

8,270

 

  

 

(122

)

  

 

167

 

   


  


  


Cash and temporary cash investments at beginning of period

  

 

307

 

  

 

429

 

  

 

262

 

   


  


  


Cash and temporary cash investments at end of period

  

$

8,577

 

  

$

307

 

  

$

429

 

   


  


  


Supplemental cash flows information:

               

Cash paid during the period for:

               

Interest

  

$

39,540

 

  

$

43,237

 

  

$

40,455

 

   


  


  


Income taxes, net of refunds

  

$

35,875

 

  

$

54,161

 

  

$

54,676

 

   


  


  


   Year Ended December 31, 
   2005  2004  2003 
   (in millions) 

Cash flows from operating activities:

    

Net income

  $105.1  $113.7  $114.9 

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

    

Depreciation and amortization

   107.9   111.0   104.9 

Other amortizations

   35.7   41.4   51.3 

Deferred tax expense (benefit) and investment tax credits

   (3.5)  8.5   21.8 

Equity income from unconsolidated investments

   (26.3)  (25.0)  (20.7)

Distributions from equity method investments

   24.7   20.5   14.0 

Other

   (1.0)  (3.7)  (2.3)

Other changes in assets and liabilities:

    

Accounts receivable

   (37.3)  (16.9)  (10.0)

Sale of accounts receivable

   —     (50.0)  (66.0)

Income tax refunds receivable

   —     16.8   (16.8)

Regulatory assets

   (91.5)  (67.0)  (40.3)

Accounts payable

   36.4   8.6   (2.6)

Regulatory liabilities

   23.2   (18.7)  (14.7)

Benefit obligations and other

   3.2   60.1   5.0 
             

Net cash flows from operating activities

   176.6   199.3   138.5 
             

Cash flows used for investing activities:

    

Utility construction and acquisition expenditures

   (185.3)  (211.5)  (151.6)

Proceeds from asset sales

   80.1   —     21.3 

Purchases of securities within nuclear decommissioning trusts

   (6.1)  (209.5)  (168.2)

Sales of securities within nuclear decommissioning trusts

   83.4   357.7   174.9 

Changes in restricted cash within nuclear decommissioning trusts

   (17.3)  (151.1)  (9.6)

Other

   2.3   0.1   24.8 
             

Net cash flows used for investing activities

   (42.9)  (214.3)  (108.4)
             

Cash flows used for financing activities:

    

Common stock dividends

   (89.8)  (89.0)  (70.6)

Preferred stock dividends

   (3.3)  (3.3)  (3.3)

Capital contribution from parent

   —     —     200.0 

Proceeds from issuance of long-term debt

   —     100.0   —   

Reductions in long-term debt

   (88.0)  (62.0)  (70.0)

Net change in commercial paper

   46.5   47.0   (60.0)

Other

   0.8   (4.7)  (7.7)
             

Net cash flows used for financing activities

   (133.8)  (12.0)  (11.6)
             

Net increase (decrease) in cash and temporary cash investments

   (0.1)  (27.0)  18.5 
             

Cash and temporary cash investments at beginning of period

   0.1   27.1   8.6 
             

Cash and temporary cash investments at end of period

  $—    $0.1  $27.1 
             

Supplemental cash flows information:

    

Cash paid during the period for:

    

Interest

  $41.9  $31.3  $39.6 
             

Income taxes, net of refunds

  $64.1  $40.4  $84.3 
             

Noncash investing and financing activities:

    

Capital lease obligations incurred

  $123.8  $—    $—   
             

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

 

A-24


CONSOLIDATED STATEMENTS OF CAPITALIZATION

 

   

December 31,


 
   

2002


   

2001


 
   

(in thousands,

except share amounts)

 

Common equity

  

$

766,980

 

  

$

701,952

 

   


  


Cumulative preferred stock:

          

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

          

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

  

 

9,997

 

  

 

9,997

 

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

  

 

7,491

 

  

 

7,491

 

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

  

 

6,498

 

  

 

6,498

 

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

  

 

2,996

 

  

 

2,996

 

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

  

 

2,995

 

  

 

2,995

 

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

  

 

15,000

 

  

 

15,000

 

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

  

 

14,986

 

  

 

14,986

 

   


  


   

 

59,963

 

  

 

59,963

 

   


  


Long-term debt:

          

First Mortgage Bonds:

          

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

  

 

8,500

 

  

 

8,500

 

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

  

 

14,600

 

  

 

14,600

 

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

  

 

16,000

 

  

 

16,000

 

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

  

 

16,000

 

  

 

16,000

 

1992 Series W, 8.6%, due 2027

  

 

70,000

 

  

 

70,000

 

1992 Series X, 7.75%, due 2004

  

 

62,000

 

  

 

62,000

 

1992 Series Y, 7.6%, due 2005

  

 

72,000

 

  

 

72,000

 

   


  


   

 

259,100

 

  

 

259,100

 

Debentures, 7%, due 2007

  

 

105,000

 

  

 

105,000

 

Debentures, 5.7%, due 2008

  

 

60,000

 

  

 

60,000

 

Debentures, 7 5/8%, due 2010

  

 

100,000

 

  

 

100,000

 

   


  


   

 

524,100

 

  

 

524,100

 

   


  


Less:

          

Variable rate demand bonds

  

 

(55,100

)

  

 

(55,100

)

Unamortized debt discount, net

  

 

(792

)

  

 

(917

)

   


  


   

 

468,208

 

  

 

468,083

 

   


  


Total capitalization

  

$

1,295,151

 

  

$

1,229,998

 

   


  


   December 31, 
   2005  2004 
   (dollars in millions, except
per share amounts)
 

Common equity (Refer to Consolidated Balance Sheets)

  $1,062.6  $1,050.9 
         

Cumulative preferred stock:

   

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

   

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

   10.0   10.0 

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

   7.5   7.5 

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

   6.5   6.5 

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

   3.0   3.0 

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

   3.0   3.0 

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

   15.0   15.0 

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

   15.0   15.0 
         
   60.0   60.0 
         

Long-term debt, net:

   

First Mortgage Bonds:

   

1984 Series A, variable rate (3.8% at Dec. 31, 2005), due 2014

   8.5   8.5 

1988 Series A, variable rate (3.7% at Dec. 31, 2005), due 2015

   14.6   14.6 

1991 Series A, variable rate (3.88% at Dec. 31, 2005), due 2015

   16.0   16.0 

1992 Series Y, 7.6%, matured in 2005

   —     72.0 

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

   —     16.0 
         
   39.1   127.1 

Other:

   

Debentures, 7%, due 2007

   105.0   105.0 

Debentures, 5.7%, due 2008

   60.0   60.0 

Debentures, 7.625%, due 2010

   100.0   100.0 

Debentures, 6.25%, due 2034

   100.0   100.0 
         
   365.0   365.0 
         

Total, gross

   404.1   492.1 

Less:

   

Current maturities

   —     (88.0)

Variable rate demand bonds

   (39.1)  (39.1)

Unamortized debt discount, net

   (0.7)  (0.8)
         

Total long-term debt, net

   364.3   364.2 
         

Total capitalization

  $1,486.9  $1,475.1 
         

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

 

A-25


CONSOLIDATED STATEMENTS OF CHANGES IN COMMON EQUITY

 

   

Common Stock


  

Additional Paid-In Capital


  

Retained Earnings


   

Accumulated Other Comprehensive Loss


   

Total Common Equity


 
   

(in thousands)

 

2000:

                       

Beginning balance

  

$

66,183

  

$

229,438

  

$

303,476

 

  

$

—  

 

  

$

599,097

 

Earnings available for common stock

          

 

68,126

 

       

 

68,126

 

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

               

 

(642

)

  

 

(642

)

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

               

 

(5,151

)

  

 

(5,151

)

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

               

 

(1,085

)

  

 

(1,085

)

                


  


Net unrealized losses on qualifying derivatives

               

 

(4,708

)

  

 

(4,708

)

                


  


Total comprehensive income

                    

 

63,418

 

Stock options exercised

      

 

78

            

 

78

 

   

  

  


  


  


Ending balance

  

 

66,183

  

 

229,516

  

 

371,602

 

  

 

(4,708

)

  

 

662,593

 

2001:

                       

Earnings available for common stock

          

 

70,180

 

       

 

70,180

 

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

               

 

(14,248

)

  

 

(14,248

)

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

               

 

5,952

 

  

 

5,952

 

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

               

 

(2,837

)

  

 

(2,837

)

                


  


Net unrealized gains on qualifying derivatives

               

 

8,789

 

  

 

8,789

 

                


  


Total comprehensive income

                    

 

64,721

 

Common stock dividends

          

 

(60,449

)

       

 

(60,449

)

Stock options exercised

      

 

87

            

 

87

 

Capital contribution from parent

      

 

35,000

            

 

35,000

 

   

  

  


  


  


Ending balance

  

 

66,183

  

 

264,603

  

 

381,333

 

  

 

(10,167

)

  

 

701,952

 

2002:

                       

Earnings available for common stock

          

 

77,614

 

       

 

77,614

 

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

               

 

(10,177

)

  

 

(10,177

)

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

               

 

(137

)

  

 

(137

)

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

               

 

3,627

 

  

 

3,627

 

                


  


Net unrealized losses on qualifying derivatives

               

 

(3,764

)

  

 

(3,764

)

                


  


Total comprehensive income

                    

 

63,673

 

Common stock dividends

          

 

(59,645

)

       

 

(59,645

)

Capital contribution from parent

      

 

61,000

            

 

61,000

 

   

  

  


  


  


Ending balance

  

$

66,183

  

$

325,603

  

$

399,302

 

  

($

24,108

)

  

$

766,980

 

   

  

  


  


  


   Common
Stock
  Additional
Paid-In
Capital
  Retained
Earnings
  Accumulated
Other
Comprehensive
Loss
  Total
Common
Equity
 
   (in millions) 

2003:

        

Beginning balance (a)

  $66.2  $325.6  $399.3  ($24.1) $767.0 

Earnings available for common stock

       111.6    111.6 

Minimum pension liability adjustment, net of tax of $2.8

        4.2   4.2 
              

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

        (6.0)  (6.0)

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

        (5.6)  (5.6)
              

Net unrealized losses on qualifying derivatives

        (0.4)  (0.4)
              

Total comprehensive income

         115.4 

Common stock dividends

       (70.6)   (70.6)

Capital contribution from parent

     200.0     200.0 
                     

Ending balance

   66.2   525.6   440.3   (20.3)  1,011.8 

2004:

        

Earnings available for common stock

       110.4    110.4 

Minimum pension liability adjustment, net of tax of $11.7

        17.6   17.6 
              

Total comprehensive income

         128.0 

Common stock dividends

       (89.0)   (89.0)

Other

     0.1     0.1 
                     

Ending balance

   66.2   525.7   461.7   (2.7)  1,050.9 

2005:

        

Earnings available for common stock

       101.8    101.8 

Minimum pension liability adjustment, net of tax of ($0.3)

        (0.4)  (0.4)
              

Total comprehensive income

         101.4 

Common stock dividends

       (89.8)   (89.8)

Other

     0.1     0.1 
                     

Ending balance

  $66.2  $525.8  $473.7  ($3.1) $1,062.6 
                     

 

(a)Accumulated other comprehensive loss at Jan. 1, 2003 consisted of ($24.5) of minimum pension liability adjustments and $0.4 of net unrealized gains on qualifying derivatives.

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

 

A-26


NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

(1) SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES

(a) General—General - The consolidated financial statements include the accounts of WP&LWisconsin Power and Light Company (WPL) and its principal consolidated subsidiaries WPL Transco LLC and South Beloit. WP&LBeloit Water, Gas and Electric Company (South Beloit). 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 watervarious other energy-related services. 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. 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 period amounts have been reclassified on a basis consistent with the current year presentation.

Most reclassifications relate to the reporting of assets and liabilities held for sale pursuant to Statement of Financial Accounting Standards (SFAS) 144, “Accounting for the Impairment or Disposal of Long-lived Assets” (SFAS 144). Unless otherwise noted, the notes herein have been revised to exclude assets and liabilities held for sale for all periods presented. Refer to Note 15 for additional information.

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

(b) Regulation—RegulationWP&L - WPL is subject to regulation under PUHCA,by the Securities and Exchange Commission (SEC), FERC, the PSCWPublic Service Commission of Wisconsin (PSCW), the Illinois Commerce Commission (ICC) and the ICC.U.S. Environmental Protection Agency (EPA). WPL is also subject to regulation by various other federal, state and local agencies.

(c) Regulatory Assets and Liabilities—LiabilitiesWP&L - WPL is subject to the provisions of SFAS 71, “Accounting for the Effects of Certain Types of Regulation,” which provides that rate-regulated public utilities record certain costs and credits allowed in the rate making process in different periods than for non-regulated entities. These are deferred as regulatory assets or accrued as regulatory liabilities and are recognized in the Consolidated Statements of Income at the time they are reflected in rates. As of

Regulatory Assets - At Dec. 31, 2002, WP&L had approximately $6 millionregulatory assets were comprised of the following items (in millions):

   2005  2004

Minimum pension liability (Note 6)

  $45.9  $39.4

Derivatives (Note 10(a))

   20.5   6.7

Kewaunee Nuclear Power Plant (Kewaunee) outage in 2005

   19.4   —  

Kewaunee sale (Note 16)

   16.1   1.5

Tax-related (Note 1(d))

   14.0   20.2

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

   12.4   11.9

Coal delivery disruptions

   12.3   —  

Asset retirement obligations (AROs) (Note 17)

   10.7   0.9

Energy conservation program costs

   9.3   14.3

Debt redemption costs

   9.1   9.6

Environmental-related (Note 11(e))

   9.0   12.9

Fuel cost recovery (Note 1(h))

   —     0.5

Other

   22.9   17.4
        
  $201.6  $135.3
        

A-27


A portion of the regulatory assets in the above table are not earning a return. These regulatory assets are expected to be recovered from customers in future rates, however the carrying costs of these assets are borne by Alliant Energy. At Dec. 31, the regulatory assets that were not earning returns.returns were as follows (in millions):

   2005  2004

Regulatory assets not earning returns

  $8  $11

Weighted average remaining life (in years)

   5   4

Kewaunee Outage in 2005 - WPL received approval from the PSCW to defer, beginning April 15, 2005, incremental fuel-related costs associated with the extension of an unplanned outage at Kewaunee, which occurred from February 2005 to early July 2005. The PSCW also approved the deferral of incremental operation and maintenance costs related to the unplanned outage.

Kewaunee Sale - WPL has received approval from the PSCW to defer all gains, losses, and transaction costs associated with the sale of Kewaunee. In July 2005, WPL completed the sale of its interest in Kewaunee and recognized a loss (excluding the benefits of the non-qualified decommissioning trust assets discussed in “Regulatory Liabilities”), including transaction costs, of $16 million from the sale. In December 2005, the PSCW issued a final order associated with Wisconsin Public Service Corporation’s (WPSC’s) 2006 base rate case, which only allowed WPSC recovery from its customers of 50% of the loss it recognized on the sale of its interest in Kewaunee. WPL will be seeking full recovery of the loss associated with the sale of its interest in Kewaunee in its next base rate case.

Coal Delivery Disruptions - WPL received approval from the PSCW to defer, beginning Aug. 3, 2005, incremental purchased power energy costs associated with coal conservation efforts at WPL due to coal delivery disruptions. The coal delivery disruptions were caused by railroad train derailments in Wyoming that caused damage to heavily-used joint railroad lines that supply coal to numerous generating facilities in the U.S., including facilities owned by WPL.

Asset Retirement Obligations - WPL believes it is probable that any differences between expenses for legal AROs calculated under SFAS 143, “Accounting for Asset Retirement Obligations” (SFAS 143) and Financial Accounting Standards Board (FASB) Interpretation No. (FIN) 47, “Accounting for Conditional Asset Retirement Obligations - an interpretation of SFAS 143” (FIN 47), and expenses recovered currently in rates will be recoverable in future rates, and is deferring the difference as a regulatory asset.

WPL periodically assesses whether its 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. WPL records charges against those regulatory assets that are no longer probable of future recovery. At Dec. 31, 2002 and 2001,2005, WPL recorded regulatory asset charges of $9 million primarily related to the uncertainty regarding the level of recovery of WPL’s loss on the sale of its interest in Kewaunee. These charges are reflected as a reduction to regulatory assets andin the “Other” line in the regulatory assets table above. While WPL feels its remaining regulatory assets are probable of future recovery, no assurance can be made that WPL will recover these regulatory assets in future rates.

Regulatory Liabilities - At Dec. 31, regulatory liabilities were comprised of the following items (in millions):

 

   

Regulatory Assets


  

Regulatory Liabilities


   

2002


  

2001


  

2002


  

2001


Energy efficiency program costs

  

$38.6

  

$33.9

  

$ —  

  

$ —  

Tax-related

  

25.0

  

29.0

  

14.6

  

15.1

Environmental-related

  

19.0

  

18.7

  

0.6

  

0.5

Other

  

48.1

  

33.4

  

17.0

  

7.6

   
  
  
  
   

$130.7

  

$115.0

  

$32.2

  

$23.2

   
  
  
  
   2005  2004

Cost of removal obligations

  $148.0  $204.4

Kewaunee decommissioning trust assets (Note 16)

   70.6   —  

Tax-related (Note 1(d))

   18.0   17.0

Derivatives (Note 10(a))

   17.1   4.7

Gas performance incentive (Note 1(h) and Note 2)

   12.0   15.1

Emission allowances

   1.6   0.9

Other

   10.8   3.2
        
  $278.1  $245.3
        

Regulatory liabilities related to cost of removal obligations, to the extent expensed through depreciation rates, reduce rate base. A significant portion of the remaining regulatory liabilities are not used to reduce rate base in the revenue requirement calculations utilized in WPL’s rate proceedings.

 

IfA-28


Cost of Removal Obligations - WPL collects in rates future removal costs for many assets that do not have an associated legal ARO. WPL records a regulatory liability for the estimated amounts it has collected in rates for these future removal costs less amounts spent on removal activities.

Kewaunee Decommissioning Trust Assets - WPL received approval from the PSCW to return the retail 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 suchKewaunee-related non-qualified decommissioning trust assets to their fair value.

customers over a two-year period through reduced rates that were effective beginning in July 2005. The regulatory liability in the above table also includes the wholesale portion of the trust assets, which refund is being addressed in WPL’s current wholesale rate case.

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

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

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

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

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

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

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

   2005  2004  2003 

PSCW formula - retail jurisdiction

  15.1% 15.2% 14.8%

FERC formula - wholesale jurisdiction

  6.7% 12.5% 9.5%

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):

   2005  2004  2003

Equity

  $2.7  $3.7  $2.9

Debt

   0.6   0.8   1.1
            
  $3.3  $4.5  $4.0
            

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

   2005  2004

Distribution

  $1,143.1  $1,050.4

Generation

   840.3   793.9

Other

   63.7   61.1
        
  $2,047.1  $1,905.4
        

A-29


WPL uses a combination of remaining life straight-line and sum-of-the-years-digitsstraight-line depreciation methods as approved by the PSCW and ICC. The remaining depreciable life of Kewaunee, of which WP&L 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 in Note 11(f).ICC. The average rates of depreciation for electric and gas properties, consistent with current rate making practices, were as follows:

 

   

2002


  

2001


  

2000


Electric

  

3.6%

  

3.7%

  

3.6%

Gas

  

4.1%

  

4.1%

  

4.1%

(g) Property, Plant and EquipmentUtility plant (other than acquisition adjustments) is recorded at original cost, which includes overhead, administrative costs and AFUDC. WP&L’s aggregate gross AFUDC recovery rates for 2002, 2001 and 2000, computed in accordance with the prescribed regulatory formula, were 2.6%, 7.9% and 10.8%, respectively.

   2005  2004  2003 

Electric

  3.6% 3.5% 3.7%

Gas

  3.8% 4.0% 4.0%

Other property, plant and equipment is recorded at original cost.cost, the majority of which is depreciated using the straight-line method, primarily over periods ranging from five to 15 years. Upon retirement or sale of property, plant and equipment, the cost and related accumulated depreciation are removed from the accounts and any gain or loss is included in “Miscellaneous, net” in the Consolidated Statements of Income. Ordinary retirements of utility plant, including removal costs less salvage value, are charged to accumulated depreciation upon removal from utility plant accounts and no gain or loss is recognized.

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

(i)(h) Utility Fuel Cost Recovery—RecoveryWP&L’s - WPL’s retail electric rates are based on annualforecasts of forward-looking test year periods and include estimates of future fuel and purchased energy costs anticipated during the test year. During each electric retail rate proceeding, the PSCW sets fuel monitoring ranges based on the forecasted fuel and purchased-power costs. Under PSCW rules, WP&L can seek emergency rate increases if the annual costs are more than 3% higher than the estimated costs used to establishdetermine rates. Any collectionsIf WPL’s actual fuel costs fall outside these fuel monitoring ranges during the test year period, WPL and/or other parties can request, and the PSCW can authorize an adjustment to future retail electric rates. The PSCW may authorize an interim rate increase, however if the final rate increase is less than the interim rate increase, WPL would refund the excess collection to customers at the current authorized return on equity rate. Recovery of capacity-related charges associated with WPL’s purchased power costs and network transmission charges are recovered from electric customers through changes in excessbase rates. WPL’s wholesale electric rates provide for subsequent adjustments to rates for changes in the cost of costs incurred will be refunded, with interest. Accordingly, WP&L has established a reserve due to overcollection of past fuel and purchased-power costs and expectspurchased energy. WPL’s retail gas tariffs provide for subsequent adjustments to refund such amountits natural gas rates for changes in 2003. WP&Lthe current monthly natural gas commodity price index. Also, WPL has a gas performance incentive which includes a sharing mechanism whereby 50% of all gains and losses relative to current commodity prices, as well as other benchmarks, are retained by WP&L,WPL, with the remainder refunded to or recovered from customers.

(j) Nuclear Refueling Outage Costs—(i) Generating Facility Outages - Operating expenses incurred during refueling outages at Kewaunee arewere expensed by WP&L as incurred. A scheduled refueling outage occurred at Kewaunee in late 2001. The next scheduled refueling outage at Kewaunee is anticipated to commence in Spring 2003.maintenance costs incurred during outages for WPL’s various other generating facilities are also expensed as incurred.

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

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

WP&L also utilizes derivatives to mitigate the equity price volatility associated with certain investments in equity securities. WP&L WPL does not use such instruments for speculative purposes. The fair value of all derivatives are recorded as assets or liabilities on the Consolidated Balance Sheets and gains and losses related to derivatives that are designated as, and qualify as hedges, are recognized in earnings when the underlying hedged item or physical transaction is recognized in income. Gains and losses related to derivatives that do not qualify for, or are not designated in hedge relationships, are recognized in earnings immediately. Based on the fuel and natural gas cost recovery mechanisms in place, as well as other specific regulatory authorizations, changes in fair market values of WP&L’sWPL’s derivatives generally have no impact on its results of operations. WP&Loperations, as they are generally reported as changes in regulatory assets and liabilities. WPL has a number ofsome commodity purchase and sales contracts that have been designated, and qualify for, the normal purchase and sale exception in SFAS 138, “Accounting for Certain Derivative Instruments and Certain Hedging Activities—an Amendment of SFAS 133.” Basedbased on this designation, these contracts are not accounted for as derivative instruments.

WP&L is exposed to losses related to financial instruments in the event of counterparties’ non-performance. WP&L has established controls to determine and monitor the creditworthiness of counterparties in order to mitigate its exposure to counterparty credit risk. WP&L is not aware of any material exposure to counterparty credit risk. Refer to NoteNotes 10 and 11(f) for further discussion of WP&L’sWPL’s derivative financial instruments.

instruments and related credit risk, respectively.

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

 

A-30


(n)(l) Asset Valuations - Long-lived assets to be held and used, excluding regulatory assets, 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.

Long-lived assets held for sale are reviewed for possible impairment each reporting period and impairment charges are recorded if the carrying value of such asset exceeds the estimated fair value less cost to sell. The fair value is determined by the use of bid information from potential buyers, quoted market prices, appraisals, or the use of other valuation techniques such as expected discounted future cash flows.

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

(n) Emission Allowances - Emission allowances are granted by the EPA to sources of pollution that allow the release of a prescribed amount of pollution each year. Unused emission allowances may be bought and sold or carried forward to be utilized in future anticipated cash flows oryears. Purchased emission allowances are recorded as intangible assets at their original cost and evaluated for impairment as long-lived assets to be held and used in accordance with SFAS 144. Emission allowances granted by the estimated fair value lessEPA are valued at a zero-cost basis. Amortization of emission allowances is based upon a weighted average cost for each category of vintage year utilized during the reporting period.

(o) New Accounting Pronouncements - Refer to sell, respectively.

Note 17 for discussion of FIN 47.

(2) UTILITY RATE MATTERS

In 2002December 2005, WPL received approval from the PSCW to begin refunding approximately $13 million to its natural gas customers for the customers’ portion of gains realized from its gas performance incentive program for the period from November 2004 to October 2005. Approximately 80%, or $10 million, of the total expected refund amount was refunded to customers in December 2005 and 2001, WP&L had an electricJanuary 2006. The remainder of the refund will be completed in 2006 after the PSCW completes its audit of the refund amount. At Dec. 31, 2005, WPL reserved for all amounts related to these refunds. Refer to Note 1(h) for further discussion of WPL’s fuel cost recovery mechanism that required WP&L to refund any overcollectionand Note 1(c) for discussion of fuel and purchased-power costs. WP&L has recorded the necessary reserve for refunds at Dec. 31, 2002 and 2001. In 2002, WP&L filed avarious other rate case with FERC related to its electric wholesale customers. An interim rate increase, subject to refund, of $6 million annually was granted effective April 2002. The case was subsequently settled with final rates of $3 million annually. At Dec. 31, 2002, WP&L recorded a reserve for the difference between interim and final rates.

matters.

(3) LEASES

(a) Operating Leases - Alliant Energy and WPL have entered into various agreements related to property, plant and equipment rights that are accounted for as operating leases. WPL’s most significant operating leases relate to certain purchased power agreements. These purchased power agreements contain fixed rental payments related to capacity and transmission rights and contingent rental payments related to the energy portion (actual megawatt-hours (MWhs)) of the respective agreements. Rental expenses associated with WPL’s operating leases were as follows (in millions):

WP&L’s

   2005  2004  2003

Operating lease rental expenses (excluding contingent rentals)

  $91  $63  $25

Contingent rentals related to certain purchased power agreements

   28   33   26

Other contingent rentals

   —     1   —  
            
  $119  $ 97  $51
            

A-31


At Dec. 31, 2005, WPL’s future minimum operating lease rental expenses, which include certain purchased-powerpayments, excluding contingent rentals, were as follows (in millions):

   2006  2007  2008  2009  2010  Thereafter  Total

Certain purchased power agreements

  $77  $78  $71  $62  $56  $131  $475

Synthetic leases

   8   7   3   3   5   8   34

Other

   1   1   1   1   1   2   7
                            
  $86  $86  $75  $66  $62  $141  $516
                            

The purchased power agreements for 2002, 2001 and 2000 were $24.5 million, $23.4meeting the criteria as operating leases are such that, over the contract term, Alliant Energy has exclusive rights to all or a substantial portion of the output from a specific generating facility. The purchased power agreements total in the above table includes $403 million and $7.9$55 million respectively. The purchased-power agreements below include $463 million and $78 million, respectively, related to a newthe Riverside plant (Riverside) currently under development and RockGen plant purchased power agreements, respectively. Alliant Energy’s agreements with Calpine Corporation (Calpine) subsidiaries related to the RockGen plant both in Wisconsin. Theand the Riverside plant is expectedprovide Alliant Energy the option to be placed in-servicepurchase these two facilities in 2004. 2009 and 2013, respectively. Refer to Note 18 for additional information concerning the impacts of FIN 46R, “Consolidation of Variable Interest Entities” (FIN 46R), on these two agreements.

The synthetic leases in the above table relate to the financing of the utility railcars and a utility radio dispatch systemsystem. The entities that werelease these assets to WPL do not meet the consolidation requirements per FIN 46R, and are not included on WP&L’sthe Consolidated Balance Sheets. WP&LWPL has guaranteed the residual value of its synthetic leases totaling $14.3which total $8 million in the aggregate. The guarantees extend through the maturity of each respective underlying lease with remaining terms up to 1310 years. Residual value guaranteesguarantee amounts have been included in the future minimumabove table.

(b) Capital Lease - In the second quarter of 2005, WPL entered into a 20-year agreement with Alliant Energy Resources, Inc.’s (Resources’) Non-regulated Generation business to lease the Sheboygan Falls Energy Facility (SFEF), with an option for two lease renewal periods thereafter. The lease became effective in June 2005 when SFEF began commercial operations. WPL is responsible for the operation of SFEF and has exclusive rights to its output. In May 2005, the PSCW approved this affiliated lease agreement with initial monthly payments of approximately $1.3 million. The lease payments notedwere based on a 50% debt to capital ratio, a return on equity of 10.9%, a cost of debt based on the cost of senior notes issued by Resources’ Non-regulated Generation business in June 2005 and certain costs incurred to construct the facility. In accordance with its order approving the lease agreement, the PSCW will review the capital structure, return on equity and cost of debt every five years from the date of the final decision. The capital lease is amortized using the straight-line method over the 20-year lease term. WPL’s 2005/2006 retail rate case that became effective in July 2005 includes recovery of the monthly SFEF lease payment amounts from WPL’s customers. In 2005, SFEF lease expenses were $11.3 million ($7.7 million included in “Interest expense” and $3.6 million included in “Depreciation and amortization,” respectively, in the table below (in millions):

   

2003


  

2004


  

2005


  

2006


  

2007


  

Thereafter


  

Total


Certain purchased-power agreements

  

$18.7

  

$51.8

  

$66.3

  

$67.6

  

$69.0

  

$308.6

  

$582.0

Synthetic leases

  

6.4

  

7.6

  

7.5

  

7.4

  

5.5

  

25.5

  

59.9

Other

  

2.0

  

1.1

  

1.2

  

1.0

  

1.0

  

2.2

  

8.5

   
  
  
  
  
  
  
   

$27.1

  

$60.5

  

$75.0

  

$76.0

  

$75.5

  

$336.3

  

$650.4

   
  
  
  
  
  
  

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

(4) UTILITY ACCOUNTS RECEIVABLE

Utility customer accounts receivable, including unbilled revenues, arise primarily from the sale of electricity and natural gas.Income). At Dec. 31, 2002 and 2001, WP&L was serving a diversified base of residential, commercial and industrial customers and did not have any significant concentrations of credit risk.2005, WPL’s estimated future minimum capital lease payments for SFEF were as follows (in millions):

 

2006  2007  2008  2009  2010  There-
after
  Total  Less:
amount
repre-
senting
interest
  Present value
of net
minimum
capital lease
payments
  Gross
assets
under lease
at 12-31-05
  Accumulated
amortization
at 12-31-05
$15  $15  $15  $15  $15  $218  $293  $170  $123  $124  $4

WP&L participates

(4)SALE OF ACCOUNTS RECEIVABLE

In March 2004, WPL discontinued its participation in a combined utility customer accounts receivable sale program whereby IP&L and WP&L may sell up toit sold a combined maximum amountportion of $250 million (there are no individual subsidiary limits) of their respectiveits accounts receivable to a third-party financial institution on a limited recourse basis through wholly-owned and consolidated variable interestspecial purpose entities. Corporate Services acts as a collection agent for the buyerIn 2004 and receives a fee for collection services that approximates fair value. The agreement expires in April 2006 and is subject to annual renewal or renegotiation for a longer period thereafter. Under terms of the agreement, the third-party financial institution purchases the receivables initially for the face amount. On a monthly basis, this sales price is adjusted, resulting in payments to the third-party financial institution of an amount that varies based on interest rates and length of time the sold receivables remain outstanding. Collections on sold receivables are used to purchase additional receivables from the utility subsidiaries.

At Dec. 31, 2002 and 2001, WP&L had sold $1162003, WPL received $30 million and $88 million of receivables, respectively. In 2002, 2001 and 2000, WP&L received $1.2 billion, $1.1 billion and $0.9$0.8 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 $2.2 million, $4.0$0.2 million and $5.0$1.2 million in 2002, 20012004 and 2000,2003, respectively.

 

WP&L accounts for the sale of accounts receivable to the third-party financial institution as sales under SFAS 140, “Accounting for Transfers and Servicing of Financial Assets and Extinguishments of Liabilities.” Retained receivables are available to the third-party financial institution to pay any fees or expenses due it, and to absorb all credit losses incurred on any of the sold receivables. Beginning in the third quarter of 2003 under FIN 46, it is reasonably possible that WP&L could be considered the primary beneficiary given the current structure of the variable interest entities related to the program, and could be required to consolidate the operating results and associated assets and liabilities of the variable interest entities in its financial statements. WP&L is currently evaluating the structure of its receivable sales program to determine if this structure can be modified to qualify for off-balance sheet treatment under FIN 46.A-32

(5) INCOME TAXES


(5)INCOME TAXES

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

 

   

2002


   

2001


   

2000


 

Current tax expense:

            

Federal

  

$42.8

 

  

$36.8

 

  

$44.5

 

State

  

9.7

 

  

11.2

 

  

10.5

 

Deferred tax expense (benefit):

            

Federal

  

(5.0

)

  

(4.6

)

  

(9.9

)

State

  

1.2

 

  

(0.4

)

  

(0.3

)

Amortization of investment tax credits

  

(1.8

)

  

(1.8

)

  

(1.9

)

Research and development tax credits

  

(2.2

)

  

—  

 

  

—  

 

   

  

  

   

$44.7

 

  

$41.2

 

  

$42.9

 

   

  

  

   2005  2004  2003 

Current tax expense:

    

Federal

  $53.0  $45.2  $29.0 

State

   13.4   13.3   15.7 

Deferred tax expense (benefit):

    

Federal

   (3.5)  9.7   22.8 

State

   1.4   0.4   0.6 

Amortization of investment tax credits

   (1.5)  (1.6)  (1.6)

Research and development tax credits

   (1.9)  (0.7)  (0.7)
             
  $60.9  $66.3  $65.8 
             

Alliant Energy files a consolidated federal income tax return. Under the terms of an agreement between Alliant Energy and its subsidiaries, 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 regulations prohibited the retention of tax benefits at the parent level through 2005. Any difference between the separate return methodology and the actual consolidated return is allocated as prescribed in Alliant Energy’s tax allocation agreement. In 2005, 2004 and 2003, WPL realized net benefits of $1.5 million, $1.2 million and $2.9 million, respectively, related to state apportionment and allocation of parent tax benefits.

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

 

   

2002


   

2001


   

2000


 

Statutory federal income tax rate

  

35.0

%

  

35.0

%

  

35.0

%

State income taxes, net of federal benefits

  

6.1

 

  

6.4

 

  

6.0

 

Adjustment of prior period taxes

  

(1.1

)

  

(2.8

)

  

(0.8

)

Amortization of investment tax credits

  

(1.4

)

  

(1.6

)

  

(1.6

)

Amortization of excess deferred taxes

  

(1.4

)

  

(1.5

)

  

(1.3

)

Research and development tax credits

  

(1.8

)

  

—  

 

  

—  

 

Other items, net

  

0.2

 

  

0.4

 

  

0.2

 

   

  

  

Overall effective income tax rate

  

35.6

%

  

35.9

%

  

37.5

%

   

  

  

   2005  2004  2003 

Statutory federal income tax rate

  35.0% 35.0% 35.0%

State income taxes, net of federal benefits

  7.5  6.2  5.8 

Adjustment of prior period taxes

  (0.7) (1.5) (0.8)

Amortization of excess deferred taxes

  (0.9) (0.5) (0.5)

Amortization of investment tax credits

  (0.9) (0.9) (0.9)

Research and development tax credits

  (1.2) (0.4) (0.3)

Other items, net

  (2.1) (1.1) (1.9)
          

Overall effective income tax rate

  36.7% 36.8% 36.4%
          

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

 

  

2002


   

2001


 

Property related

  

$201.2

 

  

$200.8

 

Minimum pension liability

  

(16.4

)

  

(9.6

)

  2005 2004 
  

Deferred

Tax Assets

 

Deferred

Tax Liabilities

  Net 

Deferred

Tax Assets

 

Deferred

Tax Liabilities

  Net 

Property

  ($12.0) $214.2  $202.2  ($13.2) $222.7  $209.5 

Decommissioning

  

(25.2

)

  

(20.8

)

  —     —     —    (23.5)  —     (23.5)

Investment in American

  —     43.7   43.7  —     14.0   14.0 

Transmission Co. LLC (ATC)

         

Regulatory liability - decommissioning

  (28.3)  —     (28.3) —     —     —   

Other

  

32.3

 

  

35.8

 

  (30.5)  30.5   —    (8.0)  32.6   24.6 
  

  

                   
  

$191.9

 

  

$206.2

 

  ($70.8) $288.4  $217.6  ($44.7) $269.3  $224.6 
  

  

                   
      2005    2004 

Other current assets

      ($7.2)     ($8.0)

Deferred income taxes

      224.8      232.6 
             

Total deferred tax (assets) and liabilities

     $217.6     $224.6 
             

 

(6) PENSION PLANS AND OTHER POSTRETIREMENT BENEFITSA-33


(6)PENSION PLANS AND OTHER POSTRETIREMENT BENEFITS

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

 

  

Qualified Pension Benefits


  

Other Postretirement Benefits


  

2002


  

2001


  

2000


  

2002


  

2001


  

2000


  Qualified Pension Benefits Other Postretirement Benefits 

Discount rate

  

6.75%

  

7.25%

  

8.00%

  

6.75%

  

7.25%

  

8.00%

  2005 2004 2003 2005 2004 2003 

Discount rate for benefit obligations

  5.5% 6% 6% 5.5% 6% 6%

Discount rate for net periodic cost

  6% 6% 6.75% 6% 6% 6.75%

Expected return on plan assets

  

9%

  

9%

  

9%

  

9%

  

9%

  

9%

  9% 9% 9% 9% 9% 9%

Rate of compensation increase

  

3.5%

  

3.5%

  

3.5%

  

3.5%

  

3.5%

  

3.5%

  3.5% 3.5% 3.5% 3.5% 3.5% 3.5%

Medical cost trend on covered charges:

                        

Initial trend rate

  

N/A

  

N/A

  

N/A

  

10.8%

  

12.0%

  

9.0%

  N/A  N/A  N/A  9% 10% 9.5%

Ultimate trend rate

  

N/A

  

N/A

  

N/A

  

5%

  

5%

  

5%

  N/A  N/A  N/A  5% 5% 5%

The expected return on plan assets was determined by analysis of forecasted asset class returns as well as actual returns for the plan over the past 10 years. An adjustment to the returns to account for active management of the assets is also made in the analysis. The obligations are viewed as long-term commitments. A long-term approach is also used when determining the expected rate of return on assets, which is reviewed on an annual basis. WPL reduced its expected return on plan assets to 8.5% for the 2006 net periodic cost.

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


 
   

2002


   

2001


   

2000


   

2002


   

2001


   

2000


 

Service cost

  

$3.6

 

  

$2.8

 

  

$3.0

 

  

$2.4

 

  

$1.6

 

  

$1.4

 

Interest cost

  

10.1

 

  

9.2

 

  

8.9

 

  

4.4

 

  

3.6

 

  

3.3

 

Expected return on plan assets

  

(12.2

)

  

(13.7

)

  

(12.9

)

  

(1.6

)

  

(1.7

)

  

(1.6

)

Amortization of:

                        

Transition obligation (asset)

  

(1.7

)

  

(2.1

)

  

(2.1

)

  

1.1

 

  

1.2

 

  

1.2

 

Prior service cost

  

0.4

 

  

0.5

 

  

0.4

 

  

—  

 

  

—  

 

  

—  

 

Actuarial loss (gain)

  

1.5

 

  

—  

 

  

—  

 

  

0.1

 

  

(0.6

)

  

(0.8

)

   

  

  

  

  

  

   

$1.7

 

  

($3.3

)

  

($2.7

)

  

$6.4

 

  

$4.1

 

  

$3.5

 

   

  

  

  

  

  

   Qualified Pension Benefits  Other Postretirement Benefits 
   2005  2004  2003  2005  2004  2003 

Service cost

  $5.3  $5.0  $4.0  $4.4  $4.0  $3.4 

Interest cost

   12.2   11.2   10.6   6.3   5.4   5.2 

Expected return on plan assets

   (17.0)  (15.9)  (13.5)  (1.8)  (1.7)  (1.4)

Amortization of (*):

       

Transition obligation

   —     —     —     1.1   1.1   1.1 

Prior service cost

   0.8   0.6   0.4   —     —     —   

Actuarial loss

   3.4   3.0   3.5   2.4   1.4   0.8 

Special termination benefits

   —     —     —     1.1   —     —   
                         
  $4.7  $3.9  $5.0  $13.5  $10.2  $9.1 
                         

 

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

The pension benefit cost shownIn the above (and in the following tables) represents onlytable, the pension benefit costbenefits costs represent only those respective 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’sother postretirement benefits costs represent costs for all WPL employees. Corporate Services provides services to WPL. The following table includes qualified pension benefits costs for WPL’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 above. The pension benefit (income) cost for WP&L’s non-bargaining employees who are now participants in other Alliant Energy plans was $0.3 million, ($1.5) million and ($1.3) million for 2002, 2001 and 2000, respectively. In addition, Corporate Services provides services to WP&L. Thethe allocated pension benefit costs associated with these services was $1.7 million, $1.3 million and $1.3 million for 2002, 2001 and 2000, respectively. The other postretirement benefit cost shown above for each period (and in the following tables) represents the other postretirement benefit cost for all WP&L employees. The allocated other postretirement benefit costbenefits costs associated with Corporate Services for WP&L was $0.5 million, $0.3 million and $0.3 million for 2002, 2001 and 2000, respectively.WPL as follows (in millions):

 

   Pension Benefits  Other Postretirement Benefits
   2005  2004  2003  2005  2004  2003

Non-bargaining WPL employees participating in other plans

  $0.8  $0.5  $1.9   N/A   N/A   N/A

Allocated Corporate Services costs

   2.2   2.1   2.0  $2.9  $1.6  $0.9

A-34


The assumed medical trend rates are critical assumptions in determining the service and interest cost and accumulated postretirement benefit obligation related to postretirement benefitbenefits costs. A one percent1% change in the medical trend rates for 2002,2005, holding all other assumptions constant, would have the following effects (in millions):

 

    

1% Increase


    

1% Decrease


  1%
Increase
  1%
Decrease
 

Effect on total of service and interest cost components

    

$0.6

    

($0.6)

  $1.2  ($1.1)

Effect on postretirement benefit obligation

    

$5.6

    

($5.1)

  $8.5  ($7.8)

The benefit obligations and assets associated with WPL’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 in the following tables. A reconciliation of the funded status of WP&L’sWPL’s plans to the amounts recognized on WP&L’sthe Consolidated Balance Sheets at Dec. 31 was as follows (in millions):

 

  

Qualified Pension Benefits


   

Other Postretirement Benefits


 
  

2002


   

2001


   

2002


   

2001


   Qualified Pension Benefits Other Postretirement Benefits 

Change in benefit obligation:

            

Net benefit obligation at beginning of year

  

$139.2

 

  

$115.9

 

  

$60.5

 

  

$42.3

 

  2005 2004 2005 2004 

Change in projected benefit obligation:

     

Net projected benefit obligation at beginning of year

  $202.5  $181.0  $105.3  $93.1 

Service cost

  

3.6

 

  

2.8

 

  

2.4

 

  

1.6

 

   5.3   5.0   4.4   4.0 

Interest cost

  

10.1

 

  

9.2

 

  

4.4

 

  

3.6

 

   12.2   11.2   6.3   5.4 

Plan participants’ contributions

  

—  

 

  

—  

 

  

1.5

 

  

1.6

 

   —     —     1.8   1.6 

Actuarial loss

  

10.3

 

  

18.3

 

  

13.2

 

  

16.6

 

Plan amendments

   —     5.7   —     —   

Actuarial loss (gain)

   24.9   6.9   (12.7)  7.7 

Special termination benefits

   —     —     1.1   —   

Gross benefits paid

  

(7.2

)

  

(7.0

)

  

(5.4

)

  

(5.2

)

   (7.6)  (7.3)  (7.9)  (6.5)
  

  

  

  

             

Net benefit obligation at end of year

  

156.0

 

  

139.2

 

  

76.6

 

  

60.5

 

Net projected benefit obligation at end of year

   237.3   202.5   98.3   105.3 
  

  

  

  

             

Change in plan assets:

                 

Fair value of plan assets at beginning of year

  

138.8

 

  

156.3

 

  

17.8

 

  

19.4

 

   192.9   175.0   20.7   19.5 

Actual return on plan assets

  

(8.1

)

  

(10.5

)

  

(1.4

)

  

(0.5

)

   22.4   20.2   1.9   2.1 

Employer contributions

  

30.0

 

  

—  

 

  

4.2

 

  

2.5

 

   7.0   5.0   4.1   4.0 

Plan participants’ contributions

  

—  

 

  

—  

 

  

1.5

 

  

1.6

 

   —     —     1.8   1.6 

Gross benefits paid

  

(7.2

)

  

(7.0

)

  

(5.4

)

  

(5.2

)

   (7.6)  (7.3)  (7.9)  (6.5)
  

  

  

  

             

Fair value of plan assets at end of year

  

153.5

 

  

138.8

 

  

16.7

 

  

17.8

 

   214.7   192.9   20.6   20.7 
  

  

  

  

             

Funded status at end of year

  

(2.5

)

  

(0.4

)

  

(59.9

)

  

(42.7

)

   (22.6)  (9.6)  (77.7)  (84.6)

Unrecognized net actuarial loss

  

63.5

 

  

34.3

 

  

20.4

 

  

4.4

 

   78.1   62.0   21.3   36.4 

Unrecognized prior service cost

  

3.4

 

  

3.9

 

  

(0.1

)

  

(0.2

)

   7.3   8.1   (0.1)  (0.1)

Unrecognized net transition obligation (asset)

  

—  

 

  

(1.7

)

  

11.5

 

  

12.6

 

Unrecognized net transition obligation

   —     —     8.0   9.2 
  

  

  

  

             

Net amount recognized at end of year

  

$64.4

 

  

$36.1

 

  

($28.1

)

  

($25.9

)

  $62.8  $60.5   ($48.5)  ($39.1)
  

  

  

  

             

Amounts recognized on the Consolidated Balance Sheets
consist of:

            

Amounts recognized on the Consolidated

     

Balance Sheets consist of:

     

Prepaid benefit cost

  

$64.4

 

  

$36.1

 

  

$1.5

 

  

$1.3

 

  $62.8  $60.5  $1.8  $1.6 

Accrued benefit cost

  

—  

 

  

—  

 

  

(29.6

)

  

(27.2

)

   —     —     (50.3)  (40.7)
  

  

  

  

             

Net amount recognized at measurement date

  

64.4

 

  

36.1

 

  

(28.1

)

  

(25.9

)

   62.8   60.5   (48.5)  (39.1)
  

  

  

  

             

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

  

—  

 

  

—  

 

  

1.0

 

  

1.1

 

Contributions paid after Sep. 30 and prior to Dec. 31

   —     —     1.7   0.6 
  

  

  

  

             

Net amount recognized at 12/31

  

$64.4

 

  

$36.1

 

  

($27.1

)

  

($24.8

)

Net amount recognized at Dec. 31

  $62.8  $60.5   ($46.8)  ($38.5)
  

  

  

  

             

 

A-35


TheIn 2004, the PSCW authorized Wisconsin utilities to record additional minimum pension liability to “Regulatory assets” in lieu of “Accumulated other comprehensive loss” on their Consolidated Balance Sheets. At Dec. 31, 2005 and 2004, Corporate Services allocated to WPL a minimum pension liability of $51 million and $44 million, respectively. Included in the following table are WPL’s accumulated benefit obligationobligations, amounts applicable to qualified pension and fair value of plan assets for theother postretirement welfare plansbenefits with accumulated benefit obligations in excess of plan assets, were $74.7 million and $13.7 million, respectively,as well as qualified pension plans with projected benefit obligations in excess of plan assets as of Sept.the measurement date of Sep. 30 2002 and $53.8 million and $8.5 million, respectively, as of Sept. 30, 2001. At Dec. 31, 2002 and 2001, Corporate Services allocated an additional minimum liability of $41.3 million and $0 million, respectively. WP&L’s(in millions):

   Qualified Pension Benefits  Other Postretirement Benefits
   2005  2004  2005  2004

Accumulated benefit obligation

  $211.7  $181.8  $98.3  $105.3

Plans with accumulated benefit obligations in excess of plan assets:

        

Accumulated benefit obligations

   —     —     96.9   103.6

Fair value of plan assets

   —     —     17.1   17.3

Plans with projected benefit obligations in excess of plan assets:

        

Projected benefit obligations

   237.3   202.5   N/A   N/A

Fair value of plan assets

   214.7   192.9   N/A   N/A

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

Postretirement benefit plans are funded via specific assets within certain retirement plans (401(h) assets) as well as a Voluntary Employees’ Beneficiary Association (VEBA) trust. The asset allocation of the 401(h) assets mirror the qualified pension plan assets and the asset allocation of the VEBA trust are reflected in the following table under “Other Postretirement Benefit Plans.” The asset allocation for WPL’s qualified pension and other postretirement benefit plans at Sep. 30, 2005 and 2004, and the qualified pension plan target allocation for 2005 were as follows:

   Qualified Pension Plan  

Other Postretirement

Benefit Plans

 
   

Target

Allocation

  

Percentage of Plan

Assets at Sep. 30,

  

Percentage of Plan

Assets at Sep. 30,

 

Asset Category

  2005  2005  2004  2005  2004 

Equity securities

  65-75% 72% 73% 63% 10%

Debt securities

  20-35% 28% 27% 18% 20%

Other

  0-5% —    —    19% 70%
              
   100% 100% 100% 100%
              

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

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

WPL estimates that funding for the qualified pension plan for the bargaining unit and other postretirement benefit plans during 2006 will be $0 and $6 million, respectively.

 

A-36


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

   2006  2007  2008  2009  2010  2011 - 2015 

Pension benefits

  $7.8  $7.9  $8.2  $8.6  $9.4  $64.7 

Other benefits

   6.5   6.9   7.4   7.8   8.1   49.1 

Medicare subsidies

   (0.6)  (0.6)  (0.7)  (0.7)  (0.7)  (3.6)
                         
  $13.7  $14.2  $14.9  $15.7  $16.8  $110.2 
                         

In 2004, WPL adopted FASB Staff Position No. SFAS 106-2, “Accounting and Disclosure Requirements Related to the Medicare Prescription Drug, Improvement and Modernization Act of 2003” (FSP 106-2). In 2005, the U.S. Department of Health and Human Services (Centers for Medicare & Medicaid Services) published regulations regarding actuarial equivalence. WPL believes that a substantial portion of its postretirement medical plans will be actuarially equivalent to the Medicare Prescription Drug Plan. WPL anticipates continuing its current prescription drug coverage for currently covered retirees and therefore should be eligible for the subsidy available from Medicare. As a result of the adoption of FSP 106-2, the estimated reductions in WPL’s 2005 and 2004 accumulated projected benefit obligation and other postretirement benefits costs were as follows:

   2005  2004

Accumulated projected benefit obligation

  $13.9  $6.8

Other postretirement benefits costs

   2.1   1.0

WPL has various life insurance policies that cover certain key employees and directors. At Dec. 31, 2005 and 2004, the cash surrender value of these investments was $11.2 million and $10.7 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 $1.5$1.9 million, $1.0$1.8 million and $1.2$1.7 million in 2002, 20012005, 2004 and 2000, respectively. WP&L has various life insurance policies that cover certain key employees and directors. At Dec. 31, 2002 and 2001, the cash surrender value of these investments was $10 million and $9 million,2003, respectively. A significant number of WP&LWPL employees also participate in a defined contribution pension plansplan (401(k) plans)plan). WP&L’sWPL’s contributions to the plans,401(k) plan, which are based on the participants’ level of contribution, were $2.2$2.4 million, $2.1$2.3 million and $2.1 million in 2002, 20012005, 2004 and 2000,2003, respectively.

Alliant Energy’s pension plans include a cash balance plan that covers substantially all of its non-bargaining unit employees, including non-bargaining unit employees of WPL. In the first quarter of 2006, Alliant Energy has announced amendments to the cash balance plan which include freezing plan participation at its current level and discontinuing additional contributions into employee’s cash balance plan accounts effective August 2008. Alliant Energy has also announced plans to increase its level of contributions to the 401(k) plan effective in August 2008 which will offset the impact of discontinuing additional contributions into the employee’s cash balance plan accounts. These amendments are designed to provide employees portability and self-directed flexibility of their retirement benefits. WPL is currently assessing the future impacts of these changes and does not currently expect these changes will have a significant impact on its future results of operations.

(7) COMMON AND PREFERRED STOCK

(a) Common Stock—StockWP&L - In 2003, Alliant Energy completed a public offering of its common stock generating net proceeds of $318 million, which were used in part to make capital contributions to WPL of $200 million in support of WPL’s generation and reliability initiatives. WPL has dividend payment restrictions based on its bond indentures, the terms of its outstanding preferred stock and state regulatory limitations. WP&L’s preferredlimitations applicable to it. In its July 2005 rate order, the PSCW stated WPL may not pay annual common stock restricts dividends, including pass-through of subsidiary dividends, in excess of $92 million to Alliant Energy if WPL’s actual average common equity ratio, on a financial basis, is or will fall below the test year authorized level of 53.14%. WPL’s dividends are also restricted to the extent that such dividend would reduce the common stock equity ratio to less than 25%. In its September 2002 rate order, the PSCW stated it must approve the payment of dividends by WP&L to Alliant Energy in excess of the level forecasted in the order ($62 million annually) if such dividends would reduce WP&L’s common equity ratio below 44.67% of total capitalization. As ofAt Dec. 31, 2002, WP&L2005, WPL was in compliance with all such dividend restrictions.

(b) Preferred Stock—Stock - The carrying value of WP&L’sWPL’s cumulative preferred stock at both Dec. 31, 20022005 and 20012004 was $60 million. The fair market value, based upon the market yield of similar securities and quoted market prices, at Dec. 31, 20022005 and 20012004 was $48$54 million and $49$55 million, respectively.

 

A-37


(8) DEBT

(a) Short-Term Debt—Debt - To provide short-term borrowing flexibility and security for commercial paper outstanding, WP&LWPL maintains committed bank lines of credit, all of which most require a fee. Alliant Energy discontinued the use of its utility money pool in 2002 and WP&L is now meeting any short-term borrowing needs it has by issuing commercial paper. At Dec. 31, 2001, W&L had money pool borrowings of $90.8 million.2005, WPL’s short-term borrowing arrangements included a $250 million revolving credit facility which expires in August 2010. Information regarding WP&L’scommercial paper and other short-term debt issued under this facility was as follows (dollars in millions):

 

   

2002


  

2001


At Dec. 31:

      

Commercial paper outstanding

  

$60.0

  

$ —  

Discount rates on commercial paper

  

1.6%

  

N/A

Money pool borrowings

  

$ —  

  

$90.8

Interest rates on money pool borrowings

  

N/A

  

2.4%

For the year ended:

      

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

  

$57.4

  

$23.8

Average interest rates on short-term debt

  

1.8%

  

3.7%

   2005  2004 

At Dec. 31:

   

Commercial paper outstanding

  $93.5  $47.0 

Average discount rates - commercial paper

   4.4%  2.3%

For the year ended:

   

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

  $18.4  $12.8 

Average interest rates - total short-term debt

   3.4%  1.4%

(b) Long-Term Debt—DebtWP&L’s First Mortgage Bonds - WPL’s first mortgage bonds are secured by substantially all of its utility plant. WP&Lplant ($39 million of such bonds were outstanding at Dec. 31, 2005). WPL also maintains indentures relatingrelated to the issuance of unsecured debt securities. WP&L’s

WPL has certain issuances of long-term debt that contain optional redemption provisions which, if elected by WPL, could require material redemption premium payments by WPL. The redemption premium payments under these optional redemption provisions are variable and dependent on applicable treasury rates at the time of redemption. At Dec. 31, 2005, the debt issuances that contained these optional redemption provisions included WPL’s debentures due 2034.

In July 2005, WPL repaid at maturity its $72 million, 7.6% first mortgage bonds with the issuance of short-term debt which was later reduced with the proceeds from the sale of its interest in Kewaunee.

At Dec. 31, 2005, WPL’s debt maturities for 20032006 to 2007 are2010 were $0, $62.0$105 million, $88.0$60 million, $0 and $105.0$100 million, respectively. The carrying value of WP&L’sWPL’s long-term debt (including current maturities and variable rate demand bonds) at both Dec. 31, 20022005 and 20012004 was $523 million.$403 million and $491 million, respectively. The fair market value, based upon the market yield of similar securities and quoted market prices, at Dec. 31, 20022005 and 20012004 was $574$425 million and $548$532 million, respectively.

WPL’s unamortized debt issuance costs recorded in “Deferred charges and other” on the Consolidated Balance Sheets were $3.0 million and $4.0 million at Dec. 31, 2005 and 2004, respectively. At Dec. 31, 2005, there were no significant sinking fund requirements related to the long-term term debt on the Consolidated Balance Sheets.

(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,” was as follows (in millions):

 

   

2002


  

2001


   

Carrying/

Fair Value


    

Unrealized Gains,

Net of Tax


  

Carrying/

Fair Value


    

Unrealized

Gains,

Net of Tax


Available-for-sale securities:

                

Nuclear decommissioning trust funds:

                

Debt securities

  

$131

    

$5

  

$122

    

$2

Equity securities

  

93

    

5

  

94

    

23

   
    
  
    

Total

  

$224

    

$10

  

$216

    

$25

   
    
  
    

   2005  2004
   

Carrying/Fair

Value

  

Unrealized

Gains, Net of

Tax

  

Carrying/Fair

Value

  

Unrealized

Gains, Net of

Tax

Available-for-sale securities:

        

Nuclear decommissioning trust funds:

        

Equity securities

  $—    $—    $51.2  $13.0

Debt securities

   —     —     21.0   0.7

Nuclear Decommissioning Trust Funds—FundsAt Dec. 31, 2002, $75 million, $24 million - The information in the above table and $32 millionthis paragraph relate to the non-qualified portion of WPL’s nuclear decommissioning trust funds. The qualified portion of WPL’s nuclear decommissioning trust funds was included in the debt securities mature in 2003-2010, 2011-2020sales agreement of Kewaunee and 2021-2049, respectively.as a result is reported as assets held for sale. The fair value of WPL’s nuclear decommissioning trust funds, as reported by the trustee, was adjusted for the tax effect of unrealized gains and losses. Net unrealized holding gains were recorded as part of regulatory liabilities or as an offset to regulatory assets related to AROs. The funds realized pre-tax gains (losses) from the sales of securities of $10.3$23 million, $2.1($3) million and $5.2($4) million in 2002, 20012005, 2004 and 2000,2003, respectively (cost of the investments based on specific identification was $92.2$110 million, $147.4$14 million and $202.1$29 million and pre-tax proceeds from the sales were $102.5$133 million, $149.5$11 million and $207.3$25 million, respectively).

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.

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Investment in ATC—Unconsolidated Equity InvestmentsAt Dec. 31, 2002 and 2001, WP&L had ownership interests in ATC of approximately 26.6% and 26.5%, respectively, and accounts - WPL’s unconsolidated investments accounted for this investment under the equity method. Pursuant to various agreements, WP&L receives a rangemethod of transmission services from ATC. WP&L provides operation, maintenance, and various transitional and construction services to ATC. WP&L and ATC also bill each other for use of shared facilities owned by each party. ATC billed WP&L $38.7 million and $36.4 millionaccounting are as follows (dollars in 2002 and 2001, respectively. WP&L billed ATC $18.1 million and $18.4 million in 2002 and 2001, respectively, and recorded equity earnings of $14.3 million and $14.6 million in 2002 and 2001, respectively.millions):

 

   

Ownership

Interest at

Dec. 31, 2005

  

Carrying Value

at Dec. 31,

  Equity (Income) /Loss 
    2005  2004  2005  2004  2003 

ATC

  21% $152  $141  ($21) ($19) ($16)

Wisconsin River Power Company (WRPC)

  50%  10   13   (5)  (6)  (5)
                      
   $162  $154  ($26) ($25) ($21)
                      

Unconsolidated Equity Investments—Summary financial information from WP&L’sthe financial statements of WPL’s unconsolidated equity investments’ financial statementsinvestments in ATC and WRPC is as follows (in millions):

 

  

2002


  

2001


  

2000


  2005  2004  2003

Operating revenues

  

$211.7

  

$180.3

  

$5.3

  $303  $270  $232

Operating income

  

75.7

  

65.8

  

1.3

   131   107   88

Net income

  

59.5

  

55.9

  

1.6

   106   91   72

As of Dec. 31:

               

Current assets

  

44.7

  

59.5

      34   39  

Non-current assets

  

774.4

  

681.4

      1,536   1,177  

Current liabilities

  

50.8

  

39.3

      142   195  

Non-current liabilities

  

7.5

  

4.4

      757   458  

Refer to Note 19 for information regarding related party transactions with ATC.

(10) DERIVATIVE FINANCIAL INSTRUMENTS

(a) Accounting for Derivative Instruments and Hedging Activities—ActivitiesWP&L - WPL records derivative instruments at fair value on the balance sheet as assets or liabilities and changes in the derivatives’ fair values are generally recorded as regulatory assets or liabilities. The PSCW issued a letter to WP&L in August 2002 authorizing accounting for its derivatives in such manner. At Dec. 31, 2002 and 2001, WP&L had $2.7 million and $5.9 million, respectively, ofcurrent derivative assets were included in “Other current assets” on its Consolidated Balance Sheetsassets,” non-current derivative assets were included in “Deferred charges and $7.1 million and $0.6 million, respectively, ofother,” current derivative liabilities were included in “Other current liabilities” and non-current derivative liabilities were included in “Other long-term liabilities and deferred credits” on itsthe Consolidated Balance Sheets.Sheets as follows (in millions):

 

   2005  2004

Current derivative assets

  $12.7  $4.7

Non-current derivative assets

   4.4   —  

Current derivative liabilities

   19.0   6.7

Non-current derivative liabilities

   1.5   —  

Cash Flow Hedging Instruments—During 2002 and 2001, WP&L held various derivative instruments designated as cash flow hedging instruments. WP&L utilized gas commodity financial swap arrangementsChanges in the derivatives’ fair values at WPL during 2005 were primarily due to reduce the impact of price fluctuations on gas purchased and injected into storage during the summer months and withdrawn and sold at current market prices during the winter months pursuant to thesignificant increases in natural gas cost incentive sharing mechanism with customersprices and additional gas contracts entered into in Wisconsin. WP&L also utilized physical coal purchase contracts, which did not qualify2005 to mitigate pricing volatility for the normal purchase and sale exception, to manage the price of anticipated coal purchases and sales.WPL’s customers.

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

Other Derivatives Not Designated in Hedge Relationships—WP&L’sWPL’s derivatives that were not designated in hedge relationships during 20022005 and/or 20012004 included electricity price collars and physicalelectric, coal and gas contracts. Electricity price collarsElectric contracts were used to manage utility energy costs during supply/demand imbalances. Physical coalCoal and gas contracts that do not qualify for the normal purchase and sale exception were used to manage the price of anticipated coal and gas purchases and sales.

(b) Weather Derivatives—DerivativesWP&L - - WPL uses weather derivatives to reduce the impact of weather volatility on its electric and natural gas sales volumes. WPL’s ratepayers do not pay any of the premiums nor do they share in the gains/losses realized from these weather derivatives.

In 2002 and 2001,2005, WPL entered into a non-exchange traded electric weather derivative agreement based on cooling degree days to reduce the impact of weather volatility on its electric margins for the period June 1, 2005 to Aug. 31, 2005. The actual cooling degree days during this period were higher than those specified in the contract resulting in WPL paying the counterparty $3.5 million in 2005, the maximum amount under the agreement.

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In 2005, Corporate Services, as agent for IP&LWPL, and WP&L,WPL on behalf of itself entered into a combination of put options and swap agreements based on heating degree days (HDD) to reduce the impact of weather volatility on WPL’s margins for the period Nov. 1, 2005 to March 31, 2006. WPL will receive up to a maximum of $4.3 million of payments from the counterparty if actual HDD are less than the HDD specified in the contract (for the put options and swaps) or remit up to a maximum of $2.2 million of funds to the counterparty if actual HDD are greater than the HDD specified in the contract (swaps only). In 2004 and 2003, Corporate Services, as agent for WPL, entered into non-exchange traded options based on heating degree daysHDD in which Corporate Services receiveshad the right to receive payment from the counterparty if actual heating degree days areHDD were less than the strike priceHDD specified in the contract. Corporate Services

Any premiums paid premiumsrelated to enter into these contracts, whichthe electric and gas weather derivative agreements are amortized to expenseexpensed over theeach respective contract period. WP&L has usedWPL uses the intrinsic value method to account for these weather derivatives. Information relating to the electric and gas weather derivatives was as follows (in millions):

 

(c) Nuclear Decommissioning Trust Fund Investments—Historically, WP&L has entered into combinations of options to mitigate the effect of significant market fluctuations on its common stock investments in its nuclear decommissioning trust funds. The derivative transactions are designed to protect the portfolio’s value while allowing the funds to earn a total return modestly in excess of long-term expectations over the hedge period. Fair value changes of these instruments do not impact net income as they are recorded as equally offsetting changes in the investment in nuclear decommissioning trust funds and accumulated depreciation.

   2005  2004  2003

Premiums expensed

  $1.1  $1.0  $0.9

Premiums paid

   0.5   1.2   0.9

Gains (losses)

   (4.5)  —     0.8

Amounts paid to counterparties

   (3.1)  —     —  

(11) COMMITMENTS AND CONTINGENCIES

(a) Construction and Acquisition Expenditures—ExpendituresCertain - WPL has made certain commitments have been made in connection with 2003its 2006 capital expenditures. During 2003, total construction and acquisition expenditures are estimated to be approximately $160 million.

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

“take-or-pay” “take-or-pay” contracts which result in dollar commitments with no associated tons or Dths.dekatherms (Dths).

Based on the System Coordination and Operating Agreement, Alliant Energy annually allocates purchased power contracts to IPL and WPL, based on various factors such as resource mix, load growth and resource availability. The amounts in the following table reflect these allocated contracts. However, for 2006 and 2007, system-wide purchased power contracts of $218.7 million (3.3 million MWhs) and $62.9 million (1.3 million MWhs), respectively, 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. WPL enters into coal transportation contracts that are directly assigned to its specific generating stations, the amounts of which are included in the following table. In addition, Corporate Services entered into system-wide coal contracts on behalf of IPL and WPL for 2006 to 2010 of $70.9 million (10.1 million tons), $55.7 million (7.6 million tons), $35.8 million (5.0 million tons), $18.5 million (2.5 million tons) and $4.8 million (0.6 million tons), respectively, to allow flexibility for the changing needs of the quantity of coal consumed by each. Coal contract quantities are allocated to specific IPL or WPL generating stations at or before the time of delivery based on various factors including projected heat input requirements, combustion compatibility and efficiency. These system-wide coal contracts have not yet been directly assigned to IPL and WPL since the specific needs of each utility are not yet known. At Dec. 31, 2002, WP&L’s2005, WPL’s minimum commitments were as follows (dollars and Dths in millions; MWhs and tons in thousands):

 

  

Purchased-power


  

Coal


  

Natural gas


  

Dollars


  

MWhs


  

Dollars


  

Tons


  

Dollars


  

Dths


  Purchased Power  Coal  Natural Gas

2003

  

$31.3

  

219

  

$6.9

  

—  

  

$48.1

  

2

2004

  

8.0

  

219

  

6.9

  

—  

  

32.3

  

—  

2005

  

—  

  

—  

  

1.3

  

—  

  

25.0

  

—  

  Dollars  MWhs  Dollars  Tons  Dollars  Dths

2006

  

—  

  

—  

  

1.3

  

—  

  

14.1

  

—  

  $80.1  1,801  $9.0  —    $196.9  18

2007

  

—  

  

—  

  

1.3

  

—  

  

13.3

  

—  

   84.1  2,001   9.0  —     24.8  —  

2008

   75.7  1,830   6.5  —     20.6  —  

2009

   87.4  1,771   6.5  —     15.3  —  

2010

   86.2  1,763   6.5  —     11.0  —  

Thereafter

  

—  

  

—  

  

—  

  

—  

  

26.4

  

—  

   224.9  5,797   25.8  —     10.5  —  
                  
  $638.4  14,963  $63.3  —    $279.1  18
                  

 

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The amounts related to WPL’s Kewaunee purchased power agreement are included in the above table. Also, at Dec. 31, 2005, WPL’s other purchase obligations, which represent individual commitments incurred during the normal course of business which exceeded $1.0 million at Dec. 31, 2005, were $3 million, $1 million and $1 million for 2006, 2007 and 2008, respectively. This excludes lease obligations which are included in Note 3.

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

(d) Guarantees and Commitments—Indemnifications - WPL provided an indemnification associated with the sale of its interest in Kewaunee in the third quarter of 2005 for losses resulting from potential breach of the representations and warranties made by WPL on the sale date and for the breach of its obligations under the sale agreement. The indemnification has a maximum limit of $12 million and expires in July 2006. WPL believes the likelihood of having to make any material cash payments under this indemnification is remote. WPL has not recorded any material liabilities related to the above indemnification as of Dec. 31, 2005. WPL follows the provisions of FIN 45, “Guarantor’s Accounting and Disclosure Requirements for Guarantees, Including Indirect Guarantees of Indebtedness to Others,” as it relates to this indemnification. Refer to Note 316 for information regarding an additional indemnity issued by WPL related to the Kewaunee sale. Refer to Note 3(a) for discussion of WP&L’sWPL’s residual value guarantees of its synthetic leases. In November 2002, the FASB issued FIN 45 which requires disclosures by a guarantor about its obligations under certain guarantees that it has issued. FIN 45 also requires recognizing, at the inception of a guarantee, a liability for the fair value of the obligation undertaken in issuing the guarantee. The recognition and measurement provisions of FIN 45 are effective on a prospective basis for guarantees issued or modified after Dec. 31, 2002. WP&L does not anticipate FIN 45 will have a material impact on its financial condition or results of operations.

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

 

   

Environmental Liabilities


  

Regulatory Assets


   

2002


  

2001


  

2002


  

2001


MGP sites

  

$6.9

  

$4.4

  

$13.0

  

$11.7

NEPA

  

2.5

  

3.1

  

3.1

  

4.0

Other

  

—  

  

—  

  

2.9

  

3.0

   
  
  
  
   

$9.4

  

$7.5

  

$19.0

  

$18.7

   
  
  
  

   2005  2004

Manufactured gas plant (MGP) sites

  $5.7  $5.2

Other

   0.7   1.3
        
  $6.4  $6.5
        

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

WP&LWPL records environmental liabilities based upon periodic studies, most recently updated in the third quarter of 2002,2005, related to the MGP sites. Such amounts are based on the best current estimate of the remaining amount to be incurred for investigation, remediation and monitoring costs for those sites where the investigation process has been or is substantially completed, and the minimum of the estimated cost range for those sites where the investigation is in its earlier stages. It is possible that future cost estimates will be greater than current estimates as the investigation process proceeds and as additional facts become known. The amounts recognized as liabilities are reduced for expenditures made and are adjusted as further information develops or circumstances change. Costs of future expenditures for environmental remediation obligations are not discounted to their fair value. Management currently estimates the range of remaining costs to be incurred for the investigation, remediation and monitoring of all WP&LWPL’s sites to be approximately $6$5 million to $7 million.

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

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

Settlement has been reached with all of WP&L’sWPL’s insurance carriers regarding reimbursement for its MGP-related costs. Insurance recoveries available

Clean Air Interstate Rule (CAIR) and Clean Air Mercury Rule (CAMR) - In March 2005, the EPA finalized CAIR and CAMR, which both require emission control upgrades to existing electric generating units with greater than 25 megawatt capacity. CAIR will cap emissions of sulfur dioxide (SO2) and nitrogen oxides (NOx) in 28 states (including Wisconsin) in the eastern U.S. and, when fully implemented, reduce SO2 and NOx emissions in these states by over 70% and 60% from 2003 levels, respectively. CAMR will reduce U.S. utility (including WPL) mercury emissions by approximately 70% when fully implemented. WPL believes that future capital investments and/or modifications to comply with these rules will be significant.

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(f) Credit Risk - WPL serves a diversified base of residential, commercial, industrial and wholesale customers and did not have any significant concentrations of credit risk. In addition, WPL has limited credit exposure from non-performance of contractual obligations by its counterparties. WPL maintains credit risk oversight and sets limits and policies with regards to its counterparties, which management believes minimizes its overall credit risk exposure. However, there is no assurance that such policies will protect WPL against all losses from non-performance by counterparties. Refer to Note 18 for discussion of the credit risk related to Calpine’s recent bankruptcy.

(12) JOINTLY-OWNED ELECTRIC UTILITY PLANT

Under joint ownership agreements with other Wisconsin utilities, WPL has undivided ownership interests in jointly-owned electric generating stations. Each of the respective owners is responsible for the financing of its portion of the construction costs. Kilowatt-hour generation and operating expenses are divided on the same basis as ownership with each owner reflecting its respective costs in its Consolidated Statements of Income. Information relative to WPL’s ownership interest in these facilities at Dec. 31, 2002 for WP&L were $2.1 million. Pursuant to the applicable rate making treatment, WP&L has recorded its recoveries as an offset against its regulatory assets.

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

(f) Decommissioning of Kewaunee—FERC, in its most recent interim wholesale rate order effective April 2002, allows WP&L to recover $3 million annually for its share of the cost to decommission Kewaunee. The interim order is subject to refund, pending determination of final rates. The PSCW, in an order effective Jan. 1, 2002, eliminated WP&L’s recovery from retail customers for the cost to decommission Kewaunee, due to the trust fund being adequately funded. Decommissioning expense is included in “Depreciation and amortization” in the Consolidated Statements of Income and the cumulative amount is included in “Accumulated depreciation” on the Consolidated Balance Sheets to the extent recovered through rates. Additional information relating to the decommissioning of Kewaunee2005 was as follows (dollars in millions):

   Fuel
Type
  Ownership
Interest %
  Plant in
Service
  Accumulated
Provision for
Depreciation
  Construction
Work in
Progress
  Cost of
Removal
Obligations
Included in
Regulatory
Liabilities

Edgewater Unit 5

  Coal  75.0  $239.5  $128.9  $2.7  $6.1

Columbia Energy Center

  Coal  46.2   215.7   115.4   8.4   11.3

Edgewater Unit 4

  Coal  68.2   74.7   41.0   1.1   4.1
                    
      $529.9  $285.3  $12.2  $21.5
                    

Refer to Note 1(c) for further discussion of cost of removal obligations.

(13) SEGMENTS OF BUSINESS

WPL is a utility serving customers in Wisconsin and Illinois and includes three segments: a) electric operations; b) gas operations; and c) other, which includes various other energy-related products and services 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 2005, 2004 and 2003, gas revenues included $51 million, $20 million and $45 million, respectively, for sales to the electric segment. All other intersegment revenues were not material to WPL’s operations and there was no single customer whose revenues were 10% or more of WPL’s consolidated revenues. Certain financial information relating to WPL’s significant business segments was as follows (in millions):

   Electric  Gas  Other  Total 

2005

       

Operating revenues

  $1,073.9  $322.3  $13.4  $1,409.6 

Depreciation and amortization

   92.7   14.6   0.6   107.9 

Operating income (loss)

   146.5   33.4   (5.3)  174.6 

Interest expense, net of AFUDC

        37.1 

Equity income from unconsolidated investments

        (26.3)

Interest income and other

        (2.2)

Income tax expense

        60.9 

Net income

        105.1 

Preferred dividends

        3.3 

Earnings available for common stock

        101.8 

Total assets

   2,070.2   380.2   217.2   2,667.6 

Investments in equity method subsidiaries

   162.5   —     —     162.5 

Construction and acquisition expenditures

   164.5   20.2   0.6   185.3 

A-42


   Electric  Gas  Other  Total 

2004

       

Operating revenues

  $939.8  $253.8  $16.2  $1,209.8 

Depreciation and amortization

   95.7   14.8   0.5   111.0 

Operating income (loss)

   164.9   24.8   (6.9)  182.8 

Interest expense, net of AFUDC

        29.0 

Equity income from unconsolidated investments

        (25.0)

Interest income and other

        (1.2)

Income tax expense

        66.3 

Net income

        113.7 

Preferred dividends

        3.3 

Earnings available for common stock

        110.4 

Total assets

   2,097.5   333.3   225.3   2,656.1 

Investments in equity method subsidiaries

   154.3   —     —     154.3 

Construction and acquisition expenditures

   189.1   20.2   2.2   211.5 

2003

       

Operating revenues

  $910.1  $272.4  $34.5  $1,217.0 

Depreciation and amortization

   89.2   14.6   1.1   104.9 

Operating income

   163.8   25.5   2.3   191.6 

Interest expense, net of AFUDC

        33.9 

Equity income from unconsolidated investments

        (20.7)

Interest income and other

        (2.3)

Income tax expense

        65.8 

Net income

        114.9 

Preferred dividends

        3.3 

Earnings available for common stock

        111.6 

Total assets

   1,950.5   306.2   212.6   2,469.3 

Investments in equity method subsidiaries

   133.3   —     —     133.3 

Construction and acquisition expenditures

   133.0   17.4   1.2   151.6 

(14) SELECTED CONSOLIDATED QUARTERLY FINANCIAL DATA (UNAUDITED)

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

   2005  2004
   March 31  June 30  Sep. 30  Dec. 31  March 31  June 30  Sep. 30  Dec. 31
   (in millions)

Operating revenues

  $341.1  $303.1  $368.4  $397.0  $339.4  $270.6  $286.2  $313.5

Operating income

   40.5   27.4   55.1   51.6   38.9   51.3   55.0   37.6

Net income

   23.9   15.6   34.4   31.2   22.3   31.2   33.6   26.7

Earnings available for common stock

   23.1   14.7   33.6   30.4   21.5   30.3   32.8   25.8

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(15) ASSETS AND LIABILITIES HELD FOR SALE

In July 2005, WPL completed the sale of its interest in Kewaunee and its water utility in Ripon, Wisconsin. Refer to Note 16 for further discussion of the Kewaunee sale. In addition, WPL has entered into an agreement to sell its Illinois utility subsidiary, South Beloit. WPL has applied the provisions of SFAS 144 to these assets and liabilities, which are recorded as held for sale. The operating results of WPL’s interest in Kewaunee, Ripon and South Beloit were not reported as discontinued operations at Dec. 31, 2005. The components of assets and liabilities held for sale on the Consolidated Balance Sheets at Dec. 31 were as follows (in millions):

   2005  2004 

Assets held for sale:

   

Property, plant and equipment:

   

Electric plant in service

  $20.3  $223.1 

Gas plant in service

   12.7   12.3 

Other plant in service

   6.7   13.6 

Accumulated depreciation

   (14.2)  (161.8)
         

Net plant

   25.5   87.2 

Construction work in progress

   0.6   15.7 

Other, less accumulated depreciation

   —     17.0 
         

Property, plant and equipment, net

   26.1   119.9 

Current assets

   —     3.8 

Nuclear decommissioning trust funds

   —     170.9 

Other assets

   —     14.3 
         

Total assets held for sale

   26.1   308.9 
         

Liabilities held for sale:

   

Long-term liabilities (primarily AROs)

   2.2   196.1 
         

Net assets held for sale

  $23.9  $112.8 
         

(16) SALE OF WPL’S INTEREST IN KEWAUNEE

In July 2005, WPL completed the sale of its interest in Kewaunee to a subsidiary of Dominion Resources, Inc. (Dominion) and received proceeds of $75 million (after $4 million of post-closing adjustments), which it used for debt reduction. The sale proceeds are subject to further adjustments for an indemnity issued by WPL to cover certain potential costs Dominion may incur related to the unplanned outage at Kewaunee in 2005. WPL recognized a $6 million obligation, the maximum exposure under the indemnity at closing, all of which was outstanding at Dec. 31, 2005. As of the closing date, WPL’s share of the carrying value of the Kewaunee assets and liabilities sold was as follows (in millions):

Assets:

  

Investments

  $172

Property, plant and equipment, net *

   85

Other

   77
    
  $334
    

Liabilities:

  

AROs

  $207

Regulatory liabilities

   46
    
  $253
    

 

Assumptions relating to current rate recovery amounts:

*

WP&L’s shareIncludes nuclear fuel, net of estimated decommissioning cost

$263.2

Year dollars in

2002

Method to develop estimate

Site-specific study

Annual inflation rate

6.50%

Decommissioning method

Prompt dismantling and removal

Year decommissioning to commence

2013

After-tax return on external investments:

Qualified

6.12%

Non-qualified

5.14%

External trust fund balance at Dec. 31, 2002

$223.7

Internal reserve at Dec. 31, 2002

$ —  

After-tax earnings on external trust fund in 2002

$19.7

amortization

The sale of Kewaunee resulted in a loss of approximately $16 million (excluding the benefits of the non-qualified decommissioning trust assets discussed below), which included the proceeds from the sale less the net assets identified in the above table, adjusted by an estimate for the fair value of the indemnity and transaction-related closing costs. The loss was reflected as a regulatory asset given the PSCW approved the deferral of any loss and related costs of sale. Refer to Note 1(c) for further discussion.

WP&L is funding all rate recoveriesWPL previously established two decommissioning funds to cover the eventual decommissioning of Kewaunee. Upon the sale closing, Dominion received WPL’s qualified decommissioning trust assets, which had a value of $172 million as of closing, and assumed responsibility for the eventual decommissioning into an externalof Kewaunee. WPL retained ownership of the non-qualified decommissioning trust fundassets, which had a value of $83 million as of closing. In July 2005, WPL liquidated the retail portion of $60 million of its non-qualified decommissioning trust assets and funding onused a tax-qualified basismajority of the proceeds to repay short-term debt. At Dec. 31, 2005, the extent possible. In accordance with its respective regulatory requirements, WP&L records the earningswholesale portion of WPL’s non-qualified decommissioning trust assets equaled $23 million and was recorded in “Other investments” on the externalConsolidated Balance Sheets. Refer to Note 1(c) for discussion of WPL’s refunds of the non-qualified decommissioning trust fund as interest income with a corresponding entryassets to depreciation expense at WP&L. The earnings accumulate in the external trust fund balancesits retail and in accumulated depreciation on utility plant.wholesale customers.

 

SFAS 143,A-44


Upon closing of the sale, WPL entered into a long-term purchased power agreement with Dominion to purchase energy and capacity at prices similar to what costs would have been had current ownership continued. The purchased power agreement extends through 2013, at which provides accountingtime Kewaunee’s current operating license will expire. At Dec. 31, 2005, WPL’s future minimum payments related to this agreement were $75 million for 2006, $79 million for 2007, $71 million for 2008, $83 million for 2009, $82 million for 2010 and disclosure requirements$213 million for retirement obligations associated2011 through 2013. These amounts are included in the purchased power commitments included in Note 11(b). In April 2004, WPL entered into an exclusivity agreement with long-livedDominion. 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 the parties’ respective share of the plant output that would extend beyond Kewaunee’s current operating license termination date. The exclusivity period extends until December 2011. Under the purchased power agreement, if Kewaunee is off-line for a forced outage during the term of the agreement, Dominion has the obligation to provide replacement power to WPL or pay performance damages to WPL based on the amount of energy not delivered and the price of energy in the market at the Kewaunee pricing location during the forced outage.

WPL’s assets was adopted by WP&Land liabilities related to the Kewaunee sale agreement as of Dec. 31, 2004 have been reclassified as held for sale on Jan. 1, 2003. the Consolidated Balance Sheets. Refer to Note 15 for further discussion.

(17) ASSET RETIREMENT OBLIGATIONS (AROs)

SFAS 143 requires that when an asset is placed in service the present value of any retirement costs associated with that asset for which WP&LWPL has a legal obligation must be recorded as liabilitiesa liability 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 adoptionOn Dec. 31, 2005, WPL adopted FIN 47, which clarifies the term “conditional AROs,” as discussed in SFAS 143, and when an entity would have sufficient information to reasonably estimate the fair value of an ARO. FIN 47 concludes that conditional AROs are within the scope of SFAS 143 will have no impact on WP&L’s earnings, as the effects will be offset by the establishment of regulatory assets or liabilities pursuant to SFAS 71.

143.

WP&L has completed a detailed assessment of the specific applicability and implications of SFAS 143. The scope of SFAS 143 and FIN 47 as it relates to WP&L primarily includes decommissioning costs for Kewaunee. It alsoWPL applies to a smaller extent tothe removal, closure or dismantlement of several other regulated and non-regulated assets including, but not limited to, active ash landfills, water intake facilities, above and underground storage tanks, groundwater wells, transmission and distribution equipment, easements, leases and the dismantlement of certain hydro facilities. Other than Kewaunee, WP&L’s asset retirement obligations asIt also applies to the remediation of Jan. 1, 2003 are not significant.

Prior to January 2003, WP&L recorded nuclear decommissioning charges in accumulated depreciation on its Consolidated Balance Sheets.asbestos, coal yards, ash ponds and polychlorinated biphenyls (PCB) contamination. Upon the adoption of SFAS 143, WP&L will reverse approximately $175 million, previously recorded in accumulated depreciationFIN 47, AROs were recognized for asbestos contamination, remediation of active landfills, PCB contamination and will record liabilities of approximately $175 million. The difference between amounts previously recorded and the net SFAS 143 liability will be deferred as a regulatory asset and is expected to approximate $0 for WP&L.

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

(12) JOINTLY-OWNED ELECTRIC UTILITY PLANT

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

   

Fuel

Type


    

Ownership

Interest %


  

Plant in

Service


  

Accumulated

Provision for

Depreciation


    

Construction

Work-In-

Progress


Edgewater Unit 5

  

Coal

    

75.0

  

$234.8

  

$112.9

    

$0.4

Columbia Energy Center

  

Coal

    

46.2

  

187.5

  

110.3

    

1.6

Kewaunee

  

Nuclear

    

41.0

  

172.6

  

120.9

    

6.8

Edgewater Unit 4

  

Coal

    

68.2

  

60.0

  

36.1

    

1.6

           
  
    
           

$654.9

  

$380.2

    

$10.4

           
  
    

(13) SEGMENTS OF BUSINESS

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

 

   

Electric


  

Gas


  

Other


  

Total


 

2002

                 

Operating revenues

  

$

787.7

  

$

179.1

  

$

5.3

  

$

972.1

 

Depreciation and amortization

  

 

117.3

  

 

17.7

  

 

1.2

  

 

136.2

 

Operating income

  

 

114.1

  

 

12.0

  

 

1.4

  

 

127.5

 

Interest expense, net of AFUDC

              

 

37.6

 

Interest income

              

 

(21.6

)

Equity income from unconsolidated investments

              

 

(17.0

)

Miscellaneous, net

              

 

2.9

 

Income tax expense

              

 

44.7

 

Net income

              

 

80.9

 

Preferred dividends

              

 

3.3

 

Earnings available for common stock

              

 

77.6

 

Total assets

  

 

1,426.7

  

 

259.5

  

 

298.4

  

 

1,984.6

 

Investments in equity method subsidiaries

  

 

121.7

          

 

121.7

 

Construction and acquisition expenditures

  

 

144.6

  

 

10.6

  

 

1.7

  

 

156.9

 

2001

                 

Operating revenues

  

$

753.5

  

$

206.9

  

$

5.0

  

$

965.4

 

Depreciation and amortization

  

 

111.5

  

 

16.4

  

 

1.2

  

 

129.1

 

Operating income

  

 

121.6

  

 

2.5

  

 

1.3

  

 

125.4

 

Interest expense, net of AFUDC

              

 

38.7

 

Interest income

              

 

(8.1

)

Equity income from unconsolidated investments

              

 

(15.5

)

Miscellaneous, net

              

 

(4.4

)

Income tax expense

              

 

41.2

 

Net income

              

 

73.5

 

Preferred dividends

              

 

3.3

 

Earnings available for common stock

              

 

70.2

 

Total assets

  

 

1,323.9

  

 

224.5

  

 

327.4

  

 

1,875.8

 

Investments in equity method subsidiaries

  

 

117.3

          

 

117.3

 

Construction and acquisition expenditures

  

 

127.9

  

 

16.8

  

 

2.3

  

 

147.0

 

2000

                 

Operating revenues

  

$

692.2

  

$

165.2

  

$

5.0

  

$

862.4

 

Depreciation and amortization

  

 

122.9

  

 

15.9

  

 

1.1

  

 

139.9

 

Operating income

  

 

123.2

  

 

12.2

  

 

1.7

  

 

137.1

 

Interest expense, net of AFUDC

              

 

39.3

 

Interest income

              

 

(13.1

)

Equity income from unconsolidated investments

              

 

(0.5

)

Miscellaneous, net

              

 

(2.9

)

Income tax expense

              

 

42.9

 

Net income

              

 

71.4

 

Preferred dividends

              

 

3.3

 

Earnings available for common stock

              

 

68.1

 

Total assets

  

 

1,344.9

  

 

226.1

  

 

286.0

  

 

1,857.0

 

Investments in equity method subsidiaries

  

 

4.8

          

 

4.8

 

Construction and acquisition expenditures

  

 

114.2

  

 

15.1

  

 

2.3

  

 

131.6

 

   2005  2004

Balance at Jan. 1

  $0.9  $0.6

Adoption of FIN 47

   10.0   —  

Accretion expense

   —     0.3
        

Balance at Dec. 31

  $10.9  $0.9
        

If FIN 47 had been adopted as of Jan. 1, 2003, WPL would have recorded FIN 47 ARO liabilities of $9.3 million and $8.8 million at Dec. 31, 2004 and 2003, respectively.

(14) SELECTED CONSOLIDATED QUARTERLY FINANCIAL DATA (UNAUDITED)Refer to Note 16 for AROs included in liabilities held for sale relating to the sale of WPL’s interest in Kewaunee.

 

SummationA-45


(18) 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. After making an ongoing exhaustive effort, WPL concluded it was unable to obtain the information necessary from the counterparties (subsidiaries of Calpine) for the Riverside and RockGen plant purchased power agreements, to determine whether the counterparties are variable interest entities per FIN 46R, and if WPL is the primary beneficiary. These agreements are currently accounted for as operating leases. The counterparties sell some or all of their generating capacity to WPL and can sell their energy output to WPL. WPL’s maximum exposure to loss from these agreements is undeterminable due to the inability to obtain the necessary information to complete such evaluation. In 2005 and 2004, Alliant Energy’s (primarily WPL’s) costs, excluding fuel costs, related to the Riverside agreement were $65 million and $39 million, respectively. The Riverside plant was placed in service in June 2004. In 2005, 2004 and 2003, WPL’s costs, excluding fuel costs, related to the RockGen agreement were $18 million, $33 million and $33 million, respectively.

In December 2005, Calpine filed voluntary petitions to restructure under Chapter 11 of the individual quarters may not equal annual totals due to rounding.

   

2002


  

2001


   

March 31


  

June 30


  

Sept. 30


  

Dec. 31


  

March 31


  

June 30


  

Sept. 30


  

Dec. 31


   

(in millions)

Operating revenues

  

$

229.5

  

$

217.5

  

$

249.0

  

$

276.1

  

$

317.2

  

$

204.1

  

$

228.3

  

$

215.8

Operating income

  

 

24.1

  

 

28.6

  

 

35.4

  

 

39.3

  

 

37.0

  

 

23.4

  

 

36.2

  

 

28.8

Net income

  

 

15.7

  

 

12.8

  

 

19.2

  

 

33.2

  

 

19.3

  

 

11.6

  

 

19.9

  

 

22.8

Earnings available for common stock

  

 

14.9

  

 

12.0

  

 

18.3

  

 

32.4

  

 

18.4

  

 

10.7

  

 

19.0

  

 

22.0

U.S. Bankruptcy Code. The RockGen facility is part of the bankruptcy proceedings but the Riverside facility is excluded. WPL utilizes the RockGen facility primarily for capacity. WPL is currently evaluating its options should the purchased power agreement be terminated by the bankruptcy trustees.

(15)(19) RELATED PARTIES

WP&LWPL and IP&L have entered intoIPL are parties to a System Coordination and Operating Agreement. The agreement, which has been approved by FERC, provides a contractual basis for coordinated planning, construction, operation and maintenance of the interconnected electric generation and transmission (IPL only) systems of WP&LWPL and IP&L.IPL. In addition, the agreement allows the interconnected system to be operated as a single entity with off-system capacity sales and purchases made to market excess system capability or to meet system capability deficiencies. Such sales and purchases are allocated among WP&LWPL and IP&LIPL based on procedures included in the agreement. The sales amounts allocated to WP&LWPL were $26.9$40 million, $32.1$25 million and $28.6$42 million for 2002, 20012005, 2004 and 2000,2003, respectively. The purchases allocated to WP&LWPL were $205.8$466 million, $209.2$279 million and $130.7$229 million for 2002, 20012005, 2004 and 2000,2003, respectively. The procedures were approved by both FERC and all state regulatory bodies having jurisdiction over these sales. Under the agreement, WP&LWPL and IP&LIPL are fully reimbursed for any generation expense incurred to support the sale to an affiliate or to a non-affiliate. Any margins on sales to non-affiliates are distributed to WP&LWPL and IP&LIPL in proportion to each utility’s share of electric production at the time of the sale.

Pursuant to a service agreement, approved by the SEC under PUHCA, WP&LWPL receives various administrative and general services from an affiliate, Corporate Services. These services are billed to WP&LWPL at cost based on payroll and other expenses incurred by Corporate Services for the benefit of WP&L.WPL. These costs totaled $117.7$113 million, $107.0$129 million and $103.4$125 million for 2002, 20012005, 2004 and 2000,2003, respectively, and consisted primarily of employee compensation, benefits and fees associated with various professional services. At Dec. 31, 20022005 and 2001, WP&L2004, WPL had a net intercompany payable to Corporate Services of $31.1$45 million and $32.2$31 million, respectively.

In 2004, Resources’ Non-regulated Generation business billed WPL $7 million related to the construction of SFEF, which WPL leases from Resources. Refer to Note 3(b) for discussion of WPL’s capital lease related to SFEF.

SHAREOWNER INFORMATIONATC -Pursuant to various agreements, WPL receives a range of transmission services from ATC. WPL provides operation, maintenance, and construction services to ATC. WPL and ATC also bill each other for use of shared facilities owned by each party. ATC billed WPL $52 million, $48 million and $41 million in 2005, 2004 and 2003, respectively. WPL billed ATC $9.3 million, $13 million and $12 million in 2005, 2004 and 2003, respectively. At Dec. 31, 2005 and 2004, WPL owed ATC net amounts of $3.7 million and $2.9 million, respectively.

Nuclear Management Company, LLC (NMC) -WPL received services from NMC for the management and operation of Kewaunee. NMC billed WPL indirectly, through WPSC, $18 million, $34 million and $33 million in 2005, 2004 and 2003, respectively, for its allocated portion for Kewaunee. Refer to Note 16 for discussion of WPL’s sale of its interest in Kewaunee. As a result of the sale, WPL no longer receives services from NMC.

 

A-46


SHAREOWNER INFORMATION

Market Information - The 4.50% series of preferred stock is listed on the American Stock Exchange, with the trading symbol of WIS_PR. All other series of preferred stock are traded on the over-the-counter market. Seventy-one percent70% of WP&L’sWPL’s individual preferred shareowners are Wisconsin residents.

Dividend Information - Preferred stock dividends paid per share for each quarter during 20022005 were as follows:

 

Series


  

Dividend


4.40%

  

$1.10

4.50%

  

$1.125

4.76%

  

$1.19

4.80%

  

$1.20

4.96%

  

$1.24

6.20%

  

$1.55

6.50%

  

$0.40625

Series

  Dividend

4.40%

  $1.10

4.50%

  $1.125

4.76%

  $1.19

4.80%

  $1.20

4.96%

  $1.24

6.20%

  $1.55

6.50%

  $0.40625

As authorized by the WP&LWPL Board of Directors, preferred stock dividend record and payment dates for 20032006 are as follows:

 

Record Date


  

Payment Date


February 28

  

March 15

May 31

June 15

August 31

September 15

November 30

  

June 14

August 29

September 15

November 28

December 15

Stock Transfer Agent and Registrar

Alliant Energy Corporation

Shareowner Services

P.O. Box 2568

Madison, WI 53701-2568

Form 10-K Information - A copy of the combined Annual Report on Form 10-K for the year ended Dec. 31, 2005 as filed with the SEC will be provided without charge upon request. Requests may be directed to Shareowner Services at the above address.

 

A-47


EXECUTIVE OFFICERS AND DIRECTORS

Executive Officers - Numbers following the names represent the officer’s age as of Dec. 31, 2005.

Erroll B. Davis, Jr.William D. Harvey, 58, 56, was elected Chairman of the Board effective April 2000February 2006 and Chief Executive Officer (CEO) effective April 1998.

William D. Harvey, 53, was elected President effective April 1998.

Eliot G. Protsch, 49, was elected Executive Vice President-Energy Delivery effective October 1998.July 2005 and has been a board member since January 2005. He previously served as Senior ViceChief Operating Officer since 2004 and President from 19931998 to 1998.2003.

Barbara J. Swan 51,, 54, was elected President effective January 2004. She previously served as Executive Vice President and General Counsel effective October 1998. She previously served as Vice President-General Counsel from 1994 tosince 1998.

Thomas M. Walker,Eliot G. Protsch 55,, 52, was elected Executive Vice President and Chief Financial Officer (CFO) effective October 1998.January 2004. He previously served as Executive Vice President and CFOChief Financial Officer since 1996 at IESSeptember 2003 and IESU.

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

Dundeana K. Doyle, 44, was elected Vice President-Infrastructure Security effective January 2002. She previously served as Vice President-Customer Operations since December 2000, Vice President-Customer Services and Operations from 1999 to 2000 and Vice President-Customer ServicesPresident-Energy Delivery from 1998 to 1999.September 2003.

Vern A. Gebhart,Thomas L. Aller 49,, 56, was elected Senior Vice President-Customer OperationsPresident-Energy Delivery effective January 2002.2004. He previously served as Managing Director-Strategic Projectsinterim Executive Vice President-Energy Delivery since September 2003 and Capital Control since 2000Vice President-Investments at Alliant Energy and Director-Strategic Projects and Capital ControlResources from 1998 to 2000 at Alliant Energy.2003.

Thomas L. Hanson 49,, 52, 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.

Patricia L. Kampling, 46, was elected Vice President-Finance effective August 2005. She previously served as Treasurer of IPSCO Inc. since September 2004 and Senior Vice President and Chief Financial Officer of Exelon Enterprises Company, LLC (a subsidiary of Exelon Corporation) from 2000 to 2002.

John E. Kratchmer 40,, 43, 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 19982000.

Directors - Refer to 2000 at Alliant Energy.WPL’s Proxy Statement for information on WPL’s board members.

 

Daniel L. Mineck, 54, was elected Vice President-Performance Engineering and Environmental effective April 1998.A-48


Barbara A. Siehr, 51, was elected Vice President-Financial Planning and Strategic Projects effective October 2002. She previously served as Managing Director-Operations and Operations Services since December 2000 at© 2006 Alliant Energy General Manager-Operations East from 1999 to 2000 at Alliant Energy and General Manager-Engineering/Operations Services from 1998 to 1999 at Alliant Energy.

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

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

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

Additional Officers

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

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

Patricia L. Reininger, 50, was elected Assistant Corporate Secretary effective January 2003. She previously served as Executive Administrative Assistant since August 2000 at Alliant Energy. Prior to joining Alliant Energy, she was Assistant to the Chairperson and Assistant Corporate Secretary from 1993 to 1999 at Sentry Insurance.71-1295 • 111569 3/06 JS

Wisconsin Power & Light Company

Shareowner Services

PO Box 2568

Madison WI 53701-2568

SHAREOWNER INFORMATION NUMBERS

Local Madison, WI

1-608-458-3110            

All Other Areas

1-800-356-5343            

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

ELECTION OF DIRECTORS

For All

Withhold

For All

For All

Except(*)

Nominees for terms

ending in 2006:

P

R

O

X

Y

¨

¨

¨

01    Erroll B. Davis, Jr.

02    Robert W. Schlutz

03    Wayne H. Stoppelmoor

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

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


Signature                                                                     Date

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


Signature                                                                     Date

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


To all Wisconsin Power and Light Company Shareowners:

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

Above is your 2003 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 Thursday, June 5, 2003 at 1:00 p.m. at the Alliant Energy Corporate Headquarters in the Seine Meeting Room at 4902 N. Biltmore Lane, Madison, Wisconsin.


Wisconsin Power & Light Company

P.O. Box 2568

Madison, WI 53701-2568

WISCONSIN POWER AND LIGHT COMPANY

PO BOX 2568

MADISON, WI 53701-2568

 


ANNUAL MEETING OF SHAREOWNERS—JUNE 5, 2003


ANNUAL MEETING OF SHAREOWNERS — MAY 24, 2006

The undersigned appoints William D. HarveyBarbara J. Swan and F.J.F. J. Buri, or either of them, attorneys and proxies with the power of substitution to vote all shares of stock of Wisconsin Power and Light Company (the “Company”), held of record in the name of the undersigned at the close of business on April 15, 2003,10, 2006, at the Annual Meeting of Shareowners of the Company to be held at 4902 N. Biltmore Lane, Madison, Wisconsin on June 5, 2003May 24, 2006 at 1:2:00 p.m., and at all adjournments thereof, upon all matters that properly come before the meeting, including the matters described in the Company’s Notice of Annual Meeting, of ShareownersProxy Statement and Annual Report, dated April 21, 2003 and accompanying Proxy Statement,18, 2006, 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”as recommended by the electionBoard of Directors. The Board of Directors recommends a vote “FOR” all listed director nominees.nominees and “FOR” the ratification of the appointment of Deloitte & Touche LLP as the Company’s independent registered public accounting firm for 2006.

 

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To access the Alliant Energy Corporation Annual Report and Proxy Statement on the Internet, please open our siteAlliant Energy’s website atwww.alliantenergy.comwww.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.


Wisconsin Power and Light CompanySHAREOWNER INFORMATION NUMBERS

Shareowner Services

Local Madison, WI

1-608-458-3110

PO Box 2568

All Other Areas

1-800-356-5343

Madison, WI 53701-2568

Indicate your vote by an (X) in the appropriate boxes.
1.ELECTION OF DIRECTORS
For AllWithhold
For All

For All

Except(*)

Nominees for terms

ending in 2009:

¨¨

¨

P

R

O

X

Y

(01) Ann K. Newhall

(02) Dean C. Oestreich

(03) Carol P. Sanders

*TO WITHHOLD AUTHORITY TO VOTE
FOR ANY INDIVIDUAL NOMINEE, STRIKE
A LINE THROUGH THE NOMINEE’S NAME
IN THE LIST TO THE LEFT AND MARK AN
(X) IN THE “For All Except” BOX.
2.Proposal to ratify the appointment of Deloitte & Touche LLP as the Company’s independent registered public accounting firm for 2006.ForAgainstAbstain
¨¨

¨

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.  ¯
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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 2006 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, May 24, 2006, at 2:00 p.m. at the Alliant Energy Corporate Headquarters in the Mississippi Meeting Room at 4902 N. Biltmore Lane, Madison, Wisconsin.