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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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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SEC 1913 (3-99)


YOUR VOTE IS IMPORTANT

Wisconsin

Power and Light

Company

NOTICEOF 2009 ANNUAL MEETING

PROXY STATEMENTAND

2008 ANNUAL REPORT


WISCONSIN POWER AND LIGHT COMPANY

ANNUAL MEETING OF SHAREOWNERS

 

DATE:

  Wednesday,Tuesday, May 20, 200917, 2011

TIME:

  2:00 p.m. (Central Daylight Time)

LOCATION:

  

Wisconsin Power and Light Company

Alliant Energy CorporateCorporation Headquarters

Mississippi MeetingSandy River Conference Room 1R600

4902 North Biltmore Lane

Madison, Wisconsin 53718

SHAREOWNER INFORMATION

Wells Fargo Shareowner Services

161 North Concord Exchange

P. O. Box 64854

St. Paul, MN 55164-0854

1-800-356-5343

www.wellsfargo.com/shareownerservices


Wisconsin Power and Light Company

4902 North Biltmore Lane

P. O. Box 14720

Madison, WI 53708-0720

Phone: 608-458-3110

NOTICE OF ANNUAL MEETING AND PROXY STATEMENT

Dear Wisconsin Power and Light Company Shareowner:

On Wednesday,Tuesday, May 20, 2009,17, 2011, Wisconsin Power and Light Company will hold its 20092011 Annual Meeting of Shareowners at the offices ofAlliant Energy Corporation, 4902 North Biltmore Lane, Mississippi MeetingSandy River Conference Room in Madison, Wisconsin. Wisconsin 53718.The meeting will begin at 2:00 p.m. (Central Daylight Time).

Only the sole common shareowner, Alliant Energy Corporation, and preferred shareowners who owned stock at the close of business on April 7, 2009March 30, 2011 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, our shareowners will be asked to:

 

 1.Elect threetwo directors to serve on our Board of Directors for terms expiring at the 20122014 Annual Meeting;

 

 2.Consider an advisory vote on compensation of our named executive officers;

3.Consider an advisory vote on the frequency of the advisory vote on compensation of our named executive officers;

4.Ratify the appointment of Deloitte & Touche LLP as our independent registered public accounting firm for 2009;2011; and

 

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

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

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

A copy of our 20082010 Annual Report appears aswas included in Appendix A 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.

Important Notice Regarding the Availability of Proxy Materials for the Shareowner Meeting to Be Heldbe held on May 20, 2009:17, 2011. Our 20092011 Notice of Annual Meeting, Proxy Statement and the 20082010 Annual Report to Shareowners are available athttp://www.alliantenergy.com/WPLproxy.WPLproxy.

Any Wisconsin Power and Light Company preferred shareowner who desires to receive a copy of the Alliant Energy Corporation 20082010 Annual Report, 20092011 Notice of Annual Meeting and Proxy Statement may do so by calling our Shareowner Services Department at (800) 353-1089 or writing to us at the address shown above.The Alliant Energy Corporation proxy statement for the 20092011 Annual Meeting of Shareowners and the 20082010 Annual Report to Shareowners are available athttp://www.alliantenergy.com/eproxy.eproxy.

By Order of the Board of Directors,

LOGO

F. J. Buri

Corporate Secretary and

Assistant General Counsel

Dated and mailed on or about April 16, 2009.8, 2011.


TABLE OF CONTENTS

 

Questions and Answers

 1

Proposal One — Election of Directors

 34

Meetings and Committees of the Board

 56

Corporate Governance

 810

Ownership of Voting Securities

 1113

Compensation Discussion and Analysis

 1214

Compensation and Personnel Committee Report

 2025

Summary Compensation Table

 2126

Grants of Plan-Based Awards

 2328

Outstanding Equity Awards at Fiscal Year-End

 2429

Option Exercises and Stock Vested

 2530

Pension Benefits

 2632

Nonqualified Deferred Compensation

 2935

Potential Payments Upon Termination or Change in Control

 3036

Proposal Two — Advisory Vote on Compensation of Our Named Executive Officers

42

Proposal Three — Advisory Vote on the Frequency on the Advisory Vote on Compensation of Our Named Executive Officers

43

Director Compensation

 3645

Report of the Audit Committee

 3947

Proposal for theFour — Ratification of the Appointment of Deloitte  & Touche LLP as the Company’s Independent Registered Public Accounting Firm for 20092011

 4048

Section 16(a) Beneficial Ownership Reporting Compliance

 4149

Appendix A — Wisconsin Power and Light Company Annual Report

 A-1


QUESTIONS AND ANSWERS

 

  1.Q:Why am I receiving these materials?
 A:Our Board of Directors is providing these proxy materials to you in connection with our Annual Meeting of Shareowners (the “Annual Meeting”), which will take place on Wednesday,Tuesday, May 20, 2009.17, 2011. As a shareowner, you are invited to attend the Annual Meeting and are entitled to and requested to vote on the proposals described in this proxy statement.

 

  2.Q:What is Wisconsin Power and Light Company and how does it relate to Alliant Energy Corporation?
 A:We are a subsidiary of Alliant Energy Corporation (“Alliant Energy” or “AEC”), a public utility holding company whose other primary first tier subsidiariesregulated utilities are Interstate Power and Light Company (“IPL”), Alliant Energy Resources, LLC (“Resources”) and Alliant Energy Corporate Services, Inc. (“Corporate Services”).our Company.

 

  3.Q:Who is entitled to vote at the Annual Meeting?
 A:Only shareowners of record at the close of business on April 7, 2009March 30, 2011 are entitled to vote at the Annual Meeting. As of the record date, 13,236,601 shares of our 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 our common stock and our 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 1/4 vote per share.

 

  4.Q:What may I vote on at the Annual Meeting?
 A:You may vote on:

 

The election of threetwo nominees to serve on our Board of Directors for terms expiring at the 20122014 Annual Meeting;

A non-binding advisory vote to approve compensation of our named executive officers;

A non-binding advisory vote on the frequency of the advisory vote on compensation of our named executive officers; and

The ratification of the appointment of Deloitte & Touche LLP as our independent registered public accounting firm for 2009.2011.

 

  5.  Q:How does the Board of Directors recommend I vote?
 A:Our Board of Directors recommends that you vote your shares FOR each of the listed director nominees; FOR approval of the compensation of our named executive officers as disclosed in the Compensation Discussion and Analysis section and accompanying compensation tables and narrative discussion contained in this proxy statement; for a frequency of 1 YEAR for future non-binding shareholder advisory votes on compensation of our named executive officers; and FOR the ratification of the appointment of Deloitte & Touche LLP as our independent registered public accounting firm for 2009.2011.

 

  6.  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:How are votes counted?
A:In voting for the election of directors, you may vote FOR all of the director nominees or you may WITHHOLD your vote with respect to one or more nominees. In voting on the proposal to ratify the appointment of Deloitte & Touche LLP as our independent registered public accounting firm for 2009, you may vote FOR, AGAINST or you may 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” all listed director nominees and “FOR” the proposal to ratify the appointment of Deloitte & Touche LLP as our independent registered public accounting firm for 2009. If your proxy card is not signed, your votes will not be counted.

A:

Election of directors — You may vote FOR all of the director nominees or you may WITHHOLD your vote with respect to one or more nominees.

Advisory vote on compensation of our named executive officers — You may vote FOR or AGAINST approval of the compensation of our named executive officers, or you may ABSTAIN.

Frequency of advisory vote on compensation of our named executive officers — You may vote to hold future advisory votes on the compensation of our named executive officers every 1 YEAR, 2 YEARS or 3 YEARS, or you may ABSTAIN.

Ratification of independent registered public accounting firm — You may vote FOR or AGAINST ratifying the appointment of Deloitte & Touche LLP as our independent registered public accounting firm for 2011, or you may 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 all listed director nominees, FOR approval of the compensation of our named executive officers, for a frequency of 1 YEAR for future advisory votes on compensation of our named executive officers and FOR ratification of the appointment of Deloitte & Touche LLP as our independent registered public accounting firm for 2011. If your proxy card is not signed, your votes will not be counted.

If you hold your shares through a bank, broker or other record holder and you do not provide such bank, broker or other record holder with specific voting instructions on a timely basis, your shares will not be voted with respect to the election of directors, the advisory vote on compensation of our named executive officers or the advisory vote on the frequency of the advisory vote on compensation of our named executive officers. We urge you to carefully consider all of the proposals and direct your bank, broker or other record holder to vote your shares as you desire.

 

  8.  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 our Corporate Secretary 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: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. We encourage you to have all accounts registered in the same name and address (whenever possible). You can accomplish this by contacting Wells Fargo Shareowner Services at the shareowner information number shown at the front of this proxy statement.

 

10.  Q:Who may attend the Annual Meeting?
 A:All shareowners who owned shares of our common stock and preferred stock on April 7, 2009March 30, 2011 may attend the Annual Meeting.

 

11.  Q:How will voting on any other business be conducted?
 A:Our Board of Directors does not know of any business to be considered at the Annual Meeting other than the four proposals set forth in this proxy statement. These consist of the election of directors, the advisory vote on compensation of our named executive officers, the advisory vote on the frequency of the advisory vote on compensation of our named executive officers and the ratification of the appointment of Deloitte & Touche LLP as our independent registered public accounting firm for 2009.2011. If any other business is properly presented at the Annual Meeting, your proxy gives Thomas L. Hanson,John O. Larsen, our Vice President-Controller and Chief Accounting Officer,President, and F. J. Buri, our Corporate Secretary, authority to vote on such matters at their discretion.

 

12.  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 us at the information number shown at the top ofon the Notice of Annual Meeting for the results. We will also publishfile the finalvoting results in our Quarterlyon a Current Report on Form 10-Q for the second quarter of 2009 to be filed8-K with the Securities and Exchange Commission (“SEC”). within four business days following the Annual Meeting.

 

13.  Q:Are our 2010 Annual Report and these proxy materials available on the Internet?
A:Yes. As required by rules adopted by the SEC, we are making our proxy statement and our annual report available to our shareowners electronically via the Internet. You can access these materials athttp://www.alliantenergy.com/WPLproxy.

14.  Q:When are shareowner proposals for the 20102012 Annual Meeting due?
 A:All shareowner proposals to be considered for inclusion in our proxy statement for the 20102012 Annual Meeting, pursuant to Rule 14a-8 under the Securities Exchange Act of 1934 (“Rule 14a-8”), must be received at our principal office by Dec. 17, 2009. In addition, any shareowner who intends to present a proposal from the floor at our 2010 Annual Meeting must submit the proposal to our Corporate Secretary no later than March 2, 2010.10, 2011.

In addition, any shareowner who intends to present a proposal from the floor at our 2012 Annual Meeting must submit the proposal to our Corporate Secretary no later than Feb. 23, 2012.

 

14.15.  Q:Who is our independent registered public accounting firm and how is it appointed?
 A:Deloitte & Touche LLP audited our financial statements for the year ended Dec. 31, 2008.2010. Representatives of Deloitte & Touche LLP are not expected to be present at the Annual Meeting. The Audit Committee of the Board of Directors has appointed, and is recommending for ratification by shareowners, its appointment of, Deloitte & Touche LLP as our independent registered public accounting firm for the year ending Dec. 31, 2009.2011.

15.16.  Q:Who will bear the cost of soliciting proxies for the Annual Meeting and how will these proxies be solicited?
 A:We 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 our officers and employees who will not receive any additional compensation for these solicitation activities. We will pay banks, brokers, nominees and other fiduciaries reasonable charges and expenses incurred in forwarding the proxy materials to their principals.

16.  Q: How can I obtain a copy of the Company’s Annual Report on Form 10-K?

A:We 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 our Annual Report on Form 10-K (without exhibits) as filed with the SEC. Written requests for the Form 10-K should be mailed to our Corporate Secretary at the address shown at the top of the Notice of Annual Meeting.

 

17.  Q:If more than one shareowner lives in my household, how can I obtain an extra copy of the 20082010 Annual Report and proxy statement?
 A:Pursuant to the rules of the SEC, services that deliver our 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 our 20082010 Annual Report and proxy statement. Upon written or oral request, we will mail a copy of the 20082010 Annual Report and proxy statement to any shareowner at a shared address to which a single copy of the document was previously delivered. You may notify us of your request by calling or writing to us as the case may be, at the information address or number shown on the Notice of Annual Meeting.

PROPOSAL ONE

ELECTION OF DIRECTORS

At the Annual Meeting, threetwo directors will be elected forwith terms expiring in 2012.2014. The nominees for election as recommended by the Nominating and Governance Committee and selected by the Board of Directors are Ann K. Newhall, Dean C. OestreichWilliam D. Harvey and Carol P. Sanders.Singleton B. McAllister. Each of the nominees is currently serving on our Board of Directors. Each person elected as a director will serve until our Annual Meeting of Shareowners in 2012,2014, or until his or her successor has been duly qualified and 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, including as a result of broker non-votes, will have no effect on the election of directors. The proxies solicited may be voted for a substitute nominee or nominees if any of the nominees are unable to serve, or for good reason will not serve, a contingency not now anticipated.

Brief biographies of the director nominees and continuing directors follow. These biographies include their ages (as of Dec. 31, 2008),2010); an account of their specific business experience andexperience; the names of publicly held and certain other corporations of which they also are, alsoor have been within the past five years, directors; and a brief discussion of their specific experience, qualifications, attributes or skills that led to the conclusion that they should serve as directors. Except as otherwise indicated, each nominee and continuing director has been engaged in his or her present occupation for at least the past five years.

Prior to Nov. 25, 2008, each of our directors served on the Board of Directors of Resources during the period they served as a director of our company. On Nov. 25, 2008, Resources was converted to a limited liability company and, as a result, no longer has a Board of Directors.

NOMINEES

 

LOGO

WILLIAM D. HARVEY

Age 61

Director since 2005

Nominated Term expires in 2014

Mr. Harvey has served as Chairman of the Board of the Company, AEC and IPL since February 2006. He has served as Chief Executive Officer of the Company, AEC and IPL since July 2005. He served as President of AEC from January 2004 until February 2011. He previously served as President and Chief Operating Officer of AEC and Chief Operating Officer of IPL and WPL from January 2004 to July 2005. He served as President of the Company and as Executive Vice President — Generation for AEC, IPL and Resources from 1998 to January 2004. Mr. Harvey serves on the board of directors of Sentry Insurance Company. Mr. Harvey’s long-term experience with our operations, customer perspectives, utility and environmental regulation, legal matters, safety, and diversity initiatives led to the conclusion that he should serve as Chairman of the Board.
LOGO

LOGO

  

ANN K. NEWHALLSINGLETON B. MCALLISTER

Age 58

Director since 2001

Nominated Term expires in 2014

Ms. McAllister has been a partner in the Washington D. C. office of the law firm of Blank Rome LLP since June 2010. She previously served as a partner in the law firm of LeClair & Ryan LLP since October 2007 and as a partner in the law firm of Mintz, Levin, Cohn, Ferris, Glovsky and Popeo P. C. from July 2005 to October 2007. She 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. Ms. McAllister has served on the board of directors of United Rentals, Inc. since 2004. Ms. McAllister has served as a Director of AEC and IPL since 2001. Ms. McAllister’s experience in legal, legislative, regulatory, public affairs, human resources and diversity initiatives led to the conclusion that she should serve on our Board of Directors.

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

CONTINUING DIRECTORS

LOGO

MICHAEL L. BENNETT

Age 57

  

Director since 2003

Nominated Term expires in 2013

Mr. Bennett has been a private investor and consultant in Sioux City, Iowa since May 2010. He previously served as President and Chief Executive Officer of Terra Industries Inc., an international producer of nitrogen products headquartered in Sioux City, Iowa, since April 2001. He also served as Chairman of the Board and President for Terra Nitrogen Company, L.P., a subsidiary of Terra Industries Inc. He has served on the board of directors of Arclin, Inc., a privately held company located in Canada since 2010. Mr. Bennett has served as a Director of AEC and IPL since 2003. Mr. Bennett is Chairperson of the Nominating and Governance Committee, our Lead Independent Director and an audit committee financial expert. Mr. Bennett’s leadership of a publicly traded company and his experience in operations, customer perspectives, legal matters, and human resource matters led to the conclusion that he should serve on our Board of Directors.

LOGO

DARRYL B. HAZEL

Age 62

Director since 2006

Term expires in 2013

Mr. Hazel has been the principal of Darryl B. Hazel Consulting LLC, a business consulting firm in Detroit, Mich., since January 2010. He retired in January 2010 from his position as Senior Vice President, Global Services Initiatives of Ford Motor Company, an automobile manufacturer. He also served as President of the Customer Service Division and Senior Vice President of Ford Motor Company from March 2006 to September 2009. He previously served as President of Marketing of Ford Motor Company from September 2005 to March 2006; President of the Ford Division from April 2005 to September 2005; and President of the Lincoln Mercury Division from August 2002 to April 2005. Mr. Hazel has served as a Director of AEC and IPL since 2006. Mr. Hazel is an audit committee financial expert. Mr. Hazel’s long-term experience as an executive of a publicly traded company and its subsidiaries along with his experience in operations, customer perspectives, human resources, technology matters and diversity initiatives led to the conclusion that he should serve on our Board of Directors.
LOGO

ANN K. NEWHALL

Age 59

Director since 2003

Term expires in 2012

  Ms. Newhall retired in August 2008 from her position as Executive Vice President, Chief Operating Officer, Secretary and a Director of Rural Cellular Corporation (“RCC”), a cellular communications corporation located in Alexandria, Minn., following RCC’s sale to Verizon. Ms. Newhall held this position from 2000 to 2008. Ms. Newhall has served as a Director of AEC and IPL since 2003. Ms. Newhall is Chairperson of the Compensation and Personnel Committee. Ms. Newhall’s leadership in a publicly traded company and her experience in operations, customer perspectives, legal, regulatory, human resources and technology matters led to the conclusion that she should serve on our Board of Directors.
LOGO

LOGO

  

DEAN C. OESTREICH

Age 5658

  

Director since 2005

Nominated Term expires in 2012

  Mr. Oestreich has been Chairman ofa consultant to Pioneer Hi-Bred International, Inc., developer and supplier of advanced plant genetics, and a wholly-owned subsidiary of DuPont Corporation, located in Johnston, Iowa, since January 2010. He previously served as Chairman from November 2007.2007 to his retirement in December 2009. He hasalso served as Vice President of DuPont Corporation since 2004.from 2004 through 2009. He previously served as President of Pioneer Hi-Bred International, Inc. from 2004 to 2007. Mr. Oestreich previously served as Vice President and Business Director of North America from 2002 to 2004. Mr. Oestreich has served as a Director of AEC and IPL since 2005. Mr. Oestreich is Chairperson of the Environmental, Nuclear, Health and Safety Committee. Mr. Oestreich’s experience with publicly traded companies, operations, customer perspectives, regulatory and public affairs, human resources, technology, environmental matters and safety led to the conclusion that he should serve on our Board of Directors.
LOGOLOGO  

CAROL P. SANDERSDAVID A. PERDUE

Age 41

Director since 2005

Nominated Term expires in 2012

Ms. Sanders has served as Chief Financial Officer and Corporate Secretary of Jewelers Mutual Insurance Company of Neenah, Wis., a nationwide insurer that specializes in protecting 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. Ms. Sanders has served as a Director of AEC and IPL since 2005. Ms. Sanders is Chairperson of the Audit Committee.

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

CONTINUING DIRECTORS

LOGO

MICHAEL L. BENNETT

Age 55

Director since 2003

Term expires in 2010

Mr. Bennett has served as President and Chief Executive Officer of Terra Industries Inc., an international producer of nitrogen products and methanol ingredients headquartered in Sioux City, Iowa, since April 2001. He also serves as Chairman of the Board for Terra Nitrogen GP Inc., a subsidiary of Terra Industries Inc. Mr. Bennett has served as a Director of AEC and IPL since 2003. Mr. Bennett is Chairperson of the Nominating and Governance Committee and the Lead Independent Director.

LOGO

WILLIAM D. HARVEY

Age 59

Director since 2005

Term expires in 2011

Mr. Harvey has served as Chairman of the Board of the Company, AEC and IPL since February 2006. He has served as Chief Executive Officer of the Company, AEC, IPL and Resources and as President and Chief Executive Officer of AEC since July 2005 and as President of Resources since January 2005. He previously served as President and Chief Operating Officer of AEC and Chief Operating Officer of IPL, WPL and Resources since January 2004. He served as President of the Company and as Executive Vice President – Generation for AEC, IPL and Resources from 1998 to January 2004.
LOGO

DARRYL B. HAZEL

Age 60

Director since 2006

Term expires in 2010

Mr. Hazel has served as President of the Customer Service Division and Senior Vice President of Ford Motor Company, an automobile manufacturer, since March 2006. He previously served as President of Marketing of Ford Motor Company from September 2005 to March 2006; President of the Ford Division from April 2005 to September 2005; and President of the Lincoln Mercury Division from August 2002 to April 2005. Mr. Hazel has served as Director of AEC and IPL since 2006.
LOGO

JAMES A. LEACH

Age 66

Director since 2007

Term expires in 2011

Former Congressman Leach is the John L. Weinberg Professor of Public and International Policy at the Woodrow Wilson School of Princeton University in Princeton, N.J., a position he has held since 2007. From January 2008 through December 2008, he served as the Director of the Institute of Politics at the John F. Kennedy School of Government at Harvard University in Boston, MA while on leave from Princeton. Congressman Leach served as a member of the United States House of Representatives from the State of Iowa during the period of 1977 through 2006. He serves on the Board of Directors of United Fire and Casualty Company and on a series of non-profit organization boards. Mr. Leach has served as a Director of AEC and IPL since 2007.
LOGO

SINGLETON B. MCALLISTER

Age 5661

  

Director since 2001

Term expires in 2011

Ms. McAllister has been a partner in the Washington D. C. office of the law firm of LeClair & Ryan LLP since October 2007. She previously served as a partner in the law firm of Mintz, Levin, Cohn, Ferris, Glovsky and Popeo P. C. from July 2005 to October 2007. Ms. McAllister 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 serves on the Board of Directors of United Rentals, Inc. Ms. McAllister has served as a Director of AEC and IPL since 2001.
LOGO

DAVID A. PERDUE

Age 59

Director since 2001

Term expires in 20102013

  Mr. Perdue has been the Chief Executive Officer of Aquila Group LLC based in Sea Island, Ga., a private investment firm involved with, among other investments, retail markets in India, since 2007. He retired in July 2007 from his position as Chairman of the Board and Chief Executive Officer of Dollar General Corporation, a retail organization headquartered in Goodlettsville, Tenn., following its sale to a private equity firm. He was named Chief Executive Officer and a Director in April 2003 and elected Chairman of the Board in June 2003. From July 2002 to March 2003, he was Chairman and Chief Executive Officer of Pillowtex Corporation, a textile manufacturing company locatedcompany. Pillowtex emerged from bankruptcy in Kannapolis, N.C.May 2002 and reentered bankruptcy in July 2003. Mr. Perdue serveshas served on the Boardboard of Directorsdirectors of Jo-Ann Stores, Inc., since 2008, and Liquidity Services, Inc., since 2009. Mr. Perdue has served as a Director of AEC and IPL since 2001. Mr. Perdue is an audit committee financial expert. Mr. Perdue’s leadership of publicly traded companies and his experience in operations, customer perspectives, marketing, human resources and technology matters led to the conclusion that he should serve on our Board of Directors.

LOGO

LOGO

  

JUDITH D. PYLE

Age 6567

  

Director since 1994

Term expires in 20102013

  Ms. Pyle is President and Chief Executive Officer of Judith Dion Pyle and Associates, a financial services company located in Middleton, Wis. Prior to assuming her current position in 2003, she served as Vice Chair of The Pyle Group, a financial services company located in Madison, Wis. She previously served as Vice Chair and Senior Vice President of Corporate Marketing of Rayovac Corporation, a battery and lighting products manufacturer located in Madison, Wis. In addition, Ms. Pyle is a Directordirector of Uniek, Inc. Ms. Pyle has served as a Director of AEC since 1992 and of IPL since 1998. Ms. Pyle’s experience in operations, marketing, human resources and diversity initiatives led to the conclusion that she should serve on our Board of Directors.

LOGO

CAROL P. SANDERS

Age 43

Director since 2005

Term expires in 2012

Ms. Sanders has been the Chief Financial Officer and Treasurer of Jewelers Mutual Insurance Company of Neenah, Wis., a nationwide insurer that specializes in protecting jewelers and personal jewelry, since 2010. She previously served as Chief Financial Officer and Corporate Secretary since 2004. She previously served as Controller and Assistant Treasurer of Sentry Insurance located in Stevens Point, Wis. from 2001 to 2004. Ms. Sanders has served as a Director of AEC and IPL since 2005. Ms. Sanders is Chairperson of the Audit Committee and an audit committee financial expert. Ms. Sanders’ experience with publicly traded companies, operations, customer perspectives, regulatory matters, human resources and technology matters led to the conclusion that she should serve on our Board of Directors.

MEETINGS AND COMMITTEES OF THE BOARD

The Board of Directors has standing Audit; Compensation and Personnel; Nominating and Governance; Environmental, Nuclear, Health and Safety; Capital Approval;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 Committees, which are available free of charge, on the Alliant Energy web site atwww.alliantenergy.com/investors under the “Corporate Governance” caption or in print to any shareowner who requests them from our Corporate Secretary.caption. The following is a description of each of these committees. Joint meetings in the descriptions below refer to meetings of the committees of the Company, Alliant Energy IPL and Resources.IPL.

Audit Committee

The Audit Committee held sevensix joint meetings in 2008.2010. The Committee currently consists of C. P. Sanders (Chair), M. L. Bennett, D. B. Hazel, and D. A. Perdue. Each of the members of the Committee is independent as defined by the New York Stock Exchange (“NYSE”) listing standards and SEC rules. The Board of Directors has determined that Ms. Sanders and the other three 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 our financial statements; (2) our compliance with legal and regulatory requirements; (3) the independent registered public accounting firm’s qualifications and independence; and (4) the performance of our internal audit function and independent registered public accounting firm. The Audit Committee is also directly responsible for the appointment, retention, termination, compensation and oversight of our independent registered public accounting firm.

Compensation and Personnel Committee

The Compensation and Personnel Committee held sevenfive joint meetings in 2008.2010. The Committee currently consists of A. K. Newhall (Chair), D. B. Hazel, J. D. C. OestreichPyle and C. P. Sanders. Each of the members of the Committee is independent as defined by the NYSE listing standards and SEC rules. This Committee reviews and approves corporate goals and objectives relevant to chief executive officer compensation and the compensation of the other principal executive officers, evaluates the chief executive officer’s performance and determines and approves as a committee, or together with the other independent directors, the chief executive officer’s compensation level based on its evaluation of the chief executive officer’s performance in addition to reviewing and approving the recommendations of the chief executive officer with regard to the other executive officers. The Committee has responsibilities with respect to our executive compensation and incentive programs and management development programs. It also makes recommendations to the Nominating and Governance Committee regarding compensation for the non-management directors.

To support the Committee in carrying out its mission, the Committee has the authority to engageretain and terminate the services of outside advisors, experts and others to assist the Committee with the expense of such outside consultants provided for by us.Alliant Energy. For 2008,a portion of 2010, the Committee formally engaged Towers PerrinWatson as an outside compensation consultant to

serve as an advisor in evaluating the compensation of our chief executive officer, other named executive officers and our outside non-management directors. Towers PerrinWatson also provides assistance and serves as an advisor and provides market information and trends regarding executive compensation programs; provides benchmarking and competitive market reviews of our executive officer total compensation; assists with the design of our short- and long-term incentive programs and executive retirement programs as well as assisting management with the implementation of these programs; and provides technical considerations and actuarial services.other consulting services at the request of the Committee. In October 2010, the Committee engaged Pay Governance LLC as an outside independent compensation consultant to perform the specific executive compensation consulting services previously provided by Towers Watson. Alliant Energy provides forwill pay the appropriate funding,fees as determined by the Committee for payment of fees and upon its request and related out of pocket expenses to Towers Perrin. The Committee has the authority to retainWatson and terminate the outsidePay Governance LLC. For executive compensation consultant. consulting services provided in 2010, these fees totaled approximately $57,000 for Towers Watson and approximately $37,000 for Pay Governance LLC.

During 2008 and previously,2010, Towers Perrin,Watson, through a separate part of its organization, also provided certain services for management purposes that are recommended and approved by members of management, including Alliant Energy’s chief executive

officer, vice president of shared services, chief human resources, officer, and/orand the director of total rewards. In the capacity as a consultant to management, Towers PerrinWatson provides competitive market data, actuarial services, and business and technical insight,employee benefits consulting, but does not recommend pay program and pay level changes. In 2010, Towers Watson was paid approximately $1,233,000 for services provided to management and Alliant Energy’s employee benefit plans. The Committee was aware of and acknowledged the services provided for management by Towers Watson when it engaged Towers Watson. The Committee determined that the measures taken to ensure the independence of the advice given by Towers Watson to the Committee were appropriate. The Committee took additional action during 2010 to ensure the independence of the advice provided by its compensation consultant by engaging Pay Governance LLC as its compensation consultant.

The Committee reviews and approves all elements of our executive compensation programs. Our chief executive officer provides input to the Committee in the assessment, design and recommendation of executive compensation programs, plans and awards. Annually, the chief executive officer reviews with the Committee market data provided by Towers PerrinWatson about the comparable companies that are identified as our peer group to help verify survey job information adequately captures officers’ duties. Based on that data, the chief executive officer recommends to the Committee base salary adjustments and short- and long-term incentive targets in relation to external market data while also considering internal equity considerations and executive officers’ individual performance. The chief executive officer provides recommendations to the Committee for total annual compensation of executive officers. The chief executive officer does not, however, make any recommendation to the Committee regarding his own compensation. Further, the chief executive officer and other executive officers assess the performance of those executive officers reporting to them. The chief executive officer is invited to attend all Committee meetings to provide an update of progress made towards achievement of annual performance goals and to provide management’s views on compensation program design features and components.

The Committee has reviewed and approved the charter for our internal Total Compensation Committee made up of vice presidents of our energy delivery, generation, finance/treasury, shared servicesfinance, legal and operationshuman resources business units. The Committee has delegated to the Total Compensation Committee various powers of design and administration associated with our employee benefit plans for salaried and hourly employees. The Committee reviews the minutes and actions of the Total Compensation Committee. The Committee has also reviewed and approved the charter for our internal Investment Committee. The Investment Committee is made up of voting members and non-voting members. The voting members include vice presidents ofofficers in our finance/treasury, accountinghuman resources, energy delivery and shared servicesaccounting business units. Non-voting members include an assistant treasurers, directortreasurer, directors of business and financial performance for sharedcorporate services and energy delivery, a lead treasury analyst and the director of total rewards. The Committee has delegated to the Investment Committee various powers regarding managing investment assets of our benefit and compensation plans and programs. The Committee reviews the investment policies related to these benefit and compensation plans on an annual basis.

Nominating and Governance Committee

The Nominating and Governance Committee held threefour joint meetings in 2008.2010. The Committee currently consists of M. L. Bennett (Chair), J. A. Leach, S. B. McAllister, D. C. Oestreich and D. A. Perdue and J. D. Pyle.Perdue. Each of the members of the Committee is independent as defined by the NYSE listing standards and SEC 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 directorships to be filled by the Board or shareowners; (2) identify and recommend Board members qualified to serve on Board committees; (3) develop and recommend to the Board a set of corporate governance principles; (4) oversee the evaluation of the Board and our management; (5) oversee our related person transaction policy; and (6) advise the Board with respect to other matters relating to our corporate governance.

The Committee is responsible for evaluating nominees for director and director candidates based on such general and specific criteria and for seeking to assure that the specific talents, skills and other characteristics that are needed to increase the Board’s effectiveness are possessed by an appropriate combination of directors. Our Corporate Governance Principles, as adopted by the Board of Directors, provide insight for the Committee on the consideration of appropriate criteria for director nominees.

In making recommendations of nominees to serve as directors to the Board of Directors, the Committee will examine each director nominee on a case-by-case basis regardless of who recommended the nomineesource of the recommendation 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 chief executive officer based on that expertise and experience;

 

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

 

have sufficient time available to devote to activities of the Board of Directors and to enhance his or her knowledge of our 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 politicalprofessional experience.

The Committee has determined that each nominee for director as well as each continuing member of the Board of Directors possesses the applicable criteria for directors outlined above. In addition, the Committee annually reviews particular attributes, qualities and skills attendant to the members of our Board of Directors and documents this annual assessment through the use of a directors’ skills matrix that assesses directors’ experiences and expertise in areas such as public company environment, finance, operations, customer perspective, regulatory and public affairs, legal, human resources, technology, environment and safety, and diversity initiatives. Diversity is a component of our core value of respect. We strive to create a workplace where people of diverse backgrounds, talents and perspectives support our mission. Diversity is reflected in our directors’ skills matrix, in the criteria specified for use in the evaluation of our director nominees by the Committee and in the Board of Directors’ responsibilities in advising and counseling management. Specifically, our Corporate Governance Principles provide that the Board of Directors is responsible for using the broad range of experiences and perspectives of directors to advise and counsel management, both in meetings and in informal consultations, on significant issues facing the Company. In its annual performance evaluation, the Committee assesses whether it effectively identifies individuals qualified to be nominated to the Board of Directors for election by the shareowners consistent with the criteria approved by the Board. We believe that our Board of Directors has been effective in assembling a diverse body of individuals as measured by the criteria of age, gender, race and professional experience specified in our Corporate Governance Principles.

The Committee will consider nominees recommended by shareowners in accordance with our Nominating and Governance Committee Charter and theour Corporate Governance Principles. Any shareowner wishing to make a recommendation should write to our Corporate Secretary and include appropriate biographical information concerning each proposed nominee. The Corporate Secretary will forward all recommendations to the Committee.

We and the Committee maintain a file of recommended potential director nominees, which is reviewed at the time a search for a new director needs to be performed. To assist the Committee in its identification of qualified director candidates, the Committee may engage an outside search firm.

The Committee has the responsibility to periodically review and make recommendations to the Board regarding policies and procedures for selection of the chief executive officer and succession planning in the event of an emergency or the retirement of the chief executive officer. The Committee, in conjunction with the full Board, discusses succession planning and other management development issues at least annually and more often, as necessary.

The Committee is responsible for ensuring that new Board members have an appropriate orientation to our company and their responsibilities as directors to permit them to become familiar with the industry, business units and corporate governance processes of our company. The Committee is also responsible for ensuring that a process is in place to provide educational opportunities on an ongoing basis to help assure that each director has the necessary skills to perform his or her responsibilities as a director. The Committee has established an aspirational continuing education guideline for approximately one half of the board members to attend a continuing education program every year.

Environmental, Nuclear, Health and Safety Committee

The Environmental, Nuclear, Health and Safety Committee held three joint meetings in 2008.2010. The Committee currently consists of D. C. Oestreich (Chair), J. A. Leach, S. B. McAllister, A. K. Newhall and J. D. Pyle. 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 us, including matters involving our company before environmental regulatory agencies and compliance with air, water and waste regulations. The Committee also reviews health-health and safety-safety related policies, activities and operational issues as they affect employees, customers and the general public. In addition, the Committee reviews issues related to nuclear generating facilities from which we and IPL purchase power.

Capital Approval Committee

The Capital Approval Committee held one meetingno meetings in 2008.2010. The Committee currently consists of M. L. Bennett, A. K. Newhall and D. C. Oestreich. Mr. Harvey is the Chair and a non-voting member of this Committee. The purpose of this Committee is to evaluate certain investment proposals where (1) an iterative bidding process is required, and/or (2) the required timelines for 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 2008.2010. The Committee currently consists of M. L. Bennett, A. K. Newhall, D. C. Oestreich and C. P. Sanders.Sanders, each the Chairperson of a committee. 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 excluded for such a Committee under the Wisconsin Business Corporation Law. The Committee meets only when a regular, or special, Board of Directors meeting, or a meeting of the Capital Approval Committee, would be impractical and an important need exists that requires action.

Attendance and Performance Evaluations

The Board of Directors held seven joint meetings during 2008.2010. Each director attended at least 75% of the aggregate number of meetings of the Board and Board committees on which he or she served.

The Board and each Board committee conduct performance evaluations annually to determine their effectiveness and suggest improvements for consideration and implementation. In addition, the Compensation and Personnel Committee evaluates Mr. Harvey’s performance as chief executive officer on an annual basis.

Board members are not expected to attend our annual meetings of shareowners. None of the Board members were present for our 20082010 Annual Meeting.

CORPORATE GOVERNANCE

Corporate Governance Principles

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

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 theseThe categorical standards are available in Appendix A to our Corporate Governance Principles available on the following relationships that currently exist or that have existed, including duringAlliant Energy web site atwww.alliantenergy.com/investors under the preceding three years, willnot be considered to be material relationships that would impair a director’s independence:“Corporate Governance” caption.

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

A director, or a family member of the director, receives or received less than $120,000 during any twelve-month period in direct compensation from us, 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 us).

A director, or a family member of the director, is a former partner or employee of our internal or external auditor but did not personally work on our audit within the last three years; or a family member of a director is employed by an internal or external auditor of ours but does not personally work on our audit.

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 our 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, us 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 our 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.

The Board of Directors also gave consideration to certain other factors in relation to an independence determination. Messrs. Bennett, Hazel, Oestreich and Ms. Pyle serve (or served during 2010) as executive officers and/or directors of companies that are customers or, in the case of us or our public utility affiliates.Mr. Bennett, suppliers of the Company and IPL. These customercustomer/supplier relationships do not constitute a material relationship under theNYSE listing standards cited above or the SEC rules governing related person transactions. Mr. Leach is a shareowner in an electrical supply company that has not done any business with us or our public utility affiliates in a substantial number of years. However, each of these circumstances was evaluated under the applicable NYSE listing standards and SEC rules and, in the case of Mr. Leach, the Federal Energy Regulatory Commission regulations.rules. The Board determined that these factors did not impair the independence of these directors.

Based on these standards and this evaluation, the Board of Directors has affirmatively determined by resolution that each of Messrs. Bennett, Hazel, Oestreich, Perdue and LeachPerdue and Mses. McAllister, Newhall, Pyle and Sanders has no material relationship with us 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.

Related Person Transactions

We have adopted a written policy that we will annually disclose information regarding related person transactions that is required by regulations of the SEC to be disclosed, or incorporated by reference, in our Annual Report on Form 10-K. For purposes of the policy:

The term related person“related person” means any of our directors or executive officers, or nominee for director, and any member of the “immediate family”immediate family of such person.

A related person transaction is generally a consummated or currently proposed transaction in which we were or are to be a participant and the amount involved exceeds $120,000, and in which the related person had or will have a direct or indirect material interest. A related person transaction doesnot include:

 

the payment of compensation by us to our executive officers, directors or nominee for director;

 

a transaction if the interest of the related person arises solely from the ownership of our shares and all shareowners receive the same benefit on a pro-ratapro rata basis;

 

a transaction in which the rates or charges involved are determined by competitive bids, or that involves the rendering of services as a common or contract carrier, or public utility, at rates or charges fixed and in conformity with law or governmental authority; or

 

a transaction that involves our services as a bank, transfer agent, registrar, trustee under a trust indenture, or similar services.

Furthermore, a related person is not deemed to have a material interest in a transaction if the person’s interest arises only (i) from the person’s position as a director of another party to the transaction; (ii) from the ownership by such person and all other related persons, in the aggregate, of less than a 10% equity interest in another person (other than a partnership) that is a

party to the transaction; (iii) from such person’s position as a limited partner in a partnership and all other related persons have an interest of less than 10% of and the person is not a general partner of or holds another position in, the partnership; and (iv) from both such director position and ownership interest. Pursuant to the policy, each of our executive officers, directors and nominees for director is required to disclose to the Nominating and Governance Committee of the Board of Directors certain information regarding the related person transaction for review, approval or ratification by the Nominating and Governance Committee. Such disclosure to the Nominating and Governance Committee should occur before, if possible, or as soon as practicable after the related person transaction is effected, but in any event as soon as practicable after the executive officer, director or nominee for director becomes aware of the related person transaction.

The Nominating and Governance Committee’s decision whether or not to approve or ratify the related person transaction should be made in light of the Committee’s determination as to whether consummation of the transaction is believed by the Committee to not be, or to have been contrary to, the best interests of our Company.company. The Committee may take into account the effect of a director’s related person transaction on such person’s status as an independent member of our board of directors and eligibility to serve on board committees under SEC and NYSE rules.

Based on these standards, we had no related person transactions in 2008,2010, and no related person transactions are currently proposed.

Lead Independent Director;Board Leadership Structure; Executive Sessions

TheOur Bylaws and our Corporate Governance Principles provide that the Board of Directors is responsible to select a Chairperson and a chief executive officer. Our Corporate Governance Principles also provide that the Board of Directors should have the flexibility to decide whether it is best for our company that the two positions be filled by the same individual and that, if the Chairperson of the Board is not an independent director, the chairperson of the Nominating and Governance Committee will be designated the designated “LeadLead Independent Director”Director. The Board of Directors has determined that the positions of Chairperson of the Board and chief executive officer should be held by one individual with the use of a Lead Independent Director. In choosing to combine the roles of Chairperson of the Board and chief executive officer, the Board of Directors has expressed its belief that our management, through the Chairperson and chief executive officer should have the primary accountability, and the responsibility to act as the spokesperson, for us. The Board of Directors believes that maintaining the positions of Chairperson and chief executive officer in a single individual will promote the enhancement of a consistent and accurate message to our investors, employees, customers and other constituencies.

While our Corporate Governance Principles do not grant the Lead Independent Director any special authority over management, both the Board of Directors and management recognize the Lead Independent Director as a key position of leadership within the Board of Directors. Our Corporate Governance Principles do provide that the Lead Independent Director will preside as the chair at meetings orregular executive sessions of the Board without management participation. We believe that the use of a Lead Independent Director has proven effective for us and has greatly assisted with the facilitation of communication of important issues between the Board of Directors and the chief executive officer. Subsequent to the adoption of our Corporate Governance Principles formally establishing the Lead Independent Director position, our Lead Independent Director’s role has developed to include additional board governance activities, including the following examples:

communicating applicable information arising out of the deliberations in executive sessions to the Chairperson and chief executive officer;

reviewing with the Chairperson and chief executive officer items of importance for consideration by the Board of Directors;

acting as principal liaison between the independent directors. directors and the Chairperson and chief executive officer on sensitive issues;

discussing with the Chairperson and chief executive officer important issues to assess and evaluate the view of the Board of Directors;

consulting and meeting with any or all of our independent directors, at the discretion of either party and with or without the attendance of the Chairperson and chief executive officer;

in conjunction with the Nominating and Governance Committee, recommending to the Chairperson the membership of the various board committees and selection of the board committee chairs;

in conjunction with the Nominating and Governance Committee, interviewing all board candidates and making recommendations to the Board of Directors on director nominees;

mentoring and counseling new members of the Board of Directors to assist them in becoming active and effective directors;

in conjunction with the Nominating and Governance and Compensation and Personnel Committees, reviewing and approving the philosophy of, and program for, compensation of the independent directors; and

evaluating, along with the other members of the Board of Directors, the chief executive officer’s performance and meeting with the chief executive officer to discuss the Board of Directors’ evaluation.

As the Chairperson of the Nominating and Governance Committee, Mr. Bennett is currently designated as the Lead Independent Director. At every regular in-person meeting of the Board of Directors, the independent directors meet in executive session with no member of our management present.

Risk Oversight

Our Corporate Governance Principles provide that the Board of Directors is responsible for overseeing and understanding our vision and mission, strategic plans, overall corporate risk profile, risk parameters, annual operating plans and annual budgets and for monitoring whether these plans are being implemented effectively. The Board of Directors annually conducts a broad based risk assessment. In 2010, this risk assessment was conducted in association with reviews by the chief audit executive and the director of strategy and communication. The methodology of the risk assessment identifies key themes and trends, quantifies our key risks and develops mitigation plans and strategies. This assessment provides the platform to develop appropriate audit plans and to ensure resources are devoted to areas having the highest risk. This assessment culminates in the Annual Risk Management Report to the Board of Directors. On an on-going basis, the Audit Committee regularly discusses our policies with respect to risk assessment and risk management, our financial risk exposures and the steps we have taken to monitor and control such exposures. The Board of Directors relies on the Compensation and Personnel Committee to address potential risks arising from our general compensation programs and policies for all employees, and the Committee conducted an assessment in 2010 of these policies and practices to determine whether risks arising from them were reasonably likely to have a material adverse effect on us, as described in further detail under “Compensation Committee Risk Assessment” below.

Communication with Directors

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

Ethical and Legal Compliance Policy

We have adopted a Code of Conduct, that serves as our code of ethics, and that applies to all employees, including our chief executive officer, chief financial officer and chief accounting officer, as well as our Board of Directors. We make our Code of Conduct available free of charge, on the Alliant Energy web site atwww.alliantenergy.com/investors under the “Corporate Governance” caption or in print to any shareowner who requests it from our Corporate Secretary.caption. We intend to satisfy the disclosure requirements under Item 5.05 of Form 8-K regarding amendments to, or waivers from, the Code of Conduct by posting such information on the Alliant Energy web site.

OWNERSHIP OF VOTING SECURITIES

All of our common stock is held by Alliant Energy. None of our directors or officers own any shares of our preferred stock. Listed in the following table are the number of shares of Alliant Energy’s common stock beneficially owned as of Feb. 27, 200928, 2011 by (1) the executive officers listed in the Summary Compensation Table, (2) all of our director nominees and directors and (3) all director nominees, directors and the executive officers as a group. The directors and executive officers as a group owned less than 1% of the outstanding shares of Alliant Energy’s common stock on that date. No individual director or officer owned more than 1% of the outstanding shares of Alliant Energy’s common stock on that date.

 

NAME OF BENEFICIAL OWNER

  SHARES
BENEFICIALLY
OWNED(1)
 

Executive Officers(2)

  

Thomas L. Aller

  122,48190,208(3)

Dundeana K. Doyle

  26,96534,826(3)

Eliot G. ProtschPatricia L. Kampling

  143,37236,551(3)

Barbara J. Swan

  64,15780,777(3)(3)(4)

Director Nominees

  

Ann K. NewhallWilliam D. Harvey

  8,922337,061(3)

Dean C. OestreichSingleton B. McAllister

  10,27213,128(3)

Carol P. Sanders

7,298(3)

Directors

  

Michael L. Bennett

  12,93021,123(3)

William D. Harvey

289,978(3)

Darryl B. Hazel

  7,492(3)(4)

James A. Leach

100

Singleton B. McAllister

11,87710,098(3)

Ann K. Newhall

14,505(3)

Dean C. Oestreich

15,892(3)

David A. Perdue

  10,25817,195(3)

Judith D. Pyle

  16,22517,826

Carol P. Sanders

12,436(3) 

All Executive Officers and Directors as a Group (17(19 people)

  790,228798,206(3)

 

(1)

Total shares of Alliant EnergyEnergy’s common stock outstanding as of Feb. 27, 200928, 2011 were 110,635,691.110,937,709.

 

(2)

Stock ownership of Mr. Harvey is shown with the directors.director nominees.

 

(3)

Included in the beneficially owned shares shown are indirect ownership interests with shared voting and investment powers: Mr. Harvey — 3,2703,615 and Mr. Aller — 1,000; shares of common stock held in deferred compensation plans: Mr. Bennett — 12,482,20,640, Mr. Harvey — 43,093,47,629, Mr. Hazel – 7,362,— 9,450, Ms. McAllister — 6,975,7,710, Ms. Newhall — 7,908,13,385, Mr. Oestreich — 9,272,14,892, Mr. Perdue — 10,258,17,195, Ms. Sanders—7,198, Mr. ProtschSanders40,818,12,336, Mr. Aller — 7,756,8,572, Ms. Doyle — 8,349,9,228, Ms. Kampling — 1,559, Ms. Swan — 25,55228,242 (all executive officers and directors as a group — 190,681)213,318); and stock options exercisable on or within 60 days of Feb. 27, 2009:28, 2011: Mr. Harvey — 33,05611,258 and Mr. Aller — 96,32156,530 (all executive officers and directors as a group — 130,377)71,719).

 

(4)

Mr. Hazel has pledged 100 shares in a margin account.Ms. Swan retired on Dec. 31, 2010.

To our knowledge, no shareowner beneficially owned 5% or more of any class of our preferred stock as of Dec. 31, 2008. The following table sets forth information, as of Dec. 31, 2008,2010, regarding beneficial ownership by the only persons known to us to own more than 5% of Alliant Energy’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     Voting Power   Investment Power           
Name and Address of Beneficial Owner  Sole  Shared  Sole  Shared  Aggregate  

Percent

of

Class

   Sole   Shared   Sole   Shared   Aggregate   

Percent

of

Class

 

Barclays Global Investors, N. A.

(and certain affiliates)

45 Fremont Street

San Francisco, CA 94105

  5,112,826  0  6,587,369  0  6,587,369  5.96%

BlackRock, Inc.

(and certain affiliates)

40 East 52nd Street

New York, NY 10022

   9,253,326     0     9,253,326     0     9,253,326     8.35

None of our directors or officers own any shares of preferred stock. To our knowledge, no shareowner beneficially owned 5% or more of any class of our preferred stock as of Dec. 31, 2010 other than the 4.96% series of preferred stock. The following table sets forth information, as of Dec. 31, 2010, regarding beneficial ownership by the only persons known to us

to own more than 5% of the 4.96% series of preferred 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

 

Wells Fargo and Company

420 Montgomery Street

San Francisco, CA 94104

   4,567     0     4,567     0     4,567     7.03

COMPENSATION DISCUSSION AND ANALYSIS

Objectives of Compensation Programs:

The following is a discussion and analysis with respect toof the compensation paid by Alliant Energy to our executive officers listed in the Summary Compensation Table for services performed for us, Alliant Energy and Alliant Energy’s other subsidiaries. References to “we,” “us,” “our,” and similar references in the following discussion and analysis include us, Alliant Energy and Alliant Energy’s other subsidiaries together unless the context indicates otherwise.

Executive Summary

We have designed our executive compensation program to motivate our executive officers to achieve results for our shareowners and customers and reward them for doing so. Our compensation program is designed to link a significant portion of the compensation of our named executive officers to defined performance standards that promote balance between the drive for near-term growth and long-term increase in shareowner value. The compensation we paid in the last three years demonstrates that our compensation program is consistent with our pay for performance philosophy.

In 2010, our financial results improved substantially over the results of 2009 and 2008. The following table shows the pay for performance linkage by displaying the results of our financial performance goals and incentive compensation payouts over the past three years.

Year Adjusted utility
earnings per
share from
continuing
operations
  Short-term
incentive
payout as %
of target
  Relative Total
Shareowner
Return
(three years)
 Performance
Share payout
as % of  target
  Performance Contingent
   Restricted Stock vesting  

2008

 $2.19    0 75th percentile  162.5 No

2009

 $1.86    0 31st percentile  0 No

2010

 $2.68    130 45th percentile  75 Yes

At the end of 2010, our relative total shareowner return compared to the S&P Midcap Utility Index performed at the 84th percentile for the last year and the 82nd percentile over the last five years. Adjusted utility earnings per share in 2010 were up 44% over 2009. We exceeded our adjusted utility earnings per share target by 9% in 2010, resulting in the first short-term incentive payment in three years. Adjusted cash flows from our utilities and service company exceeded the 2010 target by 46%. In addition, we met or exceeded performance goals related to customer satisfaction, safety and diversity. As a result of the improved financial performance of 2010, the total direct compensation we paid to our executive officers increased in 2010 over 2009 and 2008. Our compensation programs worked as designed by increasing compensation to our executive officers based on our higher earnings growth, operational performance and common stock price.

Our long-term incentive plan is entirely performance-based. The two types of equity awards that make up our long-term incentive plan, performance contingent restricted stock and performance shares, will not vest unless financial performance goals are met. The two financial goals are total shareowner return and earnings growth. In addition, we emphasize long-term incentives for our named executive officers, as they comprise on average, in the aggregate, 49% of their total direct compensation. This creates a strong link between the long-term financial performance for our shareowners and the compensation of our named executive officers.

We have implemented a policy to reduce the amount of perquisites paid to our executive officers. In 2009, we eliminated our flexible perquisite program, which paid an amount of perquisite commensurate with the position of the executive officer, and allowed the executive officer to determine on what to spend the perquisite. In 2010, we eliminated a health care benefit received by executive officers that was more generous than that paid to the balance of our non-bargaining employees, effective in 2011. Elimination of these perquisites strengthens the link between compensation and company performance.

The following discussion describes the elements of our compensation program and explains how it considers the results of our performance when determining our executive compensation.

Objectives of Compensation Programs

We are committed to maintaining a total compensation program for executive officers that:

 

furthers our strategic plan by strengthening the relationship between pay and performance by emphasizing variable at-risk compensation,

 

focuses and aligns executives’executive officers’ and employees’ interests with those of our company, our shareowners and our customers, and

 

is competitive with comparable employers to help ensureensures that we attract and retain talented employees and

through competitive compensation that is equitable among executives.comparable to other similar companies.

We believe these objectives attract, retain and motivate a highly proficient workforce.workforce that is actively engaged in producing results for our shareowners and customers.

We adhere to the following compensation principles, which are intended to facilitate the achievement of our business strategies:

 

base salary levels should be targeted at the median (50th percentile) of base salaries paid by comparable companies,

Executive officera substantial portion of our executive officers’ compensation (and in particular, long-term incentive compensation) should be closely and strongly alignedbased on achievement of performance goals, with long-term incentives comprising a majority of the long-term interests of our shareowners and customers.performance-based pay,

 

Totalrisks associated with our compensation plans should enhance our ability to attract, retain and encourage the development of exceptionally knowledgeable and experienced executive officers, upon whom, in large part, our successful operation and management depends.be minimized,

 

Base salary levels should be targeted at a competitive market range of base salaries paid to executive officers of companies comparable to Alliant Energy. Specifically, we target the median (50th percentile) of base salaries paid by companies comparable to Alliant Energy.

Incentive compensation programs should strengthen the relationship between pay and performance by emphasizing variable at-risk compensation based on meeting predetermined Company, Alliant Energy, affiliate, business unit and individual performance goals. We target incentive levels at the median (50th percentile) of incentive compensation at companies comparable to Alliant Energy.

Executive officers should have access to retirement-oriented plans commonly in use among companies comparable to Alliant Energy,companies, including deferred compensation plans, pension plans, supplemental retirement programs and 401(k) plans.plans, and

 

Executiveexecutive officers should have significant holdings of Alliant Energy’sEnergy common stock to align their interests with the interests of Alliant Energy shareowners.

Compensation Program Practices

We have many practices that help ensure that our compensation program is aligned with the interests of Alliant Energy shareowners and customers and are supportive of good compensation governance. These practices include:

a balance of short-term (adjusted utility earnings per share from continuing operations) and long-term (relative total shareholder return and adjusted net income growth) performance measures;

a balance of time horizons for our incentive awards, including an annual cash incentive program, a three-year performance share program and performance contingent restricted stock that may vest after two, three or four years;

share ownership guidelines requiring executive officers to hold a number of Alliant Energy shares valued at one-and-one-half to four times their annual salaries;

a long-standing insider trading policy for executive officers and non-employee directors that prohibits transactions involving shorting, puts, calls, options, warrants and certain other derivatives;

an annual incentive compensation repayment (“claw back”) policy;

employment of our executive officers is “at will,” without employment contracts that guarantee cash compensation for a set period of time; and

using other types of long-term equity incentives rather than stock options.

Alliant Energy’s compensation programs are subject to a thorough review process that includes Committee review and approval of all elements of our executive compensation program; the advice of an independent, third-party compensation consultant engaged by the Committee; and a Committee of independent directors that meets in executive session without management at every meeting.

Benchmarking

We utilizeAlliant Energy utilizes compensation data from companies comparable to Alliant Energy to assess our competitivenessgeneral industry and the energy services sector in base salary and incentivedetermining the appropriate levels of compensation for all officer level positions. Weour executive officers. Although our business is focused in the energy services sector, we believe compensationthat the competitive labor market for our company includes both general industry and the energy services industry, particularly for those executives who serve in a general management capacity. Compensation programs at these comparable companies shouldboth in general industry and the energy services industry therefore serve as a benchmark for what constitutes competitive compensation.

The comparable companies inbenchmark data from the energy and utility industry that we used for benchmarking in 20082010 were drawn from Towers Perrin’s 2007Watson’s 2009 Energy Services Industry Executive Compensation Database (the “2007“2009 Energy Services database”), a survey which comprises nearly all investor-owned U.S. utilities. The general industry data were obtained from Towers Perrin’s 2007Watson’s 2009 General Industry Executive Compensation Database, a survey of over 800 companies the majority of which are Fortune 1000 companies (the “2007“2009 General Industry database”). In using these broad-based surveys, we considered only aggregate data and did not select any individual companies for comparison. All of the survey data were agedupdated to Jan. 1, 2008January 2010 using a 3.75%3% annual update factor.factor, as 3% was the anticipated average annual increase for the survey companies. The data from each of the companies in both

databases were adjusted to reflect how the data compare to companies of similar revenue size using regression analysis.size-adjusted based on gross revenue. Our Compensation and Personnel Committee, or Committee, used this adjusted benchmark data, among other factors, to determine appropriate levels of pay in 2008 to2010 for our named executive officers. We refer to this adjusted data of companies comparable to Alliant Energy used bythe median in these surveys as our Compensation and Personnel Committee to determine appropriate levels of pay to our executive officers as the “peer group”“market reference point” throughout the following discussion.

For general management positions, including four of the named executive officers,Mr. Harvey’s, Ms. Kampling’s and staff positions,Ms. Swan’s, equally blended energy industry and general industry data from these databases are used as the targetour market reference point for compensation, reflecting the broader talent market for these jobs and the fact that we operateAlliant Energy operates in some diversified businesses. For utility-specific operating positions, including Mr. Aller’s one of the named executive officers,and Ms. Doyle’s, energy industry data are used as the target market.our market reference point. Overall,Alliant Energy’s revenue is ranked between the median and the average revenue of the companies in the 20072009 Energy Services database. Towers Perrin advisedWatson provided market data to our Compensation and Personnel Committee on setting compensation for our named executive officers for 2008.Committee. See “Meetings and Committees of the Board Compensation and Personnel Committee” for more details.

Compensation Elements and Design

The major elements of the executive compensation program are base salary, short-term (annual) incentives, long-term (equity) incentives and other benefits. In setting the level for each major component of compensation, we consider an executive officer’s total compensation (which consists of all elements of compensation including employee benefit and perquisite programs), our market reference point, the current market for talent, our historic levels of compensation, company culture, individual and company performance, and internal equity. We aim to strike an appropriate balance among base salary, short-term incentive compensation and long-term incentive compensation. Our goal is to provide an overall compensation package for each executive officer that is competitive with the packages offered to similarly situated executive officers within the peer group.survey companies. To achieve that goal, we target each element of compensation to the median levels withinof the peer group. Total direct compensationsurvey data.

We also have a goal to reward performance. To accomplish this goal, we weight performance-based incentive pay more heavily than other elements of our named executive officersofficers’ total direct compensation, which consists of base salary and short-term and long-term incentive pay. In 2010, incentive pay (both short-term and long-term) that we weight such that incentive pay accountsaccounted for 52-77%54%-77% of target total direct compensation. Mr. Harvey’s target incentive paycompensation for 2008 was 77% of total direct compensation. In establishing the 2008 compensation reported, in the aggregate, our named executive officers were paid, on average, base salaries 2% below the median of the peer group, target cash compensation 3% below the median of the peer group and total direct compensation 6% below the median of the peer group.officers. The following table shows the breakdown for each of our named executive officers in 20082010 of the total direct compensation pay mix. The amountsfigures in this table were calculated using targeted compensation for 20082010 and therefore may differ from the actual payments for 20082010 as reported in the Summary Compensation Table below.

 

Named Executive Officer   Title 

  Salary as a %  

of Total

 

Short-Term
  Incentive as a  

% of Total

 

Long-Term

  Incentive as a  

% of Total

Harvey, William D.

 Chairman & CEO 23% 21% 56%

Protsch, Eliot G.

 

Chief Operating Officer

 31% 22% 47%

Swan, Barbara J.

 

President

 35% 20% 45%

Aller, Thomas L.

 SVP-Energy Resource Development  46% 21% 33%

Doyle, Dundeana K.

 SVP-Energy Delivery 48% 19% 33%

The column titled “Short-Term Incentive as a % of Total” is the percentage of the total direct compensation represented by a target payout of incentive compensation under Alliant Energy’s short-term incentive plan. We made no payment to named executive officers for 2008 under the short-term incentive plan.

Named Executive Officer  Title   Salary as a %  
of Total
  Short-Term
  Incentive as a  
%  of Total
  

Long-Term

  Incentive as a  

% of Total

 

William D. Harvey

  Chairman and CEO  23  21  56

Patricia L. Kampling

  Chief Operating Officer and CFO  32  20  48

Barbara J. Swan

  President and CAO  35  21  44

Dundeana K. Doyle

  SVP-Energy Delivery  46  21  33

Thomas L. Aller

  SVP-Energy Resource Development  46  21  33

Base Salary

We pay base salaries to assure management with a level of fixed compensation at competitive levels to reflect their professional skills, responsibilities and performance to attract and retain key executives. We adjust base salaries taking into consideration both changes in the market, changes in responsibilities and performance against job expectations.

The Committee considers salaries that fall within 15% above or below the median salaries for similar positions in the peer group to be competitive. The Committee will We also consider the nature of the position, the responsibilities, skills and experience of the officer, and his or her past performance.

The Committee considers salaries that fall within 15% of our market reference point to be competitive. We may adjust base salaries to keep current with the peer group,our market reference point, to recognize outstanding individual performance or to recognize an increase in responsibility.

In 2010, aggregate base salaries of our named executive officers were, on average, approximately 2% above our market reference point, which is within our target.

The Committee adjusted Mr. Harvey’s salary from $810,000 to $845,000 in 2008 based on a review of comparable chairman and chief executive officers within the peer group. Mr. Harvey’s base salaryfor 2010 was 9%$875,000, which was slightly below the median of the peer groupblended energy industry and 1% below the median of Towers Perrin’s 2007 Energy Services database. We believe Mr. Harvey’s salary is competitive as it is near the median of the 2007 Energy Services database and within 15% of the peer group. In addition, we targetgeneral industry market reference point. Mr. Harvey’s incentive compensation elements are targeted to the median of the peer group,blended benchmark data, and believe they are generally higher than the 20072009 Energy Services database.reference point but lower than the 2009 General Industry reference point. This results in more emphasis on incentive pay for our CEO,chief executive officer, which we believe creates a stronger link between pay and performance.

Ms. Kampling’s salary was set at $385,500 at the beginning of 2010 and raised to $500,000 later in 2010. The Committee adjustedconsidered the competitive market for chief financial officers, retention and succession planning objectives, and the additional responsibilities Ms. Kampling had been assigned when increasing her salary.

The salaries of ourthe other named executive officers, as follows: Mr. Protsch from $476,000 to $495,000; Ms. Swan from $361,000 to $375,000; Mr. Aller from $257,500 to $267,500; and Ms. Doyle from $236,000 to $255,000.which are reported in the Summary Compensation Table below, were near the median of our market reference point. The Committee adjustedconsidered the market data, the elimination of the flexible perquisite program and the salary freeze in 2009 when setting executive officers’ salaries based on the peer group information provided by Towers Perrin as well as the internal considerations described earlier. We believe the salaries are all competitive with similar positions in the peer group.for 2010.

Short-Term Incentives

Our executive officers, including our named executive officers, are eligible to participate in the Alliant Energy Management Incentive Compensation Plan, or MICP, which is Alliant Energy’sour short-term (annual) incentive plan. The MICP provides executive officers with direct financial incentives in the form ofopportunity for annual cash bonuses tied directly to the achievement of our and Alliant Energy’s financial, strategiccompany and individual performance goals. The MICP encourages executive officers to achieve superior annual performance on key financial, strategic and operational goals. By setting annual goals, the Committee endeavors to drive annual performance and align the interests of management with the interests of our shareowners and customers.

The Committee seeks to set MICP opportunities at the median short-term incentive target levels compared to our benchmark data, measured as a percentage of base salary, for comparable positions in the peer group.salary. MICP targets in 20082010 were 95% of base salary for Mr. Harvey; 70% for Mr. Protsch; 55%Harvey, 65% for Ms. Swan;Kampling, 60% for Ms. Swan, and 45% for Mr. Aller;Aller and 40% for Ms. Doyle. MICP target levels of all of our named executive officers are within 2% of our market reference point. The maximum possible individual payout for all executive officers was two times the target percentage. This range aligns with our desire to emphasize variable at riskat-risk compensation.

We pay incentives from a pool of funds that Alliant Energy establishes for MICP payments. The Committee establishes threshold company-wide goals, which it derives from Alliant Energy’s strategic plan and from operational benchmarks intended to benefit shareowners, customers and employees. These company-wide goals determine the funding level of an incentive pool. Diluted adjusted earnings per share from continuing operations of our Company and IPL which together we refer to as the utilities, determines the funding level of 85% ofwhether or not the incentive pool.pool will be funded. If the adjusted utility earnings per share targetthreshold is not met, then the incentive pool is not funded and no incentives are paid under the MICP. For 2008,After the thresholdadjusted utility earnings per share was $2.33, which was the midpointthreshold is met, then a percent of the 2008incentive pool is funded based on the achievement of goals. If all goals are met at target level, the incentive pool is funded at 100% of target. The size of the incentive pool will vary, from 20% to 150% of target, based on adjusted utility earnings per share guidance provided by Alliant Energy atperformance. As a result, the end of 2007. Cash flows from the utilities and Alliant Energy’s service company subsidiary determine the funding level for 15%amount of the short term incentive pool. awards is tied directly to company financial performance.

The cash flow target for 2008 was $502 million. If the cash flow target is not met, the Committee is not required to fund the 15% of the incentive pool represented by cash flow.company-wide goals, targets and actual 2010 performance were:

We factor the level of individual performance as compared

Goal Percent
of
Incentive
Pool
 Threshold Target Maximum     Actual     Percent Payment
Toward  Incentive Pool
Adjusted earnings per share from continuing operations of Alliant Energy’s utilities 60% $2.20 $2.45 $2.81 $2.68* 78%
Adjusted cash flows from Alliant Energy’s utilities and service company 10%   $625 million   $913
million
**
 13%
Customer satisfaction 15%   Minimum rating of 4.3 out of 5.0   4.37 19.5%
Safety 10%   Maximum recordable rate of 3.72   3.64 13%
Diversity (goal achieved if two of the three goals are met) 5%   

Minimum of 5.4% diverse employee population;

 

Minimum of 10% women in non-traditional jobs

 

$50 million sourceable spend to minority- and women-owned business

   5.4%


9.4%


$70.5
million

 6.5%

TOTAL

 100%         130%

*

This non-GAAP number excludes the effects of regulatory related charges and credits, a depreciation adjustment, healthcare legislation charges, and impairment charges. These excluded items are not reflective of on-going operations and are therefore excluded when determining executive compensation.

**

This non-GAAP number excludes the effects of changes in sales of customer receivables, tax-effected qualified pension contributions and changes in net collateral held by or paid by the utilities and Alliant Energy’s service company. These items are not reflective of on-going management of operations and are therefore excluded when determining executive compensation.

In addition to the company-wide performance goals, we consider individual performance goals into individual award amounts after the pool has been funded.when determining an executive’s actual incentive payment amount. Individual awards may range from 0% to 200% of the targeted payment based on an individual’s achievement of performance goals. The Committee makes judgments about achievement of performance goals by the chief executive officer.officer’s achievement of individual performance goals. Achievement of performance goals for the other executive officers is judged by the chief executive officer or the executive to whom the executive officer reports, in consultation with the Committee. The Committee approves the final assessment of individual achievement compared to performance goals and final payment of awards to all executive officers under the MICP.

Individual performance goals are reviewed and established by the Committee to assistearly in the determination of individual awards underyear. The Committee derives the MICP. Individual performance goals are derived from Alliant Energy’s strategic plan and from operational benchmarks intended to benefit our shareowners, customers and employees. Our Committee believes that using Alliant Energy’s strategic plan to set

Mr. Harvey’s individual performance goals aligns the executives’ incentive compensation with Alliant Energy shareowner interests. Our Committee also believes that using operational benchmarks to set individual performance goals aligns the executives’ incentive compensation with customer interests.

Mr. Harvey’s performance goals for 20082010 included financial goals of achieving Alliant Energy consolidated adjusted earnings per diluted share from continuing operations of $2.65, which was the midpoint of the 2008 earnings guidance issued by Alliant Energy in December 2007,$2.60 and achieving cash flows from operations at the utilities andmeeting financial targets for Alliant Energy’s service company subsidiary, of $502 million in aggregate. These financial goals were weighted at 50%. In addition,RMT, Inc. Mr. Harvey’s goals included development and communication of a long-term strategic plan and management development and succession planning. The Committee determined that, in aggregate, Mr. Harvey achieved his goals at target level, or 100%.

Ms. Kampling’s individual performance goals for 2010 included achieving Alliant Energy consolidated adjusted earnings per diluted share from continuing operations of $2.60, development and communication of a long-term strategic plan, constructive outcomes for the Company and IPL base rate cases, and improvement of business unit efficiencies. Ms. Kampling was deemed to have achieved her goals in aggregate at target level, or 100%.

Ms. Swan’s individual performance goals for 2010 included achieving a constructive outcome in the Company’s base rate case, improving business unit efficiencies, advocating to achieve manageable new governmental rules and regulations, and managing litigation to achieve satisfactory or favorable outcomes. Ms. Swan was deemed to have achieved her goals in aggregate at target level, or 100%.

Ms. Doyle’s individual performance goals for 2010 included development and communication of a long-term strategic plan, achieving certain targets related to deployment of advanced metering infrastructure at the Company, meeting certain milestones related to the proposed coal plants for us and IPL;electric reliability targets, meeting certain milestones relatedbusiness unit financial targets, and improvement of business unit efficiencies. Ms. Doyle was deemed to have achieved her goals in aggregate at target level, or 100%.

Mr. Aller’s individual performance goals for 2010 included meeting financial targets for certain of Alliant Energy’s non-regulated businesses, implementation of our wind strategy, meeting wind yield performance targets, achieving a constructive outcome in the proposed wind projects for us and IPL;IPL base rate case, meeting certain milestones related totargets implementing our clean air compliance program, projects; achieving no fines for non-compliance with environmental laws and regulations;divesting Alliant Energy’s subsidiary, Industrial Energy Applications, Inc. Mr. Aller was deemed to have achieved his goals in aggregate at target level, or 100%.

The company-wide goals and obtaining targeted savings from Lean

Six Sigma and related process improvements. Thesethe individual goals which are referredcombined to as execution goals, were weighted at 30%. Mr. Harvey’s corporate well-being goals included achieving safety targets and employee and supplier diversity goals. The Committee established several targetsdetermine the short term incentive payment for each executive officer. The company-wide performance of the safety and diversity goals.130% was multiplied by each named executive officer’s individual performance scores to set their final annual incentive payments. The Committee determined that the goalsindividual short-term incentive payments made for 2010 are reported below in the diversity category were to be graded on a sliding scale to reward significant gains in diversity even if the full target wasSummary Compensation Table.

Design changes for future awards

The 2011 short-term incentive plan does not achieved. The Committee determined that the goals in the safety category were to be graded on a pass/fail system whereby if one milestone for safety was not met, then the whole category of safety could not be considered accomplished. The corporate well-being goals were weighted at 20%.

Mr. Protsch’s financial goals for 2008 were the same as for Mr. Harvey. These financial goals were weighted at 50%. Mr. Protsch also had execution goals of meeting certain milestones related to the proposed coal plants for us and IPL; achieving reasonable and timely approval of our base rate case; and obtaining targeted savings from Lean Six Sigma and related process improvements. These execution goals were weighted at 30%. In addition, Mr. Protsch had corporate well-being goals similar to Mr. Harvey’s, which were weighted at 20%.

Ms. Swan’sinclude individual performance goals for 2008 included financialexecutive officers. The executive officers’ incentive awards in 2011 will be based on achievement of company-wide goals of utility earnings per share from utility continuing operations of $2.33, which was the midpoint ofas may be adjusted according to Alliant Energy’s 2008 utility earnings guidance issued in December 2007, and achieving2010 Omnibus Incentive Plan, adjusted cash flows from operations at the utilities and Alliant Energy’s service company, subsidiary of $502 million in aggregate. These financial goals were weighted at 50%. Ms. Swan also had execution goals, including meeting certain milestones related to the proposed coal plants for uscustomer satisfaction, safety, diversity, availability and IPL; meeting certain milestones related to the proposed wind projects for us; obtaining targeted savings from Lean Six Sigma and related process improvements; and achieving specified customer service and reliability standards for us. These execution goals were weighted at 30%. Finally, Ms. Swan had corporate well-being goals similar to Mr. Harvey’s weighted at 20%.

Mr. Aller’s financial goals for 2008 included the same financial goals as Mr. Harvey. In addition, Mr. Aller had financial goals related to the consumer products, fleet services and transportation divisions of Alliant Energy that he oversees. These financial goals were weighted at 50%. Mr. Aller also had execution goals, including meeting certain milestones related to the proposed coal plants for us and IPL; meeting certain milestones related to the proposed wind projects of IPL; achieving no fines for non-compliance with environmental laws and regulations; obtaining targeted savings from Lean Six Sigma and related process improvements; and achieving specified customer service and reliability standards for IPL. These execution goals were weighted at 30%. In addition, Mr. Aller had corporate well-being goals similar to Mr. Harvey’s, which were weighted at 20%.

Ms. Doyle’s financial goals for 2008 were the same as for Ms. Swan and were weighted at 50%. Ms. Doyle’s execution goals included meeting certain milestones related to the proposed coal plants for us and IPL; meeting certain milestones related to the proposed wind projects for us and IPL; meeting certain milestones related to clean air compliance program projects; meeting certain regulatory milestones related to our base rate case; and obtaining targeted savings from Lean Six Sigma and related process improvements. These execution goals were weighted at 30%. Finally, Ms. Doyle had corporate well-being goals similar to Mr. Harvey’s weighted at 20%.

Alliant Energy’s strategic planning department is responsible for initial drafting of the performance goals, which is done to ensure that thereliability. The Committee eliminated individual performance goals for the 2011 short-term incentive awards to preserve the tax deductibility of the awards, which were granted under Alliant Energy’s 2010 Omnibus Incentive Plan as performance-based compensation within the meaning of Internal Revenue Code Section 162(m). The Committee believes the company-wide goals are objective and quantifiable. The Committee also believes that by paying incentives based on these specific financial and customer-driven goals, the short-term incentive plan is more closely aligned with the strategic plan. The chief executive officer provides recommendations to the Committee in reference to the applicable performance goals that should be implemented for eachinterests of the named executive officers (other than for himself) depending on the strategicour customers and functional responsibility of these officers. The chief executive officer is afforded discretion on the implementation of the performance goals for the other executive officers to keep continuity between the goals of the chief executive officer and those of the other executive officers. The Committee evaluates and ultimately approves all of the corporate and individual performance goals under the MICP for all of the executive officers. The goals are weighted. Individual performance goals are designed to be achievable but substantially challenging.

Alliant Energy’s utility earnings per share for 2008 was $2.19, which fell below the threshold utility earnings per share of $2.33 established to fund the incentive pool. The Committee determined that the threshold utility earnings per share was not met. Therefore, Alliant Energy did not pay incentives to our named executive officers under the MICP for 2008. The Committee did not consider achievement of individual performance goals when determining awards under the MICP because the threshold for incentive payments under the 2008 MICP was not met.shareowners.

Long-Term Incentives

Alliant Energy awardsWe award long-term incentive compensation based on the achievement of longer-term, multi-year financial goals. We believeLong-term, at-risk incentive payments account for 33%-56% of our named executive officers’ total targeted compensation, appropriately reflecting our compensation program’s emphasis on the long-term financial strength of the company.

Long-term incentive compensation aligns executives’ interests with those of Alliant Energy’s and our shareowners by compensatingissued to executive officers for long-term achievement of financial goals. Long-term incentive compensationin 2010 and earlier, takes the form of Alliant Energy equity awards granted under ourAlliant Energy’s 2002 Equity Incentive Plan, as amended and restated.

Plan. Equity awards were granted under the Alliant Energy determinesCorporation’s 2010 Omnibus Incentive Plan, which was adopted by Alliant Energy’s shareowners at its last years’ annual meeting, beginning in 2011. All of the equity awards granted to executive officers under our long-term incentive plans are performance based and will be forfeited if performance results are not achieved.

We determine the value of each executive officer’s long-term incentive amountsopportunity by benchmarking totargeting the median value of long-term incentives paid by the peer group,opportunities of our market reference point, assessing the individual performance of the executive officer and internal equity among our executives, and considering the competitiveness of the total direct compensation package. Based on these factors, the Committee approved, as a percentage of base salary, the following values of the long-term incentives awarded to the named executive officers for 2008:2010: 250% for Mr. Harvey;Harvey, 150% for Mr. Protsch;Ms. Kampling, 125% for Ms. Swan;Swan, 70% for Mr. Aller;Aller and 70% for Ms. Doyle. The target levels of all of our named executive officers are within the target levels for similar positions compared to our market reference point. The Committee approves the dollar value of the long-term equity awards prior to the grant date. We grantAlliant Energy grants the number of shares of Alliant Energy sharesstock necessary to approximate that dollar value based on the fair market value of Alliant Energy’sour share price on the grant date. The grant price used for accounting purposes is fair market value of Alliant Energy’s common stock on the grant date. Our shares are not used for long-term incentive compensation.

The long-term incentive awards consist of performance contingent restricted stock and performance shares. Alliant Energy believesWe believe these two types of long-term equity awards provide incentives for our executive officers to produce value for our and Alliant Energy’s shareowners over the long-term on both an absolute basis and a relative basis. Performance contingent restricted stock granted in 2008 vests if Alliant Energy’s consolidated income from continuing operations achieves 19%specified growth whichin two, three or four years. This rewards absolute long-term growth. We set the rate of growth required for the performance contingent restricted stock to vest based on Alliant Energy’s strategic plan. Performance shares vest and pay-outpay out at varying levels depending on Alliant Energy’s relative total shareowner return as compared to the companies comprising the S&P Midcap Utilities Index, whichIndex. This rewards relative total shareowner return. The Committee granted long-term equity awards in 20082010 consisting of 50% performance shares and 50% performance contingent restricted stock and 50% performance shares to equally reward bothemphasize absolute and relative long term growth and total shareowner return.

Performance contingent restricted stock granted prior to 2008 vests iflong-term growth. We discontinued the use of Alliant Energy consolidated earnings per share from continuing operations achieves 116% growth, which is 5% compounded year over year growth for three years. Forstock options in 2004 because we believe that performance contingent restricted stock and performance shares provide equal incentive value and reduce potential dilution of our shareowners.

Performance Contingent Restricted Stock

Awards granted in 2008,2010

In 2010, the Committee changed thegranted performance criteria from earnings per share from continuing operationscontingent restricted stock to our executive officers that will vest in two, three or four years if Alliant Energy’s consolidated income from continuing operations to mitigate volatility in earnings per share that can be caused by increasing or decreasing the number of shares outstanding.grows 19% over 2009 Alliant Energy consolidated income from continuing operations. The Committee increased the growth rate of income that must be achieved for the performance criteria to be met from 5% tocontingency represents 6% compounded yeargrowth over year growth for three years. The 2009 adjusted base income from continuing operations is $213.9 million. This non-GAAP figure excludes the effects of regulatory related charges, asset impairments and certain accounting charges which we believe are not reflective of on-going operations. Thus, the performance contingent restricted stock will vest in two, three or four years if our consolidated income from continuing operations in any year is $254.7 million. Consolidated income from continuing operations will be calculated excluding the effects of the following, if the amount is over $4,000,000 on a pre-tax basis and is not considered in the annual budget approved by our Board of Directors: (i) charges for reorganizing and restructuring; (ii) discontinued operations; (iii) asset write-downs; (iv) gains or losses on the disposition of an asset or business; (v) mergers, acquisitions or dispositions; and (vi) extraordinary, unusual and/or non-recurring items of gain or loss, that in all of the foregoing the Company identifies in its audited financial statements, including footnotes, or the Management’s Discussion and Analysis section of the Company’s periodic reports.

Awards paid in 2010

In 2010, following the confirmation from our audited financial statements, the Committee believeddetermined that the increase would better align management’s interests with the high expected growth in earnings during the planned new generation build out period.

The vesting of the performance contingent restricted stock granted in 2007 vested due to the successful achievement of Alliant Energy’s earnings per share growth target. The earnings per share growth goal for the 2007 performance contingent restricted stock was $2.55. Alliant Energy’s earnings per share from continuing operations for 2010 was $2.62. The amounts realized by our named executive officers as a result of this vesting can be found in the Option Exercises and Stock Vested table below.

Design changes for future grants

The Committee changed the projected growth rate for vesting performance contingent restricted stock from 119% to 116% for grants made in 2011. The growth rate represents 5% compounded growth for three years. The Committee made the change to align long-term incentive pay with Alliant Energy’s strategic plan.

Outstanding performance contingent restricted stock grants

The following list is all outstanding performance contingent restricted stock grants with performance targets.

2010 Grants: Adjusted net income growth of 119% (6% annualized) — $254.7 million

2009 Grants: Adjusted net income growth of 119% (6% annualized) — $333.2 million

2008 Grants: Adjusted net income growth of 119% (6% annualized) — $359.3 million

Performance Shares

Awards granted in 2010

In 2010, the Committee granted performance shares to our executive officers. The vesting of the performance shares is based on Alliant Energy’s growth in income from continuing operations using Alliant Energy’s final income from continuing operations in 2007 as the base, which was adjusted to remove the after tax gain on the sale of the electric transmission assets of Alliant Energy’s Iowa utility as this was a non-recurring event. The base adjusted income from continuing operations was $302 million. The performance contingent restricted stock granted in 2008 vests if Alliant Energy achieves income from continuing operations growth of 19% from 2007, within a four year period. The 19% growth is based on achieving 6% compounded year over year growth over a three year period. The target income from continuing operations is $359.4 million. In no case may the restricted stock vest earlier than two years from the grant date, and all shares will be forfeited if the income from continuing operations target is not met at the end of the four-year period.

The payout of performance shares granted in 2008 is based on Alliant Energy’srelative total shareowner return over three years.a three-year period. Performance shares will provide a 100% payout, or target payout, if Alliant Energy’s relative total shareowner return over three years is equal to the median performance of a specific peer group selected by the Committee. The Committee selected the S&P Midcap Utilities Index as the peer group for the 20082010 grants of performance shares.

Performance share payouts are capped at 200% of the target payout ifpayout. The following table shows the level of performance share payouts based on Alliant Energy’s total shareowner return is at or above the 90th percentile of the total shareowner return ofas compared to the S&P Midcap Utilities Index. The payout would be 50% of the target payout if Alliant Energy’s total shareowner return was in the 40th percentile of the total shareowner return of the S&P Midcap Utilities Index. There would be no payout if Alliant Energy’s total shareowner return fell below the 40th percentile of the S&P Midcap Utilities Index.

Alliant Energy’s Percentile RankPercent of Target Value 
Payout

90th percentile or greater

200%

80th percentile

175%

70th percentile

150%

60th percentile

125%

50th percentile

100%

45th percentile

75%

40th percentile

50%

Below 40th percentile

0%

Performance shares allow the executive officer to receive a payment in shares of Alliant EnergyEnergy’s common stock, cash, or a combination of Alliant EnergyEnergy’s common stock and cash, the value of which is equal to the number of shares awarded, adjusted by the performance multiplier. The Committee generally requires an executive that has not met the share ownership guidelines to take a payment in Alliant Energy common stock or a combination of 50% common stock

and 50% cash in order to bringIf the executive closer to achieving the share ownership guideline. If the executiveofficer chooses to take the payment in cash, the amount of the payout is determined by multiplying the number of shares earned by the average of the high and low trading prices on a date chosen by the Committee. The Committee chooses this date in advance of issuing the shares.

In 2009, theAwards paid in 2010

The Committee determined that Alliant Energy achieved itsthe performance levelslevel for the performance shares granted in 2006. Alliant Energy’sissued for the 2008-2010 performance period caused those performance shares to vest. The relative total shareowner return performance of Alliant Energy for the three years ended Dec. 31, 20082010 was at the 75th percentile.45th percentile of the peer group. Due to thethat total shareowner return, goal being achieved,performance shares vested at 75% of target. The amounts realized by our named executive officers as a result of this vesting can be found in the Option Exercises and Stock Vested table below.

Design changes for future grants

The Committee changed the peer group for determining relative total shareowner return for the performance shares granted in 2011. The new peer group is the Edison Electric Institute (EEI) Stock Index, which currently includes 58 investor-owned utility companies. Alliant Energy had abecame the largest company by market capitalization in the S&P Midcap Utilities Index

during 2010, causing the S&P Midcap Utilities Index to no longer be an appropriate benchmark for performance share payoutfor us. The median market capitalization of 162.5% of target for the 2006 grant. Also in 2009, following the confirmation fromEEI Stock Index is slightly higher than Alliant Energy’s audited financial statements, the Committee determinedmarket capitalization. We believe that the performance contingentnew peer group is a better representation of our peers because we are closer to the median size of companies in the peer group.

Time-based Restricted Stock

Occasionally, Alliant Energy grants time-based restricted stock to named executive officers in connection with an increase in responsibilities and to promote retention of that named executive officer. No time-based restricted stock awards were made to named executive officers in 2010. In 2010, restricted stock granted to Mr. Harvey in 2007 did not vest2005 vested, and restricted stock granted to Ms. Swan vested due to Alliant Energy’s earnings per share from continuing operations growth after two years. Alliant Energy’s 2007 diluted earnings per share from continuing operations growth goal was $2.55. Alliant Energy’s earnings per share from continuing operations forher retirement. The amount of stock that vested can be found in the year ended Dec. 31, 2008 was $2.54.

The Committee approves the dollar value of the long-term equity awards prior to the grant date. The grant date of the awards that Alliant Energy made in 2008 to our executive officers was the first business day of the year, which maximized the time period for the incentives associated with the awards. The grant price used for accounting purposes was the fair market value of Alliant Energy’s common stock on the grant dateOption Exercises and the value of the awards were reported in Alliant Energy’s financial statements in accordance with FAS 123(R).

Alliant Energy no longer grants stock options as incentive compensation. Alliant Energy determined that performance contingent restricted stock and performance shares provide equally motivating forms of equity incentive compensation and reduce potential dilution of Alliant Energy’s shareowners because fewer shares need be granted. Alliant Energy’s last stock options were granted in 2004 and expire in 2014.Stock Vested table below.

Other Benefits

Alliant Energy also offers benefit programs to our executive officers with a focus towards their retirement consistent with those of theour peer group. We provide these benefits to remain competitive with the general market for executives. These programs include a 401(k), savings plan, a deferred compensation plan and various pension benefits. The benefit programs are designed to be competitive in attracting, retaining and motivating key executives and employees by providing competitive retirement benefits. We apply the same peer group benchmarking approach in designing these programs in that we benchmark to median levels of benefit and design elements. The Committee reviews benefit programs on an annuala periodic basis to determine effectiveness and identify any necessary changes. The retirement-related benefit plans were allare reviewed during 2008periodically by the Committee with severaland certain changes implemented.to the plans were adopted in 2010. A brief description of the plans with associated changes follows.

401(k) Savings Plan

All of our salaried employees, including our executive officers, are eligible to participate in the Alliant Energy’sEnergy 401(k) Savings Plan. Alliant Energy matches $0.50 on each dollar for the first 8% of compensation deferred by the employee up to the IRS maximum. Beginning Aug. 3, 2008, weAlliant Energy enhanced benefits under the 401(k) Savings Plan to offset a freeze of the Alliant Energy Cash Balance Pension Plan. See “Pension Benefits” below for more information. Alliant Energy now contributes a percentage of salaried employees’ salaries to their 401(k) accounts in addition to the company match. The amount of Alliant Energythe company contribution ranges from 4% to 6% of an employee’s salary. The amount of Alliant Energythe company contribution depends on the employee’s age and number of years of service at the company.

Alliant Energy Deferred Compensation Plan

The Alliant Energy Deferred Compensation Plan, or AEDCP, enables participants, including our executive officers, to defer up to 100% of base salary and annual incentive awards on a pre-tax basis and to receive earnings or incur losses on the deferrals until the date of distribution. The AEDCP provides tax deferred savings and post-retirement income to our executive officers. The shares of Alliant Energy common stock identified as obligations under the AEDCP are held in a rabbi trust. Alliant Energy offersWe offer the AEDCP as part of the executives’ competitive compensation package to permit executives to take advantage of the tax code in saving for their retirement. In 2010, the Committee approved amendments to the AEDCP to provide new investment options for participants, and permit participants to reallocate their account balances among investment options with the exception of not permitting participants to reallocate account balances out of the Alliant Energy stock investment option. These changes took effect in 2011. We believe the AEDCP is in line with offerings from the peer group.of comparable companies. See “Nonqualified Deferred Compensation” below for more information regarding the AEDCP.

Cash Balance Pension Plan

Certain of our salaried employees, including our executive officers, are eligible to participate in the Alliant Energy Cash Balance Pension Plan. This defined benefit plan is portable, offers flexible payment options and steady growth of retirement funds. Future accruals to the Cash Balance Pension Plan were frozen for participants effective Aug. 2, 2008. See “Pension Benefits” below for more information regarding the Alliant Energy Cash Balance Pension Plan.

Excess Retirement Plan

Certain of our salaried employees, including our executive officers, participate in the unfunded Alliant Energy Excess Retirement Plan. The plan is intended to provide the accruals that the participants would have earned under the Alliant Energy Cash Balance Pension Plan and the Alliant Energy 401(k) Savings Plan but for statutory limitations on employer-provided benefits imposed on those tax-qualified plans.plans, and accruals earned on their deferrals into the AEDCP. See “Pension Benefits” below for more information regarding the Excess Retirement Plan.

Supplemental Executive Retirement Plan

Our executives, who are vice presidents or above including our named executive officers, participate in the unfunded Alliant Energy’s unfundedEnergy Supplemental Executive Retirement Plan, or SERP. Alliant Energy provides the SERP as an incentive for key executives to remain in Alliant Energy’sour service by providing retirement compensation in addition to the benefits provided by the pension plan and 401(k) Savings Plan, which are limited by the tax code, that is payable only if the executive remains with Alliant Energy until retirement, disability or death. See “Pension Benefits” below for more information regarding the SERP.

Split Dollar / Reverse Split Dollar Life Insurance Plan

Certain executive officers, including Messrs.Mr. Harvey and ProtschMses. Swan and Ms. Swan,Doyle, receive individually owned life insurance policies. Alliant Energy pays the premiums for this insurance and these payments are taxable to the individual officers. We reimburse these executive officers for taxes associated with certain of these policies. These specific policies were grandfathered in 1998 and we no longer offer the policies to other executive officers as part of total executive compensation.

Perquisites

In the past, Alliant Energy providesprovided our officers, including our named executive officers with certain perquisites. Alliant Energy provided these perquisites to maintain a Flexible Perquisite Program. Thecompetitive compensation program, provides a specified amount of fundsas it was common practice for companies to our executivesprovide perquisites. Alliant Energy has begun reducing the perquisites paid to use for benefits, including an annual fixed automobile allowance, financial planning and legal services, a variety of club memberships and long-term care insurance. The Committee reviews this program on an annual basis as part of our total compensation offering to determine its merits and the use of similar programs by our peer group. The last review took place at our December 2008 Committee meeting where Towers Perrin provided an update on market trends for these programs. The Committee determined that the Flexible Perquisite Program continued to be comparable to continuing programs found in the market and should continue as a component of total executive compensation. For 2009, the Committee set the Flexible Perquisite Program funding amounts at $26,000 for Mr. Harvey; $20,000 for Mr. Protsch; $17,500 for Ms. Swan; $14,000 for Mr. Aller; and $11,000 for Ms. Doyle which represented no change from 2008. Our executive officers are alsoas perquisites have become less common. In 2009, Alliant Energy eliminated our flexible perquisite program. In 2010, our executive officers remained eligible for executive physicals and moderately more generous health care benefits and dental insurance, accidental death insurance,long-term disability insurance vacation, and other similar benefit programs than the balance of ourAlliant Energy’s non-bargaining unit employees. In 2011, Alliant Energy eliminated a portion of the executive health care perquisite that had been historically provided.

Post-Termination Compensation

KEESAs

Alliant Energy currently has in effect key executive employment and severance agreements, or KEESAs, with our executive officers, including our named executive officers (other than Ms. Swan, who retired effective Dec. 31, 2010), and certain of our key employees. The KEESA is designed to provide economic protection to key executives following a change in control of Alliant Energy so that executives can remain focused on our business without undue personal concern. We recognize that circumstances may arise in which weAlliant Energy may consider a change of control transaction. We believe the security afforded the executives by the KEESA will help the executives to remain focused on business continuity and reduce the distraction of the executive’s reasonable personal concerns regarding future employment. We also believe that the KEESA allows the executive to better consider the best interests of Alliant Energy and its shareowners due to the economic security provided by the KEESA benefits.

The KEESAs are triggeredpaid if, within a period of up to three years after a change in control for Mr. Harvey Mr. Protsch or Ms. SwanKampling and two years for Mr. Aller or Ms. Doyle, there has occurred both a change in control and loss of employment other than for cause, causing KEESA benefits to be subject to a “double trigger.” We implemented the double trigger mechanism to ensure that only those executives adversely affected by a change in control would receive benefits under the KEESA. The cash termination benefit under the KEESA is up to three times base salary and target bonus for Mr. Harvey Mr. Protsch and Ms. SwanKampling and two times base salary and target bonus for Mr. Aller and Ms. Doyle.

The KEESAs for Mr. Aller and Ms. Doyle provide 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 Internal Revenue 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 weAlliant Energy may pay without loss of deduction under the Code.

The KEESAsKEESA for Ms. Kampling provides that if any portion of the benefits under the KEESA or under any other agreement would constitute an excess parachute payment for purposes of the Internal Revenue Code, she may receive the better of either a payment $1 less than the maximum amount she may receive without becoming subject to the 20% excise tax, or receive the fully calculated payment subject to applicable excise taxes, for which she would be personally responsible.

The KEESA for Mr. Harvey Mr. Protsch and Ms. Swan provideprovides that if any payments constitute an excess parachute payment, Alliant Energy will pay to the appropriate officerMr. Harvey the amount necessary to offset the excise tax and any additional taxes on this additional payment. Mr. Harvey is the only executive officer with a gross-up provision in his KEESA.

We believe the level of the benefits provided by the KEESAs to each executive officer reflects the appropriate amount of work that would be required of them during a change in control transaction as well as the amount of opportunities they would be asked to forego to assist the change in control transaction rather than seek future employment. Top executives are required to put forth greater effort to ensure a smooth change in control of a company and we believe that it would take a longer timecompensation necessary for them to find comparable employment based on their attained career status. The elevated positions held by Messrs. Harvey and Protsch and Ms. Swan cause us to believe that this analysis is especially true for them. Therefore, they receive the highest benefit level and a tax-gross up. We believe the benefits provided in the KEESA to our executive officers are comparable with industry practice.to consider our shareowners’ interests without interference of their own personal situation.

In consideration of the KEESA benefits, the executive agrees not to compete with Alliant Energy andor us for a period of one year after the executive leaves Alliant Energyus and to keep in confidence any proprietary information or confidential information for a period of five years after the executive leaves Alliant Energy.Energy or us. Both of these conditions can be waived in writing by Alliant Energy’s board of directors.

See “Potential Payments upon Termination or Change in Control” for more information regarding the KEESAs.

Executive Severance Plan

Alliant Energy also maintains a general executive severance plan for executive officers in the event that an officer’s position has been eliminated or significantly altered by Alliant Energy. The executive severance plan is designed to provide economic protection to key executives following the elimination of their position so that executives can remain focused on our business without undue personal concern. We recognize that circumstances may arise in which we may consider eliminating certain key positions that are no longer necessary.positions. We believe the security afforded the executives by the severance plan will keep the executives focused on their duties at our company rather than on their personal concerns of job security. The plan provides for a minimum level of severance pay equal to one times annual base salary, payment of pro-ratedprorated incentive compensation within the discretion of the chief executive officer, up to 18 months of COBRA coverage, six months of which are paid by Alliant Energy, outplacement services and/or tuition reimbursement of up to $10,000, and access to ourAlliant Energy’s employee assistance program. All executive officer severance packages are approved by the Committee. We believe our executive severance plan is consistent with plans throughout the industry.

See “Potential Payments upon Termination or Change in Control” for more information regarding the Executive Severance Plan.

Employment Agreements

We do not have any other employment agreements with our executive officers. However, in 2010, Alliant Energy entered into a Special Incentive Agreement with Ms. Swan which provided for the payment to Ms. Swan of a special incentive bonus of up to $275,000 provided she remained continuously employed until, and retired on, Nov. 30, 2010. The agreement also required Ms. Swan to achieve the following performance goals: (i) making substantial progress in assisting in the appointment of a successor General Counsel; (ii) making substantial progress and, if possible concluding, pending litigation related to certain environmental matters at the Company; (iii) making substantial progress and, if possible concluding, pending litigation against the Alliant Energy Cash Balance Plan; (iv) successfully transitioning all Strategic and Corporate Services leadership functions to successor leadership; (v) providing mentoring to the successor President of the Company, if such successor is identified prior to Ms. Swan’s retirement; and (vi) agreeing to be available to certain officers of Alliant Energy for consultation as an independent contractor on foregoing items for up to six months after retirement. The Committee determined that this agreement was needed to retain Ms. Swan to assist with the transition of her duties to her successors. Payment was not made to Ms. Swan under this agreement as she retired on Dec. 31, 2010, not Nov. 30, 2010 as provided for in the agreement.

Share Ownership Guidelines

Alliant Energy establishedhas had a share ownership guidelinesguideline for our executiveexecutives for many years. The guideline requires officers asto own a waycertain number of shares of Alliant Energy’s common stock to better align the financial interestsofficer’s interest with that of officers with thosethe shareowners. In 2010, we adopted a new guideline that determines the required number of shareowners. Under these guidelines,shares by taking the requisitefollowing multiples of the officer’s base salary as of the latest of Jan. 3, 2011 or the date of hire or promotion to a higher level of ownership numbers are 85,000 sharesrequirement: (1) chief executive officer, four times base salary; (2) president, three times base salary; (3) executive vice presidents, two-and-one-half times base salary; (4) senior vice presidents, two times base salary; and (5) vice presidents, one-and-one-half times base salary. The multiple of salary was divided by the closing price of Alliant Energy common stock for Mr. Harvey, 36,000on Jan. 3, 2011 (or the date of hire or promotion, if later) to determine the number of shares for Mr. Protschthat the officer is required to hold. That number of shares will not change unless the officer is promoted. By setting the number of shares this way, we mitigate the effect of short term volatility on compliance caused by changes in Alliant Energy’s stock price and Ms. Swan and 12,000 shares for Mr. Aller and Ms. Doyle. The executive officers are expected to make continuing progress toward compliance with these guidelines and achieve their designated levels withinby changes in salary. Officers have five years of being appointed as an officer. We monitor each officer’s progression towards achievement of these guidelines onfrom their hire date or date they were promoted into a semi-annual basis.new position with a higher

The share

multiple to achieve the goal. Shares held outright, vested restricted stock, earned performance shares, and shares held in the AEDCP count toward the ownership guidelines have an impact upon the payout of awardsguidelines; unvested restricted stock and unearned performance shares do not count for performance shares. If executivesthis purpose.

Officers who have not yet met their share ownership level theyafter five years are required to receive at least 50% of any performance share payout made upon the vestingretain 100% of the performance shares in sharesafter-tax value of Alliant Energy’s common stock. In addition, oncevested long-term equity awards until the performance or time-based restrictions lapse on shares of performance contingent or time-based restricted stock, these shares are counted towards

achievement of share ownership guidelines.requirement is met. Our chief executive officer retains the right to grant special dispensation for hardship, promotions or new hires. All of our current named executive officers who have metheld their current positions for five years are in compliance with the share ownership guidelines. Their share holdingsThe shares owned by our named executive officers are shown in the “Ownership of Voting Securities” table above.

Impact of Regulatory Requirements

Section 162(m) of the Internal Revenue Code generally limits the corporate deduction for compensation paid to our chief executive officer and the three other most highly compensated executive officers (excluding our chief financial officer) 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 above, the Committee intends to qualify future compensation paid to our executive officers for deductibility by us under Section 162(m) except in limited appropriate circumstances. We expect that short-term and long-term incentive compensation awarded under Alliant Energy’s 2010 Omnibus Incentive Plan will qualify for deductibility under Section 162(m). All of our equity compensation plans are accounted for under FAS 123(R).

In 2008, Alliant Energy amended the SERP, KEESAs and Severance Plan to comply with the deferred compensation election and payment timing requirements of Internal Revenue Code Section 409A.

The Public Service Commission of Wisconsin allows us to recover from customers portions of incentive compensation payments attributable to customer service and reliability goals. We have structured our compensation program to participate in this allowed recovery.Financial Accounting Standards Board Accounting Standards, Codification Topic 718.

Conclusion

The Committee is provided with appropriate information and reviews all components of our chief executive officer’s and other executive officers’ compensation. Based on this information, the Committee seeks to implement executive compensation that is appropriately tied to the performance of the executives on behalf of shareowners, employees and customers.

COMPENSATION AND PERSONNEL COMMITTEE REPORT

To Our Shareowners:

The Compensation and Personnel Committee (the “Committee”) of the Board of Directors of the Company has reviewed and discussed the Compensation Discussion and Analysis with our Audit Committee and our management. Based on the Committee’s reviewsreview and discussions,discussion, the Committee recommended to the Board of Directors that the Compensation Discussion and Analysis be included in this proxy statement and incorporated by reference in our Annual Report on Form 10-K for the year ended Dec. 31, 2008,2010, for filing with the SEC.

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

COMPENSATION AND PERSONNEL COMMITTEE

Ann K. Newhall (Chairperson)

Darryl B. Hazel

Dean C. OestreichJudith D. Pyle

Carol P. Sanders

SUMMARY COMPENSATION TABLE

The table below summarizes the compensation paid to or earned by our chief executive officer, our chief financial officer (which for all of 20082010 was Mr. Protsch)Ms. Kampling) and our next three highest paid Alliant Energy Corporation executive officers for all services rendered to us, Alliant Energy and Alliant Energy’s other subsidiaries in 2008, 2007for 2010, 2009 and 2006.2008. We refer to such individuals in this proxy statement collectively as our named executive officers.

 

Name and

Principal Position

 Year Salary
($)(1)
 Bonus
($)(2)
 Stock
Awards
($)(3)
 Option
Awards
($)(4)
 Non-Equity
Incentive Plan
Compensation
($)(5)
 

Change in
Pension Value
and
Nonqualified
Deferred
Compensation
Earnings

($)(6)

 All Other
Compensation
($)(7)
 

Total

($)

William D. Harvey

Chairman and Chief Executive Officer

 2008 $850,962 $0 $842,408 $0 $0 $2,103,000 $262,562 $4,058,932
 2007 $811,962 $0 $2,794,112 $0 $677,160 $3,844,938 $226,340 $8,354,512
 2006 $745,192 $151,875 $2,398,279 $32,148 $860,625 $689,334 $162,962 $5,040,415

Eliot G. Protsch

Chief Operating Officer

 2008 $498,515 $0 $325,868 $0 $0 $651,000 $129,785 $1,605,168
 2007 $477,427 $0 $1,170,638 $0 $293,216 $1,757,578 $108,774 $3,807,633
 2006 $454,519 $65,213 $1,263,614 $17,856 $369,540 $191,983 $109,941 $2,472,666

Barbara J. Swan

President

 2008 $377,669 $0 $141,131 $0 $0 $492,000 $84,344 $1,095,144
 2007 $362,081 $0 $697,271 $0 $174,724 $245,478 $63,289 $1,542,843
 2006 $342,116 $36,872 $821,333 $13,816 $208,941 $123,800 $57,299 $1,604,177

Thomas L. Aller

Senior Vice President-

Energy Resource Development

 2008 $269,404 $30,000 $57,002 $0 $0 $0 $40,036 $396,442
 2007 $258,346 $0 $304,690 $0 $90,640 $152,628 $31,199 $837,503
 2006 $249,523 $23,625 $458,293 $9,356 $133,875 $188,916 $28,179 $1,091,767

Dundeana K. Doyle

Senior Vice President-

Energy Delivery

 2008 $256,669 $0 $51,530 $0 $0 $94,791 $44,579 $447,569
 2007 $236,696 $0 $229,758 $0 $77,776 $91,558 $33,206 $668,994
 2006 $223,567 $17,719 $291,426 $4,638 $100,406 $65,785 $38,118 $741,659

Name and

Principal Position

 Year  Salary
($)(1)
  Bonus
($)(2)
  Stock
Awards
($)(3)
  Option
Awards
($)
  Non-Equity
Incentive Plan
Compensation
($)(4)
  

Change in
Pension Value
and
Nonqualified
Deferred
Compensation
Earnings

($)(5)

  All Other
Compensation
($)(7)
  Total ($) 
William D. Harvey
Chairman and
Chief Executive Officer
  2010   $872,481   $0   $2,384,547   $0   $1,080,625   $403,922   $413,208   $5,154,783  
  2009   $832,000   $0   $1,999,511   $0   $0   $147,000   $353,986   $3,332,497  
  2008   $850,962   $0   $2,076,264   $0   $0   $2,103,000   $262,562   $5,292,788  
Patricia L. Kampling
Chief Operating Officer/Chief Financial Officer(6)
  2010   $403,212   $0   $630,329   $0   $422,500   $529,000   $70,236   $2,055,277  
  2009   $294,769   $0   $425,945   $0   $0   $93,000   $42,368   $856,082  
                                    
Barbara J. Swan
President/Chief Administrative Officer(6)
  2010   $467,481   $0   $639,769   $0   $366,210   $930,000   $120,452   $2,523,912  
  2009   $442,500   $0   $632,437   $0   $0   $45,000   $97,865   $1,217,802  
  2008   $377,669   $0   $460,667   $0   $0   $492,000   $84,344   $1,414,680  
Dundeana K. Doyle
Senior Vice President- Energy Delivery
  2010   $279,658   $0   $214,699   $0   $164,619   $246,917   $59,675   $965,568  
  2009   $262,800   $0   $176,901   $0   $0   $153,832   $56,821   $650,354  
  2008   $256,669   $0   $175,416   $0   $0   $94,791   $44,579   $571,455  
Thomas L. Aller
Senior Vice President- Energy Resource Development
  2010   $280,241   $0   $215,196   $0   $164,970   $170,000   $48,260   $878,667  
  2009   $263,385   $0   $177,236   $0   $0   $151,000   $44,053   $635,674  
  2008   $269,404   $30,000   $184,012   $0   $0   $0   $40,036   $523,452  

 

(1)

The amounts shown in this column include amounts deferred by the named executive officers in theour Alliant Energy Deferred Compensation Plan Stock Account. See “Nonqualified Deferred Compensation.” The amounts shown in this column for 2009 reflect a reduction in the amount of annual base salary that would otherwise have been paid to the named executive officer due to a one week unpaid furlough for all non-bargaining employees in 2009.

 

(2)

The amountsamount in this column for 2006 represent the difference between the amounts the named executive officers received under Alliant Energy’s MICP for 2006 as a result of the waiver by the Compensation and Personnel Committee of the cash flow performance measure and what the amounts received under Alliant Energy’s MICP for 2006 would have been without the waiver. The amount shown for Mr. Aller in 2008 is a discretionary bonus awarded by the Committee to Mr. Aller in recognition of the leadership he provided Alliant Energy,us, IPL’s customers and the community of Cedar Rapids, Iowa, during the flood that occurred in June 2008.

 

(3)

The amounts in this column reflect the dollar amount Alliant Energy recognized for financial statement reporting purposes for the fiscal years ended Dec. 31, 2006, 2007aggregate grant date fair value of performance shares, performance contingent restricted stock and 2008, in accordance with FAS 123(R) (disregarding the estimate of forfeitures relating to service-based vesting), of awardstime-based restricted stock granted pursuant to Alliant Energy’s 2002 Equity Incentive Plan and thus may include amounts from awards granted in and prior to 2008. Assumptionseach year, computed in accordance with Financial Accounting Standards Board Accounting Standards Codification Topic 718. A discussion of the assumptions used in calculating the calculation of these amounts are includedaward values may be found in Note 6(b) to Alliant Energy’s 2010 audited financial statements for the fiscal year ended Dec. 31, 2008 includedcontained in ourAlliant Energy’s Annual Report on Form 10-K filed10-K. For the performance shares, the fair value at the grant date is based upon the probable outcome of the performance conditions, consistent with the Securitiesestimate of aggregate compensation cost to be recognized over the service period determined as of the grant date under Topic 718, excluding the effect of estimated forfeitures. The grant date fair value reflected in this column for performance shares was $1,290,797 for Mr. Harvey; $341,208 for Ms. Kampling; $346,318 for Ms. Swan; $116,221 for Ms. Doyle; and Exchange Commission on Feb. 27, 2009.$116,489 for Mr. Aller. The grant date fair value for performance shares at maximum would have been: $2,187,500 for Mr. Harvey; $578,242 for Ms. Kampling; $586,902 for Ms. Swan; $196,958 for Ms. Doyle; and $197,414 for Mr. Aller.

 

(4)

The amounts in this column reflect the dollar amount Alliant Energy recognized for financial statement reporting purposes for the fiscal year ended Dec. 31, 2006 in accordance with FAS 123(R) (disregarding the estimate of forfeitures relating to service-based vesting), of awards pursuant to Alliant Energy’s 2002 Equity Incentive Plan and thus include amounts from awards granted prior to 2006. Assumptions used in the calculation of these amounts are included in Note 6(b) to Alliant Energy’s audited financial statements for the fiscal year ended Dec. 31, 2006 included in our Annual Report on Form 10-K filed with the Securities and Exchange Commission on March 1, 2007.

(5)

The amounts in this column represent cash amounts received by the executive officers under Alliant Energy’s MICP for services performed in 2006, 2007 and 20082010 that were paid in 2007,2011. There were no amounts earned under the MICP in 2008 and 2009, respectively.or 2009.

 

(6)(5)

The amounts in this column reflect (a) the actuarial increase in the present value of the named executive officers benefits under all pension plans established by Alliant Energy determined using the assumptions and methods set forth

in footnote (1) to the Pension Benefits table below, which may include amounts that the named executive officer may not currently be entitled to receive because such amounts are not vested, and (b) amounts representing above market interest on non-qualifiednonqualified deferred compensation. The above market interest was calculated to be equal to the amount by which the interest on deferred compensation in a frozen legacy deferred compensation plan in 2008 (11% on deferrals made prior to July 1, 1993 and 9% on deferrals made on or after July 1, 1993) exceeded 120% of the applicable federal long-term interest rate, with compounding, at the time the interest rate was set (120% of this rate was 5.35%). The following represents the breakdown for 2010 for each of the change in pension value and above market interest on deferred compensation, respectively, for each named executive

officer: Mr. Harvey, $2,103,000/$401,000/$0; Mr. Protsch, $651,000/2,922; Ms. Kampling, $529,000/$0; Ms. Swan, $492,000/$930,000/$0; Ms. Doyle, $239,000/$7,917; and Mr. Aller, $0/$170,000/$0; and Ms. Doyle, $89,000/$5,791.0. The changes in the actuarial present values of the named executive officers’ pension benefits do not constitute cash payments to the named executive officers.

 

(6)

Ms. Kampling became a named executive officer in 2009. She was not a named executive officer in 2008. Ms. Swan was President through November 30, 2010, and Chief Administrative Officer thereafter.

(7)

The table below shows the components of the compensation reflected under this column for 2008:2010.

 

Name Perquisites and
Other Personal Benefits
(a)
  Registrant
Contributions to
Defined
Contribution Plans
(b)
  

Life Insurance
Premiums

(c)

  Tax
Reimbursements
(d)
  Dividends
(e)
  Total  Perquisites and
Other Personal  Benefits
(a)
  Company
Contributions to
Defined
Contribution  Plans
(b)
  

Life Insurance
Premiums

(c)

  Tax
Reimbursements
(d)
  Dividends
(e)
  Total 

William D. Harvey

 $21,668  $26,400  $68,955  $26,459  $119,080  $262,562  $18,982   $88,286   $80,542   $23,527   $201,871   $413,208  

Eliot G. Protsch

 $19,659  $23,445  $31,661  $5,393  $49,627  $129,785 

Patricia L. Kampling

 $3,485   $35,691   $1,497   $0   $29,563   $70,236  

Barbara J. Swan

 $24,475  $19,823  $15,234  $8,217  $16,595  $84,344  $9,521   $35,250   $15,825   $8,464   $51,392   $120,452  

Dundeana K. Doyle

 $1,985   $25,334   $10,416   $6,248   $15,692   $59,675  

Thomas L. Aller

 $18,883  $13,073  $1,810  $0  $6,270  $40,036  $4,485   $24,069   $2,922   $0   $16,784   $48,260  

Dundeana K. Doyle

 $9,701  $13,061  $10,314  $6,092  $5,411  $44,579 

 

(a)a)Consists of allowance pursuant to Alliant Energy’s Flexible Perquisite Program that may be utilized for automobile allowance; financial planning and legal services; club memberships; and premiums for additional long-term disability coverage. This amount also includes Alliant Energy contributions to the executive for a consumer driven health plan above the amount provided to other non-bargaining employees enrolled in that plan, premiums for additional long-term disability coverage, executive physicals, and the cost of spousal travel on companyAlliant Energy owned aircraft. Because an executive’s spouse accompanies the executive on a flight when the executive is traveling for business purposes, Alliant Energy does not incur additional direct operating cost in such situations. However, the personal use of the companyAlliant Energy owned aircraft is imputed income to the named executive officer and is calculated on Standard Industry Fare Level rates published periodically by the Internal Revenue Service.
(i)For Mr. Harvey, $12,000 of his perquisite allowance was for automobile allowance.
(ii)No other named executive officer had a single perquisite item in excess of $10,000.
(b)b)Matching contributions to the Alliant Energy 401(k) Savings Plan and the Alliant Energy Deferred Compensation Plan, employer contributions based on age and service to the Alliant Energy 401(k) Savings Plan accounts and employer defined contributions to the Alliant Energy Excess Retirement Plan.
(c)c)All life insurance premiums.
(d)d)Tax reimbursements for reverse split and reverse dollar life insurance and, in the case of Mr. Harvey only, financial planning and legal services.insurance.
(e)e)Dividends earned in 20082010 on unvested restricted stock.

GRANTS OF PLAN-BASED AWARDS

The following table sets forth information regarding all incentive plan awards that Alliant Energy granted to our named executive officers in 2008.2010.

 

Name         

Estimated Possible Payouts Under
Non-Equity Incentive

Plan Awards(1)

  

Estimated Future Payouts

Under Equity Incentive

Plan Awards(4)

      Grant
Date
  Committee
Approval Date
  Estimated Possible Payouts
Under Non-Equity Incentive
Plan Awards(1)
  Estimated Future Payouts
Under Equity Incentive
Plan Awards
  Grant Date Fair
Value of Stock
Awards(4)
 
Grant
Date
  Committee
Approval Date
  

Threshold
($)

20%

  

Target

($)

100%

  

Maximum

($)

200%

  

Threshold
(#)

50%

  Target
(#)
100%
  

Maximum
(#)

200%

  Grant Date Fair
Value of Stock
Awards(5)
   

Threshold

($)

20%

  

Target

($)

100%

  

Maximum

($)

200%

  

Threshold

(#)

50%

  

Target

(#)

100%

  

Maximum

(#)

200%

  
            

William D. Harvey

 1/2/2008(2) 12/12/2007      13,044  26,087  52,174  $1,056,263   2/22/2010(2)    2/11/2010          16,799    33,597    67,194   $1,290,797  
 1/2/2008(3) 12/12/2007        26,087   $1,056,263 
    12/12/2007  $160,550  $802,750  $1,605,500          

Eliot G. Protsch

 1/2/2008(2) 12/12/2007      4,585  9,169  18,338  $371,253 
 1/2/2008(3) 12/12/2007        9,169   $371,253 
    12/12/2007  $69,300  $346,500  $693,000          

William D. Harvey

 2/22/2010(3)   2/11/2010            33,597    $1,093,750  
    2/11/2010   $166,250   $831,250   $1,662,500          
  2/22/2010(2)   2/11/2010          4,441    8,881    17,762   $341,208  

Patricia L. Kampling

 2/22/2010(3)   2/11/2010            8,881    $289,121  
    2/11/2010   $65,000   $325,000   $650,000          
 1/2/2008(2) 12/12/2007      2,894  5,788  11,576  $234,356   2/22/2010(2)   2/11/2010          4,507    9,014    18,028   $346,318  
 1/2/2008(3) 12/12/2007        5,788   $234,356 
    12/12/2007  $41,250  $206,250  $412,500          

Barbara J. Swan

 2/22/2010(3)   2/11/2010            9,014    $293,451  
    2/11/2010   $56,340   $281,700   $563,400          
  2/22/2010(2)   2/11/2010          1,513    3,025    6,050   $116,221  

Dundeana K. Doyle

 2/22/2010(3)   2/11/2010            3,025    $98,479  
    2/11/2010   $25,326   $126,630   $253,260          
 1/2/2008(2) 12/12/2007      1,156  2,312  4,624  $93,613   2/22/2010(2)   2/11/2010          1,516    3,032    6,064   $116,489  
 1/2/2008(3) 12/12/2007        2,312   $93,613 
    12/12/2007  $24,075  $120,375  $240,750          

Dundeana K. Doyle

 1/2/2008(2) 12/12/2007      1,102  2,204  4,408  $89,240 
 1/2/2008(3) 12/12/2007        2,204   $89,240 
    12/12/2007  $20,400  $102,000  $204,000          

Thomas L. Aller

 2/22/2010(3)   2/11/2010            3,032    $98,707  
    2/11/2010   $25,380   $126,900   $253,800          

 

(1)

The amounts shown represent the threshold, target and maximum awards that could have been earned by each of our named executive officers under Alliant Energy’sthe MICP for 20082010 as described more fully under “Compensation Discussion and Analysis Compensation Elements and Design Short-Term Incentives.” The threshold payment level under the MICP was 20% of the target amount. The maximum payment level under the MICP was 200% of the target amount. No payments werePayments earned for 20082010 under the MICP asare shown in the “Non-Equity Compensation Plan” column of the Summary Compensation Table above.Table.

 

(2)

The amounts shown represent the threshold, target and maximum amounts of performance shares that were awarded in 20082010 to the named executive officers under Alliant Energy’s 2002 Equity Incentive Plan as described more fully under “Compensation Discussion and Analysis Compensation Elements and Design Long-Term Incentives.” The threshold amount is 50% of the target amount. The maximum amount is 200% of the target amount.

 

(3)

RepresentsThe amounts shown represent the number of shares of Alliant Energy’s performance contingent restricted stock that were awarded in 20082010 to the named executive officers under the Alliant Energy’s 2002 Equity Incentive Plan as described more fully under “Compensation Discussion and Analysis Compensation Elements and Design Long-Term Incentives.”

(4)

Performance contingent restricted stock awards granted in 20082010 accumulate dividends on the same basis as shares of Alliant Energy’s common stock.

 

(4)

(5)

The grant date fair value of each equity award was computed in accordance with FAS 123(R).Financial Accounting Standards Board Accounting Standards Codification Topic 718. For the performance shares, the fair value at the grant date is based upon the probable outcome of the performance conditions, consistent with the estimate of aggregate compensation cost to be recognized over the service period determined as of the grant date under Topic 718, excluding the effect of estimated forfeitures. The grant date fair value as determined by FASB ASC Topic 718 is $38.42.

OUTSTANDING EQUITY AWARDS AT FISCAL YEAR-END

The following table sets forth information on outstanding Alliant Energy stock option awards and unvested stock awards held by our named executive officers on Dec. 31, 2008.2010.

 

 Option Awards Stock Awards   Option Awards  Stock Awards  

Name

 Number of
Securities
Underlying
Unexercised
Options

Exercisable
(#)
 Number of
Securities
Underlying
Unexercised
Options

Unexercisable
(#)
 Option
Exercise
Price

($)(1)
 Option
Expiration
Date
 Number
of Shares
or Units of
Stock
That Have
Not
Vested

(#)
 Market Value
of Shares

or Units of
Stock

That Have
Not

Vested
($)(2)
 Equity
Incentive
Plan Awards:
Number of
Unearned
Shares,

Units or
Other Rights
That Have
Not Vested

(#)
 Equity
Incentive
Plan Awards:
Market

or Payout
Value of
Unearned
Shares, Units
or
Other Rights
That Have
Not Vested

($)(2)(3)
  
 Number of
Securities
Underlying
Unexercised
Options
Exercisable
(#)
  Number of
Securities
Underlying
Unexercised
Options
Unexercisable
(#)
  

Option
Exercise
Price

($)(1)

  Option
Expiration
Date
  

Number
of Shares
or Units of
Stock
That Have
Not
Vested

(#)

  

Market Value
of Shares
or Units of
Stock
That Have
Not
Vested

($)

  

Equity
Incentive
Plan Awards:
Number of
Unearned
Shares,
Units or
Other Rights
That Have
Not Vested

(#)

  

Equity
Incentive
Plan Awards:
Market
or Payout
Value of
Unearned
Shares, Units
or
Other Rights
That Have
Not Vested

($)(2)

  

William D. Harvey

 21,798  $31.54 1/2/2011        11,258     $25.93    2/9/2014        
11,258  $25.93 2/9/2014                 27,357   $1,005,917   (3)
    31,554 $920,746    (4a)           26,087   $959,219   (4)
      31,931 $931,747  (5)           30,118   $1,107,439   (5)
      24,677 $720,075  (6)           107,098   $3,937,993   (6)
      22,981 $670,586  (7)           39,041   $1,435,538   (7)
      27,167 $792,733  (8)           67,194   $2,470,723   (8)
 26,087 $761,219  (9)               34,731   $1,277,059   (9)

Eliot G. Protsch

     15,777 $460,373    (4b)
      11,300 $329,734  (5)
      9,106 $265,713  (6)
      8,480 $247,446  (7)
      9,549 $278,640  (8)
 9,169 $267,551  (9)
       7,344 $214,298  (5)

Patricia L. Kampling

           1,798   $66,112   (3)
          1,902   $69,937   (4)
          2,196   $80,747   (5)
          22,814   $838,871   (6)
          8,317   $305,816   (7)
          17,762   $653,109   (8)
             9,181   $337,585   (9)

Barbara J. Swan

       6,139 $179,136  (6)           6,806   $250,257   (3)
      5,717 $166,822  (7)           5,788   $212,825   (4)
      6,028 $175,897  (8)           6,682   $245,697   (5) (a)
 5,788 $168,894  (9)           28,518   $1,048,607   (6) (b)

Barbara J. Swan

          10,396   $382,261   (7) (c)
          18,028   $662,890   (8) (d)
             9,318   $342,623   (9) (e)
           1,853   $68,135   (3)
          2,204   $81,041   (4)
          2,545   $93,580   (5)
          9,476   $348,433   (6)

Dundeana K. Doyle

          3,454   $127,004   (7)
          6,050   $222,459   (8)
             3,127   $114,980   (9)
 13,255  $29.88 6/1/2009        17,438     $27.79    5/16/2012        
14,307  $28.59 1/19/2010        17,438     $16.82    1/21/2013        
12,229  $31.54 1/2/2011        18,767     $24.90    1/2/2014        
17,438  $27.79 5/16/2012        2,887     $25.93    2/9/2014        

Thomas L. Aller

17,438  $16.82 1/21/2013                 2,427   $89,241   (3)
18,767  $24.90 1/2/2014                 2,312   $85,012   (4)
2,887  $25.93 2/9/2014                 2,669   $98,139   (5)
      3,104 $90,575  (5)           9,494   $349,094   (6)
      2,189 $63,875  (6)           3,460   $127,224   (7)
      2,039 $59,498  (7)           6,064   $222,973   (8)
      2,408 $70,265  (8)              3,134   $115,237   (9)
 2,312 $67,464  (9)
       2,394 $69,857  (5)
       1,672 $48,789  (6)
      1,557 $45,433  (7)
      2,295 $66,968  (8)

Dundeana K. Doyle

 2,204 $64,313  (9)

 

(1)

The exercise price for all stock option grants is the fair market value of Alliant Energy’s common stock on the date of grant.

 

(2)

The value of unvested shares isvalues in this column are calculated by using the closing price of Alliant Energy’s common stock price of $29.18$36.77 on Dec. 31, 2008.2010.

 

(3)

This column reports dollar amounts that would be received for the equity awards based upon the executive’s achievement at the target performance level, plus dividends accumulated on the performance contingent restricted stock.

(4a)

Time-based restricted stock granted on July 11, 2005. The shares vest 50% and 50% per year in the 4th and 5th years, respectively.

(4b)

Time-based restricted stock granted on July 11, 2005. The shares vest 37.5% and 62.5% per year in the 4th and 5th years, respectively.

(5)

Performance shares granted on Jan. 3, 2006. Vesting occurs if the performance criterion is met in 3 years.

(6)

Performance contingent restricted stock granted on Jan. 3, 2007. Vesting occurs if the performance criterion is met in 3 or 4 years. The values in the table include credited dividend equivalents. These shares vested and are also reported in the Options Exercised and Stock Vested table.

(4)

(7)

Performance shares granted on Jan. 3, 2007.2, 2008. Vesting occurs if the performance criterion is met in 3 years. The values in the table assume target level performance. These shares vested and are also reported in the Options Exercised and Stock Vested table.

 

(5)

(8)

Performance contingent restricted stock granted on Jan. 2, 2008. Vesting occurs if the performance criterion is met in 2, 3 or 4 years. The values in the table included credited dividend equivalents.

 

(6)

(9)

Performance shares granted on Jan. 2, 2008.Feb. 26, 2009. Vesting occurs if the performance criterion is met in 3 years. The values in the table assume maximum level performance.

(7)

Performance contingent restricted stock granted on Feb. 26, 2009. Vesting occurs if the performance criterion is met in 3 or 4 years. The values in the table included credited dividend equivalents.

(8)

Performance shares granted on Feb. 22, 2010. Vesting occurs if the performance criterion is met in 3 years. The values in the table assume maximum level performance.

(9)

Performance contingent restricted stock granted on Feb. 22, 2010. Vesting occurs if the performance criterion is met in 2, 3 or 4 years. The values in the table included credited dividend equivalents.

As a result of Ms. Swan’s retirement, the awards listed above will be prorated pursuant to the terms of her performance contingent restricted stock agreements and performance share agreements as follows:

(a)If the performance criterion is met, Ms. Swan’s award will be prorated at 36/48 or 5,011 shares.

(b)If the performance criterion is met, Ms. Swan’s award will be prorated at 24/36 or 19,012 shares.

(c)If the performance criterion is met, Ms. Swan’s award will be prorated by a fraction, the numerator of which is 24 and the denominator of which is 36 or 48 depending on whether the performance criterion is met in 3 or 4 years, respectively.

(d)If the performance criterion is met, Ms. Swan’s award will be prorated at 12/36 or 6,009 shares.

(e)If the performance criterion is met, Ms. Swan’s award will be prorated by a fraction, the numerator of which is 12 and the denominator of which is 24, 36, 48 depending on whether the performance criterion is met in 2, 3 or 4 years, respectively.

OPTION EXERCISES AND STOCK VESTED

The following table shows a summary of the Alliant Energy stock options exercised by our named executive officers in 2008during 2010 and Alliant Energy stock awards vested for the named executive officers during 2008.2010.

 

  
 Option Awards  Stock Awards 
     Option Awards  Stock Awards 
Name Number of
Shares
Acquired
on Exercise
(#)
  Value
Realized
on Exercise
($)(1)
  Long-Term Incentive Plan Number of
Shares
Acquired
on Vesting
(#)
  

Value
Realized

on

Vesting

($)(2)(3)

  Number of
Shares
Acquired
on Exercise
(#)
  Value
Realized
on Exercise
($)(1)
  Long-Term Incentive Plan Number of
Shares
Acquired
on Vesting
(#)
  Value
Realized
on Vesting
($)(3)(6)
 

William D. Harvey

 0  $0  Time-Based Restricted stock 7,720  $262,634   21,798   $101,677   Time-Based Restricted Stock(2)  17,116   $575,773  
    Performance Shares 51,888  $1,541,852   0   $0   Performance Shares  19,565   $733,785  

Eliot G. Protsch

 0  $0  Time-Based Restricted stock  3,860  $131,317 
    

Performance Shares

 18,363  $545,657 

William D. Harvey

 0   $0   Performance Contingent Restricted Stock  27,653   $1,078,467  
  0   $0   Performance Shares  1,427   $53,520  
 0   $0   Performance Contingent Restricted Stock  1,817   $70,863  

Barbara J. Swan

 0  $0  Performance Shares 11,934  $354,619   0   $0   Time-Based Restricted Stock(4)  1,206   $37,035  

Barbara J. Swan

 0   $0   Time-Based Restricted Stock(5)  2,528   $93,435  
 0   $0   Performance Shares  4,341   $162,809  
 0   $0   Performance Contingent Restricted Stock  6,879   $268,281  
  0   $0   Performance Shares  1,653   $61,996  

Dundeana K. Doyle

 0   $0   Performance Contingent Restricted Stock  1,874   $73,086  
 0  $0  Performance Shares 5,044  $149,882   12,229   $59,311   Performance Shares  1,734   $65,034  

Dundeana K. Doyle

 0  $0  Performance Shares 3,890  $115,591 

Thomas L. Aller

 0   $0   Performance Contingent Restricted Stock  2,454   $95,706  

(1)

Reflects the amount calculated by multiplying the number of options exercised by the difference between the market price of Alliant Energy’s common stock on the exercise date and the exercise price of options.

 

(2)

Reflects an amount calculated (i) by multiplying the number of shares of time-based restricted stock which vested for Messrs.Mr. Harvey and Protsch on July 11, 2008 with a2010, and the market price of Alliant Energy’s common stock, of $34.02; and (ii)which was $33.64, plus dividend equivalents on such shares.

(3)

Reflects an amount calculated by (i) multiplying the vested number of the 2006 performance shares by the market price of Alliant Energy’s common stock on Jan. 2, 20093, 2011 of $29.34,$37.08, plus dividend equivalents on such shares, and (ii) by multiplying the number of vested shares of performance contingent restricted stock, plus accumulated dividends (including fractional amounts not shown), by the market price of Alliant Energy’s common stock on Feb. 28, 2011 of $39.00.

(4)

Reflects an amount calculated by multiplying the number of shares of time-based restricted stock which vested for Ms. Swan on Jan. 5, 2010, and the market price of Alliant Energy’s common stock on that date, which was $30.71, plus dividend equivalents on such shares.

 

(5)

(3)Reflects an amount calculated by multiplying the number of shares of time-based restricted stock, which vested for Ms. Swan on Dec. 31, 2010 due to Ms. Swan’s retirement, and the market price of Alliant Energy’s common stock on that date, which was $36.965, plus dividend equivalents on such shares.

(6)

Executive officers receiving a payout of their performance shares awarded in 2006 for the performance period endingended Dec. 31, 20082010 could elect to receive their award in cash, in shares of Alliant Energy common stock, or partially in cash and partially in Alliant Energy’sEnergy common stock. Messrs. Harvey and Protsch elected to receive 50%All of their awards in Alliant Energy common stock and 50% of their awards in cash. All otherthe named executive officers elected to receive their awards 100% in cash.cash, except Ms. Kampling who received her award 100% in Alliant Energy common stock.

PENSION BENEFITS

The table below sets forth the number of years of credited service, the present value of accumulated benefits and payments during 20082010 for each of our named executive officers under the Alliant Energy Cash Balance Pension Plan, the Excess Retirement Plan and the Supplemental Executive Retirement Plan, or SERP, which are each described below. The disclosed amounts are estimates only and do not necessarily reflect the actual amounts that will be paid to our named executive officers, which will only be known at the time that they become eligible for payment.

 

      
Name 

Plan

Name

 

Number of
Years
Credited
Service

(#)

  

Present
Value of
Accumulated
Benefit

($)(1)

  

Payments
During
2008

($)

  Plan
Name
 

Number of
Years
Credited
Service

(#)

  

Present
Value of
Accumulated
Benefit

($)(1)

  

Payments
During
2010

($)

 

William D. Harvey

 Cash Balance Plan 21.0  $633,000  $0  Cash Balance Plan  21.0   $805,000   $0  

Excess Retirement Plan

 21.4  $1,799,000  $0 

Excess Plan

  23.4   $2,378,000   $0  

SERP

 21.4  $7,443,000  $0 

SERP

  23.4   $7,239,000   $0  
  Total  $9,875,000  $0     Total   $10,422,000   $0  

Eliot G. Protsch

 Cash Balance Plan 28.8  $658,000  $0 

Excess Retirement Plan

 29.2  $857,000  $0 

SERP

 29.2  $3,923,000  $0 
  Total  $5,438,000  $0 

Patricia L. Kampling

 Cash Balance Plan  2.9   $42,000   $0  

Excess Plan

  5.3   $16,000   $0  

SERP

  5.3   $735,000   $0  
   Total   $793,000   $0  

Barbara J. Swan

 Cash Balance Plan 19.6  $523,000  $0  Cash Balance Plan  19.7   $698,000   $0  

Excess Retirement Plan

 20.0  $360,000  $0 

Excess Plan

  22.1   $467,000   $0  

SERP

 20.0  $2,853,000  $0 

SERP

  22.1   $3,546,000   $0  
  Total  $3,736,000  $0     Total   $4,711,000   $0  

Dundeana K. Doyle

 Cash Balance Plan  23.7   $438,000   $0  

Excess Plan

  26.1   $39,000   $0  

SERP

  26.1   $731,000   $0  
   Total   $1,208,000   $0  

Thomas L. Aller

 Cash Balance Plan 15.2  $143,000  $0  Cash Balance Plan  15.2   $179,000   $0  

Excess Retirement Plan

 15.6  $28,000  $0 

Excess Plan

  17.7   $32,000   $0  

SERP

 15.6  $1,408,000  $0 

SERP

  17.7   $1,689,000   $0  
  Total  $1,579,000  $0     Total   $1,900,000   $0  

Dundeana K. Doyle

 Cash Balance Plan 23.6  $336,000  $0 

Excess Retirement Plan

 24.0  $28,000  $0 

SERP

 24.0  $457,000  $0 
  Total  $821,000  $0 

 

(1)

FAS 158 required Alliant Energy to change the measurement date for the plans included in this table from Sept. 30 to Dec. 31 effective for the 2008 fiscal year. The following assumptions, among others, were used:used to calculate the present value of accumulated benefits: that the participant retires at age 62; that the benefit calculation date is Dec. 31, 2008,2010, consistent with Alliant Energy’s accounting measurement date for financial statement reporting purposes; that the discount rate is 6.15%5.35% (compared to 6.20% as of Sept. 30, 2007)5.80% for 2009); that the post-retirement mortality assumption is based on the RP-2000 table with white collar adjustment and a 10-year projection;projection using Scale AA; that the form of payment is 80%70% lump sum and 20%30% annuity; and, for participants who are not yet eligible to retire with a SERP benefit, that the SERP accrues ratably over the participant’s career until such eligibility date. For purposes of the Change in Pension Value and Nonqualified Deferred Compensation Earnings column of the Summary Compensation Table, the actuarial values of the accumulated plan benefits were calculated using an annualized approach whereby the actual change in pension present values from Sept. 30, 2007 to Dec. 31, 2008 was pro-rated by 12/15ths.

Alliant Energy Cash Balance Pension Plan — OurSubstantially all of our salaried employees, including our named executive officers, are eligible to participate in the Alliant Energy Cash Balance Pension Plan, or Pension Plan, that Alliant Energy maintains. 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. 2,1, 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 through Aug. 2, 2008, a participant received annual credits to the account equal to 5% of base pay (including certain incentive payments, pre-tax deferrals and other items). For 1998 and thereafter,through 2008, a participant also receivesreceived an interest credit on all prior accruals equal to 4%, plus a potential share of the gain on the investment return on Pension Plan assets for the year. Alliant Energy amended the Pension Plan’s interest crediting rate for 2009 and future years. The new interest crediting rate will be equal to the annual change in the consumer price index, as of October each year, plus 3%.

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 until Aug. 2, 2008.

All of our named executive officers, participate inwith the Pension Plan andexception of Ms. Kampling, are “grandfathered” under the applicable prior plan benefit formula. BecauseWith the exception of Mr. Aller, their estimated benefits under the applicable prior plan benefit formula are expected to be higher than under the Pension Plan formula, utilizing current assumptions,assumptions. Therefore, the benefits for all of our named executive officers, with the exception of Ms. Kampling and Mr. Aller, would currently be determined under the applicable prior plan benefit formula. To the extent benefits under the Pension Plan are limited by tax law, any excess will be paid under the Excess Retirement Plan described below. Pension Plan accruals ceased as of Aug. 2, 2008. This “freeze” applies to both the 5% of base pay annual credits to the hypothetical account balance and to the grandfathered prior plan formulas. Thereafter,Subsequent to Aug. 2, 2008, active participants receive enhanced benefits under the Alliant Energy 401(k) Savings Plan.

WPL 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. Our named executive officers covered by this prior formula are Messrs.Mr. Harvey and Protsch and Ms. Swan.

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.Table (subject to a limit of $245,000 specified by the Internal Revenue Code). Pension 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 general formula is (i) 55% of final average compensation less 50% of Social Security benefits, the difference multiplied by (ii) a fraction not greater than 1, the numerator of which is the number of years of credit and the denominator of which is 30. This formula provides the basic benefit payable for the life of the participant. If the participant receives an alternative form of payment, then the monthly benefit would be reduced accordingly.

Messrs. Harvey and Protsch and Ms. SwanParticipants are eligible for early retirement becauseif they are over age 55. For each year they would choose to retire and commence benefits prior to age 62, their benefits would be reduced by 5% per year. If benefits commence at or after age 62, there would be no reduction for early commencement prior to the normal retirement age of 65. Mr. Harvey is 61. Ms. Swan was 59 when she retired on Dec. 31, 2010.

IES Industries Pension Plan Prior Formula. Another applicable prior plan formula applies to Ms. Doyle. This formula provides retirement income based on years of service, final average compensation, and Social Security covered compensation. Technically, this formula also applies to Mr. Aller, but his prior plan formula benefit is frozen in the annual amount of $7,607 payable at age 65; therefore, the regularCash Balance Pension Plan formula is expected to apply to him.provide him with a greater benefit.

The benefit formula for Ms. Doyle for service until the Aug. 2, 2008 freeze date is generally the benefit she had accrued under an old formula in existence prior to 1988 plus (i) 1.05% of average monthly compensation for years of service not in excess of 35, plus (ii) 0.50% of average monthly compensation in excess of Social Security covered compensation for years of service not in excess of 35, plus (iii) 1.38% of average monthly compensation for years of service in excess of 35. Compensation generally is the salary amount reported in the Summary Compensation Table (subject to a limit of $245,000 specified by the Internal Revenue Code), with the final average compensation being calculated based on the three highest calendar years of such pay. The formula provides the basic benefit payable for the life of the participant. If the participant receives an alternative form of payment, then the monthly benefit would be reduced accordingly.

Excess Retirement Plan —Alliant Energy maintains an unfunded Excess Retirement 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 Excess Retirement Plan provides an amount equal to the difference

between the actual pension benefit payable under the Pension Plan and Alliant Energy’s actual contributions based on age and service to the 401(k) Savings Plan and what such benefits and contributions would be if calculated without regard to any limitation imposed by the Code on pension benefits or covered compensation.

Supplemental Executive Retirement Plan —Alliant Energy maintains an unfunded Supplemental Executive Retirement Plan, or SERP, to provide incentive for key executives to remain in Alliant Energy’sour service by providing additional compensation that is payable only if the executive remains with Alliant Energyus 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 our named executive officers. Participants in the SERP must be approved by the Compensation and Personnel Committee.

For Messrs.Mr. 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 consecutive 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, the Alliant Energy’sEnergy contributions based on age and service to the 401(k) Savings Plan, and the Excess Retirement 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. Messrs.Mr. Harvey and Protsch and Ms. Swan are currently eligible to electfor early retirement under such provisions. If a participant retires prior to age 62, the 60% payment under the SERP is reduced by 3% per year for each year the participant’s retirement date precedes his/her normal retirement date. The actuarial reduction factor will be waived for participants who have attained age 55 and have a minimum of 10 years of service in a senior executive position with Alliant Energy on or after April 21, 1998. Mr. Harvey and Ms. Swan meet these waiver requirements. Payment of benefits under the SERP commences six months after the participant’s retirement. At the timely election of the participant, benefits under the SERP will be made in a lump sum, in installments over a period of five years, or for the lifetime of the participant.

For Ms. Kampling and 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 consecutive 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, the Alliant Energy’sEnergy contributions based on age and service to the 401(k) Savings Plan, and the unfunded Excess Retirement 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, which age and service requirements Mr. Aller has already satisfied. If a participant retires prior to age 62, the 50% payment under the SERP is reduced by approximately 5% per year for each year the participant’s retirement date precedes his/her normal retirement date. Payment of benefits under the SERP commences six months after the participant’s retirement. 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 five years, or in monthly installments for 18 years. Participants made their elections in December 2008.

For Ms. Doyle, the SERP provides for payments of 60% of the participant’s average annual earnings (base salary and bonus) for the highest paid three consecutive 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, Alliant Energy’sthe company contributions based on age and service to the 401(k) Savings Plan, and the Excess Retirement 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. If a participant retires prior to age 62, the 60% payment under the SERP is reduced by 3% per year for each year the participant’s retirement date precedes his/her normal retirement date. Payment of benefits under the SERP commences six months after the participant’s retirement. At the timely election of the participant, benefits under the SERP will be made in a lump sum, in installments over a period of five years, or in monthly installments for 18 years.

Participants may change their form of payment once, provided that the new election is made at least 12 months prior to their retirement. If such an election is made, benefits under the SERP will not be paid for five years after they otherwise would have been.

For Messrs.Mr. Harvey, and Protsch and Ms. Swan, if the lifetime benefit is selected, and for Mr. Aller and Ms.Mses. Kampling and Doyle, if the monthly benefit is selected, and in either case the participant dies prior to receiving 12 years of payments, payments continue to any surviving spouse or dependent children, payable for the remainder of the 12 year period. In each case, if the five annual installment benefit is selected and the participant dies prior to receiving five annual payments, payments will continue to any surviving spouse or dependent children, payable for the remainder of the five year period. If the participant dies while still employed by Alliant Energy, the designated beneficiary shall receive a lump sum equal to the discounted value of retirement benefits for 12 years. For Messrs.Mr. Harvey and Protsch and Mses. Swan and Doyle, 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.beneficiary in addition to the continuation of benefit payments as described above.

NONQUALIFIED DEFERRED COMPENSATION

The table below sets forth certain information as of Dec. 31, 20082010 for each of our named executive officers with respect to the Alliant Energy Deferred Compensation Plan, which is described below.

 

      
Name 

Executive
Contributions
in 2008

 

($)(1)

  

Registrant
Contributions
in 2008

 

($)(2)

  

Aggregate
Earnings

in 2008

 

($)(3)

  

Aggregate

Withdrawals/

Distributions

 

($)

  

Aggregate
Balance as of
December 31,

2008

($)

 

William D. Harvey

 $837,865  $0  $(181,192) $0  $3,792,344 

Eliot G. Protsch

 $298,159  $5,077  $(179,641) $0  $3,157,723 

Barbara J. Swan

 $98,596  $4,229  $(290,938) $70,186  $864,110 

Thomas L. Aller

 $0  $0  $(92,056) $0  $269,968 

Dundeana K. Doyle

 $0  $0  $(62,772)(4)  $0  $371,731 

Name 

Executive
Contributions
in 2010

($)(1)

  

Company
Contributions
in 2010

($)(2)

  Aggregate
Earnings
in 2010
($)(3)
  

Aggregate
Withdrawals/

Distributions
($)

  

Aggregate
Balance as of
December 31,
2010

($)

 

William D. Harvey

 $306,120   $10,140   $528,552   $0   $5,228,509  

Patricia L. Kampling

 $32,719   $176   $5,900   $0   $49,275  

Barbara J. Swan

 $0   $0   $244,599   $0   $1,217,686  

Dundeana K. Doyle

 $0   $0   $86,644   $0   $495,314  

Thomas L. Aller

 $0   $0   $75,750   $0   $381,198  

 

(1)

The amounts reported are also reported under the “Salary” or “Non-Equity Incentive Plan Compensation” headings in the Summary Compensation Table for 2008 or prior years.2010.

 

(2)

The amounts reported in this column are also reported under the “All Other Compensation” heading in the Summary Compensation Table.

 

(3)

The following portionsportion of the amountsamount reported in this column, which representrepresents above-market interest on deferred compensation, werewas reported in the “Change in Pension Value and Nonqualified Deferred Compensation Earnings” heading in the Summary Compensation Table for 2008 or prior years:2010: Mr. Harvey – $37,938, Mr. Protsch – $37,578, Ms. Swan – $3,478, Mr. Aller – $1,628— $2,922; and Ms. Doyle – $11,349.

(4)— $7,917.

Of this amount, $5,791, which represents above-market interest on deferred compensation, is reported in the “Change in Pension Value and Nonqualified Deferred Compensation Earnings” heading in the Summary Compensation Table for 2008.

Alliant Energy maintains the Alliant Energy Deferred Compensation Plan, or AEDCP, under which participants, including our named executive officers, may defer up to 100% of base salary and annual incentive compensation. Participants who have made the maximum allowed contribution to the Alliant Energy 401(k) Savings Plan may receive an additional credit to the AEDCP. The credit made in January 20092010 was equal to 50% of (a), minus (b), where:

(a) equals the lesser of (i) 8% of base salary for the Plan Year (except that for the credit to be made in early 2009 based on 2008 compensation, such amount shall be the sum of 6% of base salary for the period Jan. 1 through July 31, 2008 plus 8% of base salary for Aug. 1 through Dec. 31, 2008), or (ii) the sum of the amounts (if any) contributed by the participant to the Alliant Energy 401(k) Savings Plan during the applicable year that were eligible for matching contributions under the Alliant Energy 401(k) Savings Plan, plus the amounts deferred by the participant during the applicable year under the AEDCP; and

(b) equals the amount of any matching contributions under the Alliant Energy 401(k) Savings Plan on behalf of the participant for the applicable year.

The participant may elect to have his or her deferrals credited to an Interest Account, Equity Account or thean Alliant Energy Stock Account. Deferrals and matching contributions to the Interest Account receive an annual return based on the 10-year Treasury Bond Rate plus 1.50% as established by the Federal Reserve. Deferrals and matching contributions credited to the Equity Account are treated as invested in an S&P 500 index fund. Beginning in 2011, participants may have their deferrals credited to additional investment accounts, which will be treated as invested in a mutual fund or other investment vehicle offered under the Alliant Energy 401(k) Savings Plan as selected by our Investment Committee. Deferrals and matching contributions credited to the Alliant Energy Stock Account are treated as though invested in Alliant EnergyEnergy’s common stock and are credited with dividend equivalents, which are treated as if reinvested. The shares of Alliant EnergyEnergy’s common stock identified as obligations under the AEDCP are held in a rabbi trust. Payments from the AEDCP due to death or retirement may be made in a lump sum or in annual installments for up to 10 years at the election of the participant. Payments from the AEDCP for any reason other than death or retirement are made in a lump sum. Participants are selected by our chief executive officer. Messrs. Harvey Protsch and Aller, and Mses. Kampling, Swan and Doyle are participants in the AEDCP.

Alliant Energy maintains a frozen legacy deferred compensation plan, the IES Deferred Compensation Plan, in which Ms. Doyle maintains a frozen account. An interest credit is provided for the balance in the account at a rate of 11% for the balance in the account prior to July 1, 1993 and 9% on the remainder of the account. This plan was frozen on April 21, 1998 and no amounts have been deferred to the account since then.

POTENTIAL PAYMENTS UPON TERMINATION OR

OR CHANGE IN CONTROL

The following tables describe potential payments and benefits under ourAlliant Energy’s compensation and benefit plans and arrangements to which our named executive officers would be entitled upon termination of employment or change in control of Alliant Energy. The estimated amount of compensation payable to each of our named executive officers (with the exception of Ms. Swan) in each situation is listed in the tables below assuming that the termination and/or change in control of Alliant Energy occurred at Dec. 31, 20082010 and that Alliant Energy’s common stock is valued at $29.18,$36.77, which was the closing market price for ourAlliant Energy’s common stock on Dec. 31, 2008.2010. The actual amount of payments and benefits can only be determined at the time of such a termination or change in control and therefore the actual amounts will vary from the estimated amounts in the tables below. Descriptions of the circumstances that would trigger payments or benefits to our named executive officers, how such payments and benefits are determined under the circumstances, material conditions and obligations applicable to the receipt of payments or benefits and other material factors regarding such agreements and plans, as well as other material assumptions that we have made in calculating the estimated compensation, follow these tables. The table below for Ms. Swan shows only the retirement amounts due to her retirement on Dec. 31, 2010.

 

William D. Harvey Death  Disability  Involuntary
Termination
Without
Cause
  Retirement  Change In
Control and
Termination
without
Cause or for
Good
Reason
  Change In
Control
without
Termination
  Death  Disability  Involuntary
Termination
Without
Cause
  Retirement  Change In
Control and
Termination
without
Cause or for
Good
Reason
  Change In
Control
without
Termination
 

Triggered Payouts

                      

Cash Termination Payment

 $—           $—           $845,000    $—           $4,943,250    $—           $—         $—         $875,000   $—         $5,118,750   $—        

Life, Medical, Dental Insurance Continuation

 $—         $—         $5,034  $—         $237,071  $—         $—         $—         $5,930   $—         $277,204   $—        

Lump Sum SERP

 $—         $—         $—         $—         $—         $—         $—         $—         $—         $—         $—         $—        

Unvested Stock Options

 $—         $—         $—         $—         $—         $—         $—         $—         $—         $—         $—         $—        

Unvested Restricted Stock

 $920,746  $920,746  $920,746  $920,746  $920,746  $920,746  $—         $—         $—         $—         $—         $—        

Unearned Performance Contingent Restricted Stock

 $558,243  $558,243  $558,243  $558,243  $558,243  $558,243  $2,490,138   $2,490,138   $2,490,138   $2,490,138   $2,490,138   $2,490,138  

Unearned Performance Shares

 $700,797  $700,797  $700,797  $700,797  $700,797  $700,797  $1,724,452   $1,724,452   $1,724,452   $1,724,452   $1,724,452   $1,724,452  

Outplacement Services

 $—         $—         $10,000  $—         $84,500  $—         $—         $—         $10,000   $—         $87,500   $—        

Tax Preparation Assistance

 $—         $—         $—         $—         $15,000  $—         $—         $—         $—         $—         $—         $—        

Legal and Accounting Advisor Services

 $—         $—         $—         $—         $10,000  $—         $—         $—         $—         $—         $10,000   $—        

Excise Tax Gross Up

  n/a   n/a   n/a   n/a  $2,688,942  $—          n/a    n/a    n/a    n/a   $3,955,322   $—        

Life Insurance Proceeds

 $2,227,797  $—         $—         $—         $—         $—         $2,891,235   $—         $—         $—         $—         $—        

Total Pre-tax Benefit

 $4,407,583  $2,179,786  $3,039,820  $2,179,786  $10,158,549  $2,179,786  $7,105,825   $4,214,590   $5,105,520   $4,214,590   $13,663,366   $4,214,590  

Eliot G. Protsch Death  Disability  Involuntary
Termination
Without
Cause
  Retirement  Change In
Control and
Termination
without
Cause or for
Good
Reason
  Change In
Control
without
Termination
 
Patricia L. Kampling Death  Disability  Involuntary
Termination
Without
Cause
  Retirement  Change In
Control and
Termination
without
Cause or for
Good
Reason
  Change In
Control
without
Termination
 

Triggered Payouts

                      

Cash Termination Payment

 $—           $—           $495,000    $—           $2,524,500    $—           $—         $—         $500,000   $—         $2,475,000   $—        

Life, Medical, Dental Insurance Continuation

 $—         $—         $7,742  $—         $141,438  $—         $—         $—         $9,176   $—         $59,544   $—        

Lump Sum SERP

 $—         $—         $—         $—         $—         $—         $—         $—         $—         $—         $973,000   $—        

Unvested Stock Options

 $—         $—         $—         $—         $—         $—         $—         $—         $—         $—         $—         $—        

Unvested Restricted Stock

 $460,373  $460,373  $460,373  $460,373  $460,373  $460,373  $—         $—         $—         $—         $—         $—        

Unearned Performance Contingent Restricted Stock

 $202,509  $202,509  $202,509  $202,509  $202,509  $202,509  $397,153   $397,153   $397,153   $397,153   $397,153   $397,153  

Unearned Performance Shares

 $254,148  $254,148  $254,148  $254,148  $254,148  $254,148  $388,475   $388,475   $388,475   $388,475   $388,475   $388,475  

Outplacement Services

 $—         $—         $10,000  $—         $49,500  $—         $—         $—         $10,000   $—         $50,000   $—        

Tax Preparation Assistance

 $—         $—         $—         $—         $15,000  $—         $—         $—         $—         $—         $—         $—        

Legal and Accounting Advisor Services

 $—         $—         $—         $—         $10,000  $—         $—         $—         $—         $—         $10,000   $—        

Excise Tax Gross Up

  n/a   n/a   n/a   n/a  $—         $—        

Excise Tax Cut Back

  n/a    n/a    n/a    n/a    n/a    n/a  

Life Insurance Proceeds

 $1,619,461  $—         $—         $—         $—         $—         $—         $—         $—         $—         $—         $—        

Total Pre-tax Benefit

 $2,536,491  $917,030  $1,429,772  $917,030  $3,657,468  $917,030  $785,628   $785,628   $1,304,804   $785,628   $4,353,172   $785,628  

 

Barbara J. Swan Death  Disability  Involuntary
Termination
Without
Cause
  Retirement  Change In
Control and
Termination
without
Cause or for
Good
Reason
  Change In
Control
without
Termination
 

Triggered Payouts

          

Cash Termination Payment

 $—           $—           $375,000    $—           $1,743,750    $—          

Life, Medical, Dental Insurance Continuation

 $—         $—         $5,034  $—         $75,908  $—        

Lump Sum SERP

 $—         $—         $—         $—         $—         $—        

Unvested Stock Options

 $—         $—         $—         $—         $—         $—        

Unvested Restricted Stock

 $—         $—         $—         $—         $—         $—        

Unearned Performance Contingent Restricted Stock

 $133,557  $133,557  $133,557  $133,557  $133,557  $133,557 

Unearned Performance Shares

 $167,513  $167,513  $167,513  $167,513  $167,513  $167,513 

Outplacement Services

 $—         $—         $10,000  $—         $37,500  $—        

Tax Preparation Assistance

 $—         $—         $—         $—         $15,000  $—        

Legal and Accounting Advisor Services

 $—         $—         $—         $—         $10,000  $—        

Excise Tax Gross Up

  n/a   n/a   n/a   n/a  $—         $—        

Life Insurance Proceeds

 $370,923  $—         $—         $—         $—         $—        

Total Pre-tax Benefit

 $671,993  $301,070  $691,104  $301,070  $2,183,228  $301,070 

Thomas L. Aller Death  Disability  Involuntary
Termination
Without
Cause
  Retirement  Change In
Control and
Termination
without
Cause or for
Good
Reason
  Change In
Control
without
Termination
 

Triggered Payouts

            
Barbara J. Swan Death  Disability  Involuntary
Termination
Without
Cause
  Retirement(1)  Change In
Control and
Termination
without
Cause or for
Good
Reason
  Change In
Control
without
Termination
 

Triggered Payments

  N/A    N/A    N/A      N/A    N/A  

Cash Termination Payment

 $—           $—           $267,500    $—           $775,750    $—                 $—            

Life, Medical, Dental Insurance Continuation

 $—         $—         $5,034  $—         $23,758  $—               $—            

Lump Sum SERP

 $—         $—         $—         $—         $—         $—               $—            

Unvested Stock Options

 $—         $—         $—         $—         $—         $—               $—            

Unvested Restricted Stock

 $—         $—         $—         $—         $—         $—               $—            

Unearned Performance Contingent Restricted Stock

 $49,518  $49,518  $49,518  $49,518  $49,518  $49,518        $614,758      

Unearned Performance Shares

 $62,153  $62,153  $62,153  $62,153  $62,153  $62,153        $460,017      

Outplacement Services

 $—         $—         $10,000  $—         $26,750  $—               $—            

Tax Preparation Assistance

 $—         $—         $—         $—         $—         $—               $—            

Legal and Accounting Advisor Services

 $—         $—         $—         $—         $10,000  $—               $—            

Excise Tax Cut Back

  n/a   n/a   n/a   n/a  $—          n/a 

Excise Tax Gross Up

        N/A      

Life Insurance Proceeds

 $—         $—         $—         $—         $—         $—               $—            

Total Pre-tax Benefit

 $111,671  $111,671  $394,205  $111,671  $947,929  $111,671        $1,074,775      

 

Dundeana K. Doyle Death  Disability  Involuntary
Termination
Without
Cause
  Retirement  Change In
Control and
Termination
without
Cause or for
Good
Reason
  Change In
Control
without
Termination
 

Triggered Payouts

          

Cash Termination Payment

 $—           $—           $255,000    $—           $714,000    $—          

Life, Medical, Dental Insurance Continuation

 $—         $—         $—         $—         $20,628  $—        

Lump Sum SERP

 $—         $—         $—         $—         $1,111,000  $—        

Unvested Stock Options

 $—         $—         $—         $—         $—         $—        

Unvested Restricted Stock

 $—         $—         $—         $—         $—         $—        

Unearned Performance Contingent Restricted Stock

 $41,144  $41,144  $41,144  $41,144  $41,144  $41,144 

Unearned Performance Shares

 $51,726  $51,726  $51,726  $51,726  $51,726  $51,726 

Outplacement Services

 $—         $—         $10,000  $—         $25,500  $—        

Tax Preparation Assistance

 $—         $—         $—         $—         $—         $—        

Legal and Accounting Advisor Services

 $—         $—         $—         $—         $10,000  $—        

Excise Tax Cut Back

  n/a   n/a   n/a   n/a  $(52,028)  n/a 

Life Insurance Proceeds

 $299,308  $—         $—         $—         $—         $—        

Total Pre-tax Benefit

 $392,178  $92,870  $357,870  $92,870  $1,921,970  $92,870 
(1)

Amounts in this column were calculated based on prorated shares at target performance. Ms. Swan is eligible to receive payments after the performance periods end if the performance criteria are met.

Dundeana K. Doyle Death  Disability  Involuntary
Termination
Without
Cause
  Retirement  Change In
Control and
Termination
without
Cause or for
Good
Reason
  Change In
Control
without
Termination
 

Triggered Payouts

            

Cash Termination Payment

 $—         $—         $281,400   $—         $816,060   $—        

Life, Medical, Dental Insurance Continuation

 $—         $—         $9,176   $—         $57,535   $—        

Lump Sum SERP

 $—         $—         $—         $—         $659,000   $—        

Unvested Stock Options

 $—         $—         $—         $—         $—         $—        

Unvested Restricted Stock

 $—         $—         $—         $—         $—         $—        

Unearned Performance Contingent Restricted Stock

 $216,575   $216,575   $216,575   $216,575   $216,575   $216,575  

Unearned Performance Shares

 $153,221   $153,221   $153,221   $153,221   $153,221   $153,221  

Outplacement Services

 $—         $—         $10,000   $—         $28,140   $—        

Tax Preparation Assistance

 $—         $—         $—         $—         $—         $—        

Legal and Accounting Advisor Services

 $—         $—         $—         $—         $10,000   $—        

Excise Tax Cut Back

  n/a    n/a    n/a    n/a   $(114,700  n/a  

Life Insurance Proceeds

 $373,889   $—         $—         $—         $—         $—        

Total Pre-tax Benefit

 $743,685   $369,796   $670,372   $369,796   $1,825,831   $369,796  

Thomas L. Aller Death  Disability  Involuntary
Termination
Without
Cause
  Retirement  Change In
Control and
Termination
without
Cause or for
Good
Reason
  Change In
Control
without
Termination
 

Triggered Payouts

            

Cash Termination Payment

 $—         $—         $282,000   $—         $817,800   $—        

Life, Medical, Dental Insurance Continuation

 $—         $—         $5,930   $—         $29,562   $—        

Lump Sum SERP

 $—         $—         $—         $—         $—         $—        

Unvested Stock Options

 $—         $—         $—         $—         $—         $—        

Unvested Restricted Stock

 $—         $—         $—         $—         $—         $—        

Unearned Performance Contingent Restricted Stock

 $221,392   $221,392   $221,392   $221,392   $221,392   $221,392  

Unearned Performance Shares

 $153,527   $153,527   $153,527   $153,527   $153,527   $153,527  

Outplacement Services

 $—         $—         $10,000   $—         $28,200   $—        

Tax Preparation Assistance

 $—         $—         $—         $—         $—         $—        

Legal and Accounting Advisor Services

 $—         $—         $—         $—         $10,000   $—        

Excise Tax Cut Back

  n/a    n/a    n/a    n/a    n/a    n/a  

Life Insurance Proceeds

 $—         $—         $—         $—         $—         $—        

Total Pre-tax Benefit

 $374,919   $374,919   $672,849   $374,919   $1,260,481   $374,919  

Change in Control Agreements

Alliant Energy currently has in effect Key Executive Employment and Severance Agreements, or KEESAs, with our executive officers, including our named executive officers, and certain of our key employees.employees, except Ms. Swan who retired on Dec. 31, 2010. 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 (in the case of Mr. Harvey Mr. Protsch and Ms. Swan)Kampling) or two years (in the case of Mr. Aller orand Ms. Doyle) after a change in control of Alliant Energy (as defined below), the officer’s employment is ended through

(a) termination by Alliant Energy, other than by reason of death or disability or for cause (as defined below) or (b) termination by the officer for good reason (as defined below).

The KEESAs provide the following benefits, each of which are reflected in the tables above assuming the maximum potential amounts payable pursuant to the terms of the KEESAs:

 

reimbursement for up to 10% of the officer’s annual base salary for outplacement services;

 

continuation of life, hospital, medical and dental insurance coverage for up to three years (in the case of Mr. Harvey Mr. Protsch and Ms. Swan)Kampling) or two years (in the case of Mr. Aller orand Ms. Doyle);

 

full vesting of the officer’s accrued benefit under any supplemental executive retirement plan, or SERP, and in any defined contribution retirement plan and deemed satisfaction of any minimum years of service requirement under the SERP (the amounts shown in the tables above assume a lump sum form of payment under the SERP using the 20082010 lump sum interest rate of 4.63%3.21% and a single life annuity or lump sum payment under Alliant Energy’s qualified Cash Balance Pension Plan and nonqualified Unfunded Excess Plan), provided that the SERP benefit will not be received until the executive officer reaches age 55;

 

full vesting of any time-based restricted stock and stock options;

 

payment at target of all performance plan awards pursuant to any long-term incentive plan on a pro rata basis unless the award cycle has been in effect less than six months;

 

a cash termination payment of up to three times (in the case of Mr. Harvey Mr. Protsch and Ms. Swan)Kampling) or two times (in the case of Mr. Aller and Ms. Doyle) the sum of the officer’s annual base salary and the greater of the officer’s target bonus for the year in which the termination date occurs or the officer’s bonus in the year prior to the change in control which is immediately payable up to $460,000$490,000 (the limit provided in Section 409A of the Internal Revenue Code), with any amounts over $460,000$490,000 payable in six months after the termination date; and

 

reimbursement for up to $10,000 in legal or accounting advisor fees.

In addition, the KEESAsKEESA for Mr. Harvey Mr. Protsch and Ms. Swan provideprovides that if the aggregate payments under the KEESA or otherwise are an “excess parachute payment” for purposes of the Internal Revenue Code, then Alliant Energy will pay the officer the amount necessary to offset the 20% excise tax imposed by the Internal Revenue Code and any additional taxes on this payment. In determining the amount of the excise tax gross-up included in the tables above, weAlliant Energy made the following material assumptions: a Section 280G excise tax rate of 20%, a 35% federal income tax rate, a 1.45% Medicare tax rate, a 6.75%7.75% state income tax rate for Mr. Harvey and Ms. Swan and a 8.98% state income tax rate for Mr. Protsch;Harvey; the calculation also assumes that Alliant Energy would pay 18 months of COBRA coverage, the performance period for outstanding performance contingent restricted stock would be two years and that Alliant Energy can prove that the awards of performance contingent restricted stock and performance shares in 20082010 were not made in connection with or contemplation of a change of control of Alliant Energy. Furthermore, it was assumed that no value will be attributed to reasonable compensation under any non-competition agreement. At the time of any change in control, a value may be so attributed, which would result in a reduction of amounts subject to the excise tax. The KEESA for Ms. Kampling provides that if any portion of the benefits under the KEESA or under any other agreement would constitute an excess parachute payment for purposes of the Internal Revenue Code, she may receive the better of either a payment $1 less than the maximum amount she may receive without becoming subject to the 20% excise tax, or receive the fully calculated payment subject to applicable excise taxes, for which she would be personally responsible. The KEESAs for Mr. Aller and Ms. Doyle provide that if the aggregate payments under the KEESA or otherwise are an “excess parachute payment,” then the payments will be reduced so that the officer will be entitled to receive $1 less than the maximum amount which the officer could receive without becoming subject to the 20% excise tax or which weAlliant Energy may pay without loss of deduction under the Internal Revenue Code. For Mr. Aller and Ms. Doyle, the potential payment and benefit amounts shown in the tables above reflect this cutback provision from their KEESAs.her KEESA.

In consideration of the KEESA benefits, the executive officer agrees not to compete with Alliant Energy andor us for a period of one year after the executive officer leaves employmentAlliant Energy and to keep in confidence any proprietary information or confidential information for a period of five years after the executive officer leaves Alliant Energy. Both of these conditions can be waived in writing by ourAlliant Energy’s Board of Directors.

Under the KEESAs, a “change in control” is deemed to have occurred if:

 

any person is or becomes the beneficial owner of securities representing 20% or more of Alliant Energy’s outstanding shares of common stock or combined voting power;

 

there is a change in the composition of Alliant Energy’s Board of Directors that is not approved by at least two-thirds of the existing directors;

Alliant Energy’s shareowners approve a merger, consolidation or share exchange with any other corporation (or the issuance of voting securities in connection with a merger, consolidation or share exchange) in which Alliant Energy’s shareowners control less than 50% of combined voting power after the merger, consolidation or share exchange;

 

Alliant Energy’s shareowners approve of a plan of complete liquidation or dissolution or an agreement for the sale or disposition by Alliant Energy of all or substantially all of its assets.

Under the KEESAs, the term “cause” means:

 

engaging in intentional conduct that causes Alliant Energy demonstrable and serious financial injury;

 

conviction of a felony that substantially impairs the officer’s ability to perform duties or responsibilities; or

 

continuing willful and unreasonable refusal by an officer to perform duties or responsibilities.

Under the KEESAs, the term “good reason” means:

 

a material breach of the agreement by Alliant Energy;

 

a material diminution in the officer’s base compensation;

 

a material diminution in the officer’s authority, duties, or responsibilities, including a material diminution in the budget over which he or she retains authority; or

 

a material diminution in the authority, duties, or responsibilities of the supervisor to whom the officer is required to report, including a requirement that he or she report to a corporate officer or employee instead of reporting directly to the board of directors.

Stock Option Agreements

The agreements under which Alliant Energy has awarded Alliant Energy stock options to our executive officers provide that:

 

if the officer’s employment is terminated by reason of death or disability, then the options will immediately vest and remain exercisable for twelve months after such termination;

 

if the officer’s employment is terminated by reason of retirement after satisfying the minimum requirements for early retirement under the Alliant Energy Cash Balance Pension Plan, then the options will immediately vest and may be exercised for three years after such termination; and

 

upon a change in control of Alliant Energy, which is defined in the same manner as under the KEESAs except that the trigger for a merger consolidation or share exchange will only be triggered upon consummation of such a transaction, the options will immediately vest and become exercisable.

The tables above include the amounts by which the closing priceNone of Alliant Energy’s common stock on Dec. 31, 2008 exceeds the exercise price for unvested options held by our named executive officers.

Restricted Stock Agreements

The agreements under which Alliant Energy has awarded restricted stock to our executive officers provide that the forfeiture restrictions on such restricted stock will immediately lapse upon:

a change in control of Alliant Energy, which is defined in the same manner as under the KEESAs;

the termination of the officer’s employment by reason of death or disability; and

the termination of the officer’s employment without cause, which is defined in the same manner as under the KEESAs.

The tables above include the amounts attributable to unvested restricted stock held by our named executive officers valued at the closing price of Alliant Energy’s commonhave unvested stock on Dec. 31, 2008.options.

Performance Contingent Restricted Stock Agreements and Performance Share Agreements

The agreements under which Alliant Energy has awarded performance contingent restricted stock and performance shares to our executive officers provide that:

 

if the performance contingency under the award is satisfied and if the officer’s employment is terminated by reason of death, disability, involuntary termination without cause (which means the admission by or conviction of the officer of an act of fraud, embezzlement, theft, or other criminal act constituting a felony involving moral turpitude) or retirement (which means after the officer has reached age 55 with 10 years of service), then the officer will be entitled to a prorated number of shares based on the ratio of the number of months the officer was employed during the performance period to the total number of months in the performance period; and

 

if a change in control of Alliant Energy, which is defined in the same manner as under the KEESAs except that the trigger for a merger consolidation or share exchange will only be triggered upon consummation of such a transaction, at least 180 days after the date of the award, then the officer will be entitled to a prorated number of shares based on the ratio of the number of months the officer was employed during the performance period up to the change in control to 36 (unless the performance period was already into its fourth year, in which case the denominator would be 48).36.

The tables above include the amounts attributable to the pro rata shares that would be received by our named executive officers valued at the closing price of Alliant Energy’s common stock on Dec. 31, 20082010 assuming, in the case of a termination by reason of death, disability, involuntary termination without cause or retirement, that the applicable performance contingency was satisfied.satisfied at target level performance.

Executive Severance Plan

Alliant Energy also maintains a general executive severance plan for our executive officers and general managers that applies when the officer’s or manager’s position is eliminated or significantly altered by Alliant Energy.us. The plan provides for a minimum level of severance pay equal to one times base salary, except that any amount over the Internal Revenue Code Section 409A limit (currently about $460,000)$490,000) will be delayed for six months, payment of pro-ratedprorated incentive compensation as within the discretion of the chief executive officer, up to 18 months of COBRA coverage, six months of which are paid by us,Alliant Energy, outplacement services and/or tuition reimbursement of up to $10,000, and access to ourAlliant Energy’s employee assistance program. Eligibility for benefits under this plan is conditioned upon the executive executing a severance agreement and release form. All executive officer severance packages are approved by the Compensation and Personnel Committee.

Life Insurance Proceeds

The amounts shown in the tables above reflect proceeds to be paid to the executive officer’s beneficiaries pursuant to life insurance policies Alliant Energy offers that are not otherwise available to all employees (i.e., split dollar and/or reverse split dollar policies, as applicable).

Pension Plans

The tables above do not include any amounts for the Alliant Energy Cash Balance Pension Plan or the unfunded Excess Retirement Plan because those plans are not impacted by the nature of the termination of employment nor whether or not there has been a change in control of Alliant Energy. The tables above also do not include any amounts for the Supplemental Executive Retirement Plan other than in the event of a termination after a change in control because that plan is not impacted by the nature of the termination of employment unless there has been a change in control of Alliant Energy, in which case the benefits under the Supplemental Executive Retirement Plan may be enhanced under the KEESA as described above under “Change in Control Agreements.”

Compensation Committee Risk Assessment

In December 2010, the Compensation and Personnel Committee undertook an assessment of our general compensation policies and practices for all employees, including Alliant Energy’s non-regulated businesses, to evaluate whether risks arising from these policies and practices were reasonably likely to have a material adverse effect on us. The Committee did not recommend or implement any material changes in 2011 as a result of its assessment, but has identified or implemented the following features of Alliant Energy’s policies and practices that it believes serve to mitigate any risks arising from Alliant Energy’s compensation policies and practices:

Use of a mix of short-term and long-term incentive awards to provide an appropriate balance of short and long-term risk and reward horizons;

Use of a variety of performance metrics for incentive awards to avoid excessive focus on a single measure of performance;

Caps on incentive awards to reduce incentives to take short-term or inappropriately risky measures to increase payouts in any given year;

Review of our compensation programs for reasonableness by our state utility commission mitigates risk;

Claw-back policies that provide Alliant Energy with the ability to recoup short-term and long-term incentive awards under appropriate circumstances; and

Stock ownership requirements for certain executives, including our named executive officers, which we believe help to focus our executives on long-term stock price appreciation and sustainability.

PROPOSAL TWO

ADVISORY VOTE ON COMPENSATION OF OUR NAMED EXECUTIVE OFFICERS

We and Alliant Energy view executive compensation as an important matter both to us and to our shareowners. We are asking shareowners to vote, on a non-binding basis, on a resolution approving the compensation of our named executive officers as disclosed in the Compensation Discussion and Analysis section and the accompanying compensation tables and narrative discussion contained in this Proxy Statement.

Alliant Energy has in the past sought approval from its shareowners regarding incentive compensation plans. Those incentive plans, including the Alliant Energy 2010 Omnibus Incentive Plan approved by Alliant Energy’s shareowners at the Alliant Energy 2010 Annual Meeting of Shareowners, make up a significant amount of the pay that we and Alliant Energy provide to our executives. This incentive plan enables us to motivate our employees and focus them on our financial and strategic objectives. These financial and strategic objectives are important to executing Alliant Energy’s strategic plan, delivering long-term value to our shareowners and customers, and sustaining our credibility with investors.

The Compensation and Personnel Committee of our Board of Directors has overseen the development and implementation of the executive compensation programs. Alliant Energy has designed compensation programs to align management interests with the interests of our shareowners and customers by directly linking a significant portion of the compensation of our named executive officers to defined performance standards that promote balance between the drive for near-term growth and long-term increase in shareowner value. The Committee also designed our compensation programs to attract, retain and motivate key executives who are essential to the implementation of Alliant Energy’s strategic growth and development strategy. We are, therefore, as required by Section 14A of the Securities Exchange Act of 1934, asking shareowners to vote in favor of the resolution below.

The Committee bases its executive compensation decisions on the core compensation objectives as more fully described in the Compensation Discussion and Analysis, including the following:

furthering Alliant Energy’s strategic plan by strengthening the relationship between pay and performance by emphasizing variable at-risk compensation;

aligning executives’ and employees’ interests with those of our shareowners and our customers; and

ensuring that we attract and retain talented employees through competitive compensation that is comparable to other similar companies.

We believe that Alliant Energy’s existing compensation programs have been effective at motivating our key executives, including our named executive officers, to achieve enhanced performance and results for our company, effectively aligning compensation with performance results, giving our executives an ownership interest in Alliant Energy so their interests are aligned with its shareowners, and enabling us to attract and retain talented executives whose services are in key demand in our industry and market sectors.

With the core compensation objectives in mind, the Committee has taken compensation actions in recent years including the following:

maintaining Alliant Energy base salaries close to the median of our market reference point for similar positions;

maintaining the structure of Alliant Energy’s short-term and long-term incentive awards generally to provide compensation around the median of Alliant Energy’s market reference point for similar positions;

setting performance objectives which are consistent with our pay for performance philosophy resulting in the first corporate short-term incentive payment in three years for 2010;

structuring a new Alliant Energy change-in-control agreement for our newest executive vice president that does not include excise tax gross-ups;

structuring Alliant Energy’s short-term incentive plan for fiscal year 2010 on the basis of forecasted performance of our company rather than simply basing the awards on historical results;

establishing a claw-back policy for short-term incentives and designing incentive plan features that mitigate risk to shareowners; and

eliminating a flexible perquisite program and limiting the number and value of other perquisites.

As a reflection of our emphasis on performance standards and variable at-risk compensation, all of Alliant Energy’s short-term (annual) and equity-based awards in 2010 were granted contingent upon the achievement of performance goals. As a result, on average in the aggregate, approximately 70% of our named executive officers’ target total compensation for 2010 was dependent on performance. Alliant Energy did not grant any equity-based awards in 2010 that were subject only to time-based vesting conditions.

Alliant Energy will continue to design and implement our executive compensation programs and policies in line with our philosophy to promote superior performance results and generate greater value for our shareowners and customers.

The Board would like the support of our shareowners for the compensation of our named executive officers as disclosed in this Proxy Statement. This advisory vote on the compensation of our named executive officers allows our shareowners to express their opinions about our executive compensation programs. As we seek to align our executive compensation programs with our performance results and shareowners’ interests, we ask that our shareowners approve the compensation of our named executive officers. Accordingly, for the reasons we discuss above, the Board recommends that shareowners vote in favor of the following resolution:

RESOLVED, that the shareowners approve, on an advisory basis, the compensation of the named executive officers as disclosed pursuant to Item 402 of Regulation S-K, including the Compensation Discussion and Analysis section and the compensation tables and narrative discussion contained in this Proxy Statement.”

The votes cast “for” must exceed the votes cast “against” the proposal at the Annual Meeting (assuming a quorum is present) to approve the compensation of our named executive officers as disclosed in this proxy statement. For purposes of determining the vote required for this proposal, abstentions and broker non-votes will have no impact on the vote. This advisory vote on the compensation of our named executive officers is not binding on us, our Board or the Compensation and Personnel Committee. However, our Board and the Committee will review and consider the outcome of this advisory vote when making future compensation decisions for our named executive officers.

The Board of Directors recommends a vote “FOR” approval of the compensation of our named executive officers as disclosed in this proxy statement.

PROPOSAL THREE

ADVISORY VOTE ON THE FREQUENCY OF THE ADVISORY VOTE ON COMPENSATION

OF OUR NAMED EXECUTIVE OFFICERS

We are also seeking a vote, on a non-binding, advisory basis, on a resolution regarding the frequency of the advisory vote on the compensation of our named executive officers as disclosed pursuant to the executive compensation disclosure rules of the SEC. Shareowners may vote to approve holding an advisory vote on the compensation of our named executive officers, as required by Section 14A of the Securities Exchange Act of 1934, every one, two or three years.

After considering the benefits and consequences of each option for the frequency of submitting the advisory vote on the compensation of our named executive officers to shareowners, the Board recommends submitting the advisory vote on the compensation of our named executive officers to our shareowners annually.

We believe an annual advisory vote on the compensation of our named executive officers will allow us to obtain information on shareowners’ views of the compensation of our named executive officers on a more consistent basis. In addition, we believe an annual advisory vote on the compensation of our named executive officers will provide our and Alliant Energy’s Board and the Compensation and Personnel Committee with frequent input from shareowners on our compensation programs for our named executive officers. Finally, we believe an annual advisory vote on the compensation of our named executive officers promotes corporate transparency while also allowing shareowners frequent direct input on our and Alliant Energy’s compensation philosophy, policies and programs.

For the reasons discussed above, the Board recommends that shareowners vote in favor of holding an advisory vote on the compensation of our named executive officers at an annual meeting of shareowners every year. In voting on this advisory vote on the frequency of the advisory vote on the compensation of our named executive officers, shareowners should be aware that they are not voting “for” or “against” the Board’s recommendation to vote for a frequency of every year for holding future advisory votes on the compensation of our named executive officers. Rather, shareowners will be casting votes to recommend an advisory vote on the compensation of our named executive officers which may be every one, two or three years, or they may abstain entirely from voting on the proposal.

The particular frequency of the advisory vote on the compensation of our named executed officers receiving the greatest number of votes for such frequency at the Annual Meeting (assuming a quorum is present) will be the frequency of the advisory vote on the compensation of our named executive officers that shareowners approve. Abstentions and broker non-votes will not constitute a vote for any particular frequency. The option on the frequency of the advisory vote on the compensation of our named executive officers that receives the most votes from shareowners will be considered by the Board and Compensation and Personnel Committee as the shareowners’ recommendation as to the frequency of future advisory votes on the compensation of our named executive officers. However, the outcome of this advisory vote on the frequency of the advisory vote on the compensation of our named executive officers is not binding on us or our or Alliant Energy’s Board. Nevertheless, our Board will review and consider the outcome of this vote when making determinations as to when the advisory vote on the compensation of our named executive officers will again be submitted to shareowners for approval at an annual meeting of shareowners.

The Board of Directors recommends a vote for submitting the advisory vote on the compensation of our named executive officers to shareowners every “1 YEAR.”

DIRECTOR COMPENSATION

The following table summarizes the compensation paid to, or earned by, our non-employee directors for all services rendered to us, Alliant Energy and Alliant Energy’s other subsidiaries during 2008.2010.

 

Name(1)  

Fees Earned

or Paid in

Cash ($)(2)

   All Other
Compensation
($)(3)
   Total ($)   Fees Earned
or Paid in
Cash ($)(2)
   All Other
Compensation
($)(3)
   Total ($) 

Michael L. Bennett

  $149,994   $12,462   $162,456   $173,500    $12,462    $185,962  

Darryl B. Hazel

  $128,490   $0   $128,490   $148,500    $0    $148,500  

James A. Leach

  $125,000   $1,081   $126,081 

Singleton B. McAllister

  $130,000   $18,750   $148,750   $145,000    $17,555    $162,555  

Ann K. Newhall

  $128,495   $13,136   $141,631   $150,000    $12,462    $162,462  

Dean C. Oestreich

  $130,000   $492   $130,492   $150,000    $0    $150,000  

David A. Perdue

  $128,496   $21,892   $150,388   $148,500    $21,892    $170,392  

Judith D. Pyle

  $125,000   $5,524   $130,524   $145,000    $5,574    $150,574  

Carol P. Sanders

  $138,492   $0   $138,492   $158,500    $0    $158,500  

 

(1)

Directors who also are employees, such as Mr. Harvey, receive no additional compensation for their service on our Board of Directors and are not included in this table. The compensation received by Mr. Harvey for other services rendered to us, Alliant Energy and Alliant Energy’s other subsidiaries during and for 20082010 is shown in the Summary Compensation Table above.Table.

 

(2)

The amounts shown in this column include the following aggregate dollar amounts deferred and the equivalent number of shares of common stock acquired by each of the following directors in the Alliant Energy’sEnergy Deferred Compensation Plan Stock Account: Mr. Bennett $74,994$72,300 or 2,071 shares;2,237 shares at $32.32 per share and $101,200 or 3,192 shares at $31.70 per share; Mr. Hazel $128,490$15,500 or 3,548 shares;480 shares at $32.32 per share and $21,625 or 682 shares at $31.70 per share; Ms. Newhall $62,960$75,000 or 1,739 shares;2,321 shares at $32.32 per share; Mr. Oestreich $75,000 or 2,321 shares at $32.32 per share; Mr. Perdue $38,546$61,900 or 1,065 shares;1,915 shares at $32.32 per share and $86,600 or 2,732 shares at $31.70 per share; and Ms. Sanders $103,867$55,475 or 2,868 shares. For Ms. McAllister the following aggregate amounts were used to purchase1,716 shares in Alliant Energy’s Shareowner Direct Plan: $52,500 or 1,424 shares.at $32.32 per share.

 

(3)

The amounts in this column reflect the sum of amounts attributable to directors for director life insurance premiums, director charitable award premiums and, other miscellaneous compensation attributable toin the directors as set forth below:case of Ms. Pyle, $137 for imputed income on director life insurance.

Name

  Charitable Award
Premium Paid
  All Other
Compensation Paid
  Total

Michael L. Bennett

  $12,462  $0  $12,462

Darryl B. Hazel

  $0  $0  $0

James A. Leach

  $0  $1,081  $1,081

Singleton B. McAllister

  $17,555  $1,195  $18,750

Ann K. Newhall

  $12,462  $674  $13,136

Dean C. Oestreich

  $0  $492  $492

David A. Perdue

  $21,892  $0  $21,892

Judith D. Pyle

  $5,437  $87  $5,524

Carol P. Sanders

  $0  $0  $0

Retainer FeesIn 2008,2010, all non-employee directors, each of whom served on the Boards of the Company, Alliant Energy IPL, and Resources (for Resources until Nov. 25, 2008),IPL, received an annual retainer for service on all Boards consisting of $125,000$145,000 in cash. Also in 2008,2010, the Chairperson of the Audit Committee received an additional $13,500 cash retainer and the Chairpersons of the Compensation and Personnel, Nominating and Governance, and Environmental, Nuclear, Health, and Safety Committees received an additional $5,000 cash retainer; other members of the Audit Committee received an additional $3,500 cash retainer; and the Lead Independent Director received an additional $20,000 cash retainer.

Effective in 2009, our Board of Directors adopted the Compensation and Personnel Committee and Nominating and Governance Committee recommendations to maintain the same retainer fees as paid in 2008. The Board of Directors through its Compensation and Personnel Committee and Nominating and Governance Committee expressed a philosophy to set appropriate levels ofMeeting FeesIn 2010, directors did not receive any additional compensation for directors that will ensure we attract and retain highly qualified individuals. Theattendance at Board of Directors determined that they would revisit the issue of an appropriate level of competitive compensation for directors at the Board Meeting in August 2009.or Committee meetings.

OtherPursuant to the Alliant EnergyEnergy’s directors’ expense reimbursement policy, we reimburseAlliant Energy reimburses all directors for travel and other necessary business expenses incurred in the performance of their responsibilities for us. Committees are provided the opportunity to retain outside independent advisors, as needed. Alliant Energy also extends coverage to directors under our travel accident and directors’ and officers’ indemnity insurance policies.

Receipt of Fees in StockFor fees paid in 2008,2010, each director was encouraged to voluntarily elect to use not less than 50% of his or her cash retainer to purchase shares of Alliant Energy’s common stock pursuant to Alliant Energy’s Shareowner Direct Plan or to defer such amount through the Alliant Energy Stock Account in the Alliant Energy Deferred Compensation Plan. For fees paid in 2011, the Compensation and Personnel Committee and the Nominating and Governance Committee again recommended that each non-employee director voluntarily elect to use a portion of his or her cash retainer to purchase shares of Alliant Energy common stock. Under Alliant Energy’s 2002 Equity2010 Omnibus Incentive Plan, was amended in 2006 to provide that, in the discretion of, and subject to restrictions imposed by the Compensation and Personnel Committee, a non-employee director may elect to

receive, or the Compensation and Personnel Committee may require that a non-employee director will be paid, all or any portion of his or her annual cash retainer payment or other cash fees for serving as a director in the form of shares of Alliant Energy’s common stock under thethat Plan. For fees paid in 2009, the Compensation and Personnel Committee recommended to the Nominating and Governance Committee that each non-employee director voluntarily elect to receive a portion of his or her cash retainer to purchase shares of Alliant Energy’s common stock.

Share Ownership GuidelinesPursuant to Alliant Energy’s Articles of Incorporation, directors are required to be shareowners of Alliant Energy. For 2008, upon the recommendation of the Compensation and Personnel and Nominating and Governance Committees, Alliant Energy’s Board amended theThe target share ownership level to beis the number of Alliant Energy common shares equal to the value of two times the annual retainer amount received by each of the non-employee directors. The achievement of this ownership level is to be accomplished by each director within five years of joining the Board or as soon thereafter as practicable. Shares held by directors in the Alliant Energy Shareowner Direct Plan and the Alliant Energy Deferred Compensation Plan are included in the target goal. As of Dec. 31, 2008,Feb. 28, 2011, all non-management directors, with the exception of Ms. Sanders, who joined the Board in November 2005, Mr. Hazel, who joined the Board in 2006, and Mr. Leach, who joined the Board in 2007, had met the 2008 target ownership level. As of Feb. 27, 2009, given market conditions, only Mr. Bennett and Mses. McAllister and Pyle met the 2008 established target ownership levels. We will continue to monitor the status of achievement of the target ownership levels and review them with the Board of Directors.

Alliant Energy Deferred Compensation Plan In 2008, underUnder the Alliant Energy Deferred Compensation Plan, directors may elect to defer all or part of their retainer fee. Amounts deposited to the Interest Account receive an annual return based on the 10-year Treasury Bond Rate plus 1.50% as established by the Federal Reserve. Amounts deposited to the Equity Account are treated as invested in an S&P 500 index fund. Amounts deposited to ana Alliant EnergyEnergy’s Stock Account are treated as though invested in Alliant Energy’s common stock and will be credited with dividend equivalents, which will be treated as if reinvested. For 2011, the Plan was amended to permit deferrals into additional investment accounts. The director may elect that the Deferred Compensation Account be paid in a lump sum or in annual installments for up to 10 years beginning in the year of or one, two or three tax years after retirement or resignation from the Board. Effective Jan. 1, 2008, the Director’s Deferred Compensation Plan was consolidated with the Alliant Energy Deferred Compensation Plan. See: “Nonqualified Deferred Compensation” above.years.

Directors’ Charitable Award ProgramAlliant EnergyEnergy’s maintains a Director’sDirectors’ Charitable Award Program applicable to certain members of our Board of Directors beginning after three years of service. The Board has terminated this Program for all directors who joined the Board after Jan.January 1, 2005. The participants in this Program currently are Mr. Bennett, Ms. McAllister, Ms. Newhall, Mr. Perdue and Ms. Pyle. The purpose of the Program is to recognize our and our directors’ interest in supporting worthy charitable institutions. Under the Program, when a director dies, Alliant Energy will donate a total of $500,000 to one qualified charitable organization or divide that amount among a maximum of five qualified charitable organizations selected by the individual director. The individual director derives no financial benefit from the Program. We takeAlliant Energy takes all deductions for charitable contributions, and Alliant Energy funds the donations through life insurance policies on the directors. Over the life of the Program, all costs of donations and premiums on the life insurance policies, including a return of Alliant Energy’s cost of funds, will be recovered through life insurance proceeds on the directors. The Program, over its life, will not result in any material cost to Alliant Energy. The cost to Alliant Energy of the Program for the individual directors in 20082010 is included in the Director Compensation table above.

Directors’ Life Insurance ProgramAlliant Energy maintains a split-dollar Directors’ Life Insurance Program for non-employee directors. In November 2003, the Board of Directors terminated this insurance benefit for any director not already having the required vesting period of three years of service and for all new directors. The only active director participant in this Programprogram is Ms. Pyle. The Program provides a maximum death benefit of $500,000 to each eligible director. Under the split-dollar arrangement, directors are provided a death benefit only and do not have any interest in the

cash value of the policies. The Program is structured to pay a portion of the total death benefit to Alliant Energy to reimburse Alliant Energy for all costs of the Program, including a return on its funds. The Program, over its life, will not result in any material cost to Alliant Energy. TheDuring 2010, there was no cost to Alliant Energy ofincurred under the Programprogram for the individual directors in 2008 is included in the Director Compensation table above.current directors.

Alliant Energy Matching Gift ProgramDirectors are eligible to participate in the Alliant Energy Foundation, Inc. matching gift program, which is generally available to all employees and retirees. Under this program, the foundation matches 100% of charitable donations over $25 to eligible charities up to a maximum of $10,000 per year for each individual. These limits apply to active employees, retirees and directors.director.

REPORT OF THE AUDIT COMMITTEE

To Our Shareowners:

The Audit Committee of our Board of Directors is composed of four directors, each of whom is independent under the NYSE listing standards and SEC rules. The Committee operates under a written charter adopted by the Board of Directors.

Our management is responsible for our internal controls and the financial reporting process, including the system of internal controls. The independent registered public accounting firm is responsible for expressing opinions on the conformity of our audited consolidated financial statements with accounting principles generally accepted in the United States of America. The Committee has reviewed and discussed the audited consolidated financial statements with management and the independent registered public accounting firm. The Committee has discussed with the independent registered public accounting firm matters required to be discussed by StatementAU Section 380 of Auditing Standards No. 61, as amended and as adopted by the Public Company Accounting Oversight Board, as amended, SEC regulations and NYSE requirements.

Our independent registered public accounting firm has provided to the Committee the written disclosures required by applicable requirements of the Public Company Accounting Oversight Board regarding the independent registered public accounting firm’s communications with the Audit Committeeaudit committee concerning independence, and the Committee discussed with the independent registered public accounting firm its independence.

The Committee has adopted a policy that requires advance approval of all audit, audit-related, tax and other permitted services performed by the independent 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 that the Chairperson reports any decisions to the Committee at its next scheduled meeting. In accordance with the policy, the Committee pre-approved all audit, audit-related, tax and other permitted services performed by Deloitte & Touche LLP and its affiliates and related entities in 2008.2010.

The fees that were billed to usthe Company by ourits independent registered public accounting firm for work performed on behalf of our companyCompany and our subsidiaries for 20072009 and 20082010 were as follows:

 

  2007  2008  2009   2010 

Audit Fees

  $        1,093,000  $        1,087,000  $        925,000    $           907,000  

Audit-Related Fees

   76,000   39,000   29,000     129,000  

Tax Fees

   82,000   11,000   569,000     115,000  

All Other Fees

   2,000   9,000   7,000     8,000  

Audit Feesfees consisted of the fees billed for the auditaudits of the consolidated financial statements of our companyCompany and our subsidiaries;subsidiaries, for reviews of financial statements included in Form 10-Q filings;filings, and for services normally provided in connection with statutory and regulatory filings such as financing transactions. Audit fees also included our company’sCompany’s portion of fees for the audits of Alliant Energy’s consolidated financial statements and effectiveness of internal controls overour financial reporting.

Audit-Related FeesAudit-related fees consisted of the fees billed for services rendered related to employee benefits plan audits and attest services not required by statute or regulations. Audit-related fees for 2010 also included the Company’s portion of the fees billed for an assessment of International Financial Reporting Standards.

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

All Other Feesother fees consisted of education programs, seminars and license fees for accounting research software products.products, seminars and other education programs.

 

 

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

The Committee discussed with our internal auditor and independent registered public accounting firm the overall scopes and plans for their respective audits. The Committee meets with the internal auditor and independent registered public accounting firm, with and without management present, to discuss the results of their examinations, the evaluation of our internal controls and overall quality of our financial reporting.

Based on the Committee’s reviews and discussions with management, the internal auditor and the independent registered public accounting firm referred to above, the Committee recommended to the Board of Directors that the audited consolidated financial statements be included in our Annual Report on Form 10-K for the year ended Dec. 31, 20082010 for filing with the SEC.

AUDIT COMMITTEE

Carol P. Sanders (Chairperson)

Michael L. Bennett

Darryl B. Hazel

David A. Perdue

PROPOSAL FOR THE FOUR

RATIFICATION OF THE APPOINTMENT

OF DELOITTE & TOUCHE LLP AS THE COMPANY’S

INDEPENDENT REGISTERED PUBLIC ACCOUNTING FIRM FOR 20092011

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, 20092011, and is requesting that its shareowners ratify such appointment.

Representatives of Deloitte & Touche LLP are not expected to attend the annual meeting.Annual Meeting. Further information about the services of Deloitte & Touche LLP, including the fees paid in 20072009 and 2008,2010, is set forth in the “Report of the Audit Committee.”

Vote Required

The affirmative vote of a majority ofvotes cast “for” must exceed the votes cast on“against” 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 2009.2011. For purposes of determining the vote required for this proposal, abstentions and broker non-votes 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 for 2009, 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 failure by the shareowners to ratify will be considered by the Audit Committee as an indication that it should consider selecting another independent registered public accounting firm for the following fiscal year. Even if the shareowners ratify the appointment, 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“FOR” the ratification of the appointment of Deloitte & Touche LLP as the Company’s independent registered public accounting firm for 2009.2011.

SECTION 16(a) BENEFICIAL OWNERSHIP

REPORTING COMPLIANCE

Section 16(a) of the Securities Exchange Act of 1934 requires the Company’s directors and certain officers to file reports of ownership and changes in ownership of the Company’s preferred stock with the SEC and furnish copies of those reports to us. As a matter of practice, Alliant Energy’s Shareowner Services Department assists the Company’s directors and executive officers in the preparation of initial reports of ownership and reports of changes in ownership and files those reports with the SEC on their behalf. Based on the written representations of the reporting persons and on copies of the reports filed with the SEC, the Company believes that all reporting persons of the Company satisfied the filing requirements in 2008.2010.

We will furnish to any shareowner, without charge, a copy of our Annual Report on Form 10-K for the year ended Dec. 31, 2008.2010. You may obtain a copy of the Form 10-K by writing Alliant Energy Shareowner Services at 4902 North Biltmore Lane, P.O. Box 14720, Madison, WI 53708-0720 or via email atshareownerservices@alliantenergy.com.

By Order of the Board of Directors,

LOGO

F. J. Buri

Corporate Secretary and

Assistant General Counsel

APPENDIX A

WISCONSIN POWER AND LIGHT COMPANY

ANNUAL REPORT

For the Year Ended December 31, 20082010

 

Contents

  Page

Forward-looking Statements

  A-2

The Company

  A-3

Selected Financial Data

  A-4A-5

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

  A-4A-5

Management’s Annual Report on Internal Control Over Financial Reporting

  A-36A-38

Report of Independent Registered Public Accounting Firm

  A-37A-39

Consolidated Financial Statements

  A-38A-40

Consolidated Statements of Income

  A-38A-40

Consolidated Balance Sheets

  A-39A-41

Consolidated Statements of Cash Flows

  A-41A-43

Consolidated Statements of Capitalization

A-42

Consolidated Statements of Changes in Common Equity

  A-43A-44

Notes to Consolidated Financial Statements

  A-44A-45

Shareowner Information

  A-70A-81

Executive Officers and Directors

  A-71A-82

Wisconsin Power and Light Company (WPL) filed a combined Form 10-K for 20082010 with the Securities and Exchange Commission (SEC). Such document included the filings of WPL’s parent, Alliant Energy Corporation (Alliant Energy), Interstate Power and Light Company (IPL) and WPL. The primary first tier subsidiaries of Alliant Energy are WPL, IPL, Alliant Energy Resources, LLC (Resources) and Alliant Energy Corporate Services, Inc. (Corporate Services). Certain portions of Management’s Discussion and Analysis of Financial Condition and Results of Operations (MDA) and the Notes to Consolidated Financial Statements included in this WPL Annual Report represent excerpts from the combined Form 10-K. As a result, the disclosure included in this WPL Annual Report at times includes information relating to Alliant Energy, IPL, Resources and/or Corporate Services. All required disclosures for WPL are included in this Annual Report thus such additional disclosures represent supplemental information. The information contained in this Annual Report, with the exception of the section entitled “Shareowner Information,” was filed with the SEC on February 27, 200928, 2011 and was complete and accurate as of that date. WPL disclaims any responsibility to update that information in this Annual Report.

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. These forward-looking statements can be identified as such because the statements include words such as “expect,” “anticipate,” “plan” or other words of similar import. Similarly, statements that describe future financial performance or plans or strategies are forward-looking statements. 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 WPL’s risks and uncertainties include:

 

federal and state regulatory or governmental actions, including the impact of energy-relatedenergy, tax, financial and taxhealth care legislation, and of regulatory agency orders;

 

its ability to obtain adequate and timely rate relief to allow for, among other things, the recovery of operating costs, fuel costs, transmission costs, deferred expenditures, capital expenditures, and deferred expenditures,remaining costs related to generating units that may be permanently closed, the earning of reasonable rates of return, and the paymentpayments to its parent of expected levels of dividends;

the ability to continue cost controls and operational efficiencies;

the state of the economy in its service territory and resulting implications on sales, margins and ability to collect unpaid bills;

 

developments that adversely impact its ability to implement its strategic plan including unanticipated issues in connection with Alliant Energy’s construction and operation or regulatory approval of itsa new wind generating facility to utilize the remaining 100 megawatts (MW) of Vestas-American Wind Technology, Inc. (Vestas) wind turbine generator sets, new emission control equipment for various coal-fired generating facilities, and its potential purchases of the Riverside Energy Center (Riverside) and Resources’ electric generating facilityWisconsin Electric Power Company’s (WEPCO’s) 25% interest in Neenah, Wisconsin;the Edgewater Generating Station Unit 5 (Edgewater Unit 5);

weather effects on results of operations;

successful resolution of the pending challenge by interveners of the approval by the Public Service Commission of Wisconsin (PSCW) of its Bent Tree - Phase I wind project;

 

issues related to the availability of generating facilities and the supply and delivery of fuel and purchased electricity and price thereof, including the ability to recover and to retain the recovery of purchased power, fuel and fuel-related costs through rates in a timely manner;

 

the impact that fuel and fuel-related prices and other economic conditions may have on its customers’ demand for utility services;

 

impacts that stormsthe ability to defend against environmental claims brought by state and federal agencies, such as the United States of America (U.S.) Environmental Protection Agency (EPA), or natural disasters in its service territory may have on its operations;third parties, such as the Sierra Club;

 

issues associated with environmental remediation efforts and with environmental compliance generally, including changing environmental laws and regulations and regulations;

the ability to recover through rates all environmental compliance costs;costs, including costs for projects put on hold due to uncertainty of future environmental laws and regulations;

potential impacts of any future laws or regulations regarding global climate change or carbon emissions reductions;

the statereductions, including those that contain proposed regulations (including cap-and-trade) of the economy in its service territory and resulting implications on sales and ability to collect unpaid bills, in particular as a result of the current recession;greenhouse gas (GHG) emissions;

 

continued access to the capital markets underon competitive terms and rates;

 

weather effects on results of operations;inflation and interest rates;

 

financial impacts of risk hedging strategies, including the impact of weather hedges or the absence of weather hedges on earnings;

 

changes to the growth ratecreditworthiness of ethanolcounterparties which WPL has contractual arrangements including participants in the energy markets and biodiesel production in its service territory;fuel suppliers and transporters;

 

issues related to electric transmission, including operating in the Midwest IndependentRegional Transmission System Operator (MISO)Organization (RTO) energy and ancillary services markets, the impacts of potential future billing adjustments and cost allocation changes from MISORTOs and recovery of costs incurred;

 

unplanned outages, attransmission constraints or operational issues impacting fossil or renewable generating facilities and risks related to recovery of resulting incremental costs through rates;

current or future litigation, regulatory investigations, proceedings or inquiries;

 

Alliant Energy’s ability to successfully defend against,pursue appropriate appeals with respect to, and any liabilities arising out of, the alleged violation of the Employee Retirement Income Security Act of 1974 by Alliant Energy’s Cash Balance Pension Plan;

 

Alliant Energy’s ability to successfully resolve with the directInternal Revenue Service (IRS) issues related to Alliant Energy’s Cash Balance Pension Plan;

current or indirect effects resulting from terrorist incidentsfuture litigation, regulatory investigations, proceedings or responses to such incidents;inquiries;

 

employee workforce factors, including changes in key executives, collective bargaining agreements and negotiations, work stoppages or work stoppages;additional restructurings;

impacts that storms or natural disasters in its service territory may have on its operations and recovery of and rate relief for costs associated with restoration activities;

 

access to technological developments;

 

any material post-closing adjustments related to any of its past asset divestitures;

increased retirement and benefit plan costs;

 

the impact of necessary accruals for the terms of incentive compensation plans;

 

the effect of accounting pronouncements issued periodically by standard-setting bodies;

 

the ability to continue cost controlsutilize tax credits and operational efficiencies;net operating losses generated to date, and those that may be generated in the future, before they expire;

 

increased retirement plan costs due to decreases in market value of plan assets;

the ability to successfully complete ongoing tax audits and appeals with no material impact on earnings and cash flows;

 

inflation and interest rates;the direct or indirect effects resulting from terrorist incidents or responses to such incidents; and

 

factors listed in “Other Matters - Other Future Considerations” in MDA.

WPL assumes no obligation, and disclaims any duty, to update the forward-looking statements in this report.

THE COMPANY

OverviewOverview- - WPL was incorporated in 1917 in Wisconsin as Eastern Wisconsin Electric Company. WPL is a public utility engaged principally in the generation and distribution of electric energyelectricity and the distribution and transportation of natural gas in selective markets in southsouthern and central Wisconsin. WPL operates in municipalities pursuant to permits of indefinite duration and state statutes authorizing utility operation in areas annexed by a municipality. At Dec. 31, 2008,2010, WPL supplied electric and gas service to 453,078454,776 and 177,354178,570 retail customers, respectively. WPL also provides various other energy-related productsIn 2010, 2009 and services. In 2008, 2007 and 2006, WPL had no single customer for which electric, gas and/or other sales accounted for 10% or more of WPL’s consolidated revenues. WPL Transco LLC is a wholly-owned subsidiary of WPL and holds WPL’s investment in the American Transmission Company LLC (ATC). At Dec.31, 2010, WPL had 1,244 full- and part-time employees.

Regulation -WPL is subject to regulation by the Public Service Commission of Wisconsin (PSCW)PSCW related to its operations in Wisconsin for various issues including, but not limited to, retail utility rates and standards of service, accounting requirements, issuance and use of proceeds of securities, approval of the location and construction of electric generating facilities and certain other additions and extensions to facilities.

Retail Utility Base Rates- WPL files periodic requests with the PSCW for retail rate relief. These filings are required to be based on forward-looking test periods. There is no statutory time limit for the PSCW to decide retail rate requests. However, the PSCW attempts to process base retail rate cases in approximately 10 months and has the ability to approve interim retail rate relief, subject to refund, if necessary.

Retail Commodity Cost Recovery Mechanisms -

Electric - WPL’s retail electric base rates include estimates of annual fuel-related costs (fuel and purchased power energy costs) anticipated during the test period. During each electric retail rate proceeding or in a separate fuel cost plan approval proceeding, the PSCW sets fuel monitoring ranges based on the forecasted fuel-related costs used to determine rates in such proceeding. If WPL’s actual fuel-related costs fall outside these fuel monitoring ranges, WPL is authorized to defer the incremental over- or under-collection of fuel-related costs from electric retail customers that are outside the approved ranges. Any over- or under-collection of fuel-related costs for each year are reflected in future billings to retail customers. This cost recovery mechanism became effective for WPL on Jan. 1, 2011.

Natural Gas - WPL’s retail natural gas tariffs contain an automatic adjustment clause for changes in prudently incurred natural gas costs required to serve its retail gas customers. Any over- /under-collection of natural gas costs for each given month are automatically reflected in future billings to retail customers.

Energy Efficiency Cost Recovery Mechanism -WPL contributes a certain percentage of its annual retail utility revenues to help fund Focus on Energy, Wisconsin’s statewide energy efficiency and renewable energy resource program. Contributions to Focus on Energy are recovered from WPL’s retail customers through changes in base rates determined during periodic rate proceedings and include a reconciliation to eliminate any over- or under-recovery of contributions from prior periods.

New Electric Generating Facilities- A Certificate of Authority (CA) application is required to be filed with the PSCW for construction approval of any new electric generating facility located in Wisconsin with a capacity of less than 100 megawatts (MW) and any new electric generating facility located outside of Wisconsin.MW. A Certificate of Public Convenience and Necessity (CPCN) application is required to be filed with the PSCW for construction approval of any new electric generating facility located in Wisconsin with a capacity of 100 MW or more. In addition, WPL’s ownership and operation of electric generating facilities (including those located outside the state of Wisconsin (including Minnesota)Wisconsin) to serve Wisconsin customers is subject to retail utility rate regulation by the PSCW. WPL is required to file retail rate cases with the PSCW using a forward-looking test period. There is no statutory time limit for the PSCW to decide retail rate cases. However, the PSCW attempts to process all base retail rate cases in 10 months or less and the PSCW has the ability to approve interim retail rate relief, subject to refund, if necessary. For fuel-only retail rate case increases, the PSCW attempts to

Advance Rate Making Principles- Wisconsin Statutes §196.371 provide interim retail rate relief within 21 days of notice to customers, subject to refund. There is no statutory time limit for final fuel-only retail rate relief decisions. Wisconsin’s Act 7 provides Wisconsin utilities with the necessaryopportunity to request rate making principles - and resulting, increased regulatory and investment certainty - prior to the purchase or construction of any nuclear or fossil-fueled electric generating facility or renewable generating resource, such as a wind facility, utilized to serve Wisconsin customers. WPL is not obligated to file for or accept authorized rate making principles under Act 7.Wisconsin Statutes §196.371. WPL can proceed with an approved project under traditional rate making if the terms of the rate making principles issued under Act 7 are viewed as unsatisfactory by WPL.terms.

Other -WPL is also subject to regulation by the Federal Energy Regulatory Commission (FERC) and the United States of America (U.S.) Environmental Protection Agency (EPA),EPA, as well as various other federal, state and local agencies.

Electric Utility Operations - - As of Dec. 31, 2008,2010, WPL provided electric service to 453,078454,776 retail, 2221 wholesale and 2,1312,245 other customers in 607606 communities. 20082010 electric utility operations accounted for 79%85% of WPL’s operating revenues and 82%90% of WPL’s operating income. Electric sales are seasonal to some extent with the annual peak normally occurring in the summer months due to air conditioning requirements. In 2008,2010, the maximum peak hour demand for WPL was 2,5832,654 MW on July 16, 2008.Aug. 12, 2010.

Gas Utility Operations- As of Dec. 31, 2008,2010, WPL provided natural gas service to 177,354178,570 retail and 219226 transportation and other customers in 236237 communities. 20082010 gas utility operations accounted for 20%14% of WPL’s operating revenues and 17%11% of WPL’s operating income. In addition to sales of natural gas to retail customers, WPL provides transportation service to commercial and industrial customers by moving customer-owned gas through WPL’s distribution system to the customers’ meters. Gas sales follow a seasonal pattern with an annual base-load of gas and a large heating peak occurring during the winter season. Natural gas obtained from producers, marketers and brokers, as well as gas in storage, is utilized to meet the peak heating season requirements.

SELECTED FINANCIAL DATA

 

  2008 (a)  2007 (a)  2006 (a)  2005  2004  2010 (a)   2009 (a)   2008 (a)   2007   2006 
  (in millions)  (in millions) 

Operating revenues

  $1,465.8  $1,416.8  $1,401.3  $1,409.6  $1,209.8  $1,423.6    $1,386.1    $1,465.8    $1,416.8    $1,401.3  

Net income

   152.3     89.5     118.4     113.5     105.3  

Earnings available for common stock

   115.1   110.2   102.0   101.8   110.4   149.0     86.2     115.1     110.2     102.0  

Cash dividends declared on common stock

   91.3   191.1   92.2   89.8   89.0   109.5     91.0     91.3     191.1     92.2  

Cash flows from operating activities

   239.7   258.0   162.6   176.6   199.3   372.4     305.8     239.7     258.0     162.6  

Total assets

   3,265.5   2,788.6   2,699.1   2,667.6   2,656.1   3,889.6     3,681.4     3,265.5     2,788.6     2,699.1  

Long-term obligations, net

   899.0   715.7   524.5   526.4   491.3   1,193.7     1,146.3     899.0     715.7     524.5  

 

(a)Refer to “Results of Operations” in MDA for a discussion of the 2008, 20072010, 2009 and 20062008 results of operations.

Alliant Energy is the sole common shareowner of all 13,236,601 shares of WPL’s common stock outstanding. As such, earnings per share data is not disclosed herein.

MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL

CONDITION AND RESULTS OF OPERATIONS

MDA consists of the following information:

Executive Summary

Strategic Overview

Rate Matters

Environmental Matters

Legislative Matters

Results of Operations

Liquidity and Capital Resources

Other Matters

Market Risk Sensitive Instruments and Positions

New Accounting Pronouncements

Critical Accounting Policies and Estimates

Other Future Considerations

EXECUTIVE SUMMARY

Description of Business

General- WPL is a public utility engaged principally in the generation and distribution of electric energyelectricity and the distribution and transportation of natural gas in selective markets in southern and central Wisconsin. WPL owns an approximate 16% interest in ATC, a transmission-only utility operating in Wisconsin, Michigan, Illinois and Minnesota. WPL also owns a portfolio of electric generating facilities located in Wisconsin 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 453,000455,000 retail electric customers in Wisconsin. WPL also procures natural gas from various suppliers to provide service to approximately 177,000179,000 retail gas customers in Wisconsin. 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, the impact of weather and economic conditions on electric and gas sales volumes and other factors listed in “Forward-looking Statements.”

Financial Results- In 2008, 20072010, 2009 and 2006,2008, WPL’s earnings available for common stock were $115.1$149.0 million, $110.2$86.2 million and $102.0$115.1 million, respectively. Refer to “Results of Operations” for details regarding the various factors impacting earnings during 2008, 20072010, 2009 and 2006.2008.

Strategic Plan DevelopmentsOverview

The strategic plan for WPL centersfocuses on an infrastructure investment program, which includes significant capital expenditures for buildingconstruction of new electric generation to meet customer demandwind generating facilities, purchasing newer and renewable portfolio standardsmore-efficient coal and fornatural gas generating facilities and implementing air pollutionemission controls and performance upgrades at its existing fleet of electricnewer, larger and more-efficient generating facilities to meet environmental regulations.enable it to continue to produce reliable and affordable energy for its customers. Key strategic plan developments impacting WPL during 20082010 and early 2011 include:

 

April 2010 - WPL announced plans to purchase WEPCO’s 25% ownership interest in Edgewater Unit 5, subject to regulatory approval. WPL currently expects the transaction to close in the first half of 2011.

May 2010 - WPL received an order from the PSCW authorizing the installation of a selective catalytic reduction (SCR) system at Edgewater Unit 5 to reduce nitrogen oxide (NOx) emissions at the facility. Construction of the SCR system began in the third quarter of 2010.

February 20082011 - WPL’s 200 MW Bent Tree - Phase I wind project in Freeborn County, Minnesota began full commercial operation.

February 2011 - WPL received approval from the PSCW to begin implementing Advanced Metering Infrastructure (AMI) for its customers.

March 2008 - The U.S. Court of Appeals forinstall scrubbers and baghouses at Columbia Units 1 and 2 to reduce sulfur dioxide (SO2) and mercury emissions, respectively, at the District of Columbia Circuit vacated and remanded the federal Clean Air Mercury Rule to the EPA for reconsideration.

June 2008 - Corporate Services, as agent for IPL and WPL, entered into a master supply agreement with Vestas-American Wind Technology, Inc. (Vestas) for the purchase of 500 MW of wind turbine generator sets and related equipment to support IPL’s and WPL’s wind generation plans.

September 2008 - WPL received approval from FERC to purchase Resources’ 300 MW, simple-cycle, dual-fueled (natural gas/diesel) electric generating facility in Neenah, Wisconsin. WPL previously received PSCW approval in April 2008.

December 2008 - The PSCW rejected WPL’s application to construct Nelson Dewey #3, a 300 MW hybrid coal-fired electric generating facility with a preferred location in Cassville, Wisconsin.

December 2008 - WPL’s first owned and operated wind project, the 68 MW Cedar Ridge wind project, began commercial operations.

December 2008 - The U.S. Court of Appeals for the District of Columbia Circuit reversed its July 2008 decision to vacate the Clean Air Interstate Rule (CAIR) and remanded CAIR to the EPA for reconsideration.facility.

Refer to “Strategic Overview” and “Liquidity and Capital Resources - Environmental” for additional details regarding these and other strategic plan developments.

Regulatory DevelopmentsRate Matters

WPL is subject to federal regulation by FERC, which has jurisdiction over wholesale electric rates, and state regulation in Wisconsin for retail utility rates and standards of service.rates. Key regulatory developments impacting WPL during 20082010 and early 20092011 include:

 

February 2008December 2010 - The Economic Stimulus ActWPL received an order from the PSCW authorizing an annual retail electric rate increase of 2008 (ESA) was enacted. The ESA allows$8 million, or approximately 1%, effective Jan. 1, 2011, related to WPL’s request to reopen the rate order for its 2010 test year. In addition, WPL received an order from the PSCW authorizing no increase in retail electric rates in 2010 related to fuel-related costs and required a 50% bonus tax depreciation deduction for certain property that is acquired or constructed2010 interim rate increase of $9 million to terminate effective Dec. 31, 2010. These two items will result in 2008.a net $1 million decrease in annual electric retail rates charged to customers effective January 2011.

 

April 2008January 2011 - The PSCW approved WPL’s request to implement an interim electric retail rate increase (equivalent to an annual increase of $16 million) to recover anticipated increasedNew electric fuel and purchased energy costs (fuel- related costs) for 2008. Actualcost recovery rules in Wisconsin became effective, which allow WPL to automatically defer electric fuel-related costs that fall outside a symmetrical cost tolerance band and reflect the over- /under-recovery of these deferred costs in 2008 were lower than expected at the time interim rates were set therefore WPL anticipates refunding $23 million, including interest,future billings to its retail customers.

Refer to “Rate Matters” for additional details regarding regulatory developments.

Environmental Matters

WPL is subject to regulation of environmental matters by various federal, state and local authorities. Key environmental developments during 2010 and early 2011 that may impact WPL include:

January 2010 - The EPA issued an information collection request for coal- and oil-fired electric customersgenerating units (EGUs) over 25 MW in 2009.order to develop a proposed Utility Maximum Achievable Control Technology (MACT) Rule for the control of mercury and other federal hazardous air pollutants (HAPs). Compliance with a MACT Rule is currently expected to be required by November 2014.

 

August 2008June 2010 - FERCThe EPA issued a final rule that establishes new one-hour National Ambient Air Quality Standards (NAAQS) for SO2 at a level of 75 parts per billion (ppb). Compliance with the new SO2 NAAQS rule is currently expected to be required by 2017. The final rule is being challenged by several groups in the D.C. Circuit Court.

June 2010 - The EPA issued a proposed rule seeking comment regarding two potential regulatory options for management of Coal Combustion Residuals (CCRs): 1) regulate as a special waste under the hazardous waste regulations when the CCRs are destined for disposal, but continue to allow beneficial use of CCRs as a non-hazardous material; or 2) regulate as a non-hazardous waste for all applications subject to new national standards. The schedule for compliance with this rule has not yet been established.

July 2010 - The EPA issued its proposed Clean Air Interstate Rule (CAIR) replacement rule, referred to as the Clean Air Transport Rule (CATR), which would require SO2 and NOx emissions reductions beginning in 2012 from WPL’s fossil-fueled EGUs with greater than 25 MW of capacity.

September 2010 - The Sierra Club filed complaints in U.S. District Court against WPL alleging air permitting violations at WPL’s Nelson Dewey, Columbia and Edgewater generating facilities.

October 2010 - The EPA approved the Wisconsin State Thermal Rule. Compliance with this rule will be evaluated on a case-by-case basis as wastewater discharge permits for WPL’s request to implement a formula rate structure for its wholesale electric customers effective June 1, 2007. FERC also approved a settlement reached between WPL and its wholesale customers resultinggenerating facilities are renewed in a refund of $10 million to its wholesale customers in September 2008.the future.

 

December 20082010 - The PSCW approvedEPA announced the future issuance of GHG standards for electric utilities under the Clean Air Act (CAA). The GHG emission limits are to be established as New Source Performance Standards (NSPS) for new and existing fossil-fueled EGUs. The EPA is expected to propose NSPS by July 2011 and finalize NSPS by May 2012. The schedule for compliance with NSPS has not yet been established.

January 2011 - The EPA’s GHG Tailoring Rule became effective. The rule establishes a stipulated agreement on electricGHG threshold for major sources under the Prevention of Significant Deterioration (PSD) and gas retail rate changes for 2009 reached by WPL and major intervenors in WPL’s 2009/2010 retail rate case.Title V Operation Permit programs at 100,000 tons per year of CO2-equivalent (CO2e). The parties agreedrule is subject to hold retail electric rates flat and decrease retail gas rates by $4 million effective January 2009.legal challenge.

 

February 20092011 - The Wisconsin Senate Bill 62 (SB 62)EPA promulgated a revised Industrial Boiler and Process Heater MACT Rule related to HAPs from fossil-fueled EGUs with less than 25 MW capacity as well as certain auxiliary boilers and process heaters operated at EGUs. The compliance deadline for this rule is currently expected to be 2014.

Refer to “Environmental Matters” for additional details regarding environmental developments.

Legislative Matters

WPL monitors various legislative developments, including those relating to energy, tax, financial and other matters. Key legislative developments impacting WPL during 2010 include:

March 2010 - Federal health care legislation was enacted. SB 62 contains variousOne of the most significant provisions intendedof the federal health care legislation for WPL requires a reduction in its tax deductions for retiree health care costs beginning in 2013, to reduce the state’s current budget gap.extent its drug expenses are reimbursed under the Medicare Part D retiree drug subsidy program. The reduction in the future deductibility of retiree health care costs accrued as of Dec. 31, 2009 required WPL to record deferred income tax expense of $3 million in 2010.

July 2010 - The Dodd-Frank Wall Street Reform and Consumer Protection Act (Dodd-Frank Act) was enacted. One of the most significant financial provisions of the Dodd-Frank Act for WPL is a commercial end-user exemption that is expected to allow utilities to continue trading derivatives “over-the-counter” without having to make such trades through cleared exchanges with collateral requirements.

September 2010 and December 2010 - The Small Business Jobs Act of 2010 (SBJA) and the Tax Relief, Unemployment Insurance Reauthorization and Job Creation Act of 2010 (the Act) were enacted. The most significant provisionprovisions of SB 62the SBJA and the Act for WPL is combined reportingprovide an extension of the bonus depreciation deductions for corporate income taxation in Wisconsin.

February 2009 - The American Recovery and Reinvestment Bill of 2009 (ARRB) was enacted. The ARRB extends tax creditscertain expenditures for wind generating facilities placed into service byproperty that are incurred through Dec. 31, 2012.

Refer to “Rates and Regulatory“Legislative Matters” for additional details regarding these and other regulatory developments including plans to file a retail rate case in Wisconsin in the first half of 2009.legislative developments.

Financing DevelopmentsLiquidity and Capital Resources

Based on its current liquidity position and capital structure, as of Dec. 31, 2008, WPL believes it will be able to secure the additional capital required to implement its strategic plan and to meet its long-term contractual obligations. Key financing developments impacting WPL during 20082010 include:

 

August 2008March 2010 - WPL’s shelf registration became effective, which provides it the flexibility to offer up to an aggregate of $450WPL paid at maturity $100 million of preferred stock and unsecured debt securities through August 2011.its 7.625% debentures.

 

October 2008June 2010 - WPL issued $250$150 million of 7.60%4.6% debentures due 2038.2020. Proceeds from this issuance were used initially to repay short-term debt and invest in short-term assets, and thereafter to fund capital expenditures and for general working capital purposes.

 

December 20082010 - The PSCW authorized WPL finished 2008 with a liquidity position including $196to issue up to $200 million of long-term debt securities in 2011.

December 2010 - At Dec. 31, 2010, WPL had $193 million of available capacity under its revolving credit facility.

Refer to “Liquidity and Capital Resources” for additional details regarding these and other financing developments.

STRATEGIC OVERVIEW

Strategic PlanSummary- - WPL’s corporate strategy focuses on the execution of its infrastructure investment program, while meeting or exceeding customers’ and regulators’ expectations regarding reliability, availability, customer service and community support. WPL’s strategic plan focuses on its core business of delivering regulated electric and natural gas service in its Wisconsin service territory. The strategic plan is concentrated on: 1) buildingbuilt upon three key elements: competitive costs, reliable service and maintainingbalanced generation.

Competitive Costs -Providing competitive and predictable energy costs for customers is a key element of the generation and infrastructure necessarystrategic plan. WPL is aware that the majority of its costs become part of rates charged to provide its customers and any rate increase has an impact on its customers. Given that potential public policy changes and resulting increases in future energy cost are possible, WPL is focused on controlling its costs with safe,the intent of providing competitive rates to its customers. Energy efficiency is also an important part of the strategic plan and is an option that provides customers with the opportunity to save on their energy bills. WPL’s approach to energy efficiency is based on regulations in Wisconsin. The objective is to meet prescribed goals in the most cost-effective manner. Additional details regarding energy efficiency programs used by WPL are included in “Energy Efficiency Programs” below.

Reliable Service- The strategic plan is intended to focus resources on providing reliable electricity and environmentally responsible energy service; 2) earning returns authorized bynatural gas service. Investments are expected to be targeted in system improvements, replacing aging infrastructure and distribution grid efficiency to maintain strong reliability. WPL monitors system performance and takes the necessary steps to continually improve the reliability of its regulators;service for its customers. Providing exceptional customer service, including emergency and 3) controlling costsoutage response, is part of WPL’s mission and commitment to mitigate potential rate increases.the customers it serves.

Balanced Generation- WPL utilizes a comprehensive Lean Six Sigma program to assist it in controlling costs through the generation of cost savings and operational efficiencies. The infrastructure investment program reflectsbelieves a balanced approachand flexible generation portfolio provides long-term advantages to meeting the needs of its customers shareownersand its parent company, Alliant Energy. The strategic plan calls for a focus on reducing overall fuel costs and the environment and includes the following key components:

New electric generating facilities - The infrastructure investment program includes building or acquiring several electric generating facilities to meet customer demand and renewable portfolio standards, reducevolatility of those costs by reducing reliance on purchased electricity and generation produced by older, smaller and less-efficient EGUs to meet the demands of our customers. The strategic plan reflects the recent construction of new wind generating facilities and proposed acquisitions of newer and more-efficient coal and natural gas plants to replace the electricity from purchased power agreements (PPAs) and mitigate any impactsgeneration produced by less efficient EGUs. Additional details of future plant retirements.changes to WPL’s generation portfolio are included in “Generation Plans” below. The strategic plan also includes investments in performance and reliability upgrades and new emission controls at newer, larger, more-efficient EGUs to continue producing affordable energy for customers and to benefit the environment. Additional details regarding proposed new electricemission controls for WPL’s generating facilities have a diversified fuel mix and currently include several wind projectsare included in the Midwest and two natural gas-fired generating facilities in Wisconsin.“Environmental Compliance Plans” below. WPL believes a diversified fuel mix for new electric generating facilitiesEGUs is important to meeting the needs of its customers, shareownersits parent company and the environment while preparing for a potentially carbon constrainedcarbon-constrained environment in the future. Additional details of new electric generating facilities are included in “Generation Plan” below.

New air pollution controls - The infrastructure investment program also includes implementing air pollution controls at WPL’s existing fleet of electric generating facilities to meet current and proposed environmental regulations issued by the EPA and state environmental agencies. WPL’s new air pollution controls are expected to significantly reduce future emissions of nitrogen oxide (NOx), sulfur dioxide (SO2) and mercury at its generating facilities after they have been implemented. Additional details regarding proposed new air pollution controls are included in “Multi-emission Compliance Plan” below.

Energy efficiency and conservation - Lastly, the infrastructure investment program includes installing AMI in WPL’s service territory and other initiatives to promote energy efficiency and conservation. AMI technology is expected to improve customer service, enhance energy management initiatives and provide operational savings through increased efficiencies. WPL has completed its initial limited AMI deployment by installing over 120,000 AMI electric meters and gas modules in its service territory as of Dec. 31, 2008. WPL currently plans to fully install AMI through a phased approach from 2008 through 2010 at total cost of approximately $95 million.

Financing the Infrastructure Investment Program - WPL is committed to maintaining sustained, long-term strong financial performance with strong balance sheets and credit ratings. WPL believes strong financial performance will help ensure access to capital markets at reasonable costs to finance the significant capital expenditures required for its infrastructure investment program. Refer to “Liquidity and Capital Resources - Cash Flows - Investing Activities - Construction and Acquisition Expenditures” for details of anticipated capital expenditures and financing plans for the infrastructure investment program.

Favorable Laws for New Electric Generation - Wisconsin law (Act 7) provides WPL with the ability to receive rate making principles - and resulting increased regulatory and investment certainty - prior to making certain significant investments in new generation. This law contributes towards the execution of the infrastructure investment program by enabling WPL to pursue additional generation investments to serve its customers that may provide shareowners with greater certainty regarding the returns on these investments. Refer to “Rates and Regulatory Matters - Rate Making Principles for New Electric Generating Facilities” for additional information.

Generation PlanPlans- WPL reviews and updates, as deemed necessary and in accordance with regulatory requirements, its generation planplans. WPL is currently evaluating the types of capacity additions it will pursue to address variousmeet its customers’ long-term energy needs and is monitoring several related external factors.factors that will influence those evaluations. Some of these external factors include regulatory decisions regarding proposed projects, changes in long-term projections of customer demand, availability and cost effectiveness of different generation technologies, market conditions for obtaining financing, developments related to federal and state renewable portfolio standards, environmental requirements, for new generation, changes in long-term projections of customer demandsuch as future carbon and renewable requirements, and federal and state tax incentives. The following provides details of

New Generation Projects -WPL’s new generation projects completed in 2008 and generation projects denied by regulators in 2008 and updates regarding various generation projects under construction or pending regulatory agency approvals.

Generation Projects Completed in 2008

Cedar Ridge - In December 2008, WPL’s 68 MW Cedar Ridge wind project located in Fond du Lac County, Wisconsin began commercial operation. Total project costs for Cedar Ridge were $149 million, excluding allowance for funds used during construction (AFUDC), as of Dec. 31, 2008. In May 2007, WPL received approval from the PSCW to construct the project, however, WPL did not accept the PSCW’s Act 7 decision, which included a return on common equity of 10.50% compared to WPL’s requested return on common equity of 12.90%. Instead, WPL is utilizing traditional rate making procedures for the recovery of and return on its capital costs for this wind project.

Generation Projects Denied in 2008

Nelson Dewey #3 - In February 2007, WPL filed a CPCN application with the PSCW for approval to proceed with construction of a new facility at a preferred site adjacent to the existing Nelson Dewey Generating Station (Nelson Dewey) in Cassville, Wisconsin. In December 2008, the PSCW issued a written order denying WPL’s Nelson Dewey #3 CPCN application. In its written order, the PSCW acknowledged WPL’s need for additional electric generating capacity and recommended WPL consider alternatives to its proposed facility in Cassville, Wisconsin. As a result of this order, WPL is currently evaluating alternatives for its long-term generation needs in Wisconsin. As of Dec. 31, 2008, WPL had $36 million

of capitalized expenditures for Nelson Dewey #3 recorded in “Other assets - regulatory assets” on the Consolidated Balance Sheet. WPL will be pursuing rate recovery for these expenditures. Refer to “Rates and Regulatory Matters - Rate Making Principles for New Electric Generating Facilities - Preliminary Survey and Investigation Charges and Pre-construction Expenditures” for details of rate recovery for WPL’s capitalized expenditures for Nelson Dewey #3.

Generation Projects Under Construction or Pending Regulatory Agency Approvals

The current generation plan for WPL through 2013 isare as follows (Not Applicable (N/A); To Be Determined (TBD)):

 

Primary
Generation
Type

  

Project Name /
Location

  Capacity
(MW)
  Expected
Availability
Date
  Cost
Estimate (a)
  Current
Capitalized
Costs (b)
  Actual / Expected
Regulatory
Decision Date
  

Project Name / Location

  Capacity
(MW)
   

Actual / Expected
Availability

Date

  Cost
Estimate (a)
  Current
Capitalized
Costs (b)
   

Actual / Expected

Regulatory

Decision Date

Natural gas/ diesel

  Neenah Energy Facility Neenah, WI  300  2009  $95   N/A  September 2008

Wind

  

Bent Tree

Freeborn County, MN

  200  2010   425 - 475  $1  Second quarter
of 2009
  

Bent Tree - Phase I

Freeborn County, MN

   200    Q4 2010 and Q1 2011  $440 - $450  $406    October 2009

Wind

  TBD  200  By 2013   TBD   —    TBD

Natural-gas

  Riverside Energy Center Beloit, WI  600  2013   365 - 375   N/A  2012 - 2013

Natural gas

  

Riverside

Beloit, WI

   600    2013  365 - 375   N/A    2012 - 2013

Coal

  

25% of Edgewater Unit 5

Sheboygan, WI

   95    2011  40 - 45   N/A    First half of 2011
                           
          $1            $406    
                           

 

(a)Cost estimates represent WPL’s estimated portion of the total escalated construction and acquisition expenditures in millions of dollars and exclude AFUDC,allowance for funds used during construction (AFUDC), if applicable. WPL expects the purchase price for the Neenah facility to be based on the book value of the facility on the transfer date.

(b)Costs represent capitalized expenditures in millions of dollars as of Dec. 31, 2008, including costs recorded in “Other assets - regulatory assets”“Property, plant and equipment” on the Consolidated Balance Sheet as of Dec. 31, 2010 and excludingexclude AFUDC, if applicable. Refer to Note 1(b) of the “Notes to Consolidated Financial Statements” for additional details of costs recorded in “Other assets - regulatory assets.”

Neenah Energy Facility (NEF)Wind Generation Projects

Bent Tree - Phase I Wind Project - In September 2008 and April 2008,2009, WPL received approval from FERC and the PSCW, respectively, to purchase Resources’ 300 MW, simple-cycle, dual-fueled (natural gas/diesel) electric generating facility in Neenah, Wisconsin. WPL intends to replace the output currently obtained under the RockGen Energy Center (RockGen) purchased power agreement (PPA) with output from NEF. WPL currently plans to acquire NEF effective June 1, 2009, which coincides with the expected termination of WPL’s RockGen PPA scheduled for May 31, 2009.

Bent Tree - In April 2008, WPL announced it entered into a letter of intent to purchase aacquired approximately 400 MW of wind project site capacity in Freeborn County, Minnesota. WPL currently anticipates the purchase of the site to be complete in the first half of 2009. In June 2008, WPL filed a CPCN application with the PSCW and a Certificate of Need application with the Minnesota Public Utilities Commission (MPUC) to developused 200 MW of the capacity from this capacity beginning in 2009. In June 2008,site for its Bent Tree - Phase I wind project. WPL also filed a Site Permit application with the MPUC for a multi-phase 400 MW facility, with the first phase consisting of a 200 MW wind project beginning in 2009. In September 2008, the PSCW determined that the CPCN statute does not apply to out-of-state projects and that the Bent Tree wind project will be processed under the CA statute. WPL expects the PSCW to issue a ruling on its application in the second quarter of 2009. WPL also expects the MPUC to issue a decision on the Site Permit and Certificate of Need applications in the second quarter of 2009. In June 2008, Corporate Services, as agent for IPL and WPL, entered into a master supply agreement with Vestas for the purchase of 500 MW of wind turbine generator sets and related equipment. WPL anticipates utilizingused 200 MW of wind turbine generator sets and related equipment under the master supply agreement entered into with Vestas in 2008 for the initial phase of the Bent Tree - Phase I wind project. Construction of Bent Tree - Phase I was completed and full commercial operation began in February 2011.

In 2009, Wisconsin Industrial Energy Group, Inc. (WIEG) and Citizens Utility Board (CUB) filed a Petition for Review with the Circuit Court of Dane County, Wisconsin seeking judicial review of: 1) the PSCW’s 2008 interim order that determined WPL’s application for the Bent Tree - Phase I wind project must be reviewed under the CA statute and not the Certificate of Public Convenience and Necessity statute; and 2) the PSCW’s 2009 final order that granted WPL a CA to construct the Bent Tree - Phase I wind project. In 2009, the PSCW filed a motion to dismiss the petition, which was subsequently denied in April 2010. In September 2010, WIEG’s and CUB’s Petition for Review was denied by the Circuit Court of Dane County,

Wisconsin. WIEG and CUB appealed the Circuit Court’s decision to the Appellate Court. In January 2011, WIEG and CUB filed briefs in support of their appeal. The PSCW, WPL and other interveners have the opportunity to file a brief in February 2011. WPL expects a decision on this matter in 2011.

Wind Turbine Generators - In 2008, Alliant Energy entered into a master supply agreement with Vestas to use traditional rate making procedures for the recovery of and return on its capital costs for the 200purchase 500 MW of capacity. The expected commercial operation datewind turbine generator sets and related equipment. Alliant Energy utilized 400 MW of these wind turbine generator sets and related equipment to construct IPL’s Whispering Willow - East wind project and WPL’s Bent Tree - Phase I wind project. Alliant Energy believes the Whispering Willow wind site in Iowa is subjectthe best location to deploy the timingremaining 100 MW of pending regulatory approvals, completionwind turbine generator sets and related equipment and is currently evaluating which of its subsidiaries will construct the 100 MW wind project.

Refer to Note 1(e) of the purchase“Notes to Consolidated Financial Statements” for discussion of thean additional wind site and execution of a transmission interconnect agreement. Future development of the balance of theexpected to be used by WPL to develop future wind project will depend on numerous factors such as renewable portfolio standards and availability of wind turbines.projects.

Natural Gas-Fired Generation Projects

Riverside Energy Center - WPL has a PPA with a subsidiary of Calpine Corporation related to Riverside that extends through May 31, 2013 and provides WPL the option to purchase Riverside at the end of the PPA term. For planning purposes, WPL is currently assuminganticipates it will exercise its option to purchase Riverside, a 600 MW natural-gas firednatural gas-fired electric generating facility in Beloit, Wisconsin, to replace the output currently obtained under the PPA.

Coal-Fired Generation Projects

Edgewater Unit 5 - WPL and WEPCO entered into an agreement, which became effective in March 2010, for WPL to purchase WEPCO’s 25% ownership interest in Edgewater Unit 5 for WEPCO’s net book value, including working capital. The proposed transaction was approved by PSCW and FERC in 2010. WEPCO is currently working with the Michigan Public Service Commission to obtain satisfactory approval for the transaction. WPL currently expects the transaction to close in the first half of 2011 at an approximate purchase price of $40 million to $45 million depending on WEPCO’s working capital balances and level of capital investment in Edgewater Unit 5 prior to the sale. If the purchase is completed, WPL would own 100% of Edgewater Unit 5.

Multi-emissionEnvironmental Compliance PlanPlans- WPL has developed a multi-emissionenvironmental compliance planplans to help ensure cost effective compliance with current and proposed environmental regulations expected to significantly reduce future emissions of NOx, SO2 and mercury at its generating facilities. Details of these current and proposed environmental regulations are discussed in “Liquidity and Capital Resources - Environmental.” The current multi-emission compliance plan for WPL includes investments in air pollution controls for its electric generating facilities as well as purchases of emission allowances. WPL reviews and updates, as deemed necessary and in accordance with regulatory requirements, its multi-emissionenvironmental compliance planplans to address various external factors. Some of these external factors include regulatory decisions regarding proposed air pollutionemission control projects, developments related to environmental regulations, outcomes of legal proceedings, availability and cost effectiveness of different emission reduction technologies, market prices for emission allowances, market conditions for obtaining financings and federal and state tax incentives. Refer to “Environmental Matters” for details of current and proposed environmental regulations, including regulations for which these plans are expected to support compliance obligations. The following provides details of capital expenditure estimates for air pollution2011 through 2013 for emission control projects included in WPL’s current multi-emissionenvironmental compliance planplans (in millions):

 

Emissions
Controlled

  

Primary
Technology (a)

  Current Estimated Capital Expenditures
    2009  2010  2011  2012 - 2019  Total

Mercury

  Baghouse/Carbon Injection  $10  $80  $135  $285-$325  $510-$550

NOx

  Selective Catalytic Reduction   20   80   70   50-70   220-240

SO2

  Scrubber   5   40   105   90-130   240-280
                      
    $35  $200  $310  $425-$525  $970-$1,070
                      

These capital expenditure estimates represent WPL’s portion of the total escalated capital expenditures and exclude AFUDC, if applicable. Capital expenditure estimates are subject to change based on future changes to plant specific costs of air pollution control technologies and air quality rules.

Generating Unit

    

Emissions Controlled

    

Technology (a)

      2011   2012   2013 

Edgewater Unit 5 (b)

    NOx    SCR    $    55    $60    $15  

Columbia Units 1 and 2

    SO2 and Mercury    Scrubber and Baghouse     20     95     125  
                         
            $75    $    155    $    140  
                         

 

(a)Baghouse/Carbon Injection is a post-combustion process that injects carbon particles into the stream of gases leaving the generating facility boiler to facilitate the capture of mercury in filters or bags. A baghouse / carbon injection process can remove more than 85% of mercury emissions.

Selective Catalytic Reduction (SCR)SCR is a post-combustion process that injects ammonia or urea into the stream of gases leaving the generating facility boiler to convert NOx emissions into nitrogen and water. The use of a catalyst enhances the effectiveness of the conversion enabling NOx emissions reductions of up to 90%.

Baghouse / carbon injection processis a post-combustion process that injects carbon particles into the stream of gases leaving the generating facility boiler to facilitate the capture of mercury in filters or bags. A baghouse / carbon injection process can remove more than 85% of mercury emissions.

Scrubberis a post-combustion process that injects lime or lime slurry into the stream of gases leaving the generating facility boiler to remove SO2 and capture it in a solid or liquid waste by-product. A scrubber typically removes more than 90% of the SO2 emissions regardless of generating facility boiler type or design.

 

(b)Scrubber is a post-combustion process that injects lime or lime slurry into the stream of gases leaving the generating facility boiler to remove SO2 and capture itCapital expenditure estimates above assume WPL acquires WEPCO’s 25% ownership interest in a solid or liquid waste by-product. A scrubber typically removes more than 90% of the SO2 emissions regardless of generating facility boiler type or design.Edgewater Unit 5 in 2011.

These capital expenditure estimates represent WPL’s portion of the total escalated capital expenditures and exclude AFUDC, if applicable. Capital expenditure estimates are subject to change based on future changes to plant-specific costs of emission control technologies and air quality rules. WPL is currently evaluating its environmental compliance plans for 2014 and beyond and will update its capital expenditure plans for these periods in the future when the plans are finalized. Refer to “Environmental Matters” for additional details regarding proposed environmental rules that may impact environmental compliance plans.

Air PollutionEmission Control Projects Submitted-WPL must file a CA and receive authorization from the PSCW to proceed with any individual clean air compliance project containing estimated project costs of $8 million or more. In March 2007, the PSCW approved the deferral of the retail portion of WPL’s incremental pre-certification and pre-construction costs for current or future clean air compliance projects requiring PSCW Approvalapproval, effective on the request date of November 2006. WPL currently anticipates that such deferred costs will be recovered in future rates and therefore does not expect these costs to have an adverse impact on its financial condition or results of operations. WPL has filed CAs for the following individual clean air compliance projects.

Edgewater Unit 5 - In May 2010, WPL received an order from the PSCW authorizing the installation of an SCR system at Edgewater Unit 5 to reduce NOx emissions at the facility. Construction began in the third quarter of 2010 and is expected to be completed prior to May 2013 when additional NOx emission reductions at Edgewater are required for WPL to comply with Wisconsin Reasonably Available Control Technology (RACT) Rule compliance deadlines. As of Dec. 31, 2010, WPL recorded $17 million of capitalized expenditures, excluding AFUDC, related to this project in “Construction work in progress - other” on the Consolidated Balance Sheet. Total capital expenditures, excluding AFUDC, for the Edgewater Unit 5 SCR are currently estimated to be approximately $155 million assuming WPL acquires WEPCO’s 25% ownership interest in Edgewater Unit 5 in 2011. The portion of these capital expenditures expected to be incurred in 2011 through 2013 are included in the above estimates for WPL’s environmental compliance plans. The SCR system at Edgewater Unit 5 is expected to support compliance obligations for current and anticipated air quality regulatory requirements, including the CATR and the Wisconsin RACT Rule.

Columbia Units 1 and 2 - In February 2011, WPL received approval from the PSCW to install scrubbers and baghouses at Columbia Units 1 and 2 to reduce SO2 and mercury emissions, respectively, at the generating facility. WPL’s portion of the capital expenditures, excluding AFUDC, for the Columbia Units 1 and 2 emission controls is currently estimated to be $290 million, a portion of which is included in the above estimates for WPL’s environmental compliance plans. The scrubbers and baghouses at Columbia Units 1 and 2 are expected to be placed into service in 2014 and support compliance obligations for current and anticipated air quality regulatory requirements, including CATR, the Utility MACT Rule and the Wisconsin State Mercury Rule.

Nelson Dewey - In 2007, WPL filed a construction applicationCA with the PSCW to install a scrubber and baghouse at the two existing units at Nelson Dewey to reduce SO2 and mercury emissions, respectively, at the generating facility. TotalWPL is re-evaluating this project due to forthcoming changes in environmental rules and regulations. There are no capital expenditures excluding AFUDC, for the Nelson Dewey air pollution controls are currently estimated to be $200 million ($80 million for controls to reduce SO2 and $120 million for controls to reduce mercury) and are included in the above estimates for WPL’s multi-emission compliance plan.table relating to this project.

Edgewater Generating Station Unit 5 (Edgewater Unit 5)Energy Efficiency Programs- In WPL has several energy efficiency programs and initiatives that help customers reduce their energy usage and related costs through the fourth quarteruse of 2008,new energy efficient equipment, products and practices. The following are WPL’s current key energy efficiency programs:

Smart Grid Initiatives- Smart Grid initiatives are designed to improve customer service, enhance energy management and conservation and provide operational savings through increased efficiencies of WPL’s electric distribution systems. Advanced metering infrastructure (AMI) is expected to be the foundation for the Smart Grid in WPL’s service territory. WPL filed a construction application with the PSCW to install a SCR system at Edgewater Unit 5 to reduce NOx emissions at the facility. Totalhas substantially completed its AMI deployment by installing over 641,000 AMI electric meters and gas modules in its service territory as of Dec. 31, 2010. WPL anticipates its total capital expenditures excluding AFUDC, for AMI will be approximately $115 million upon completion of the SCR at Edgewater Unit 5 are currently estimateddeployment. There is approximately $10 million of planned AMI investment remaining to be $115 millionmade for system and are included in the above estimates for WPL’s multi-emission compliance plan.network enhancements at WPL through 2013.

RATES AND REGULATORYFocus on Energy Program- In 2010, WPL contributed 1.2% of annual retail utility revenues to help fund Focus on Energy, Wisconsin’s statewide energy efficiency and renewable energy resource program. This contribution level increased to approximately 1.5% of WPL’s revenues in 2011 with additional increases in succeeding years not to exceed 3.2% by 2014. Focus on Energy works with eligible Wisconsin residents and businesses to finance and install energy efficiency and renewable energy equipment. Contributions to Focus on Energy are recovered from WPL’s retail rate payers through base rates.

Shared Savings Programs- WPL offers energy efficiency programs to certain customers referred to as Shared Savings programs. These programs provide low-cost financing to help customers identify, purchase and install energy efficiency improvement projects. The customers repay WPL with monthly payments over a term up to five years. Refer to Note 4 of the “Notes to Consolidated Financial Statements” for additional details of shared savings programs.

RATE MATTERS

Overview -WPL is 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 for retail utility rates and standards of service. Such regulatory oversight also covers WPL’s plans for construction and financing of new generation facilities and related activities.

UtilityRecent Retail Base Rate CasesFilings -Details of WPL’s recent retail base rate cases impacting its historical and future results of operations are as follows (dollars in millions; Electric (E); Gas (G); Not Applicable (N/A); Fuel-related (F-R); Fourth Quarter (Q4)):

 

Rate Case

  Utility
Type
  Filing
Date
  Increase
Requested
  Interim
Increase
Granted (a)
  Interim
Effective
Date
  Final
Increase
(Decrease)
Granted (a)
  Final
Effective
Date
  Return
on
Common
Equity
 

2008 Retail (F-R)

  E  Mar-08  $16  $16  Apr-08  N/A  N/A  N/A 

2009/2010 Retail

  E/G  Feb-08   92   N/A  N/A  ($4) Jan-09  N/A 

2008 Retail

  E  Apr-07   26   N/A  N/A  26  Jan-08  N/A 

2007 Wholesale

  E  Sep-06    (b)   (b)  (b)  (b) Jun-07  10.90%

2007 Retail

  E/G  Mar-06   96   N/A  N/A  34  Jan-07  10.80%

2005 Retail (F-R)

  E  Aug-05   96   96  Q4 ‘05  54  Sep-06  N/A 

Retail Base Rate Cases

Utility
Type
Filing
Date
Final
Increase
(Decrease)
Granted (a)
Final
Effective
Date

2011 Test Year

EApr-10$8Jan-11

2010 Test Year

E/GMay-09E-59; G-6Jan-10

2009/2010 Test Period

E/GFeb-08G-(4)Jan-09

 

(a)InterimRate increases reflect both returns on additions to WPL’s infrastructure and a recovery of increased costs incurred or expected to be incurred by WPL. Given a portion of the rate relief is implemented, subjectincreases will offset increased costs, revenues from rate increases cannot be expected to refund, pending determination of final rates. The final rate relief granted replaces the amount of interim rate relief granted.

(b)Refer to “2007 Wholesale Rate Case” below for additional information.result in an equal increase in income.

2008Retail Electric Rate Case (2011 Test Year) -In April 2010, WPL filed a request with the PSCW to reopen the rate order for its 2010 test year to increase annual retail electric rates for 2011 by $35 million, or approximately 4%. The request was based on a forward-looking test period that included 2011. The key drivers for the filing include recovery of investments in WPL’s Bent Tree - Phase I wind project and expiring deferral credits, partially offset by lower variable fuel expenses. In August 2010, WPL revised its request for an annual retail electric rate increase to $19 million, or approximately 2%. The primary differences between WPL’s original request in April 2010 and its revised request filed in August 2010 relate to reduced variable fuel expenses, increased wind generation production tax credits and the impact of the $9 million annual rate increase implemented in June 2010 with the interim order in WPL’s 2010 test year retail fuel-related rate filing, which is discussed below.

In December 2010, WPL received an order from the PSCW authorizing an annual retail electric rate increase of $8 million, or approximately 1%, effective Jan. 1, 2011. This $8 million increase in annual rates effective Jan. 1, 2011 combined with the termination of the $9 million interim fuel-related rate increase effective Dec. 31, 2010 will result in a net $1 million decrease in annual electric retail rates charged to customers effective January 2011. Refer to “Retail Fuel-related Rate Filings - 2010 Test Year” below for additional details of the interim fuel-related rate increase implemented in 2010 and a $5 million reduction to the 2011 test year base rate increase for refunds owed to electric retail customers related to interim fuel cost collections in 2010.

Retail Rate Case (2010 Test Year) -In March 2008,May 2009, WPL filed a request with the PSCW to increase annual retail electric rates by $16$86 million, to recover anticipatedor approximately 9%, and increase annual retail natural gas rates by $6 million, or approximately 3%. The request was based on a 2010 forward-looking test year. The key drivers for the filing included recovery of infrastructure costs of the electric and natural gas utility systems, which had been impacted by a material reduction in sales and increased electric fuel and purchased energy costs (fuel-related costs). Actual fuel-related costs through February 2008, combined with projectionscosts. In addition, WPL requested recovery of continued higher fuel-relatedthe remaining retail portion of the deferred costs for its cancelled 300 MW coal-fired electric generating facility project, Nelson Dewey #3. In September 2009, WPL revised its request to an annual electric retail rate increase of $99 million and annual retail natural gas rate increase of $8 million. The increase in the remainder of 2008, significantly exceededrequested amount for the amounts being recovered in retail electric rates at the time of the filing. was primarily due to increased infrastructure costs and a reduced 2010 sales forecast.

In the second quarter of 2008,December 2009, WPL received an order from the PSCW authorizing an annual retail electric rate increase of $59 million, or approximately 6%, and an annual retail natural gas rate increase of $6 million, or approximately 2%, effective Jan. 1, 2010. The annual retail electric rate increase of $59 million reflects an increase in the requested $16 million interim increase, subject to refund, effectivenon-fuel component of rates and a decrease in April 2008.

Fuel-relatedthe fuel component of rates. The December 2009 order from the PSCW also approved recovery of certain deferred benefits costs incurred by WPL in 2008 subsequent to the implementation2009 and a portion of the interimpreviously deferred costs for the cancelled Nelson Dewey #3 project. Refer to Note 1(b) of the “Notes to Consolidated Financial Statements” for further discussion regarding the PSCW’s decision regarding recovery of these deferred costs and regulatory-related charges in 2009 for the portion of the cancelled Nelson Dewey #3 costs that WPL was denied recovery.

The 2010 test year retail electric rate increase were significantly lower than anticipated resulting in refunds owed to its retail electric customers. In January 2009, WPL received approval fromapproved by the PSCW to payincluded an $18 million interim refund to retail electric customers in the first quarter of 2009. In February 2009, WPL also filedamount that represented a final fuel refund report, including interest less the interim refund amount, resulting in a final residual refund of $5 million in addition to the interim refund. Pending PSCW approval, WPL will refund the remaining $5 million, including interest, in the second quarter of 2009. As of Dec. 31, 2008, WPL reserved $23 million, including interest, for refunds anticipated to be paid to its retail electric customers based upon its estimatecurrent return on 50% of the final order. WPL anticipates receiving the final order fromestimated construction work in progress (CWIP) for WPL’s Bent Tree - Phase I wind project for 2010. The remaining CWIP balance for its Bent Tree - Phase I wind project accrued AFUDC during 2010. In addition, the PSCW authorized WPL to defer the retail portion of return on rate base, depreciation expense and other operation and maintenance expenses for those portions of the Bent Tree - Phase I wind project placed in the first quarter of 2009 and completing any remaining refundsservice in the second quarter of 2009.2010.

2009/2010 Retail Rate Case (2009/2010 Test Period) -In February 2008, WPL filed a request with the PSCW to increase current retail electric rates by $93 million, or approximately 9%, and reduce current retail gas rates by $1 million, or approximately 1%, effective Jan. 1, 2009. The electric request was based on a 2009 forward-looking test year with approval to reopen the case to address limited cost drivers for 2010. The electric request reflected recovery for increased projected spending on electric generation infrastructure, environmental compliance and stewardship, enhanced investment in renewable energy projects, stepped-up customer energy efficiency and conservation efforts, and related electric transmission and distribution costs. The gas request was based on an average of 2009 and 2010 projected costs. The request was based on the previously authorized return on common equity of 10.80%.

Through the course of the PSCW audit, the 2009 request was updated for various new cost estimates and removal of capital projects that had not yet been approved by the PSCW. These projects include Bent Tree - Phase I, Nelson Dewey #3 (subsequently rejected by the PSCW in December 2008) and various environmental compliance projects. Any projects that receive approval in 2009 are expected to be included in a planned 2010 test year base rate case.

In December 2008, WPL and major intervenorsinterveners in the case reached a stipulated agreement on electric and gas rate changes for 2009. The parties agreed to hold retail electric rates flat and decrease retail gas rates by $4 million. The stipulated agreement also included a provision that authorizesauthorized WPL to defer, and record carrying costs on, the retail portion of pension and benefit costs in excess of $4 million, any change in the retail portion of network wheeling costs charged by ATC that is different than the $82 million included in rates and any change in the retail portion of emission allowance expense that is different than $2 million. In addition, the stipulated agreement included the recovery of $9 million over a two-year period for pre-certification costs related to the Nelson Dewey #3 project that had been incurred through December 2007. Lastly, the stipulated agreement provides an option for WPL to file for a full 2010 test year rate case, instead of the limited reopener that was part of the original rate case filing. The PSCW approved the stipulations in December 2008.

Planned Utility Rate Cases in 2011 -WPL currently expects to make a retail rate filing in the second quarter of 2011 based on a forward-looking test period that includes 2012 and 2013. The form and magnitude of such filing is currently being analyzed and could range from a future test year 2012 electric fuel plan to a full rate case for the 2012 and 2013 test period. The rate filing is expected to include a new fuel cost recovery plan under Wisconsin’s new fuel rules, which allow for recovery of costs for emission control chemicals and emission allowances within the fuel recovery mechanism. The key drivers for the filing include partial recovery of the approved emission control project at Edgewater Unit 5 and the emission control projects at Columbia Units 1 and 2. Any rate changes granted are expected to be effective in early 2012.

2008 Retail Fuel-related Rate CaseFilings -

2010 Test Year -In April 2007,2010, WPL filed a request with the PSCW to reopenincrease annual retail electric rates by $9 million to recover anticipated increased electric production fuel and energy purchases (fuel-related costs) in 2010. Actual fuel-related costs through March 2010, combined with projections of continued higher fuel-related costs for the remainder of 2010, significantly exceeded the amounts being recovered in retail electric rates at the time of the filing. WPL received approval from the PSCW to implement an interim rate increase of $9 million, on an annual basis, effective in June 2010. As part of the interim decision, the PSCW also approved annual forecasted fuel-related costs per megawatt-hour (MWh) of $28.29 based on $389 million of variable fuel costs for WPL’s 2010 test period and left unchanged the annual fuel monitoring range of plus or minus 2%. Updated annual 2010 fuel-related costs during the proceeding resulted in WPL no longer qualifying for a fuel-related rate increase for 2010. In December 2010, the PSCW issued an order authorizing no increase in retail electric rates in 2010 related to fuel-related costs and requiring the interim rate increase to terminate at the end of 2010. The order also required WPL to refund to its 2007 retail electric customers the interim fuel rates collected in 2010 as a reduction to the 2011 test year base rate increase. As of Dec. 31, 2010, WPL reserved $5 million, including interest, for all interim fuel cost collections in 2010.

2009 Test Year -In August 2009, WPL notified the PSCW that its actual retail fuel-related costs incurred during the month of July 2009 were below the monthly monitoring range of plus or minus 8% and projected annual retail fuel-related costs for 2009 could fall outside the annual monitoring range of plus or minus 2%. In September 2009, the PSCW issued an order that set WPL’s retail electric fuel rates currently in effect subject to refund beginning Sep. 1, 2009. In January 2010, WPL filed a retail electric fuel refund report indicating retail fuel over collections of $4 million for the period from Sep. 1, 2009 through Dec. 31, 2009. In April 2010, WPL received approval from the PSCW to refund $4 million to its retail electric customers for retail fuel over collections for the period from Sep. 1, 2009 through Dec. 31, 2009. WPL refunded the $4 million to its retail electric customers in 2010.

2008 Test Year -In March 2008, WPL filed a request with the PSCW to increase annual retail electric rates by $16 million to recover anticipated increased electric production fuel and energy purchases (fuel-related costs). Actual fuel-related costs through February 2008, combined with projections of continued higher fuel-related costs for the remainder of 2008, significantly exceeded the amounts being recovered in retail electric rates at the time of the filing. In the second quarter of 2008, WPL received an order from the PSCW authorizing the requested $16 million interim increase, subject to refund, effective in April 2008. Retail fuel-related costs incurred by WPL in 2008 were lower than retail fuel-related costs used to determine interim rates that were effective April 2008, resulting in $23 million, including interest, of refunds owed to its retail electric customers. WPL refunded the $23 million to its retail electric customers in 2009.

Rule Changes -

Electric Fuel Cost Recovery Rule Changes in Wisconsin -In May 2010, Act 403 was enacted in Wisconsin to change statutes related to the process by which utilities recover electric fuel-related costs from their retail electric customers. On Jan. 1, 2011, revised new fuel rules issued by the PSCW became effective. The new fuel rules currently provide the following provisions and requirements for Wisconsin utilities:

PSCW approval of a future test year fuel cost plan resulting in changes in rates either as a separate proceeding or in a base rate case proceeding;

deferral of any change in unit fuel costs from the approved fuel cost plan outside a range established by the PSCW (initial range for WPL is between plus and minus 2%);

inclusion of selected other variable costs and revenues directly related to fuel costs in the limited purposefuel cost plan (costs for emission control chemicals and emission allowances are expected to be included in fuel costs for WPL beginning in 2012 with the approval of increasing electric retail ratesWPL’s next fuel cost plan);

reporting after completion of the plan year for comparison of actual plan year costs to those included in an amount equal to deferral credits that were fully amortizedthe fuel cost plan; and

restrictions on Dec. 31, 2007. WPL also requested clarification that it is authorized to record AFUDC on all CWIP balancesthe collection of deferred amounts if Wisconsin utilities earn in excess of their authorized return on common equity.

Refer to Note 1(h) of the CWIP balance included in the 2007 test year. In November 2007, the PSCW issued a final written order approving an annual“Notes to Consolidated Financial Statements” for additional details of WPL’s electric retail rate increase of $26 million effective Jan. 1, 2008 and approving WPL’s requested clarification regarding AFUDC and CWIP.fuel-related cost recovery mechanism.

2007 Wholesale Formula Rate CaseStructure -In December 2006, WPL received an order from FERC authorizing an interim rate increase, subject to refund, effective June 1, 2007 related to WPL’s request to implement a formula rate structure for its wholesale electric customers. In February 2008, final written agreements were filed with FERC that contained a settlement between WPL and its wholesale customers of the issues identified in WPL’s filing requesting the formula rate structure. In August 2008, FERC approved the settlement and the implementation of settlement rates effective June 1, 2008.2007. During the period the interim rate increase was effective from June 1, 2007 to May 31, 2008, WPL over-recovered $10 million, including interest, from its wholesale customers. In September 2008, WPL refunded the $10 million to its wholesale electric customers.

2007 Retail Rate Case - In January 2007,2009, WPL receivedfiled a request with FERC seeking approval of changes to WPL’s wholesale formula rates in order to implement for billing purposes the full impact of accounting for defined benefit pension and other postretirement benefits plans. In July 2010, FERC approved a settlement agreement reached earlier in 2010 between WPL and the wholesale customers regarding the formula rate change. WPL recorded an order fromadditional $4 million of electric revenues and regulatory assets in 2010 to reflect the PSCW approving a net increase in electricsettlement and gas retail rates of $34 million effective in January 2007. The final increase granted was lower thanis reducing the increase requested largely due to a decrease in forecasted fuel and purchased energy costs for the 2007 test period. The PSCW approval included a regulatory capital structure with 54% equity (compared to 59% requested), a return on common equity of 10.80% (compared to 11.20% requested) and lengthened certain regulatory asset amortization periods. The regulatory capital structure approved by the PSCW was determined by adjusting WPL’s financial capital structure by approximately $200 million (compared to $330 million requested) of imputed debt largelyconcurrently with collections from the Kewaunee Nuclear Power Plant (Kewaunee) and Riverside PPAs. The lower imputed debt adjustment than requested was primarily the resultcustomers.

Rate Case Details -Details of the PSCW denying WPL’s request to include the Sheboygan Falls Energy Facility (SFEF) lease in the regulatory capital structure calculation. In addition, as a result of a PSCW audit of plant costs, the PSCW determined that WPL should have used an after-tax AFUDCmost recent rate instead of a pre-tax AFUDC rate. WPL has made the required entries in 2007 to reflect this change and will record AFUDC at the after-tax rate for future retail jurisdiction construction projects.

Pursuant to the January 2007 order, WPL was allowed recovery of a portion of the previously deferred loss associated with the sale of Kewaunee in July 2005 and recovery of previously deferred costs associated with the extension of the unplanned outage at Kewaunee prior to the sale. The PSCW order included recovery of $23 million of these deferred costs through increased retail electric rates charged by WPL over a two-year recovery period ending December 2008.

The January 2007 PSCW order also approved modifications to WPL’s gas performance incentive sharing mechanism. Beginning in 2007, 35% of all gains and losses from WPL’s gas performance incentive sharing mechanism were to be retained by WPL, with the remaining 65% refunded to or recovered from customers. The January 2007 PSCW order also directed WPL to work with PSCW staff to help the PSCW determine if it may be necessary to reevaluate the current benchmarks for WPL’s gas performance incentive sharing mechanism or explore a modified one-for-one pass through of gas costs to retail customers. In October 2007, the PSCW issued an order providing WPL the option to choose to utilize a modified gas performance incentive sharing mechanism or switch to a modified one-for-one pass through of gas costs to retail customers using benchmarks. WPL evaluated the alternatives and chose to implement the modified one-for-one pass through of gas costs, which became effective Nov. 1, 2007.

In May 2007, WPL notified the PSCW that its actual average fuel-related costs for the month of March 2007 had fallen below the monthly fuel monitoring range setorders in WPL’s 2007 retail rate case and that projected average fuel-related costs for 2007 could be below the annual monitoring range to an extent that would warrant a decrease in retail electric rates. WPL’s notification also included a request for the PSCW to set WPL’s retail electric rates subject to refund. key jurisdictions were as follows (Common Equity (CE); Preferred Equity (PE); Long-term Debt (LD); Short-term Debt (SD)):

Jurisdictions

  Test
Period
  Authorized
Return on
Common

Equity (a)
  Capital Structure  After-tax
Weighted-
Average Cost

of Capital
  Average
Rate Base

(in millions)
 
    CE  PE  LD  SD   

Retail (PSCW):

         

Electric

   2011(b)   10.40  50.4  2.4  43.3  3.9  8.18 $1,697(c) 

Gas

   2011(b)   10.40  50.4  2.4  43.3  3.9  8.18 $215(c) 

Wholesale (FERC):

         

Electric

   2010    10.90  55.0  N/A    45.0  N/A    8.92 $169  

(a)Authorized returns on common equity may not be indicative of actual returns earned or projections of future returns.
(b)WPL’s 2011 rate order did not change the returns or capital structures approved in the prior rate order effective Jan. 1, 2010.
(c)Retail rate base amounts do not include CWIP. The PSCW provides a return on selected CWIP by adjusting the percentage return on rate base.

Other -

Economic Development Program -In June 2007,2010, the PSCW issued an order approving an economic development program effective July 2010, which is intended to attract and retain industrial customers in WPL’s service territory. The program permits WPL to provide eligible industrial customers a discounted energy rate based upon specifically-defined conditions. To be eligible for the program, each customer needs to demonstrate that it is also eligible for direct governmental assistance through a local, state or federal economic development program, in addition to other criteria. The discount amounts are limited to ensure recovery of marginal costs and will be decreased over time until a customer is paying the full tariff rate. In July 2010, CUB filed a petition for review with the Circuit Court of Dane County, Wisconsin (Circuit Court). CUB requested that the order be set aside, reversed or remanded to the PSCW for further deliberation and action. In February 2011, CUB’s petition for review was denied by the Circuit Court. WPL is currently unable to determine what action, if any, CUB may take in response to the Circuit Court’s decision or if any other legal action will occur. WPL is also unable to determine the level of participation in the program and the ultimate impact on its financial condition and results of operations.

Edgewater Unit 5 Purchase Agreement -WPL and WEPCO entered into an agreement, which became effective in March 2010, for WPL to purchase WEPCO’s 25% ownership interest in Edgewater Unit 5 for WEPCO’s net book value, including working capital. In June 2010, FERC authorized the transaction. In November 2010, the PSCW approved the transaction and WPL’s request to set retail electric rates subjectdefer all costs and benefits related to refund effective June 1, 2007. the purchase and operation of Edgewater Unit 5 between the time of the transaction and WPL’s next base rate case. WEPCO is currently working with the Michigan Public Service Commission to obtain satisfactory approval for the transaction. WPL currently expects the transaction to close in the first half of 2011.

Deferral Request for Federal Health Care Legislation Costs -In August 2007,April 2010, WPL received approval fromfiled a request with the PSCW for authorization to refund to its retail electric customers any over-recovery of retail fuel-relateddefer the anticipated and potential incremental costs during the period June 1, 2007 through Dec. 31, 2007. As of Dec. 31, 2008, WPL estimated the over-recovery of retail fuel-related costs during this period to be $22 million, including interest. WPL refunded to its retail electric customers $4 million in 2007 and $16 million in 2008. As of Dec. 31, 2008, WPL reserved $2 million for the remaining refund amounts, including interest, anticipated to be paid to its retail electric customers in the second quarter of 2009. WPL expects to receiveincur in order to comply with the PSCW’s decision onfederal health care legislation that was enacted in March 2010. The vast majority of the remaining refund amountincremental costs relate to changes in the first quartertaxability of 2009.

2005 Fuel-related Retail Rate Case -Medicare Part D supplement reimbursements. In September 2006,December 2010, the PSCW approved the deferral request for 2010 only. In order to obtain recovery of deferred amounts in a settlement agreement submittedfuture rate proceeding, WPL must prove that the actual amounts incurred meet the deferral criteria.

ENVIRONMENTAL MATTERS

Overview -WPL is subject to regulation of environmental matters by federal, state and local authorities as a result of its current and past operations. WPL monitors these environmental matters and intervenorsaddresses them with pollution abatement programs. These programs are subject to continuing review and are periodically revised due to various factors, including changes in environmental regulations, litigation of environmental requirements, construction plans and compliance costs. There is currently significant regulatory uncertainty with respect to the various environmental rules and regulations discussed below. Given the dynamic nature of environmental regulations and other related regulatory requirements, WPL has established an integrated planning process that established final fuel-related retailis used for environmental compliance for its operations. WPL anticipates future expenditures for environmental compliance will be material, including significant capital investments. WPL anticipates that prudent expenditures incurred to comply with environmental requirements likely would be recovered in rates at a level reflective of actual fuel costs incurred from July 1, 2005its

customers. Refer to “Strategic Overview - Environmental Compliance Plans” for details of WPL’s environmental compliance plans, including estimated capital expenditures. The following are major environmental matters that could potentially have a significant impact on WPL’s financial condition and results of operations.

Air Quality- The CAA and its amendments mandate preservation of air quality through June 30, 2006. The approval also allowed previously deferred, incremental purchased power energy costs associated with coal conservation efforts at WPL dueexisting regulations and periodic reviews to coal delivery disruptions to be included in the actual fuel costs and resolved all issues in the rate case regarding risk management activities and forecasting methodologies. WPL refunded $36 million to customers in October 2006 related to amounts collected in excessensure adequacy of final rates through June 2006.these provisions based on scientific data. As part of the settlement,basic framework under the CAA, the EPA is required to establish NAAQS, which serve to protect public health and welfare. These standards address six “criteria” pollutants, four of which are particularly relevant to WPL’s electric utility operations, including NOx, SO2, particulate matter (PM), and ozone. Ozone is not directly emitted from WPL’s generating facilities; however, NOx emissions may contribute to its formation in the atmosphere. Fine particulate matter (PM2.5) may also be formed in the atmosphere from SO2 and NOx emissions.

State implementation plans (SIPs) document the collection of regulations that individual state agencies will apply to maintain NAAQS and related CAA requirements. The EPA must approve each SIP and if a SIP is not acceptable to the EPA or if a state chooses not to issue separate state rules, then the EPA can assume enforcement of the CAA in that state by issuing a federal implementation plan (FIP). Areas that comply with NAAQS are considered to be in attainment, whereas routinely monitored locations that do not comply with these standards may be classified by the EPA as non-attainment and require further actions to reduce emissions. Additional emissions standards may also be applied under the CAA regulatory framework beyond NAAQS. The specific federal and state air quality regulations that may affect WPL’s operations include: CAIR, CATR, Clean Air Visibility Rule (CAVR), Utility MACT Rule, Wisconsin State Mercury Rule, Wisconsin RACT Rule, Industrial Boiler and Process Heater MACT Rule and NAAQS rules. WPL also agreed to refund any over-collection of fuel costs in the second half of 2006. In June 2007, the PSCW approved a $3 million refund, including interest, to WPL’s retail customersmonitors various other potential environmental matters related to air quality, including: litigation of various federal rules issued under the over-collectionCAA statutory authority; revisions to the New Source Review/PSD permitting programs and NSPS; and proposed legislation or other regulatory actions to regulate the emission of retail fuel-related costs duringGHG. Refer to the second half of 2006. WPL completedsections below the refund in August 2007.

Planned Utility Rate Case in 2009 - WPL expects to file a retail electric and gas rate case in April 2009 based on a 2010 forward-looking test period. The key driversfollowing tables for the filing include recovery of investments in reliability and emissions controls, deferred retirement plan costs and changes in retail electric demand forecasts as a resultdetailed discussion of the economy. WPL also expects the rate case to address various policy initiatives such as electric and gas decoupling for residential and small commercial customers, expanded energy efficiency initiatives and incentive mechanisms for managing gas commodity costs. Any rate changes granted are expected to be effective in January 2010. WPL does not plan to request emergency rate relief for 2009.

Other Utility Rate Case Information - With the exception of recovering a return on additions to WPL’s infrastructure, a significant portion of the rate increases included in the above table reflect a reduction in the amortization of deferred credits or the recovery of increased costs incurred or expected to be incurred by WPL. Thus, increases in revenues from rate increases are not expected to result in a significant increase in net income.

Authorized Return on Equity - At Dec. 31, 2008, WPL’s most recently authorized return on common equity for each of its key jurisdictions were as follows:following air quality regulations.

 

Jurisdictions

Authorized Return
on Common Equity

Wisconsin retail (PSCW):

ElectricEnvironmental

Regulation

  10.80%

GasEmissions
Regulated

    10.80%

Wholesale (FERC):EGUs Potentially

Affected

  

Actual/Anticipated

Compliance Deadline

CAIRSO2, NOx

Fossil fuel-fired EGUs
over 25 MW capacity

Phase I - NOx (2009); SO2 (2010) Phase II - 2015
CATRSO2, NOx

Fossil fuel-fired EGUs
over 25 MW capacity

Phase I - 2012

Phase II - 2014 (SO2 only)

CAVRSO2, NOx, PM

Fossil fuel-fired EGUs

To Be Determined (TBD)
Utility MACT Rule

Mercury and
other HAPs

Coal- and oil-fired EGUs
over 25 MW capacity

2014
Wisconsin State Mercury RuleMercury

Coal-fired EGUs

Phase I - 2010

Phase II - 2015

Wisconsin RACT RuleNOx

Edgewater Units 3-5

Phase I - 2009

Phase II - 2013

ElectricIndustrial Boiler and Process Heater MACT Rule

  10.90

Mercury and other HAPs

%

Fossil fuel-fired EGUs
below 25 MW capacity

2014
Ozone NAAQS RuleNOx

Fossil fuel-fired EGUs

TBD
Fine Particle NAAQS RuleSO2, NOx, PM

Fossil fuel-fired EGUs

TBD
NO2 NAAQS RuleNO2

Fossil fuel-fired EGUs

TBD
SO2 NAAQS RuleSO2

Fossil fuel-fired EGUs

2017

The following table lists the fossil fuel-fired EGUs by primary fuel type that WPL currently owns or operates with greater than 25 MW of nameplate capacity, all of which are located in Wisconsin.

Coal

Natural Gas

Columbia 1-2Sheboygan Falls 1-2
Edgewater 3-5Neenah 1-2
Nelson Dewey 1-2

South Fond du Lac 1-4

Rock River 3,5-6

Sheepskin 1

Rate Making PrinciplesCAIR- CAIR established new SO2 and NOx (both annual and ozone season) emission caps beginning in 2010 and 2009, respectively, with further reductions in SO2 and NOx emission caps effective in 2015. CAIR impacts WPL’s fossil fuel-fired EGUs with greater than 25 MW of capacity. CAIR included a large regional cap-and-trade system, where compliance may be achieved by either adding emission controls and/or purchasing emission allowances. In 2008, the U.S. Court of Appeals for New Electric Generating Facilities - Wisconsin has a law (Act 7) that allows a public utility that proposes to purchase or construct an electric generating facility in Wisconsin to applythe D.C. Circuit (D.C. Circuit Court) remanded CAIR to the PSCWEPA for an order that specifiesrevision to address flaws identified in advancea 2008 opinion issued in response to legal challenges to this rule. In the rate making principles thatinterim, CAIR obligations became effective for NOx on Jan. 1, 2009 and SO2 on Jan. 1, 2010 and remain in place until the PSCW will applyEPA issues a final CAIR replacement rule.

CATR -In July 2010, the EPA issued its proposed CAIR replacement rule, referred to certain electric generating facility costsas the CATR. The CATR would require SO2 and NOx emissions reductions from emission sources located in future rate making proceedings. This law is designed to give utilities31 states in Wisconsin more regulatory certainty, including providing utilities with a fixed rate of return and recovery period for these investments, when financing electric generation projects. WPL may utilize the rate making principles included in Act 7 for someeastern half of the electric generating facilities includedU.S. as well as the District of Columbia. The CATR would affect WPL’s fossil-fueled EGUs with greater than 25 MW of capacity. Existing CAIR compliance requirements remain effective until the final CATR compliance requirements supersede them, which the EPA currently estimates will occur in its generation plan. Refer to “Strategic Overview - Generation Plan”2012. Beginning in 2012, the CATR would establish state emission caps for additional details of WPL’s generation plan including discussionSO2 and NOx (Phase I). These SO2 emission caps would be lowered further in 2014 (Phase II). While the NOx emission caps are not lowered further in the CATR, the EPA indicates that it will likely lower these caps in the final version of the PSCW’s May 2007 decision regarding WPL’s applicationCATR or subsequent rulemakings.

In the CATR, the EPA identifies one preferred and two alternative approaches. All three approaches establish state emission caps; however, they allow varying degrees of limited, if any, emissions trading to meet compliance requirements. In addition, the emission allowances used for advance rate making principlesAcid Rain and CAIR program compliance cannot be used for its Cedar Ridge wind project (WPL subsequently did not accept the PSCW’s decision). WPL expects to use traditional rate making procedures for the recovery of and return on its capital costs for the 200 MW Bent Tree wind project.

Under Act 7 in Wisconsin, a utility seeking to construct an electric generating facility has the option to seek advance rate making treatment for that facility. A Wisconsin utility therefore is not obligated to file for advance rate making principles. Also, under Act 7 a utility can proceed with an approved project under traditional rate making if the terms of the PSCW order on the advance rate making principles are viewed as unsatisfactory to the utility. A CA application is required to be filedcompliance with the PSCWCATR.

WPL continues to implement its environmental compliance plans to meet the currently effective CAIR requirements, which include investments in emission controls for the construction approvalEGUs as well as use of any new electric generating facility located in Wisconsin with a capacity of less than 100 MW or any new electric generating facility located outside of Wisconsin. A CPCN applicationemission allowances. The final CATR is required to be filed with the PSCW for construction approval of any new electric generating facility located in Wisconsin with a capacity of 100 MW or more. In both situations, construction may not commence until the PSCW has granted approval based on a finding that the project is in the public interest. In addition, WPL’s ownership and operation of electric generating facilities located outside of Wisconsin to serve Wisconsin customers is subject to retail utility rate regulation by the PSCW.

AFUDC - New electric generating facilities require large outlays of capital and long periods of time to construct resulting in significant financing costs. Financing costs incurred by utilities during construction are generally included as part of the CWIP cost of the new generating facility through AFUDC rates as approved by the applicable regulatory commission. In

December 2008, the PSCW issued its written order for WPL’s 2009/2010 retail electric rate case which authorizes WPL to record AFUDC on all CWIP balances in excess of the CWIP balances used to determine settlement rates in the 2009 test year. General rate making principles provide WPL the ability to recover AFUDC as depreciation expense after the asset is placed in service.

Preliminary Survey and Investigation Charges and Pre-construction Expenditures - New electric generating facilities require material expenditures for planning, siting, engineering studies and other activities, which must be undertaken prior to receiving approval from regulatory commissions to begin construction. These expenditures commonly called preliminary survey and investigation charges are generally recorded as “Regulatory assets” on the Consolidated Balance Sheet for large generating facility projects in accordance with FERC regulations. In Wisconsin, the retail portion of these amounts is expensed immediately, unless otherwise authorized by the PSCW. However, since these amounts are material for WPL’s Cedar Ridge wind project, WPL’s proposed Nelson Dewey #3 generating unit and WPL’s Clean Air Compliance Program (CACP) projects, WPL requested and received deferral accounting approval to record the retail portion of these costs as “Regulatory assets” on the Consolidated Balance Sheet. In the fourth quarter of 2008, the PSCW denied continuation of the Nelson Dewey #3 generating unit project. As a result, no material additional costs for this project are expected to be deferred.

In additionissued by the EPA in mid-2011. WPL will monitor future developments relating to the expenditures noted above, certain projects needing regulatory approval may also require that payments for long-lead materials be incurred prior to project approval in order to meet anticipated completion schedules. These expenditures have been identifiedCATR and update its environmental compliance plans as pre-construction expenditures by WPL. For WPL, the retail portion of pre-construction expenditures for the projects described in the previous paragraph has also been approved for deferral as regulatory assets. All remaining pre-construction expenditures for WPL are recorded as “Regulatory assets” on the Consolidated Balance Sheet.

For WPL, the wholesale portion of amounts deferred and recorded as preliminary survey and investigation charges do not include any accrual of carrying costs or AFUDC. WPL’s retail portion of deferred preliminary survey and investigation charges (commonly referred to as pre-certification expenditures) and pre-construction expenditures include accrual of carrying costs as prescribed in the approved deferral order. Upon regulatory approval of the project, the wholesale portion of deferred preliminary survey and investigation charges as well as all pre-construction expenditures are transferred to CWIP and begin to accrue AFUDC. The retail portion of deferred preliminary survey and investigation charges or pre-certification expenditures remain as regulatory assets until they are approved for inclusion in revenue requirements and amortized to expense. WPL believes amounts currently deferred as either preliminary survey and investigation expenditures or pre-construction expenditures are probable of recovery from customers through changes in future rates. WPL is currently recovering through retail rates the amounts for the Cedar Ridge wind project and a portion of the Nelson Dewey #3 pre-certification expenditures. Remaining deferred amounts for Nelson Dewey #3 and the CACP projects have not yet been included in rates charged to customers.

Refer to “Strategic Overview - Generation Plan” and Note 1(b) of the “Notes to Consolidated Financial Statements” for additional details on these costs.

Utility Fuel Cost Recovery - WPL’s wholesale electric and retail gas tariffs provide for subsequent adjustments to its rates for changes in commodity costs thereby mitigating price risk for prudently incurred commodity costs. Such rate mechanisms significantly reduce commodity price risk associated with WPL’s wholesale electric margins and WPL’s retail gas margins. WPL’s retail electric margins, however, are more exposed to the impact of changes in commodity prices due largely to the current retail recovery mechanism in place in Wisconsin for fuel-related costs as discussed below.

Retail Electric Fuel-related Cost Recovery Mechanism - WPL’s retail electric rates are based on forecasts of forward-looking test periods and include estimates of future monthly fuel-related costs (includes fuel and purchased power energy costs) anticipated during the test period. During each electric retail rate proceeding, the PSCW sets fuel monitoring ranges based on the forecasted fuel-related costs used to determine rates in such proceeding. If WPL’s actual fuel-related costs fall outside these fuel monitoring ranges, the PSCW can authorize an adjustment to future retail electric rates.

The fuel monitoring ranges set by the PSCW include three different ranges based on monthly costs, cumulative costs and annual costs during the test period. In order for WPL to be authorized to file for a proceeding to change rates related to fuel-related costs during the test period, WPL must demonstrate: a) that either 1) any actual monthly costs during the test period exceeded the monthly ranges or 2) the actual cumulative costs to date during the test period exceeded the cumulative ranges; and b) that the annual projected costs (that include cumulative actual costs) for the test period also exceed the annual ranges. WPL, the PSCW or any other affected party may initiate a proceeding to change rates due to changes in fuel-related costs

during the monitoring period based on the above criteria. In December 2008, the PSCW approved an order continuing WPL’s fuel cost monitoring ranges of plus or minus 8% for the monthly range; for the cumulative range, plus or minus 8% for the first month, plus or minus 5% for the second month, and plus or minus 2% for the remaining months of the monitoring period; and plus or minus 2% for the annual range.

The PSCW attempts to authorize, after a required hearing, interim fuel-related rate increases within 21 days of notice to customers. Any such change in rates would be effective prospectively and would require a refund with interest at the authorized return on common equity if final rates are determined to be lower than interim rates approved. Rate decreases due to reductions in fuel-related costs can be implemented without a hearing. The rules also include a process whereby Wisconsin utilities can seek deferral treatment of 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 retail rate cases.

Potential Changes to Electric Fuel-related Cost Recovery Mechanism - In February 2007, WPL and certain other investor-owned utilities jointly filed with the PSCW proposed changes to the current retail electric fuel-related cost recovery rules in Wisconsin. The proposal recommends each utility annually file a forecast of total fuel-related costs and sales for the upcoming 12-month period, which will be used to determine fuel-related rates for such period. Any under- or over-collection of actual fuel-related costs, in excess of plus or minus 1%, for a utility during such 12-month period would be reflected in an escrow account, with interest for that utility. The balance of the escrow account at the end of each year would be included in the forecast of total fuel-related costs for the following 12-month period allowing recovery of under-collected costs or refund of over-collected costs in each subsequent year. The proposal also provides the PSCW an opportunity to review the actual fuel-related costs for each 12-month period to ensure the fuel-related costs were prudent. The definition of fuel-related costs would also be expanded to specifically include MISO market costs and revenues, emission allowance and trading costs and revenues, renewable resource credit costs and revenues and other variable operation and maintenance costs.

In May 2007, PSCW Commissioners directed PSCW staff to draft proposed new retail electric fuel-related cost recovery rules in Wisconsin similar to the joint utility proposal filed with the PSCW in February 2007. The major differences between the joint utility proposal and the current PSCW staff draft rules include: 1) the PSCW staff draft rules include a plus or minus 2% threshold for changes in rate recovery compared to the 1% level included in the joint utility proposal; 2) the PSCW staff draft rules propose an annual deferral accounting process instead of the monthly escrow accounting proposed by the joint utilities; and 3) the PSCW staff draft rules include an earnings test such that future collection of under collected amounts deferred under these rules may be limited if the individual utility is earning in excess of its authorized return on equity.

In July 2008, PSCW Commissioners voted to formally proceed with the promulgation of new retail electric fuel-related cost recovery rules in Wisconsin that were developed by PSCW staff in 2007. A public hearing and comment period, as well as subsequent legislative committee review, are required before any changes to the current rules could become effective. More recently the PSCW has indicated some desire for statutory changes prior to promulgating revised fuel rules. WPL expects the fuel cost recovery process will be a subject of both legislative and administrative interest in 2009.needed. WPL is currently unable to predict the final outcome of this initiative.the EPA’s CATR as a replacement rule for CAIR, but expects that capital investments and/or modifications to meet compliance requirements of the rule could be significant.

Recent Regulatory-related Legislative DevelopmentsCAVR -

Greenhouse Gas (GHG) Emissions Legislative Developments:

Midwestern GHG Accord (GHG Accord) - In November 2007, several Midwest state Governors (including the Governor of Wisconsin) signed the GHG AccordCAVR requires states to be carried out through the Midwest Governor’s Association (MGA). Under the GHG Accord, a working group is discussing implementation of a Midwestern GHG Reduction Program that will: 1) establish GHG reduction targets and timeframes consistent with member state targets; 2) develop a market-based and multi-sector cap and trade program to help achieve GHG reductions; 3) establish a system to enable tracking, management, and crediting for entities that reduce GHG emissions; and 4) develop and implement SIPs to address visibility impairment in designated national parks and wilderness areas across the country with a national goal of no impairment by 2064. A proposed CAVR SIP for Wisconsin has been submitted to the EPA for review and approval. This SIP includes Best Available Retrofit Technology Rule (BART) emission controls and other additional steps asmeasures needed for reducing state contributions to achieveregional haze. The EPA has not issued a response on this CAVR SIP. If the reduction targets, such asCAVR SIP is found to be deficient, then the EPA is required to promulgate a low-carbon fuel standardsCAVR FIP to address these requirements in the interim until the CAVR SIP is approved. The CAVR SIP will determine required compliance actions and deadlines.

There are uncertainties in the applicability of and compliance outcomes of BART control approaches that will be approved by the EPA for inclusion in CAVR SIPs. EGU emissions of primary concern for BART and regional incentiveshaze regulation include SO2, NOx and funding mechanisms. APM. There are pending obligations under the EPA’s CAVR to complete BART determinations that would evaluate control options to reduce these emissions at certain WPL EGUs that were built between 1962 and 1977. The D.C. Circuit Court remand of CAIR to the EPA in 2008 may have an indirect impact on the CAVR and BART SIP implementation approach because the EPA allowed BART obligations for SO2 and NOx emissions to be fulfilled by CAIR. The proposed capCATR does not address the EPA’s prior decision related to CAIR being sufficient to meet compliance obligations for units subject to BART emissions reduction requirements for SO2 and trade agreementNOx under the CAVR (often referred to as “CAIR equals BART”). The EPA’s revised assessment of the relationship for the CAVR’s BART requirements and comprehensivethe proposed CATR remains pending, including whether the EPA’s compliance approach and final rule will allow for “CATR equals BART” for SO2 and NOx. In addition, there are uncertainties whether additional emission reductions could be required to address regional haze impacts beyond BART. WPL is unable to predict the impact that CAVR might have on the operations of its existing EGUs until the EPA final approval of state CAVR plans, which is currently expected in 2011.

Utility MACT Rule -In 2009, the EPA announced its intention to develop MACT rules for EGUs pursuant to Section 112 of the CAA. When developing a MACT rule, the EPA looks at the current level of emissions control achieved by best-performing similar sources. These emissions control levels set a baseline, often referred to as the “MACT floor,” used in determination of GHG proposals from the MGA will not be available until some timeperformance standards required under the new rule. Each regulated EGU must demonstrate performance with the standards adopted in the final rule. The CAA requirements of Section 112 state that these standards become effective upon promulgation of the final rule and that compliance is required no later than three years after the effective date of the standards. In January 2010, the EPA issued an information collection request for coal- and oil-fired EGUs over 25 MW in 2009. Further legislative and/or regulatory action in each participating state will beorder to develop a proposed Utility MACT Rule for the control of mercury and other federal HAPs. The purpose of the proposed information collection request was to collect data necessary to adopt any model rule oridentify affected categories of EGUs that will be

subject to implement other provisionsa Utility MACT Rule and to define the MACT floor. In February 2010, the EPA entered into a consent decree that mayrequires the agency to propose Utility MACT Rules for coal- and oil-fired EGUs no later than March 2011 and promulgate final rules no later than November 2011. Based upon the timeline set forth in the consent decree, compliance with the Utility MACT Rule is expected to be proposed under this GHG Accord.required by November 2014. WPL is currently unable to determine what impacts the GHG Accord will have on its future financial condition, results of operations or cash flows.

Other - In April 2007, Governor Doyle signed Executive Order 191 which created the Wisconsin Task Force on Global Warming. In July 2008, the task force issued its final report containing policy recommendations for state action on climate change. The report contains a series of short- and long-term goals and action items Wisconsin might undertake. Some of these items require legislative action before they can take effect, while others can be implemented by administrative action.

Specifically,predict the final report recommendsoutcome of a Utility MACT Rule to regulate mercury and other federal HAPs from EGUs, but expects that capital investments and/or modifications could be significant to comply with any such regulations.

Wisconsin GHGState Mercury Rule -The Wisconsin State Mercury Rule requires electric utility companies in Wisconsin to meet compliance requirements to reduce annual mercury emissions return to 2005 levels no later than 2014,by 40% from a 22% reduction from 2005 levels by 2022 and a 75% reduction from 2005 levels by 2050. The report also includes recommendations for aggressive energy efficiency and conservation policies across the Wisconsin economy, recommended exploration of innovative rate design and demand response programs, and calls for the removal of financial disincentives for utilities to promote and investhistoric baseline beginning in conservation and efficiency. The task force report also recommended increased funding for the Wisconsin efficiency program, Focus on Energy, which is funded by a recoverable percentage of utility gross revenues.2010 (Phase I). In addition, the Wisconsin task force final report recommendedState Mercury Rule requires large coal-fired EGUs with greater than 150 MW of capacity to either achieve a 90% annual mercury emissions reduction standard or limit the annual concentration of mercury emissions to 0.008 pounds of mercury per gigawatt-hour beginning in 2015 (Phase II). Small coal-fired EGUs between 25 MW and 150 MW of capacity must install Best Available Control Technology (BACT) by January 2015 to reduce mercury emissions. As an alternative, this rule allows large and small EGUs to achieve compliance through averaging. There is also an alternative multi-pollutant option that utilitiesextends the time for compliance with the annual mercury reduction requirement until 2021. However, this requires the affected facilities to achieve NOx and SO2 reductions beyond those currently required by federal and state regulations. In December 2010, WPL filed its compliance plan with the Wisconsin Department of Natural Resources (DNR). WPL’s plan states that WPL will utilize large and small EGU averaging to comply with the additional mercury rule emissions reduction requirements that commence in 2015 and not use the multi-pollutant option. WPL continues to evaluate the impact of this state mercury rule and the federal Utility MACT Rule discussed above to determine further mercury emission reductions that will be requiredrequired. Refer to produce 25%“Strategic Overview - Environmental Compliance Plans - Emission Control Projects” for discussion of proposed WPL emission controls that support compliance with the requirements of this rule.

Wisconsin RACT Rule -In 2004, the EPA designated 10 counties in Southeastern Wisconsin as non-attainment areas for the ozone NAAQS. This designation includes Sheboygan County, where WPL operates the Sheboygan Falls Energy Facility and Edgewater. In 2007, the Wisconsin DNR issued a RACT Rule that requires NOx emission reductions at EGUs as part of the electricity they generatefederal ozone SIP submittal to address non-attainment areas in Wisconsin. Facility modifications are not necessary at the Sheboygan Falls Energy Facility to comply with this rule. As part of its environmental compliance plan, WPL completed investments for installation of NOx emission control technologies at Edgewater to meet the 2009 to 2012 compliance requirements (Phase I). Additional investments will be needed at Edgewater to achieve compliance with the 2013 requirements that include facility boiler NOx rate limitations and a mass emissions cap (Phase II). Refer to “Strategic Overview - Environmental Compliance Plans - Emission Control Projects” for discussion of proposed emission controls for further NOx emission reductions at Edgewater to meet 2013 compliance deadlines.

Ozone NAAQS Rule -In 2008, the EPA announced reductions in the primary NAAQS for eight-hour ozone to a level of 0.075 parts per million (ppm) from renewable energy sources by 2025 (current state lawthe previous standard of 0.08 ppm. In January 2010, the EPA issued a proposal to reduce the primary standard to a level within the range of 0.06 to 0.07 ppm and establish a new seasonal secondary standard. The final rule is approximately 10% by 2015). These topics continueexpected to be studiedissued by wayJuly 2011. Depending on the level and location of various generic dockets which are currently on going. Regarding the cap and trade policy, the task force concluded that a broadly based, multi-sector, mandatory federal level cap and trade program is strongly preferred. However, it also recommended that Wisconsin work with the MGA to develop a regional cap and trade program. Recommendations from these efforts would likely require legislative action before implementation approaches can be determined. In addition, state effortsnon-attainment areas, WPL may be influenced bysubject to additional NOx emissions reduction requirements to meet the outcomes of the GHG Accord.new ozone standard. The schedule for compliance with this rule has not yet been established. WPL is currently unable to determine what impacts these initiatives will have on its future financial condition, resultspredict the impact of operations or cash flows.

Renewable Energy Standards Legislative Developments:

In March 2006, a law (Act 141) governing renewable energy was enacted in Wisconsin. Act 141 commits Wisconsin utilitiesany potential changes to a Renewable Portfolio Standard (RPS) using a benchmark of average retail sales of renewable electricity in 2001, 2002 and 2003, which was approximately 3% for WPL. WPL must increase renewable retail electric sales as a percentage of total retail electric sales by two percentage points above this benchmark by 2010 and by six percentage points above this benchmark by 2015. Wisconsin utilities may meet the renewable energy requirements of the RPS with renewable energy generated by the utility, renewable energy acquired under PPAs or the use of renewable resource credits.

Refer to “Strategic Overview - Generation Plan” for discussion of WPL’s generation plan, which includes additional supply from wind generation that will contribute towards WPL meeting the RPS in Wisconsin discussed above. The wind generation proposed by WPL was selected as an economic source of energy as part of a resource planning process. WPL will need to add approximately 50 MW of incremental renewable electric supply to its current electric supply portfolio to increase by 1% its sales from renewable energy sources as a percentage of its total retail electric sales.

Income Tax Legislative Developments:

American Recovery and Reinvestment Bill of 2009 - In February 2009, the ARRB was enacted. The ARRB contains various provisions that are intended to stimulate the economy and provide tax relief to individuals and employers. The most significant provisions of the ARRB for WPL are related to credits available for wind facilities placed in service by Dec. 31, 2012. The bill provides for a choice of the renewable production tax credit over a 10-year period or a 30% investment tax credit based on the qualifying cost of the plant in the year the facility is placed in service. The ARRB also provides a one year extension of 50% bonus depreciation for certain expenditures for property that is acquired or constructed in 2009. WPL is currently evaluating the impacts of ARRBOzone NAAQS on its financial condition and results of operations. Refer to “Other Matters - Other Future Considerations - Production Tax Credits” for additional details of potential tax credits for WPL’s proposed wind projects.

Wisconsin Senate Bill 62Fine Particle NAAQS Rule -The EPA lowered the 24-hour fine particle primary NAAQS (PM2.5 NAAQS) from 65 micrograms per cubic meter (ug/m3) to 35 ug/m3 in 2006. In February 2009, SB 62 was enacted. SB 62 contains various provisions intended to reduce the state’s current budget gap. The most significant provisionEPA announced final designation of SB 62 forPM2.5 non-attainment areas. WPL is combined reporting for corporate income taxation in Wisconsin. WPL is currently evaluating the impacts of SB 62 on its financial condition, results of operations and cash flows from operations.

Emergency Economic Stabilization Act of 2008 (EESA) - In October 2008, the EESA was enacted. The EESA contains various provisions intended to improve the U.S. economy by restoring confidencedoes not have any generating facilities in the credit markets and providing tax relief to individuals and businesses. One of the tax law changes includednon-attainment areas announced in the EESA that may provide benefits to WPL is an extension of tax credits for research and development activities. In January2009. However, in 2009, the PSCWD.C. Circuit Court issued an order requiring WPLa decision for litigation regarding the EPA’s determination not to defer,lower the annual PM2.5 NAAQS in 2006. In response to the litigation decision, the EPA must re-evaluate its justification for not tightening the annual standard related to adverse effects on health and visibility. If the annual PM2.5 standard becomes more stringent, it could require SO2 and NOx emission reductions in additional areas not currently designated as non-attainment. The schedule for compliance with carrying costs at the authorized pre-tax weighted average costs of capital, the revenue requirement impacts resulting from the EESA until future rate proceedings when the impacts are discernable.this rule has not yet been established. WPL is currently unable to predict the complete impactspotential impact of the EESA will havere-evaluation of the annual PM2.5 NAAQS on its financial condition and results of operationsoperations.

Nitrogen Dioxide (NO2) NAAQS Rule -In January 2010, the EPA issued a final rule to strengthen the primary NAAQS for NOx as measured by NO2. The final rule establishes a new one-hour NAAQS for NO2 of 100 ppb and cash flows.associated ambient air monitoring requirements, while maintaining the current annual standard of 53 ppb. The EPA is expected to designate non-attainment areas for the new NO2 NAAQS by January 2012. The final rule is currently being challenged by several groups in the D.C. Circuit Court. The schedule for compliance with this rule has not yet been established. WPL is currently unable to predict the impact of any potential NO2 NAAQS changes on its financial condition or results of operations.

SO2 NAAQS Rule -In June 2010, the EPA issued a final rule that establishes a new one-hour NAAQS for SO2 at a level of 75 ppb. The final rule also revokes both the existing 24-hour and annual standards. The EPA is expected to designate non-attainment areas for the SO2 NAAQS by June 2012. Compliance with the new SO2 NAAQS rule is currently expected to be required by 2017 for non-attainment areas designated in 2012. The final rule is being challenged by several groups in the D.C. Circuit Court. WPL is currently unable to predict the impact of any potential SO2 NAAQS changes on its financial condition or results of operations.

Industrial Boiler and Process Heater MACT Rule - The initial Industrial Boiler and Process Heater MACT Rule issued by the EPA contained compliance requirements beginning in 2007 related to HAPs from fossil-fueled EGUs with less than 25 MW capacity as well as certain auxiliary boilers and process heaters operated at EGUs. In 2007, a court decision vacated the initial rule. In February 2011, the EPA promulgated a revised Industrial Boiler and Process Heater MACT Rule. The revised Industrial Boiler and Process Heater MACT Rule will be effective 60 days after it is published in the Federal Register. The CAA requirements of Section 112 state that the standards become effective upon promulgation of the final rule and that compliance is required no later than three years after the effective date of the standards. Based on this requirement, the anticipated deadline for compliance with this rule is 2014. The federal CAA generally requires affected facilities to submit to state permitting authorities an application for a case-by-case MACT determination for all potentially affected EGUs under this rule. Case-by-case MACT determinations are the compliance measures that are in effect until revised final federal regulations can replace these interim requirements. WPL submitted case-by-case permit application information in 2009. The outcome of the case-by-case MACT determinations by the Wisconsin DNR is uncertain at this time. WPL will monitor future developments relating to this rule and update its environmental compliance plans as needed. WPL is currently unable to predict the outcome of the Industrial Boiler and Process Heater MACT Rule, but expects that capital investments and/or modifications to meet compliance requirements of the rule could be significant.

Air Permit Renewal Challenges- WPL is aware of certain public comments or petitions from citizen groups that have been submitted to the Wisconsin DNR or to the EPA regarding the renewal of air operating permits at certain of its generating facilities. In some cases, the EPA has responded to these comments and petitions with orders to the Wisconsin DNR to reconsider the air operating permits of WPL’s generating facilities. WPL has received renewed air permits for Columbia, Edgewater and Nelson Dewey from the Wisconsin DNR, which considered all public comments received as part of the renewal process.

Economic Stimulus Act of 2008Columbia - In February 2008, the ESA was enacted. The ESA contains various provisionsSierra Club submitted a notice of intent to sue the EPA for failure to respond to its petition encouraging the EPA to challenge the air permit issued by the Wisconsin DNR for Columbia. In 2009, the EPA responded to the Sierra Club petition and granted one of three issues from the Sierra Club petition, objecting to that are intended to provide tax relief to individuals and employers. The most significant provisionportion of the ESApermit issued by the Wisconsin DNR. In July 2010, WPL received a copy of a notice of intent to file a civil lawsuit (NOI) by the Sierra Club against the EPA based on what the Sierra Club asserts is unreasonable delay in the EPA performing its duties related to the granting or denial of the Columbia air permit. Specifically, the Sierra Club alleges that because the Wisconsin DNR has exceeded its 90-day timeframe in which to respond to the EPA’s order, the EPA must now act on the permit. In September 2010, the Wisconsin DNR proposed a construction permit and a revised operation permit for Columbia. In October 2010, WPL submitted comments objecting to the appropriateness of the proposed draft permits. In November 2010, the comment period closed, and in February 2011, the Wisconsin DNR made the determination not to issue either of the permits. WPL believes the previously issued air permit for Columbia is still valid. WPL is a 50% bonus tax depreciation deduction for certain expenditures for property that is acquired or constructed in 2008. At Dec. 31, 2008, WPL estimated its related 2008 bonus tax depreciation deductioncurrently unable to be approximately $65 million.

Other Legislative Developments:

Worker, Retireepredict the outcome of this matter and Employer Recovery Act of 2008 (WRERA) - In December 2008, the WRERA was enacted. The WRERA contains various provisions that are intended to provide relief to individuals and retirement plan sponsors impacted by material losses to their retirement plan assets in 2008. The most significant provision of the WRERA that may impact WPL relates to pension plan funding relief. The WRERA permits pension plan asset values to be smoothed over a 24-month period and eliminates the cliff effect for companies that do not achieve their annual funding targets. Refer to “Liquidity and Capital Resources - Cash Flows - Operating Activities - Pension Plan Contributions” for discussion of anticipated retirement plan contributions by WPL that are expected to meet or exceed the new pension plan funding requirements under WRERA.

Other Recent Regulatory Developments -

Clean Air Compliance Projects -WPL must file a construction application and receive authorization from the PSCW to proceed with any individual clean air compliance project containing estimated project costs of $8 million or more. In March 2007, the PSCW approved the deferral of the retail portion of WPL’s incremental pre-certification and pre-construction costs for current or future clean air compliance rule projects requiring PSCW approval, effective with the request date of November 2006. WPL currently anticipates that such deferred costs will be recovered in future rates and therefore does not expect these costs to have an adverse impact on its financial condition or results of operations. Refer to “Strategic Overview - Multi-emission Compliance Plan” for discussion of WPL’s construction applications filed with the PSCW in 2007 to install air pollution controls to reduce SO2 and mercury emissions at Nelson Dewey and in 2008 to install air pollution controls to reduce NOx at Edgewater Unit 5.

Advanced Metering InfrastructureEdgewater -AMI technology is expected In 2009, the Sierra Club petitioned the EPA to improve customer service, enhance energy management initiatives and provide operational savings through increased efficiencies. WPL currently plansobject to fully install AMI through a phased approach from 2008 through 2010.proposed Title V air permit for Edgewater that the Wisconsin DNR had submitted to the EPA for review. In February 2008,2009, the PSCWSierra Club filed a notice of intent to sue the EPA over its failure to act on the petition. In August 2010, the EPA issued an order approving WPL’s CA application for construction authority forto the installationWisconsin DNR granting in part and denying in part the Sierra Club’s petition. The Wisconsin DNR has not yet acted on the EPA order. In December 2010, WPL received a copy of AMIan NOI by the Sierra Club against the EPA based on what the Sierra Club asserts is unreasonable delay in Wisconsin. WPL’s capital expenditures for AMI arethe EPA performing its duties related to the reconsideration of the Edgewater Title V air permit. Specifically, the Sierra Club alleges that because the Wisconsin DNR has exceeded its 90-day timeframe in which to respond to the EPA’s order, the EPA must now act on the reconsideration of the permit. WPL is currently estimatedunable to be $95 million ($75 million forpredict the electric portionoutcome of this matter and $20 million for the gas portion).impact on its financial condition or results of operations.

MISO MarketNelson Dewey -In August 2007,September 2010, the PSCWSierra Club petitioned the EPA and the Wisconsin DNR to reopen a Nelson Dewey air permit. The Sierra Club alleges that the Nelson Dewey air permit issued an order requiringby the Wisconsin DNR in 2008 should be corrected because certain modifications were made at the facility without complying with the PSD program requirements. In November 2010, WPL filed a response to discontinue, effective Dec. 31, 2007, the deferralpetition with the EPA and the Wisconsin DNR objecting to its claims and supporting the Wisconsin DNR’s issuance of the retail portioncurrent permit. No action on this petition has been taken by the EPA or the

Wisconsin DNR. WPL is currently unable to predict the outcome of certain costs incurred by WPL to participate inthis petition and the MISO market. Beginning Jan. 1, 2008, these MISO costs are subject to recovery through WPL’s retail electric fuel-related cost recovery mechanism. At Dec. 31, 2008, WPL had $10 millionimpact on its financial condition or results of deferred retail costs incurred prior to 2008 to participate in the MISO market that were recognized in “Regulatory assets” on the Consolidated Balance Sheet. In December 2008, WPL received approval from the PSCW, as part of the stipulated agreement reached regarding the 2009/2010 retail rate case, to recover the $10 million of deferred retail costs over a two-year period ending Dec. 31, 2010.operations.

Depreciation StudyAir Permitting Violation Claims -In February 2008, the PSCW issued an order approving the implementation of updated depreciation rates for WPL effective July 1, 2008 as a result of a new depreciation study. In June 2008, FERC accepted the updated depreciation rates for use in WPL’s wholesale formula rates. Refer to Note 1(e)12(c) of the “Notes to Consolidated Financial Statements” for detailsdiscussion of complaints filed by the Sierra Club in September 2010 and a notice of violation issued by the EPA in December 2009 regarding alleged air permitting violations at Nelson Dewey, Columbia and Edgewater.

Water Quality -

Section 316(b) of Federal Clean Water Act -The Federal Clean Water Act requires the EPA to regulate cooling water intake structures to assure that these structures reflect the “best technology available” for minimizing adverse environmental impacts to fish and other aquatic life. The second phase of this EPA rule is generally referred to as Section 316(b). Section 316(b) applies to existing cooling water intake structures at large steam EGUs. In 2007, a court opinion invalidated aspects of the Section 316(b), which allowed for consideration of cost-effectiveness when determining the appropriate compliance measures. As a result, the EPA formally suspended Section 316(b) in 2007. In 2009, the U.S. Supreme Court granted the EPA authority to use a cost-benefit analysis when setting technology-based requirements under Section 316(b). A revised Section 316(b) rule reflecting the U.S. Supreme Court’s decision is anticipated to be proposed by the EPA in 2011 and a final rule is expected in 2012. WPL has identified two (Nelson Dewey Units 1-2 and Edgewater Units 3-5) generating facilities that may be impacted by the revised Section 316(b) rule. The schedule for compliance with this rule has not yet been established. WPL is currently unable to predict the final requirements from Section 316(b), but expects that capital investments and/or modifications resulting from the rule could be significant.

Wisconsin State Thermal Rule -Section 316(a) of the Federal Clean Water Act requires the EPA to regulate thermal impacts from wastewater discharges of industrial facilities, including those from EGUs. States have authority to establish standards for these discharges in order to minimize adverse environmental impacts to aquatic life. All WPL facilities are subject to these standards upon state promulgation, which become applicable upon their incorporation into a facility’s wastewater discharge permit. In January 2010, the Wisconsin Natural Resources Board adopted its state standard for regulating the amount of heat that facilities can discharge into Wisconsin waters. This rule was necessary because the EPA determined that Wisconsin had not developed a state thermal standard consistent with Section 316(a) of the Federal Clean Water Act. The Wisconsin State Thermal Rule was approved by the EPA in October 2010. Compliance with the thermal rule will be evaluated on a case-by-case basis as wastewater discharge permits for WPL’s generating facilities are renewed in the future. WPL continues to evaluate the thermal rule regulatory requirements and the compliance options available to meet the heat limitations for discharges from its EGUs. WPL is unable to predict the final requirements of this rule until wastewater discharge permits for impacted facilities are renewed. If capital investments and/or modifications are required, WPL believes these investments could be significant.

Hydroelectric Fish Passages and Fish Protective Devices -In 2002, FERC issued an order requiring the following actions by WPL regarding its Prairie du Sac hydro plant: 1) develop a detailed engineering and biological evaluation of potential fish passages for the facility; 2) install an agency-approved fish-protective device at the facility; and 3) install an agency-approved fish passage at the facility. In December 2009, WPL completed the installation of the agency-approved fish-protective device. WPL continues to work with the agencies to design and install the fish passage. The U.S. Fish and Wildlife Service and the Wisconsin DNR have requested additional information to support the conceptual plan for the fish passage and extended the required completion date to Dec. 31, 2012. WPL currently expects to request an additional extension from FERC in 2011. WPL believes the required capital investments and/or modifications to comply with the FERC order for the fish passage at its Prairie du Sac hydro plant could be significant.

Land and Solid Waste -

CCRs -WPL is monitoring potential regulatory changes that may affect the rules for operation and maintenance of ash surface impoundments (ash ponds) and/or landfills, in the wake of a structural failure in the containment berm of an ash surface impoundment at a different utility. In 2009, WPL responded to information collection requests from the EPA for data on coal ash surface impoundments at certain of its facilities. The EPA continues to evaluate the responses and conducted on-site follow-up inspections at certain WPL sites in 2010.

In June 2010, the EPA issued a proposed rule seeking comment regarding two potential regulatory options for management of CCRs: 1) regulate as a special waste under the federal hazardous waste regulations when the CCR is destined for disposal, but continue to allow beneficial use applications of CCRs as a non-hazardous material; or 2) regulate as a non-hazardous waste for all applications subject to new national standards. These proposed regulations include additional requirements with significant impact for CCR management, beneficial use applications and disposal. WPL has four current or former coal generating facilities with one or more existing ash surface impoundments. In addition, WPL has two active CCR company-

owned landfills. All of these CCR disposal units would be subject to the proposed rule anticipated to be final in 2012. The schedule for compliance with this rule has not yet been established. WPL is currently unable to predict the impact of these information collection requests, site inspections, or potential regulations resulting from such requests for the management of CCRs, but expects that capital investments, operating expenditures and/or modifications to comply with CCR rules could be significant.

Polychlorinated Biphenyls (PCB) -In April 2010, the EPA published an Advance Notice of Proposed Rulemaking (ANPRM) to support a re-evaluation of all existing use authorizations for PCB-containing equipment. Based on the EPA’s review of the information obtained by this ANPRM, significant changes in PCB regulations may be proposed, including a possible mandated phase out of all PCB-containing equipment. The EPA plans to issue a proposed PCB rule amendment for public comment in 2013. The schedule for compliance with this rule has not yet been established. Pending the development of a final rule, WPL is currently unable to predict the outcome of this possible regulatory change, but believes that the required capital investment and/or modifications resulting from these potential regulations could be significant.

Manufactured Gas Plant (MGP) Sites -Refer to Note 12(e) of the “Notes to Consolidated Financial Statements” for discussion of WPL’s MGP sites.

GHG Emissions -Climate change continues to garner public attention along with support for policymakers to take action to mitigate global warming. There is considerable debate regarding the public policy response that the U.S. should adopt, involving both domestic actions and international efforts. Several members of Congress have proposed legislation to regulate GHG emissions, primarily targeting reductions of carbon dioxide (CO2) emissions. The EPA is responding to a court ruling that requires issuance of federal rules to reduce GHG emissions under the existing CAA. Associated regulations to implement these federal GHG rules are also underway in Wisconsin. Given the highly uncertain outcome and timing of future regulations regarding the control of GHG emissions, WPL currently cannot predict the financial impact of any future climate change regulations on its operations but believes the expenditures to comply with any new emissions regulations could be significant.

Significant uncertainty exists surrounding the final implementation of the EPA’s GHG regulations. Furthermore, while implementation of these regulations continues to proceed, the impacts of these regulations remain subject to change as a consequence of the complexity and magnitude of determining how to effectively control GHGs under the existing legal framework of the CAA, which may include the EPA and state agency interpretations of appropriate permitting and emission compliance requirements. The outcome of these regulations and challenges will determine whether and how GHG stationary sources, including electric utility operations, will be regulated under the CAA. WPL is currently unable to predict the timing and nature of stationary source rules for GHG emissions including future issuance of regulations that would mandate reductions of GHGs at electric utilities.

In 2009, the EPA issued a final Endangerment and Cause or Contribute Findings for GHG under the CAA with an effective date of January 2010. This final action includes two distinct findings regarding GHG emissions under the CAA. First, the current and projected concentrations of GHG emissions in the atmosphere threaten the public health and welfare of current and future generations. This is referred to as the endangerment finding and includes the six key GHG emissions identified in the EPA’s mandatory GHG reporting rule. Second, the combined emissions of CO2, methane (CH4), nitrous oxide (N2O), and hydrofluorocarbons (HFCs) from new motor vehicles and motor vehicle engines contribute to the atmospheric concentrations of these key GHG emissions and hence to the threat of climate change. This is referred to as the cause or contribute finding. In April 2010, the EPA, under authority from the GHG Endangerment and Cause or Contribute Findings, also issued a final rule that regulates GHG emissions from motor vehicles as a pollutant under the CAA. This finding and rule are subject to legal challenges in the D.C. Circuit Court. These actions by the EPA enable it to regulate GHG stationary sources, including electric utility operations and natural gas distribution operations.

The primary GHG emitted from WPL’s operations is CO2 from the combustion of fossil fuels at its larger EGUs. WPL’s annual CO2 emissions from its larger EGUs, in terms of total mass, ranged from 8.4 million tons (or 7.6 million metric tons) to 9.6 million tons (or 8.7 million metric tons) during the 2006 through 2010 period. These amounts represent emissions from WPL’s ownership portion of fossil-fueled EGUs with a design nameplate of 25 MW or greater that are required to be equipped with continuous emissions monitoring systems.

EPA Mandatory GHG Reporting Rule -In December 2009, the final EPA Mandatory GHG Reporting rule became effective. The final rule does not require control of GHG emissions, rather it requires that sources above certain threshold levels monitor and report emissions. The EPA anticipates that the data collected by this rule will improve the U.S. government’s ability to formulate a set of climate change policy options. The GHG emissions covered by the final EPA reporting rule include CO2, CH4, N2O, sulfur hexafluoride, HFCs, perfluorocarbons and other fluorinated gases. Emissions of GHG will be reported at the facility level in CO2e and include those facilities that emit 25,000 metric tons or more of CO2e annually. The final rule applies to electric utility and natural gas distribution operations at WPL. The annual reporting compliance requirement begins for calendar year 2010, with the first GHG emissions reports due by March 31, 2011. WPL continues to maintain and update its emissions monitoring methodologies and data collection procedures to capture all the GHG emissions data required to comply with the EPA’s mandatory GHG reporting rule. This rule is subject to legal challenge in the D.C. Circuit Court.

EPA NSPS for GHG Emissions from Electric Utilities- In December 2010, the EPA announced the future issuance of GHG standards for electric utilities under the CAA. The GHG emission limits are to be established as NSPS for new and existing fossil-fueled EGUs. The EPA is expected to propose NSPS by July 2011 and finalize NSPS by May 2012. For existing EGUs, the NSPS issued by the EPA is expected to include emission guidelines that states must use to develop plans for reducing EGU GHG emissions. The guidelines will be established based on demonstrated controls, GHG emission reductions, costs and expected timeframes for installation and compliance. Under existing EPA regulations, states must submit their plans to the EPA within nine months after publication of the guidelines unless the EPA sets a different schedule. States have the ability to apply less or more stringent standards, or longer or shorter compliance schedules. The implications of the EPA’s NSPS rule for GHG emissions from EGUs are highly uncertain, including the nature of required emissions controls and compliance timeline for mandating reductions of GHGs. WPL is currently unable to predict the final outcome, but expects that expenditures to comply with any regulations to reduce GHG emissions could be significant.

EPA GHG Tailoring Rule -In June 2010, the EPA issued the GHG Tailoring Rule, which became effective on Jan. 2, 2011. The rule establishes a GHG emissions threshold for major sources under the PSD Construction Permit and Title V Operation Permit programs at 100,000 tons per year (tpy) of CO2e. The rule also establishes a threshold for what will be considered a significant increase in GHG emissions. New major sources and significantly modified existing sources of GHG will be required to obtain PSD construction permits that demonstrate BACT emissions measures to minimize GHG. The rule establishes a phased-in implementation schedule for compliance with these GHG permitting requirements. Through June 2011, GHG requirements only apply to sources that are already obtaining CAA permits for other (non-GHG) pollutants. In July 2011, GHG requirements will apply to all new major sources and modifications at existing major sources that would increase GHG emissions by at least 75,000 tpy for CO2e. The rule is subject to legal challenges in the D.C. Circuit Court. The implications of the EPA’s GHG Tailoring Rule are highly uncertain, and WPL is currently unable to predict the impact on its financial condition or results of operations, but expects that expenditures to comply with these regulations to reduce GHG emissions could be significant.

Refer to Note 12(e) of the “Notes to Consolidated Financial Statements,” “Strategic Overview” and “Liquidity and Capital Resources - Cash Flows - Investing Activities - Construction and Acquisition Expenditures” for further discussion of environmental matters.

LEGISLATIVE MATTERS

Recent Legislative Developments -

Federal Tax Legislation -In 2010, the SBJA and the Tax Relief, Unemployment Insurance Reauthorization and Job Creation Act of 2010 (the Act) were enacted. The most significant provisions of the SBJA and the Act for WPL were related to the extension of bonus depreciation study.deductions for certain expenditures for property that are incurred through Dec. 31, 2012. Based on capital projects placed into service in 2010 and capital projects expected to be placed into service in 2011, WPL currently estimates its total bonus depreciation deductions to be claimed in its 2010 and 2011 U.S. federal income tax returns will be approximately $215 million and $280 million, respectively. WPL is currently unable to estimate its bonus depreciation deductions to be claimed on its 2012 U.S. federal income tax return but believes bonus depreciation deductions will likely contribute to annual federal net operating losses through 2012. WPL’s federal net operating losses carryforwards including mixed service costs are currently expected to offset future federal taxable income through 2015 resulting in minimal federal cash tax payments to the IRS through 2015. Refer to Note 5 of the “Notes to Consolidated Financial Statements” for further discussion of the SBJA and the Act.

Federal Health Care Legislation -In March 2010, the Patient Protection and Affordable Care Act, and Health Care and Education Reconciliation Act of 2010 (Federal Health Care Legislation) were enacted. One of the most significant provisions of the Federal Health Care Legislation for WPL requires a reduction in its tax deductions for retiree health care costs beginning in 2013, to the extent its drug expenses are reimbursed under the Medicare Part D retiree drug subsidy program. The reduction in the future deductibility of retiree health care costs accrued as of Dec. 31, 2009 required WPL to record deferred income tax expense of $3 million in 2010. In addition, WPL currently anticipates increased annual tax expense beginning in 2010 of approximately $1 million as a result of this legislation. The Federal Health Care Legislation also contains provisions that may impact future benefits costs for WPL. These provisions include the elimination of annual and lifetime caps for certain benefits beginning in 2011 and the implementation of an excise tax for health insurance plans with annual premiums in excess of certain thresholds beginning in 2018. Refer to Notes 5 and 6(a) of the “Notes to Consolidated Financial Statements” for further discussion of the Federal Health Care Legislation.

Federal Regulatory Reform Legislation -In July 2010, the Dodd-Frank Act was enacted. One of the most significant financial provisions of the Dodd-Frank Act for WPL is a commercial end-user exemption that is expected to allow utilities to continue trading derivatives “over-the-counter” without having to make such trades through cleared exchanges with collateral requirements. As a result of this commercial end-user exemption, WPL currently does not believe the Dodd-Frank Act will have a material impact on its financial condition and results of operations.

Electric Demand Planning Reserve Margin (PRM)Fuel Cost Recovery Rule Changes in Wisconsin -The PSCW requires WPLRefer to maintain a PRM above its projected annual peak demand forecast to help ensure reliability of electric service to its customers. In October 2008, the PSCW issued an order lowering the PRM requirement from 18.0% to 14.5%“Rate Matters - Rule Changes” for long-term planning (planning years two through 10). The PSCW also determined that the short-term (planning year one) PRM for Wisconsin utilities will follow the PRM established by MISO under Module E - Resource Adequacy Requirements of its Open Access Transmission and Energy Markets Tariff. WPL does not expect the reduction in the PRM to change its current generation plan.

Electric Risk Management Plan (ERMP) -In October 2008, the PSCW issued an order approving an ERMP for WPL that expires in December 2010. The ERMP determines hedging options for WPL’s electric operations and which costs of hedging transactions can be included in fuel costs for purposes of cost recovery. The ERMP was developed with the involvement of individuals representing key customer groups as well as PSCW staff, and as proposed, included a numberdiscussion of new elements which would expand WPL’s hedging options, including longer time horizons and greater protections for decisions made to take advantage of unusual market conditions. However,legislation enacted in approvingMay 2010 that changed the ERMP, the PSCW added a new limitation that WPL may not hedge more than a cumulative 75% of a future month’s expected open position (expected electric system demand less expected generation and firm purchases) although this limitation may be waived for the month immediately preceding the future monthfuel cost recovery rules in order to assure reliable provision of service.Wisconsin effective Jan. 1, 2011.

RESULTS OF OPERATIONS

Overview -WPL’s earnings available for common stock increased $5$63 million in 20082010 and $8decreased $29 million in 2007.2009. The 20082010 increase was primarily due to lower purchased power capacity coststhe impact of the electric and gas retail rate increases effective in January 2010 and higher AFUDC relatedelectric sales in 2010 compared to the construction of2009 caused by weather conditions in WPL’s Cedar Ridge wind project. These items were partially offset by higher interest expense resulting from the issuance of WPL’s 7.6% debentures in October 2008 and gains in 2007 from WPL’s performance-based gas commodity cost recovery program.service territory. The 2007 increase2009 decrease was primarily due to improved retaillower electric fuel-related cost recoveriessales in 2009 compared to 2008 caused by weather and lower retirement planadverse economic conditions in WPL’s service territory, higher depreciation expense from its Cedar Ridge wind project and incentive expenses. These items were partially offset by lower gains in 2007the acquisition of the Neenah Energy Facility, and higher interest expense from WPL’s performance-based gas commodity cost recovery program.the issuances of new debentures.

Electric Margins -Electric margins are defined as electric operating revenues less electric production fuel, energy purchases and purchased powerelectric capacity expenses. Management believes that electric margins provide a more meaningful basis for evaluating utility operations than electric operating revenues since electric production fuel, energy purchases and purchased powerelectric capacity expenses are generally passed through to customers, and therefore result in changes to electric operating revenues that are comparable to changes in electric production fuel, energy purchases and purchased powerelectric capacity expenses. Electric margins and megawatt-hour (MWh)MWh sales for WPL were as follows:

 

  Revenues and Costs (dollars in millions) MWhs Sold (MWhs in thousands)   Revenues and Costs (dollars in millions) MWhs Sold (MWhs in thousands) 
  2008  2007  (a) 2006  (b) 2008  2007  (a) 2006  (b)   2010   2009   (a) 2008   (b) 2010   2009   (a) 2008   (b) 

Residential

  $389.5  $396.3  (2%) $385.9  3% 3,446  3,549  (3%) 3,513  1%  $439.6    $389.7     13 $389.5     —      3,541     3,419     4  3,446     (1%) 

Commercial

   218.1   219.0  —     212.4  3% 2,270  2,310  (2%) 2,277  1%   240.3     220.0     9  218.1     1  2,275     2,257     1  2,270     (1%) 

Industrial

   327.7   329.9  (1%)  323.0  2% 4,748  4,942  (4%) 4,948  —      320.9     298.2     8  327.7     (9%)   4,252     4,119     3  4,748     (13%) 
                                                    

Retail subtotal

   935.3   945.2  (1%)  921.3  3% 10,464  10,801  (3%) 10,738  1%   1,000.8     907.9     10  935.3     (3%)   10,068     9,795     3  10,464     (6%) 

Sales for resale:

                                  

Wholesale

   178.5   158.5  13%  143.3  11% 3,364  3,141  7% 3,029  4%   167.0     166.6     —      178.5     (7%)   2,900     2,848     2  3,364     (15%) 

Bulk power and other

   10.0   14.5  (31%)  20.7  (30%) 301  969  (69%) 1,082  (10%)   20.6     61.0     (66%)   10.0     510  695     1,682     (59%)   301     459

Other

   29.2   22.5  30%  26.1  (14%) 74  74  —    72  3%   21.5     24.8     (13%)   29.2     (15%)   70     71     (1%)   74     (4%) 
                                                    

Total revenues/sales

   1,153.0   1,140.7  1%  1,111.4  3% 14,203  14,985  (5%) 14,921  —      1,209.9     1,160.3     4  1,153.0     1  13,733     14,396     (5%)   14,203     1
                                              

Electric production fuel

   174.6   170.0  3%  151.0  13%        

Purchased power expense:

                 

Energy

   259.6   247.5  5%  271.9  (9%)        

Capacity

   145.1   166.6  (13%)  155.6  7%        
                    

Total electric production fuel and purchased power expense

   579.3   584.1  (1%)  578.5  1%        

Electric production fuel expense

   171.7     160.6     7  174.6     (8%)         

Energy purchases expense

   229.5     290.7     (21%)   259.6     12        

Purchased electric capacity expense

   134.7     144.6     (7%)   145.1     —            
                                           

Margins

  $573.7  $556.6  3% $532.9  4%          $674.0    $564.4     19 $573.7     (2%)         
                                           

 

(a)Reflects the % change from 20072009 to 2008.2010. (b) Reflects the % change from 20062008 to 2007.2009.

20082010 vs. 20072009 Summary -Electric margins increased $17$110 million, or 3%,19% in 2008,2010, primarily due to $16the impact of a non-fuel retail rate increase effective January 2010, which increased WPL’s electric revenues by $94 million in 2010, an estimated $23 million increase in electric margins from changes in the net impacts of purchased power capacity costs in 2007 related to a contract that ended in December 2007, $8weather conditions and WPL’s weather hedging

activities, $7 million of lower purchased powerelectric capacity costsexpenses related to the RockGen Energy Center (RockGen) PPA, which terminated in 2008 fromMay 2009, and increased rates charged to wholesale customers including the Kewaunee PPA andimpact of a wholesale formula rate change, which increased electric revenues by $4 million impact from changes in WPL’s annual adjustments to unbilled revenue estimates.2010. These items were partially offset by an $11 million reductiondecrease in electric margins from the impact of WPL’s annual adjustments to unbilled revenue estimates and an $11 million decrease in electric margins from the impact of changes in the recovery of electric production fuel and purchased power energy cost recoveries and lower industrial sales volumes due to the negative impact the slowing economy in 2008 had on WPL’s large industrial customer demand during such period.purchases expense.

20072009 vs. 20062008 Summary- Electric margins increased $24decreased $9 million, or 4%,2% in 2007,2009, primarily due to the impact of WPL’s 2007 retail base rate increase, which beganan estimated $12 million reduction in January 2007, an increaseelectric margins from changes in weather-normalized retail sales volumes, and the net impacts of weather conditions and WPL’s weather hedging activities.activities, $12 million of higher purchased electric capacity expenses related to the Kewaunee Nuclear Power Plant (Kewaunee) PPA and a decrease in weather-normalized sales volumes. These increasesitems were partially offset by $9 million of lower purchased electric capacity expenses related to the impact of annual adjustments to WPL’s unbilled revenue estimates during the second quarter andRockGen PPA, which terminated in May 2009, a $5 million increase in electric margins from the impact of WPL’s sale of itsannual adjustments to unbilled revenue estimates and a $3 million increase in electric distribution properties in Illinois in February 2007. Themargins from the impact of WPL’s 2007 retail base rate increase resultedchanges in retail fuel-related rates exceeding retail fuel-related costs by approximately $16 million in 2007. The increase in weather-normalized retail sales volumes was primarily due to the negative impact high electric prices during 2006 had on customer usage during that period.

Fuel and Purchased Power Energy (Fuel-related) Cost Recoveries - WPL’srecovery of electric production fuel and purchased power energy expense increased $17 million, or 4%, and decreased $5 million, or 1%, in 2008 and 2007, respectively, primarily duepurchases expense.

Non-fuel Retail Rate Increases- Increases to changes in commodity prices. WPL’s rate recovery mechanism for wholesale fuel-related costs provides for subsequent adjustments to its wholesale electric rates for changes in commodity costs, thereby mitigatingrevenues from the impacts of changes to commodity costs on its electric margins.non-fuel retail rate increases for 2010 were as follows (dollars in millions):

WPL’s retail fuel-related costs incurred in both 2008 and 2007 were lower than the forecasted fuel-related costs used to set retail rates during such periods. WPL estimates the lower than forecasted retail fuel-related costs increased electric margins by approximately $5 million and $16 million in 2008 and 2007, respectively. WPL’s recovery of fuel-related costs during 2006 did not have a significant impact on its electric margins. The 2008 and 2007 increases in electric margins relate to fuel-related fuel cost recoveries during January 2008 through March 2008 and January 2007 through May 2007, respectively. In accordance with orders received from the PSCW, WPL established reserves for rate refund of $23 million in 2008 and $20 million in 2007 for the estimated refunds related to the over-recovery of retail fuel-related costs during the months of April 2008 through December 2008 and June 2007 through December 2007, respectively. WPL refunded approximately $4 million of these rate refunds to its retail electric customers in 2007 and $16 million in 2008.

Retail Base Rate Cases

  Percent
Increase
  Effective
Date
   Revenue
Impact
 

2010 Test Year

   6  Jan. 1, 2010    $94  

Refer to “Other Matters - Market Risk Sensitive Instruments and Positions - Commodity Price Risk” for discussion of risks associated with increased fuel and purchased power energy costs on WPL’s electric margins. Refer to “Rates and Regulatory Matters - Utility Fuel Cost Recovery” and Note 1(h) of the “Notes to Consolidated Financial Statements”“Rate Matters” for additional information relating to recovery mechanisms for electric fuelrate increases and purchased power energy costs including proposed changes to the retailan anticipated rate recovery mechanismfiling in place in Wisconsin for fuel-related costs.2011.

Impacts of Weather Conditions -Estimated increases (decreases) to WPL’s electric margins from the net impacts of weather and WPL’s weather hedging activities were as follows (in millions):

 

  2008 2007 2006   2010   2009 2008 

Weather impacts on demand compared to normal weather

   ($1) $5  $—     $11    ($11 ($1

Gains (losses) from weather derivatives (a)

   1   (3)  (2)   —       (1  1  
                     

Net weather impact

  $—    $2   ($2)  $11    ($12 $—    
                     

 

(a)Recorded in “Other” revenues in the aboveelectric margins table.

WPL’s electric sales demand is seasonal to some extent with the annual peak normally occurring in the summer months due to air conditioning usage by its residential, commercial and commercialwholesale customers. Cooling degree days (CDD) data is used to measure the variability of temperatures during summer months and is correlated with electric sales demand. Heating degree days (HDD) data is used to measure the variability of temperatures during winter months and is correlated with electric and gas sales demand. Refer to “Gas Margins - Impacts of Weather Conditions” for details regarding HDD in WPL’s service territory. CDD in WPL’s service territory were as follows:

 

  Actual     Actual     
  2008  2007  2006  Normal (a)  2010   2009   2008   Normal (a) 

CDD (a):

                

Madison, Wisconsin

  538  781  637  642   829     368     538     623  

 

(a)CDD are calculated using a simple average of the high and low temperatures each day compared to a 65 degree base. Normal degree days are calculated using a rolling 20-year average of historical CDD.

WPL periodically utilizes weather derivatives based on CDD and HDD to reduce the potential volatility on its margins during the summer months of June through August and the winter months of November through March, respectively. WPL estimatedentered into weather derivatives based on CDD in Madison, Wisconsin for the period June 1, 2008 to Aug. 31, 2008. WPL entered into weather derivatives based on HDD in Madison, Wisconsin for the periods Nov. 1, 2008 to March 31, 2009 and Nov. 1, 2007 to March 31, 2008. WPL has not entered into any weather derivatives since March 31, 2009.

Electric Production Fuel and Energy Purchases (Fuel-related) Cost Recoveries -WPL burns coal and other fossil fuels to produce electricity at its generating facilities. The cost of fossil fuels used during each period is included in electric production fuel expense. WPL also purchases electricity to meet the demand of its customers and charges these costs to energy purchases expense. WPL’s electric production fuel expense increased $11 million, or 7%, in 2010 and decreased $14 million, or 8%, in 2009. The 2010 increase was primarily due to higher coal volumes burned at its generating facilities

resulting from increased generation needed to serve the higher electricity demand in 2010. The 2009 decrease was primarily due to lower coal volumes burned at its generating facilities resulting from reduced generation needed to serve the lower electricity demand in 2009. WPL’s energy purchases expense decreased $61 million, or 21%, in 2010 and increased $31 million, or 12%, in 2009. The 2010 decrease was primarily due to lower energy volumes purchased and lower energy prices. The 2009 increase was primarily due to higher energy purchased volumes and higher costs in 2009 related to derivative instruments used to mitigate pricing volatility for the electricity purchased to supply to its customers. The impact of the changes in energy purchases volumes were largely offset by the impact of changes in bulk power sales volumes discussed below.

WPL’s rate recovery mechanism for wholesale fuel-related costs provides for adjustments to its wholesale electric rates for changes in commodity costs, thereby mitigating impacts of changes to commodity costs on demand comparedWPL’s electric margins.

WPL’s retail fuel-related costs incurred in 2010 were higher than the forecasted fuel-related costs used to normal weatherset retail rates effective at the beginning of 2010. In April 2010, WPL filed a request with the PSCW to increase its annual fuel-related retail electric rates for the remainder of 2010 to recover anticipated increased fuel-related costs for 2010. In June 2010, WPL received approval from the PSCW to implement an interim rate increase of $9 million, on an annual basis, subject to refund, effective in June 2010. Updated annual 2010 fuel-related costs during Septemberthe proceeding resulted in WPL no longer qualifying for a fuel-related rate increase for 2010. In December 2010, the PSCW issued an order authorizing no increase in retail electric rates in 2010 related to fuel expense and authorized continuation of the interim rates through the end of 2010. The order obligates WPL to return the $5 million of interim rate over-collections to its retail customers as an offset to rate increases requested for 2011 rather than refunding a lump sum to applicable customers in early 2011. As of Dec. 31, 2010, WPL fully reserved $5 million, including interest, for all interim rate over-collections in 2010.

WPL estimates the higher than forecasted retail fuel-related costs decreased electric margins by approximately $3 million in 2010. WPL’s retail fuel-related costs incurred in 2009 and 2008 2007 and 2006 (such months were not coveredboth lower than the forecasted fuel-related costs used to set retail rates during such periods. WPL estimates the lower than forecasted retail fuel-related costs increased electric margins by weather derivatives) was $0, $1approximately $8 million and ($2)$5 million in 2009 and 2008, respectively.

Refer to “Other Matters- Market Risk Sensitive Instruments and Positions” for discussion of risks associated with increased electric production fuel and energy purchases expenses on WPL’s electric margins. Refer to “Rate Matters” and Note 1(h) of the “Notes to Consolidated Financial Statements” for additional information relating to recovery mechanisms for electric production fuel and energy purchases expenses and changes to the retail rate recovery rules in Wisconsin for electric production fuel and energy purchases expenses beginning in 2011.

Purchased PowerElectric Capacity CostsExpense -WPL enters into PPAs to help meet the electricity demand of its customers. Certain of these PPAs include minimum payments for WPL’s rights to electric generating capacity. Details of purchased powerelectric capacity costsexpense included in the electric marginmargins table above were as follows (in millions):

 

   2008  2007  2006

Kewaunee PPA

  $62  $70  $68

Riverside PPA

   56   57   53

RockGen PPA

   16   16   15

Minnesota Power PPA - Expired December 2007

   —     16   15

Other

   11   8   5
            
  $145  $167  $156
            

   2010   2009   2008 

Kewaunee PPA

  $72    $74    $62  

Riverside PPA

   58     57     56  

RockGen PPA (Expired May 2009)

   —       7     16  

Other

   5     7     11  
               
  $135    $145    $145  
               

At Dec. 31, 2008,2010, the future estimated purchased powerelectric capacity costsexpense related to the Kewaunee (expires in 2013), and Riverside (expires in 2013) and RockGen (expires in 2009) PPAs werewas as follows (in millions):

 

  2009  2010  2011  2012  2013  2011   2012   2013   Total 

Kewaunee PPA

  $74  $73  $52  $60  $63  $51    $59    $62    $172  

Riverside PPA

   57   57   58   59   17   59     60     17     136  

RockGen PPA

   7   —     —     —     —  
                
  $110    $119    $79    $308  
                

Unbilled Revenue Estimates -In the second quarter of each year, when weather impacts on electric sales volumes are historically minimal, WPL refines its estimates of unbilled electric revenues. Adjustments resulting from these refined estimates can increase (e.g. 2006) or decrease (e.g. 2007) electric margins reported each year in the second quarter. Estimated increases (decreases)

in WPL’s electric margins from the annual adjustments to unbilled revenue estimates recorded in the second quarter of 2010, 2009 and 2008 2007 and 2007 were $0, ($4)6) million, $5 million and $4 million,$0, respectively.

Sales Trends - Wholesale and retailRetail sales volumes increased 3% and decreased 6% in 20082010 and 2007 were impacted2009, respectively. The 2010 increase was primarily due to higher usage per customer caused by changes in weather and economic conditions in WPL’s service territory in 2010 compared to 2009, partially offset by the impact of the annual unbilled sales of its electric distribution propertiesadjustments discussed above. The 2009 decrease was largely due to a 13% decrease in Illinois in February 2007. Prior to these asset sales, electric revenues and MWhs sold to retail customers in Illinois were included in residential, commercial and industrial sales, which was caused by plant closures and shift reductions as a result of economic conditions in 2009.

Wholesale sales volumes increased 2% and decreased 15% in 2010 and 2009, respectively. The 2010 increase was primarily due to higher sales caused by weather conditions. The effect of the higher sales in 2010 was partially offset by lower sales to WPL’s partial-requirement wholesale customers that have contractual options to be served by WPL, other power supply sources or the Midwest Independent Transmission System Operator (MISO) market. The 2009 decrease was largely due to the impact of weather and economic conditions in 2009 on the electric margin table above. Upon completionsales demand of these asset sales, WPL entered into separateWPL’s wholesale agreements to continue to provide electric service to its former retail customers in Illinois. Electric revenues and MWhs sold under these wholesale agreements are included in wholesale sales in the electric margin table above. The lower pricing for wholesale customers as compared to retail customers resulted in a decrease to electric margins following the sale of the electric distribution properties in Illinois.customers.

Bulk power and other revenuesales volumes changes were largely due to changes in revenues from sales in the wholesale energy marketmarkets operated by MISO.MISO and PJM Interconnection, LLC. These changes are impacted by several factors including the availability of WPL’s generating facilities and electricity demand within MISO.these wholesale energy markets. Changes in bulk power and other sales revenues were largely offset by changes in electric production fuel and purchased powerenergy purchases expense and therefore did not have a significant impact on electric margins.

Refer to “Rate Matters” for discussion of WPL’s retail electric rate filings, the wholesale formula rate change in 2010, changes to the retail cost recovery rules in Wisconsin for electric production fuel and energy purchases expenses beginning in 2011 and an anticipated rate filing in 2011. Refer to “Other Matters - Other Future Considerations - Electric Sales Projections”Considerations” for discussion of retail electric sales projections expected to be influenced by the current economic conditions.

Gas Margins - - Gas margins are defined as gas operating revenues less cost of gas sold. Management believes that gas margins provide a more meaningful basis for evaluating utility operations than gas operating revenues since cost of gas sold are generally passed through to customers, and therefore, result in changes to gas operating revenues that are comparable to changes in cost of gas sold. Gas margins and dekatherm (Dth) sales for WPL were as follows:

 

  Revenues and Costs (dollars in millions) Dths Sold (Dths in thousands)   Revenues and Costs (dollars in millions) Dths Sold (Dths in thousands) 
  2008  2007  (a) 2006  (b) 2008  2007  (a) 2006  (b)   2010   2009   (a) 2008   (b) 2010   2009   (a) 2008   (b) 

Residential

  $165.7  $145.2  14% $144.9  —    12,520  11,596  8% 11,270  3%  $118.1    $122.2     (3%)  $165.7     (26%)   11,205     11,639     (4%)   12,520     (7%) 

Commercial

   103.2   84.0  23%  84.4  —    9,362  8,337  12% 8,155  2%   65.8     73.9     (11%)   103.2     (28%)   8,095     9,274     (13%)   9,362     (1%) 

Industrial

   10.7   8.2  30%  8.3  (1%) 1,019  883  15% 876  1%   8.9     5.7     56  10.7     (47%)   1,289     771     67  1,019     (24%) 
                                                    

Retail subtotal

   279.6   237.4  18%  237.6  —    22,901  20,816  10% 20,301  3%   192.8     201.8     (4%)   279.6     (28%)   20,589     21,684     (5%)   22,901     (5%) 

Interdepartmental

   5.6   14.8  (62%)  17.0  (13%) 1,156  2,264  (49%) 2,116  7%   0.5     2.0     (75%)   5.6     (64%)   739     464     59  1,156     (60%) 

Transportation/other

   14.8   13.5  10%  19.3  (30%) 24,477  24,478  —    21,094  16%   13.0     12.7     2  14.8     (14%)   21,598     23,656     (9%)   24,477     (3%) 
                                                    

Total revenues/sales

   300.0   265.7  13%  273.9  (3%) 48,534  47,558  2% 43,511  9%   206.3     216.5     (5%)   300.0     (28%)   42,926     45,804     (6%)   48,534     (6%) 
                                           

Cost of gas sold

   213.6   175.0  22%  174.8  —              125.3     138.1     (9%)   213.6     (35%)         
                                           

Margins

  $86.4  $90.7  (5%) $99.1  (8%)          $81.0    $78.4     3 $86.4     (9%)         
                                           

 

(a)Reflects the % change from 20072009 to 2008.2010. (b) Reflects the % change from 20062008 to 2007.2009.

2010 vs. 2009 Summary -Gas margins increased $3 million, or 3% in 2010, primarily due to the impact of the 2010 retail gas rate increase effective in January 2010, which increased gas revenues by $5 million in 2010. This item was partially offset by a 5% decrease in retail sales primarily due to lower usage per customer caused by weather conditions.

2009 vs. 2008 vs. 2007 Summary - Gas margins decreased $4$8 million, or 5%9% in 2008,2009, primarily due to $5the impact of the 2009 retail gas rate decrease effective in January 2009, which reduced gas revenues in 2009 by $4 million of gains in 2007 from WPL’s performance-based gas commodity cost recovery program (benefits were allocated between ratepayers and WPL) and a decrease in weather-normalized retail residential sales largely due to the negative impacts high natural gas prices and the slowing economy in 2008 had on customer demand during such period. These items were partially offset by an estimated $5$2 million increasereduction in gas margins from changes in the net impacts of weather conditions and WPL’s weather hedging activities.

2007 vs. 2006 Summary - Gas margins decreased $8 million, or 8%, in 2007, primarily due to $8 million of lower gains from WPL’s performance-based gas commodity cost recovery program (benefits were allocated between ratepayers and WPL) and the net impacts of weather conditions and WPL’s weather hedging activities. These items were partially offset by an increase in weather-normalized retail sales volumes largely caused by the negative impact high natural gas prices in the first quarter of 2006 had on customer usage during that period.

Natural Gas Cost Recoveries -In 20082010 and 2007,2009, WPL’s cost of gas sold increased $39decreased $13 million, or 22%9%, and $76 million, or 35%, respectively. The 2010 and 2009 decreases were primarily due to an increase in natural gas prices and an increasea decrease in Dths sold to retail customers.customers and a decrease in natural gas prices. Due to WPL’s rate recovery mechanisms for natural gas costs, these changes in cost of gas sold resulted in comparable changes in gas revenues and, therefore, did not have a significant impact on gas margins. Refer to Note 1(h) of the “Notes to Consolidated Financial Statements” for additional information relating to natural gas cost recoveries.

Impacts of Weather Conditions -Estimated increases (decreases) to WPL’s gas margins from the net impacts of weather and WPL’s weather hedging activities were as follows (in millions):

 

  2008 2007 2006   2010 2009 2008 

Weather impacts on demand compared to normal weather

  $4  ($1) ($5)  ($2 $1   $4  

Gains (losses) from weather derivatives (a)

   (2) (2) 4 

Losses from weather derivatives (a)

   —      (1  (2
                    

Net weather impact

  $2  ($3) ($1)  ($2 $—     $2  
                    

 

(a)Recorded in “Transportation/other” revenues in the abovegas margins table.

WPL’s gas sales demand follows a seasonal pattern with an annual base load of gas and a large heating peak occurring during the winter season. HDD data is used to measure the variability of temperatures during winter months and is correlated with gas sales demand. HDD in WPL’s service territory were as follows:

 

  Actual     Actual     
  2008  2007  2006  Normal (a)  2010   2009   2008   Normal (a) 

HDD (a):

                

Madison, Wisconsin

  7,714  6,935  6,520  7,095   6,798     7,356     7,714     7,105  

 

(a)HDD are calculated using a simple average of the high and low temperatures each day compared to a 65 degree base. Normal degree days are calculated using a rolling 20-year average of historical HDD.

WPL periodically utilizes weather derivatives based on HDD to reduce the potential volatility on its gas margins during the winter months of November through March.

Performance-based Gas Commodity Recovery Program - During 2006, WPL had a gas performance incentive which included a sharing mechanism whereby 50% of gains and losses relative to current commodity prices, as well as other benchmarks, were retained by WPL, with the remainder refunded or recovered from customers. Starting in 2007, the program was modified such that 35% of all gains and losses from WPL’s gas performance incentive sharing mechanism were retained by WPL, with 65% refunded to or recovered from customers. Effective Nov. 1, 2007, WPL’s gas performance incentive sharing mechanism was terminated and replaced with a modified one-for-one pass through of gas costs. WPL’s performance-based gas commodity recovery program resulted in gains which increased gas margins by $5 million and $13 million in 2007 and 2006, respectively. Refer to Note 1(h) of the “Notes to Consolidated Financial Statements” for additional details of the gas commodity recovery program implemented in the fourth quarter of 2007.

Sales Trends - Transportation/other sales volumes were higher in 2008 and 2007 as compared to 2006 largely due to the impact of WPL’s sales of its gas distribution properties in Illinois in February 2007. Prior to these asset sales, gas revenues and Dths sold to retail customers in Illinois were included in residential, commercial and industrial sales in the gas margin table above. Upon completion of these asset sales, WPL entered into agreements to continue to provide services for this Illinois demand. Gas revenues and Dths sold under these agreements were included in transportation/other sales in the gas margin table above. The lower pricing for transportation/other customers as compared to retail customers resulted in a decrease to gas margins following the sale of the gas distribution properties in Illinois.

WPL supplies natural gas to the natural gas-fired generating facilities it owns and operates and accounts for these sales as interdepartmental gas sales. Interdepartmental gas sales volumes were lower in 2008 as compared to 2007 and 2006 due largely to decreased usage of natural gas-fired generating facilities in 2008 to meet electric demand partially due to cool summer weather conditions in 2008.

Refer to “Rates and Regulatory Matters - Utility Rate Cases”“Rate Matters” for discussion of WPL’s electric and gas rate filings. Refer to Note 11(b) of the “Notes to Consolidated Financial Statements” for additional information regarding weather derivatives entered into by WPL in the fourth quarter of 2008 to reduce potential volatility on its margins from Jan. 1, 2009 through March 31, 2009.

Other Revenues -

2007 vs. 2006 Summary - Other revenues decreased $6 million in 2007, primarily due to lower coal sales. Changes in other revenues were largely offset by related changes in other operation and maintenance expenses.

Electric Transmission Service Expenses -

20082010 vs. 20072009 Summary -Electric transmission service expenses increased $12$6 million in 2008, largely due to increased transmission rates billed to WPL by ATC.

2007 vs. 2006 Summary - Electric transmission service expenses increased $10 million in 2007,2010, largely due to increased transmission rates billed to WPL by ATC.

Other Operation and Maintenance Expenses -

20082010 vs. 20072009 Summary -Other operation and maintenance expenses decreased $4$2 million in 2010, primarily due to $11 million of regulatory-related charges in 2009 related to the Nelson Dewey #3 project, $7 million of restructuring charges incurred in 2009 related to the elimination of certain corporate and operations positions, $7 million of lower pension and other postretirement benefits costs, a $2 million loss contingency reserve recorded in 2009 related to the Alliant Energy Cash Balance Pension Plan lawsuit and lower expenses related to other energy-related products and services. These items were partially offset by a $12 million deferral of retail pension and benefits costs recorded in 2009 in accordance with the stipulation agreement approved by the PSCW related to WPL’s 2009 retail rate case, $12 million of higher incentive-related compensation expenses and $2 million of restructuring charges incurred in 2010 related to the elimination of certain corporate and operations positions.

2009 vs. 2008 Summary -Other operation and maintenance expenses increased $2 million in 2009, primarily due to $15 million of higher pension and other postretirement benefits costs, $11 million of regulatory-related charges in 2009 related to the Nelson Dewey #3 project, $7 million of restructuring charges incurred in 2009 related to the elimination of certain corporate and operations positions and a $2 million loss contingency reserve recorded in 2009 related to the Alliant Energy Cash Balance Pension Plan lawsuit. These items were substantially offset by a $12 million deferral of retail pension and benefits costs recorded in 2009 in accordance with the stipulation agreement approved by the PSCW related to WPL’s 2009 retail rate case, $4 million of regulatory-related charges in 2008 related to the Nelson Dewey #3 project, $3 million of lower incentive-related compensation expenses and a $4 million regulatory-related charge in the first quarter of 2007. These items were partially offset by $5 million of higher employee health care costs, a $4 million regulatory-related charge in the fourth quarter of 2008, $3 million of lower regulatory liability amortizations and $1 million of higher bad debt expenses primarily due to the current economic conditions.

2007 vs. 2006 Summary - Other operation and maintenance expenses decreased $9 million in 2007, primarily due to $7 million of lower pension and other postretirement benefits expenses largely due to the impact of benefit plan contributionscost saving initiatives implemented by WPL in 2006, $5 million of lower incentive-related compensation expense and lower expenses related to coal sales. These decreases were partially offset by a $4 million regulatory-related charge in 2007.2009.

Refer to “Other Matters - Other Future Considerations - Pension and Other Postretirement Benefits Costs for 2009”Considerations” for discussion of anticipated material increasesdecreases in pension and other postretirement benefits costs in 2011 resulting from increases in retirement plan assets during 2010 and anticipated increases in maintenance expenses in 2009 resulting from decreases2011 for WPL’s Bent Tree - Phase I wind project, which began generating electricity in retirement plans’ assets during 2008.late 2010.

Depreciation and Amortization Expenses -

20082010 vs. 20072009 Summary -Depreciation and amortization expenses decreased $8$7 million in 2008,2010, primarily due to a $9 million decrease from the implementation of lower depreciation ratesadjustment recorded in 2010, which is not anticipated to have a material impact on July 1, 2008 as a result of a new depreciation study and lower amortization expenses from enterprise resource planning software that became fully amortized in the third quarter of 2007. These items werefuture periods. This item was partially offset by additional depreciation expense from the impact of utility property additions including WPL’s Cedar Ridge wind project that was placed in service in the fourth quarter of 2008.

2007 vs. 2006 Summary - Depreciation and amortization expense increased $3 million in 2007, primarily due to additional depreciation expense from the impact of property additions partially offset by lower software amortization.related to AMI placed into service in 2009 and the June 2009 acquisition of the Neenah Energy Facility.

2009 vs. 2008 Summary -Depreciation and amortization expenses increased $14 million in 2009, primarily due to the impact of property additions related to WPL’s Cedar Ridge wind project, which began generating electricity in late 2008, AMI placed into service in 2009 and the June 2009 acquisition of the Neenah Energy Facility.

Refer to “Rates and RegulatoryNote 1(e) of the “Notes to Consolidated Financial Statements” for details of WPL’s Bent Tree - Phase I wind project, which is expected to result in a material increase in depreciation expense in 2011.

Refer to “Rate Matters” for discussion of the interplay between utility operating expenses and utility margins given their impact on WPL’s utility rate activities.

Interest Expense -

2010 vs. 2009 Summary -Interest expense increased $4 million in 2010, primarily due to interest expense from WPL’s issuances of $250 million of 5% debentures in July 2009 and $150 million of 4.6% debentures in June 2010. These items were partially offset by the impact of WPL’s retirement of $100 million of 7.625% debentures in March 2010.

2009 vs. 2008 vs. 2007 Summary -Interest expense increased $13 million in 2008,2009, primarily due to higher interest expense from WPL’s 6.375% debentures issued in August 2007 andissuances of $250 million of 7.6% debentures issued in October 2008.2008 and $250 million of 5% debentures in July 2009. These items were partially offset by lower interest expense as a result of WPL’s 7% debentures retired in June 2007 and 5.7% debentures retired in October 2008.

2007 vs. 2006 Summary - Interest expense increased $1 million in 2007, primarily due to the impact of WPL’s 6.375%retirement of $60 million of 5.7% debentures issued in 2007, substantially offset byOctober 2008 and lower commercial paper outstanding balances and interest rates in 2009 compared to 2008.

Refer to Note 8(b) of the impact“Notes to Consolidated Financial Statements” for details of WPL’s 7% debentures retired in 2007long-term debt issuances and interest expense accrued in 2006 on the regulatory liability related to the reserve for rate refund associated with WPL’s fuel-related rate case.retirements.

Equity Income from Unconsolidated Investments -2008 vs. 2007 Summary - Equity income from unconsolidated investments increased $6 million in 2008, primarily due to $5 million of higher equity income from ATC.

AFUDC -2008

2010 vs. 20072009 Summary -AFUDC increased $7 million in 2010 primarily due to $7 million of higher AFUDC recognized in 2010 as compared to 2009 for the Bent Tree - Phase I wind project.

2009 vs. 2008 Summary -AFUDC decreased $4 million in 2009, primarily due to AFUDC recognized in 2008 related to the construction of WPL’sthe Cedar Ridge wind project, partially offset by AFUDC recognized in 2009 related to the construction of the Bent Tree - Phase I wind project.

Income Taxes - TheWPL’s effective income tax rates were 36.6%39.2%, 34.3%,33.9% and 37.1%36.6% in 2010, 2009 and 2008, 2007 and 2006, respectively.

2008 vs. 2007 Summary - The increased effective tax rate for 2008 compared to 2007 was primarily due to a reserve recorded in 2008 for a tax-related regulatory asset and deferred tax rate changes as a result Details of estimated higher statethe effective income tax rates from apportionment changes anticipatedwere as follows:

   2010  2009  2008 

Statutory federal income tax rate

   35.0  35.0  35.0

Federal Health Care Legislation enacted in March 2010

   1.2    —      —    

State filing changes due to Wisconsin Senate Bill 62 (SB 62) enacted in February 2009

   —      (1.8  —    

Production tax credits

   (1.4  (2.9  (0.2

Other items, net

   4.4    3.6    1.8  
             

Overall income tax rate

   39.2  33.9  36.6
             

2010 vs. 2009 Summary -The increase in the future.

2007 vs. 2006 Summary - The decreased effective income tax rate for 2007 compared to 20062010 was primarily due to lower state taxes, amortization$3 million of prior years deferred manufacturing production deductionincome tax expense recognized in 2010 related to the impacts of the Federal Health Care Legislation enacted in March 2010, which is expected to reduce WPL’s tax deductions for retiree health care costs beginning in 2013, to the extent prescription drug expenses are reimbursed under the Medicare Part D retiree drug subsidy program, and $2 million of income tax benefits recognized in 2009 related to the net impacts of SB 62 enacted in February 2009 and increased current year manufacturinga 2009 decision to allow WPL to do business in Iowa thus requiring WPL to file as part of the Iowa consolidated tax return.

2009 vs. 2008 Summary -The decrease in the effective income tax rate for 2009 was primarily due to $4 million of production deductions.tax credits in 2009 from the Cedar Ridge wind project, which began generating electricity in December 2008, and $2 million of income tax benefits recognized in 2009 related to the net impacts of the SB 62 enacted in February 2009 and a decision by management to allow WPL to do business in Iowa thus requiring WPL to file as part of the Iowa consolidated tax return.

Refer to Note 5 of the “Notes to Consolidated Financial Statements” for additional information.information regarding WPL’s effective income tax rates. Refer to “Other Matters - Other Future Considerations - Production Tax Credits”Considerations” for discussion of production tax credits for wind projects, which are expected to decreasemay impact future effective income tax rates.

LIQUIDITY AND CAPITAL RESOURCES

Overview - WPL believes it has, and expects to maintain, an adequate liquidity position to operate its business as a result of available capacity under its revolving credit facility and operating cash flows. Based on its liquidity position and capital structure, WPL believes it will be able to secure the additional capital required to implement its strategic plan and to meet its long-term contractual obligations. Access by WPL to capital markets to fund its future capital requirements at reasonable terms is largely dependent on its credit quality and on developments in those capital markets.

Liquidity Position - At Dec. 31, 2008,2010, WPL had $196$193 million of available capacity under its revolving credit facility. Refer to “Cash Flows - Financing Activities - Short-term Debt” and Note 8(a) of the “Notes to Consolidated Financial Statements” for further discussion of the credit facility.

Capital Structure - WPL plans to maintain consolidated debt-to-total capitalization ratios that are consistent with investment-grade credit ratings in order to facilitate ongoing and reliable access to capital markets on reasonable terms and conditions. WPL’s capital structure at Dec. 31, 20082010 was as follows (dollars in millions):

 

Common equity

  $1,159.5  56.7%  $1,369.3     53.5

Preferred equity

   60.0  2.9%

Long-term debt (incl. current maturities)

   782.9  38.3%

Preferred stock

   60.0     2.3

Long-term debt

   1,081.7     42.3

Short-term debt

   43.7  2.1%   47.4     1.9
               
  $2,046.1  100.0%  $2,558.4     100.0
               

In addition to capital structure, other important financial considerations used to determine the characteristics of future financings include financial coverage ratios, flexibility forregarding WPL’s generation plan,plans, state regulations and the levels of debt imputed by rating agencies. The most significant debt imputations include operating leases, a portion of the Kewaunee and Riverside PPAs, and RockGen PPAs. Refer to “Rates and Regulatory Matters - Utility Rate Cases - 2007 Retail Rate Case” for details ofpostretirement benefits obligations. The PSCW explicitly factors certain imputed debt adjustments approved by the PSCW in establishing a regulatory capital structure as part of WPL’s 2007 retail rate case, which was not changed in the recent stipulated agreement approved by the PSCW in December 2008.cases, particularly those related to operating leases and PPAs.

WPL intends to manage its capital structure and liquidity position in such a way that it does not compromise its ability to raise the necessary funding required to enable it to continue to provide utility services reliably and at reasonable costs.costs, while maintaining financial capital structure targets consistent with those approved by regulators. Key considerations include maintaining access to the financial markets on the terms, in the amounts and within the timeframes required to fund WPL’s strategic plan, retaining a prudent level of financial flexibility and maintaining its investment-grade credit ratings. The capital structure is only one of a number of components that needs to be actively managed in order to achieve these objectives. WPL currently expects to maintain a capital structure in which total debt would not exceed 40%45% to 45%50%, and preferred stock would not exceed 5% to 10%, of total capital. These targets may be adjusted depending on subsequent developments and their potential impact on WPL’s investment-grade credit ratings.

Credit and Capital Market Developments - WPL’s ability to provide reliable and cost-effective utility services depends on its access to cost-effective capital. Financial markets have come underthat were subjected to considerable strain oversince 2007 have shown signs of selective recovery. Certain sectors of the past year, resultingequity and debt capital markets, including the regulated utility sector, have attracted and retained investor interest. However, areas of concern remain, including certain issues in adverse impacts onthe U.S. and overseas, which have impacted the availability and terms of credit for businesses. A numberand the liquidity of initiatives are underwayfinancial assets. There is also concern about the level of spending by the U.S. Treasury Departmentfederal government and the temporary monetary policies of the Federal Reserve System intended to contain the contractionspur economic growth, with potential implications over time for inflation and interest rate levels. The evolving profile and impact of creditfinancial market re-regulation, both in the economyU.S. and overseas, contributes to the unsettled tone of liquidity in the various market sectors. These developments translate into uncertainties regarding the availability of capital markets. However, financial marketand for the terms and conditions remain highly sensitiveof capital raised to the evolving economic outlook. Liquidity in the various markets has fluctuated unpredictably, as investment flows into the safety of U.S. Treasury obligations have led to historically low yields in shorter-dated Treasury bills, inducing funds to be re-invested in higher-yielding instruments and/or longer-dated instruments at the beginning of 2009.meet funding requirements.

WPL is aware of the potential implications that these credit and capital market developments might have on its ability to raise the external funding required for its operations and capital expenditure plan.plans. The strategic implications include protecting its liquidity position and avoiding over-reliance on short-term funding to meet its long-term asset profile. WPL had already taken measures over the past several years to improve its financial strength including: securingmaintains a multi-year committed revolving credit facility to provide backstop liquidity to its commercial paper programsprogram and a committed source of alternative liquidity in the event the commercial paper market becomes disrupted; extending WPL’sand extended its long-term debt maturity profile, and avoiding undue concentrations of maturities over the next few years; and converting WPL’s pollution control revenue bonds from variable interest rates to fixed interest rates.years as WPL executes its capital investment program. As

discussed below, WPL retains flexibility in undertaking its capital expenditure program, particularly with respect to capital expenditures to fund the infrastructure investment program within its strategic plan.

Primary Sources and Uses of Cash -WPL’s most significant source of cash is from electric and gas sales to its customers. Cash from these sales reimburses WPL for prudently incurred expenses to provide service to its customers and provides WPL a return on the rate base assets required to provide such services. Operating cash flows are expected to cover the majority of WPL’s capital expenditures required to maintain its current infrastructure and dividends paid to Alliant Energy. Capital requirements needed to retire debt and fund capital expenditures for utility rate base growth related to environmental compliance programs and new generating facilities and environmental compliance programs, are expected to be financedmet primarily through external financings. Ongoing monitoring of credit and capital market conditions allows management to monitorevaluate the availability of funding and the terms and conditions attached to such financing. In order to maintain debt-to-total capitalization ratios that are consistent with investment-grade ratings, WPL may periodically fund such capital requirements with additional debt and equity.

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

 

  2008 2007 2006   2010 2009 2008 

Cash and cash equivalents at Jan. 1

  $18.5   $4.5   $0.4  

Cash flows from (used for):

        

Operating activities

  $239.7  $258.0  $162.6    372.4    305.8    239.7  

Investing activities

   (376.0)  (207.0)  (149.0)   (449.3)   (493.4  (376.0

Financing activities

   140.4   (52.2)  (12.0)   58.5    201.6    140.4  
          

Net increase (decrease)

   (18.4)   14.0    4.1  
          

Cash and cash equivalents at Dec. 31

  $0.1   $18.5   $4.5  
          

Operating Activities -

20082010 vs. 2007 - WPL’s cash flows from operating activities decreased $18 million primarily due to $22 million of collateral payments received from counterparties of derivative contracts in 2007, $16 million of refunds paid to retail electric customers in 2008 for over-recovered fuel-related costs in 2007 and other changes in working capital. These items were partially offset by $32 million of lower income tax payments.

2007 vs. 20062009 - WPL’s cash flows from operating activities increased $95$67 million primarily due to lowerincreased collections from WPL’s customers during 2010 caused by the impacts of rate increases and higher electric sales, $47 million of pension plan contributions during 2009 and $23 million of refunds paid by WPL to its retail customers during 2009 for over-collected fuel-related costs in 2008. These items were partially offset by $72 million of lower income tax refunds.

2009 vs. 2008 - WPL’s cash flows from operating activities increased $66 million primarily due to $107 million of higher cash flows from changes in income tax payments and refunds, lower payments for gas stored underground partially due to lower natural gas prices, $28 million of higher cash flows from changes in the amount of collateral paid to and received from counterparties of derivative contracts the impactduring 2009 and 2008, and $16 million of improvedrefunds paid by WPL to retail electric customers in 2008 related to over-recovered fuel-related cost recoveries and other changescosts in working capital.2007. These items were partially offset by $47 million of pension plan contributions in 2009, $23 million of refunds paid by WPL to its retail customers in 2009 for over-collected fuel-related costs in 2008, and the impact of lower electric sales due to weather and economic conditions in 2009.

Electric and Gas Rate Increases - WPL implemented rate increases in 2010 that resulted in higher collections from its retail customers. A portion of these higher collections was used to reimburse WPL for prudently incurred expenses to provide service to its customers resulting in limited impacts on cash flows from operations. Another portion of these rate increases provided WPL returns on new rate base additions (e.g. returns on new wind projects), which significantly increased cash flows from operations for WPL in 2010. Refer to “Rate Matters” for additional details of retail rate increases implemented by WPL in 2010.

Income Tax Payments and Refunds - Income tax payments and refunds resulted in higher cash flows from operations for WPL in 2010 and 2009 compared to 2008 primarily due to income tax payments.refunds received in 2010 and 2009 related to claims filed with the IRS to carryback net operating losses to prior years. Refer to “Legislative Matters - Federal Tax Legislation” and “Other Matters - Other Future Considerations - Tax Accounting for Mixed Service Costs” for additional discussion of anticipated future trends in federal income tax payments and refunds impacted by bonus tax depreciation deductions for 2010 and 2009 and potential deductions for mixed service costs.

Pension Plan Contributions - In 2006, the Pension Protection Act of 2006 was enacted. This legislation included changes to minimum funding level requirements of pension plans beginning in 2008. In December 2008, the Worker, Retiree and Employer Recovery Act of 2008 was enacted. This legislation provides pension plan funding relief to retirement plan sponsors impacted by material losses to their retirement plan assets in 2008. WPL is currently in compliance with these two acts and expects to maintain compliance with these acts as a result of future expected pension plan contributions. Pension plan contributions for WPL include contributions to its qualified pension plan as well as an allocated portion of the contributions to pension plans sponsored by Corporate Services and were $0, $47 million and $0 for 2010, 2009 and $43 million for 2008, 2007 and 2006, respectively. Estimates of pension plan contributions currently expected to be made in 2009, 20102011, 2012 and 20112013 are $20 million, $15 million$0, $0 and $15$5 million, respectively, whichand are based on the funded status and assumed return on assets as of the

Dec. 31, 20082010 measurement date for WPL’s plans.the plans and are subject to change. Refer to Note 6(a) of the “Notes to Consolidated Financial Statements” for discussion of the current funded levels of WPL’s pension plan.

Cash Collateral - WPL has entered into various commodity contracts that contain provisions requiring it to provide cash collateral if its liability position under the contract exceeds certain limitations. Refer to “Legislative Matters - Federal Regulatory Reform Legislation” for additional details of legislation enacted in 2010, which WPL currently does not believe will have a material impact on its financial condition and results of operations.

Investing Activities -

20082010 vs. 20072009 - WPL’s cash flows used for investing activities decreased $44 million primarily due to $58 million of lower construction and acquisition expenditures resulting from expenditures during 2009 for the acquisition of the Neenah Energy Facility and implementation of AMI, partially offset by higher expenditures during 2010 for its Bent Tree - Phase I wind project. The lower construction and acquisition expenditures were partially offset by changes in the collection of and advances for customer energy efficiency projects.

2009 vs. 2008 - WPL’s cash flows used for investing activities increased $169$117 million primarily due to $160$145 million of higher construction and acquisition expenditures including expenditures in 2009 for its Cedar Ridgethe Bent Tree - Phase I wind project, in 2008the Neenah Energy Facility and $24 millionimplementation of net proceeds from the sale of its Illinois properties in 2007.

2007 vs. 2006 - WPL’s cash flows used for investing activities increased $58 million primarily due to construction expenditures related to the Cedar Ridge wind project in 2007 and proceeds from the liquidation of nuclear decommissioning trust fund assets in 2006. These items wereAMI. This item was partially offset by proceeds fromchanges in the salecollection of its Illinois properties in 2007.and advances for customer energy efficiency projects.

Construction and Acquisition Expenditures - Capital expenditures investments and financing plans are reviewed, approved and updated as part of WPL’s strategic planning and budgeting processes. In addition, significant capital expenditures and investments are subject to a cross-functional review prior to approval. Changes in WPL’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, changing market conditions and new opportunities. WPL currently anticipates construction and acquisition expenditures during 2009, 2010 and 2011 as follows (in millions):

   2009  2010  2011

Generation - new facilities:

      

Wind - Bent Tree

  $165  $285  $—  

Wind - Other

   20   90   135

Gas - NEF (a)

   95   —     —  
            

Total generation - new facilities

   280   375   135

Environmental

   35   200   310

Advanced metering infrastructure

   55   5   —  

Other capital expenditures

   175   175   175
            
  $545  $755  $620
            

(a)WPL currently plans to purchase NEF from Resources effective June 1, 2009.

Cost estimates represent WPL’s estimated portion of total escalated construction and acquisition expenditures in millions of dollars and exclude AFUDC, if applicable. WPL has not yet entered into contractual commitments relating to the majority of its anticipated future capital expenditures. As a result, it has some discretion with regard to the level, and timing of, capital expenditures eventually incurred and closely monitors and frequently updates such estimates based on numerous economic and other factors. WPL has capital purchase obligations under a master supply agreement executed in the second quarter of 2008 with Vestas for the purchase of 500 MW of wind turbine generator setscurrently anticipates construction and related equipment to support its wind generation plans. Refer to “Certain Financial Commitments - Contractual Obligations” for long-term contractual obligations related to wind projects and “Strategic Overview” for further discussion of WPL’s generation plan and multi-emission compliance plan.acquisition expenditures during 2011 through 2013 as follows (in millions):

   2011   2012   2013 

Generation - new facilities:

      

Coal - 25% of Edgewater Unit 5

  $45    $—      $—    

Wind - Bent Tree - Phase I (b)

   35     —       —    

Gas - Riverside

   —       —       375  
               

Total generation - new facilities

   80     —       375  

Environmental

   75     155     140  

Other utility capital expenditures

   205     225     225  
               

Total utility business

  $360    $380    $740  
               

(a)Cost estimates represent WPL’s estimated portion of total escalated construction and acquisition expenditures in millions of dollars and exclude AFUDC, if applicable. Refer to “Strategic Overview” for further discussion of the generation plans and environmental compliance plans.
(b)Refer to “Certain Financial Commitments - Contractual Obligations” for long-term capital purchase obligations related to wind projects. WPL has capital purchase obligations under a master supply agreement executed in 2008 with Vestas for the purchase of wind turbine generator sets and related equipment to support its wind generation plans.

WPL expects to finance its 2009 to 2011 through 2013 capital expenditure planplans in a manner that allows it to adhere to the capital structure targets discussed in the “Capital Structure” section above. 20092011 capital expenditures are expected to be funded with a combination of internally-generated cash and short-term debt and internally generated cash. Such short-term debt is expected to be refinanced with approximately $250 million of long-term debt issuances and capital contributions from WPL’s parent in the second half of 2009.debt. The precise characteristics of the financing for the 20102012 and 20112013 capital expenditures and any potential changes to the revolving credit facilities will be determined closer to the time that the financing isneeds are required. Flexibility will be required in implementing the long-term financing for capital expenditure plans to allow for scheduling variations in the required authorization and construction work, changing market conditions and any adjustments that might be required to ensure there are no material adverse impacts to WPL’s capital structure.

Proceeds from Asset Sales - Net proceeds from asset sales have been used for general corporate purposes. Proceeds from assets sales for WPL during 2008, 2007 and 2006 were as follows (in millions):

   2008  2007  2006

Assets Sold:

      

Electric and gas utility assets in Illinois

  $—    $24  $—  

Other

   3   —     4
            
  $3  $24  $4
            

Financing Activities -

20082010 vs. 20072009 - WPL’s cash flows from financing activities increased $193decreased $143 million primarily due to impacts of long-term debt issued and retired during 2010 and 2009 discussed below and $100 million of lower common stock dividends and a $100 million capital contributioncontributions received during 2009 from its parent company, Alliant Energy, in 2008.Energy. These items were partially offset by changes in the amount of commercial paper outstanding and $75 million of capital contributions received during 2010 from WPL’s parent company.

WPL’s increases (decreases) in financing cash flows due to changes in long-term debt for 2010 vs. 2009 were as follows (in millions):

Proceeds from issuances:

  

4.6% debentures issued in June 2010

  $150  

5% debentures issued in July 2009

   (250

Payments to retire:

  

7.625% debentures retired in March 2010

   (100
     
  ($200
     

2009 vs. 2008 - WPL’s cash flows from financing activities increased $61 million primarily due to impacts of long-term debt issued and retired during 20082009 and 20072008 discussed below.

2007 vs. 2006 - - WPL’s increases (decreases) in financing cash flows used for financing activities increased $40 million primarily due to higher common stock dividends and a capital contribution from Alliant Energy in 2006. These items were partially offset by changes in the amount oflong-term debt issued and retired.for 2009 vs. 2008 were as follows (in millions):

Proceeds from issuances:

  

5% debentures issued in July 2009

  $250  

7.6% debentures issued in October 2008

   (250

Payments to retire:

  

5.7% debentures retired in October 2008

   60  
     
  $60  
     

State Regulatory Financing AuthorizationAuthorizations - In September 2008,December 2010, WPL received authorization from the PSCW to issue up to $350$200 million of unsecured indebtedness through March 31, 2009 with terms not to exceed 31 years, among other conditions. As of Dec. 31, 2008,long-term debt securities in 2011. WPL had $100 million remaining under the authorization issuedis also authorized by the PSCW.PSCW to have up to $250 million of short-term borrowings and letters of credit outstanding.

Shelf RegistrationRegistrations - In the third quarter of 2008, WPL filedhas a current shelf registration statement with the SEC. WPL’s shelf registration became effective in August 2008 and provides WPL flexibility to offer up to an aggregate of $450 million of its preferred stock and unsecured debt securities from August 2008 through August 2011. As of Dec. 31, 2008, WPL had $200 million remaining available under its shelf registration.SEC as follows:

Aggregate amount available as of Dec. 31, 2010

$300 million

Time period available

Jun-2009 - Jun-2012

Securities available to be issued

Preferred stock and un-
secured debt securities

Common Stock Dividends - Refer to Note 7(a) of the “Notes to Consolidated Financial Statements” for discussion of WPL’s dividend payment restrictions based on the terms of its outstanding preferred stock and applicable regulatory limitations.

Common Stock IssuancesCapital Contributions - Refer to Note 7(a) of the “Notes to Consolidated Financial Statements” for discussion of capital contributions made byfrom Alliant Energy to WPL during 2008.and payments of common stock dividends by WPL to its parent company in 2010.

Short-term Debt - In October 2007, WPL extended the terms of its revolving credit facility to November 2012. This credit facility backstops commercial paper issuances used to finance short-term borrowing requirements, which fluctuate based on seasonal corporate needs, the timing of long-term financings and capital expenditures, and capital market conditions. At Dec. 31, 2008,2010, WPL’s short-term borrowing arrangements included a revolving credit facility of $240 million. During the fourth quarter of 2008, WPL became aware that Lehman Brothers Bank (Lehman) may not be able to fund its portion of the commitments under the WPL credit facility agreement. Therefore, Lehman’s total commitment to WPL’s credit facility of $10 million is excluded from the amount above. There are currently 1413 lenders that participate in WPL’sthe credit facility, with aggregate respective commitments ranging from $8 million to $26$45 million. At Dec. 31, 2008,2010, additional credit facility information was as follows (dollars in millions):

 

Commercial paper:

    

Amount outstanding

  $44   $47  

Weighted average maturity

   6 days 

Weighted average interest rates

   1.4%

Remaining maturity

   3 days 

Interest rate

   0.3

Available credit facility capacity

  $196   $193  

During 2008,2010, WPL issued commercial paper to meet short-term financing requirements and did not borrow directly under its credit facility.

TheWPL’s credit facility agreement contains a financial covenant whichthat requires WPL to maintain a debt-to-capital ratio of less than 58%. in order to borrow under the facility. At Dec. 31, 2008,2010, WPL’s actual debt-to-capital ratio was 44%46%. The debt component of the capital ratio includes long- and short-term debt (excluding non-recourse debt and hybrid securities to the extent such hybrid securities do not exceed 15% of consolidated capital of the borrower), capital lease obligations, letters of credit, guarantees of the foregoing and new synthetic leases. The equity component excludes accumulated other comprehensive income (loss).

TheWPL’s credit facility agreement contains negative pledge provisions, which generally prohibit placing liens on any of WPL’s property with certain exceptions. Exceptions include among others, securing obligations of up to 5% of the consolidated assets of the borrower, non-recourse project financing and purchase money liens.

The credit facility 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.

The credit facility agreement contains customary events of default. If an event of default under the credit facility agreement occurs and is continuing, the lenders may declare any outstanding obligations under the credit facility agreement immediately due and payable and could terminate such agreement. In addition, if any order for relief is entered under bankruptcy laws

with respect to WPL, then any outstanding obligations under the credit facility agreement would be immediately due and payable. At Dec. 31, 2008,2010, WPL did not have any direct borrowings outstanding under its credit facility agreement. A default by either Alliant Energy, IPL or Resources would not trigger a cross defaultcross-default event for WPL.

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

At Dec. 31, 2008,2010, WPL was in compliance with all covenants and other provisions of the credit facility agreement.

Refer to Note 8(a) of the “Notes to Consolidated Financial Statements” for additional information on short-term debt.

Long-term Debt- In 20082010 and 2007,2009, significant issuances of long-term debt were as follows (dollars in millions):

 

Year  Amount  Type  Interest
Rate
  Due Date  

Use of Proceeds

2008  $250.0  Debentures  7.6% Oct-38  

Invest in short-term assets, repay short-term debt, and repay at maturity its
$60 million 5.7% debentures

2007  $300.0  Debentures  6.375% Aug-37  

Repay short-term debt, pay a $100 million common stock dividend to Alliant Energy to realign WPL’s capital structure, and for working capital purposes

Year

  Principal
Amount
   

Type

  Interest
Rate
 

Due Date

  

Use of Proceeds

2010

  $150.0    Debentures  4.6% Jun-2020  

Repay short-term debt, fund capital expenditures and for general working capital purposes

2009

  $250.0    Debentures  5% Jul-2019  

Repay short-term debt and invest in short-term assets

In 2008 and 2007, significant retirements of long-term debt2010, WPL retired its $100 million 7.625% debentures, which were as follows (dollars in millions):due March 2010.

Year  Amount  Type  Interest
Rate
  Original
Due Date
2008  $60.0  Debentures  5.7% Oct-08
2007  $105.0  Debentures  7% Jun-07

In addition, in 2008, WPL converted pollution control revenue bonds from variable interest rates to fixed interest rates as follows (dollars in millions):

Amount
Converted
  Due Dates  Fixed Interest Rate 
$24.5  2014 and 2015  5%
$14.6  2015  5.375%

Refer to Note 8(b) of the “Notes to Consolidated Financial Statements” for additional information on long-term debt.

Creditworthiness -

Credit Ratings -Access to the capital markets and the costs of obtaining external financing are dependent on creditworthiness. WPL is committed to taking the necessary steps required to maintain investment-grade credit ratings. WPL’s current credit ratings and outlooks are as follows:

Standard & Poor’s
Ratings Services (S&P)
Moody’s Investors
Service (Moody’s)

Senior unsecured long-term debt

A-A2

Commercial paper

A-2P-1

Preferred stock

BBBBaa1

Corporate/issuer

A-A2

Outlook

StableStable

Ratings Triggers -The long-term debt of WPL is not subject to any repayment requirements as a result of explicit credit rating downgrades or so-called “ratings triggers.” However, WPL is party to various agreements, including PPAs and fuelcommodity contracts that are dependent on maintaining investment-grade credit ratings. In the event of a downgrade below investment-grade level, WPL may need to provide credit support, such as letters of credit or cash collateral equal to the amount of the exposure, or may need to unwind the contract or pay the underlying obligation. In the event of a downgrade below investment-grade level, management believes WPL has sufficient liquidity to cover counterparty credit support or collateral requirements under these various agreements. In addition, a downgrade in the various agreements withcredit ratings triggers.of WPL could also result in it paying higher interest rates in future financings, reduce its pool of potential lenders, increase its borrowing costs under the existing credit facility or limit its access to the commercial paper market. WPL is committed to taking the necessary steps required to maintain investment-grade credit ratings. WPL’s current credit ratings and outlooks are as follows:

Standard & Poor’s
Ratings Services
Moody’s Investors
Service

Corporate/issuer

A-A2

Commercial paper

A-2P-1

Senior unsecured long-term debt

A-A2

Preferred stock

BBBBaa1

Outlook

StableStable

Credit ratings are not recommendations to buy or sell securities and are subject to change, and each rating should be evaluated independently of any other rating. WPL assumes no obligation to update its credit ratings. Refer to Note 11(a) of the “Notes to Consolidated Financial Statements” for additional information on ratings triggers for commodity contracts accounted for as derivatives.

Off-Balance Sheet Arrangements -

Synthetic Leases -WPL utilizes off-balance sheet synthetic operating leases related to the financing of certain utility railcars. Synthetic leases provide favorable financing rates to WPL while allowing it to maintain operating control of its leased assets. Refer to Note 3(a) of the “Notes to Consolidated Financial Statements” for future minimum lease payments and residual value guarantees associated with these synthetic leases.

Special Purpose Entities -Refer to Note 18 of the “Notes to Consolidated Financial Statements” for information regarding Financial Accounting Standards Board Interpretation No. (FIN) 46R, “Consolidation of Variable Interest Entities.”variable interest entities.

Certain Financial Commitments -

Contractual Obligations -WPL’s consolidated long-term contractual obligations as of Dec. 31, 20082010 were as follows (in millions):

 

  2009  2010  2011  2012  2013  Thereafter  Total  2011   2012   2013   2014   2015   Thereafter   Total 

Operating expense purchase obligations (Note 12(b)):

                            

Purchased power and fuel commitments (a)

  $375  $209  $103  $101  $111  $46  $945  $160    $125    $111    $25    $13    $21    $455  

Other (b)

   5   3   1   —     —     —     9   9     8     7     1     —       —       25  

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

   —     100   —     —     —     689   789   —       —       —       8     31     1,050     1,089  

Interest - long-term debt obligations

   54   50   46   46   46   1,069   1,311   66     66     66     66     65     1,056     1,385  

Wind generation projects (Note 12(a)) (c)

   132   301   43   —     —     —     476

Neenah Energy Facility (Note 12(a)) (d)

   95   —     —     —     —     —     95

Wind generation capital purchase obligations (Note 12(a))(c)

   25     —       —       —       —       —       25  

Operating leases (Note 3(a))

   68   68   61   61   19   7   284   63     67     20     5     1     1     157  

Capital lease (Note 3(b))

   15   15   15   15   15   173   248

Capital lease - Sheboygan Falls Energy Facility (Note 3(b))

   15     15     15     15     15     143     218  

Capital leases - other

   —       —       —       —       —       2     2  
                                                 
  $744  $746  $269  $223  $191  $1,984  $4,157  $338    $281    $219    $120    $125    $2,273    $3,356  
                                                 

 

(a)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, through its subsidiary Corporate Services, has entered into various coal commitments that have not yet been directly assigned to WPL. Such commitments are not included in WPL’s purchased power and fuel commitments.

(b)Other operating expense purchase obligations represent individual commitments incurred during the normal course of business that exceeded $1 million at Dec. 31, 2008.2010.

(c)In the second quarter of 2008, Corporate Services, as agent for IPL and WPL, entered into a master supply agreement with Vestas for the purchase of 500 MW of wind turbine generator sets and related equipment to support IPL’s and WPL’s wind generation plans. WPL’s wind generation plan isplans are described in more detail in “Strategic Overview - Generation Plan.Plans. WPL’s minimum future commitments for capital purchase obligations related to this agreement are based on currency exchange rates and steel prices at Dec. 31, 2008. Refer to “Other Matters - Market Risk Sensitive Instruments and Positions” for further discussion of potential impacts of changes in currency exchange rates and steel prices on the minimum future commitments related to this agreement.

(d)In September 2008 and April 2008, WPL received approval from FERC and the PSCW, respectively, to purchase Resources’ 300 MW, simple-cycle, dual-fueled (natural gas/diesel) electric generating facility in Neenah, Wisconsin. WPL currently plans to acquire NEF effective June 1, 2009.

At Dec. 31, 2008,2010, WPL had $2.5$34 million of unrecognizeduncertain tax benefitspositions recorded as liabilities, in accordance with FIN 48, “Accounting for Uncertainty in Income Taxes,” which are not included in the above table. It is uncertain if, and when, such amounts may be settled with the respective taxing authorities. Related to these unrecognized tax benefits, WPL also recorded liabilities for potential interest of $0.3 million at Dec. 31, 2008, which are also not included in the above table.

Refer to Note 6(a) of the “Notes to Consolidated Financial Statements” for anticipated pension and other postretirement benefits funding amounts, which are not included in the above table. Refer to “Cash Flows - Investing Activities - Construction and Acquisition Expenditures” for additional information on WPL’s construction and acquisition program.programs. In addition, at Dec. 31, 2008,2010, there were various other long-term liabilities and deferred credits included on the Consolidated Balance Sheet that, due to the nature of the liabilities, the timing of payments cannot be estimated and are therefore excluded from the above table.

Environmental -

Overview -WPL is subject to regulation of environmental matters by various federal, state and local authorities as a result of its current and past operations. WPL addresses these environmental matters with pollution abatement programs, which are subject to continuing review and are periodically revised due to various factors, including changes in environmental regulations, construction plans and compliance costs. Given the dynamic nature of environmental regulations and other

related regulatory requirements, WPL has established an integrated planning process that is used for environmental compliance of its future anticipated operations. WPL anticipates future expenditures for environmental compliance will be material and will require significant capital investments. WPL anticipates that prudent expenditures incurred to comply with environmental requirements likely would be recovered in rates from its customers. Refer to “Strategic Overview - Multi-emission Compliance Plan” for details of WPL’s multi-emission compliance plan, including estimated capital expenditures. The following are major environmental matters that could potentially have a significant impact on WPL’s financial condition, results of operations and cash flows.

Air Quality -The Clean Air Act (CAA) and its amendments mandate preservation of air quality through existing regulations and periodic reviews to ensure adequacy of these provisions based on scientific data. As part of the basic framework under the CAA, the EPA is required to establish National Ambient Air Quality Standards (NAAQS), which serve to protect public health and welfare. These standards address six “criteria” pollutants, four of which are particularly relevant to WPL’s electric utility operations, including NOx, SO2, particulate matter (PM), and ozone. Ozone is not directly emitted from WPL’s generating facilities; however, NOx emissions may contribute to its formation in the atmosphere.

State implementation plans (SIPs) document the collection of regulations that individual state agencies will apply to maintain NAAQS and related CAA requirements. The EPA must approve each SIP and if a SIP is not acceptable to the EPA or if a state chooses not to issue separate state rules, then the EPA can assume enforcement of the CAA in that state by issuing a federal implementation plan (FIP). Areas that comply with NAAQS are considered to be in attainment, whereas routinely monitored locations that do not comply with these standards may be classified by the EPA as non-attainment and require further actions to reduce emissions. Additional emissions standards may also be applied under the CAA regulatory framework beyond the NAAQS. The specific federal and state regulations that may affect WPL’s operations include: Clear Air Interstate Rule, Clean Air Visibility Rule, Clean Air Mercury Rule, Wisconsin Reasonably Available Control Technology Rule, Wisconsin State Mercury Rule, Ozone National Ambient Air Quality Standards Rule and Fine Particle National Ambient Air Quality Standards Rule and Industrial Boiler and Process Heater Case-by-Case Maximum Achievable Control Technology Rule. WPL also monitors various other potential environmental matters related to air quality, including: litigation of various federal rules issued under the CAA statutory authority; revisions to the New Source Review/Prevention of Significant Deterioration permitting programs and New Source Performance Standards; and proposed legislation or other regulatory actions to regulate the emission of GHG.

Clean Air Interstate Rule - CAIR was issued by the EPA in 2005 to reduce emissions of SO2 and NOx from electric generating units with greater than 25 MW of capacity. CAIR established new SO2 and NOx (both annual and ozone season) emission caps beginning in 2010 and 2009, respectively, with further reductions in SO2 and NOx emission caps effective in 2015. CAIR included a national cap-and-trade system, where compliance may be achieved by either adding air pollution controls and/or purchasing emission allowances. In July 2008, the U.S. Court of Appeals for the D.C. Circuit (D.C. Circuit Court) vacated CAIR in its entirety. In September 2008, the EPA and other affected parties filed petitions requesting the D.C. Circuit Court review this decision, including a request that CAIR be remanded to the EPA for reconsideration and not vacated in its entirety. In October 2008, the D.C. Circuit Court requested the petitioners to file briefs as to whether any party is seeking vacatur of CAIR and whether the D.C. Circuit Court should stay its mandate until the EPA promulgates a revised rule. In December 2008, the D.C. Circuit Court issued an order that denied rehearing of the original court decision and also remanded (rather than vacated) CAIR to the EPA for revision to address flaws identified in the July 2008 opinion in the case. The impact of the court’s remand of CAIR to the EPA is that CAIR obligations became effective Jan. 1, 2009 and require EPA issuance of NOx emission allowances to regulated sources in the first quarter of 2009. In addition, the EPA must undertake additional rule making to revise CAIR in accordance with the remand.

The court ruling in July 2008 did not impact other air quality regulations of the EPA which currently remain in effect including the Acid Rain Program regulations, which utilize a cap and trade program to reduce SO2 emissions. The ruling also does not impact the regulatory requirements for Reasonable Available Control Technology to reduce NOx emissions imposed in the Wisconsin counties that are currently non-attainment areas under the national ambient air quality standard for ozone. The 2008 court ruling may have an indirect impact on the Clean Air Visibility Rule (CAVR) issued by the EPA in 1999 and related Best Available Retrofit Technology Rule (BART) determination guidance in 2005 to address regional haze as discussed below. The EPA’s response to this court decision and associated implications to WPL are uncertain at this time. There are also uncertainties regarding the applicability of state regulations in Wisconsin that were adopted to implement CAIR and state responses in the interim until the uncertainties are resolved.

WPL is currently unable to predict the final outcome of the 2008 court ruling, but expects that capital investments and/or modifications resulting from the reconsidered air quality rules that address SO2 and NOx emissions could be significant. Until CAIR is resolved through further action by the EPA, WPL plans to continue to implement its current multi-emissions

compliance plan, which includes investments in air pollution controls for electric generating facilities as well as purchases of emission allowances. WPL will closely monitor the future developments of these regulations and update its multi-emission compliance plan as needed.

Clean Air Visibility Rule - CAVR requires states to develop and implement SIPs to address visibility impairment in designated national parks and wilderness areas across the country with a national goal of no impairment by 2064. Affected states, including Wisconsin, were required to submit a CAVR SIP to the EPA by December 2007 to include BART air pollution controls and other additional measures needed for reducing state contributions to regional haze. Wisconsin has not yet submitted a CAVR SIP for EPA review. In January 2009, the EPA found Wisconsin to be deficient regarding the CAVR SIP submittal. The EPA is now required to promulgate a FIP within two years. However, the FIP requirement is void if a state submits a regional haze SIP, and the EPA approves that SIP within the two-year period. Electric generating facility emissions of primary concern for BART and regional haze regulation include SO2, NOx and PM. There are pending obligations under the EPA’s CAVR to complete BART determinations that would evaluate control options to reduce these emissions at certain WPL units that were in existence on Aug. 7, 1977 and began operation after Aug. 7, 1962. The D.C. Circuit Court CAIR ruling in 2008 may have an indirect impact on the CAVR and BART SIP implementation approach because the EPA allowed for BART obligations for SO2 and NOx emissions to be fulfilled by the CAIR program and this compliance approach was adopted by Wisconsin. As a result of the D.C. Circuit Court CAIR ruling in December 2008 to revise CAIR, there are uncertainties in the applicability of and compliance outcomes of BART control approaches that will be approved for inclusion in Wisconsin CAVR SIPs. In addition, there are uncertainties whether additional emissions reductions could be required to address regional haze impacts beyond BART. WPL is unable to predict the impact that CAVR might have on the operations of its existing coal-fired generating facilities until Wisconsin has received final EPA approvals of CAVR SIP submittals, which is currently expected in 2010.

Clean Air Mercury Rule (CAMR) - CAMR was issued by the EPA in 2005 to reduce mercury emissions from existing and new U.S. coal-fired electric generating units with greater than 25 MW of capacity in a two-phased approach. The first phase of compliance was required by Jan. 1, 2010 and the second phase by Jan. 1, 2018. Similar to the CAIR program, CAMR would use a national cap-and-trade system, where compliance may be achieved by either adding mercury pollution controls and/or purchasing emission allowances. In March 2008, the D.C. Circuit Court vacated the federal CAMR rule. In October 2008, the EPA petitioned the U.S. Supreme Court to review the D.C. Circuit Court’s decision. In February 2009, the EPA notified the court that it is no longer seeking review of the CAMR vacatur decision and the Supreme Court subsequently denied a remaining petitioner’s request to reconsider the lower court ruling in this case. The EPA will now propose new federal mercury regulations for coal-fired electric generating units. The EPA’s federal mercury rules and associated implications to WPL are uncertain at this time. Wisconsin proposed rules to implement the federal CAMR but these rules were never finalized as a result of the vacatur of CAMR. The Wisconsin Department of Natural Resources (DNR) has subsequently issued a revised state-only mercury rule that is discussed in “Wisconsin State Mercury Rule” below. WPL is currently unable to predict the final outcome of federal mercury emission regulations, but expects that capital investments and/or modifications resulting from mercury emission regulations could be significant.

Wisconsin Reasonably Available Control Technology (RACT) Rule - In 2004, the EPA designated 10 counties in Southeastern Wisconsin as non-attainment areas for the ozone NAAQS. This designation includes Sheboygan County, where WPL operates SFEF and the Edgewater Generating Station (Edgewater). In 2007, the Wisconsin DNR approved the RACT rule for NOx as part of the federal ozone SIP submittal to address non-attainment areas in Wisconsin. Facility modifications are not necessary at SFEF to comply with this rule. As part of its air emissions compliance plan, WPL has invested in installation of low NOx combustion control technologies and will continue to evaluate its compliance approach to meet the 2009 and 2013 compliance deadlines for NOx emissions reductions at Edgewater. However, final compliance requirements cannot be certain until final EPA approval of the RACT rule has been received, which is currently expected in 2009. Refer to “Strategic Overview - Multi-emission Compliance Plan - Air Pollution Control Projects Submitted for PSCW Approval” for discussion of proposed air pollution controls for NOx emission reductions at Edgewater.

Wisconsin State Mercury Rule - In 2004, the Wisconsin DNR independently issued a state-only mercury emission control rule that affects electric utility companies in Wisconsin. The rule explicitly recognizes an underlying state statutory restriction that state regulations cannot be more stringent than those included in any federal mercury program unless there is a demonstration that more stringent requirements are necessary to provide adequate protection for public health or welfare. The rule states that the Wisconsin DNR must adopt state rule changes within 18 months of publication of any federal rules. In March 2008, the Wisconsin DNR issued a mercury public health and welfare finding and related notice of proposed revisions to Wisconsin’s current state mercury rule. The current and revised rules apply to coal-fired generating units with greater than 25 MW of capacity. Under the revised rule, WPL must reduce mercury emissions by 40% by Jan. 1, 2010 from a baseline established in the current state mercury rule. In addition, large coal-fired electric generating units with greater

than 150 MW of capacity must either achieve a 90% mercury emissions reduction standard by Jan. 1, 2015 or choose a multi-pollutant alternative that requires the affected facilities to achieve NOx and SO2 reductions beyond those currently required by federal and state regulations. If the multi-pollutant approach is elected, an additional six years is allowed to achieve the 90% mercury emission reduction standard for the affected facilities. Other coal-fired electric generating units between 25 MW and 150 MW of capacity must install Best Available Control Technology by Jan. 1, 2015 to reduce mercury emissions. The Wisconsin mercury rule revisions were adopted by the Natural Resources Board in June 2008, approved by the Wisconsin legislature in October 2008 and became effective in December 2008. WPL continues to evaluate the impact of these rule revisions and believes its current multi-emission compliance plan includes sufficient controls to achieve compliance.

Ozone NAAQS Rule - In March 2008, the EPA announced reductions in the primary NAAQS for 8-hour ozone to a level of 0.075 parts per million (ppm) from the previous standard of 0.08 ppm. The EPA’s final designations of non-attainment areas for this new ozone standard are to be issued in 2010 with SIPs required in 2013. WPL is currently unable to predict the potential impact of this new ozone standard on its operations. Depending on the level and location of non-attainment areas, WPL may be subject to additional NOx emissions reduction requirements to meet the new ozone standard. WPL continues to monitor regulatory developments related to the new ozone standard issuance and the associated uncertainties to its current multi-emission compliance plan.

Fine Particle NAAQS Rule - The EPA lowered the 24-hour fine particle primary NAAQS (PM2.5 NAAQS) from 65 micrograms per cubic meter (ug/m3) to 35 ug/m3 in 2006. In December 2008, the EPA issued its decision on non-attainment areas designated as not achieving the 2006 PM2.5 NAAQS. The non-attainment areas for Wisconsin include the location of WPL’s Columbia Energy Center (Columbia). The EPA’s designation of areas in non-attainment of the new PM2.5 standard is based on the three most recent years of air monitoring data (2005 through 2007). The EPA’s official designations remain pending until publication in the Federal Register. In February 2009, Wisconsin DNR submitted complete, quality assured, and certified monitoring data for 2008, which may be used with two previous years of data (2006 and 2007) to have an area changed back to attainment status provided the three years of data show the area is now in compliance with the standard. Wisconsin DNR concluded that the 2006 through 2008 data supports a designation of attainment for some areas including the location of Columbia; however, final status requires EPA approval. The effective date of final designations will be 90 days after publication in the Federal Register. Therefore, the anticipated future timeline for action is as follows: the EPA publishes final 2006 PM2.5 designations in the Federal Register, which will take effect within 90 days of publication; SIPs filed with the EPA that demonstrate actions to be taken to achieve attainment are due three years from the effective date of the designations; and attainment deadline to meet the 2006 PM2.5 NAAQS required five years from effective date of designations.

In February 2009, the D.C. Circuit Court of Appeals issued a decision for litigation regarding the EPA’s determination not to lower the annual PM2.5 NAAQS in 2006. In response to the litigation decision, the EPA must re-evaluate its justification for not tightening the annual standard related to adverse effects on health and visibility. WPL is currently unable to predict the potential impact of the 2006 PM2.5 NAAQS on its operations, but WPL may be subject to additional emission reduction requirements including SO2, NOx and PM. WPL continues to monitor regulatory developments related to the PM2.5 NAAQS and the associated uncertainties to its current multi-emission compliance plan.

Industrial Boiler and Process Heater Case-by-Case Maximum Achievable Control Technology (MACT) Rule - In 2004, the EPA’s Industrial Boiler and Process Heater Case-by-Case MACT rule became effective, and compliance with these new emission requirements for hazardous air pollutants was required by September 2007. This rule applies to fossil fuel electric generating units with less than 25 MW capacity as well as certain auxiliary boilers and process heaters operated at electric generating facilities. In June 2007, a court decision vacated this rule. The EPA will be revising the Industrial Boiler and Process Heater Case-by-Case MACT rule in response to this court decision and the implications to WPL are uncertain at this time. Until the EPA issues a revised Industrial Boiler and Process Heater Case-by-Case MACT rule, the federal CAA generally requires affected facilities to submit a permit application for a case-by-case MACT determination to state permitting authorities for all potentially affected units under this rule. Case-by-case MACT determinations are effective compliance measures until revised final federal regulations can replace these interim requirements. WPL anticipates submittal of case-by-case permit applications in the first quarter of 2009. The outcome of the case-by-case MACT determinations by the Wisconsin DNR is uncertain at this time.

Third Party Excess Emission Claims - WPL is aware that certain citizen groups have begun pursuing claims against owners of utility generating facilities regarding excess emissions, including opacity emissions. In addition, WPL is aware that certain public comments have been submitted to the Wisconsin DNR regarding excess emission reports for WPL’s generating facilities. WPL is unable to predict what actions, if any, the Wisconsin DNR or the public commenters may take

in response to these public comments. WPL continues to monitor its emissions closely to determine whether additional controls will be required. The anticipated additional capital investments for compliance with air quality rules discussed in “Strategic Overview - Multi-emission Compliance Plan” are expected to contribute to improvements in opacity emissions. WPL has received several renewed air operating permits for its generating facilities and will continue to evaluate the timing of investments and control equipment options to comply with any new permit requirements.

Third Party Alleged Air Permitting Violation Claims - Citizen groups have pursued claims against utilities and permitting agencies for alleged air permitting violations. WPL is aware of certain public comments or petitions from citizen groups that have been submitted to the Wisconsin DNR regarding the renewal of air operating permits at certain of its facilities. WPL has since received renewal air permits for two facilities that contain changes to permit conditions that resulted from the Wisconsin DNR’s review of the comments or petitions. In December 2008, a citizen group submitted a notice of intent to sue the EPA for failure to respond to its petition encouraging EPA to challenge one of these permits. WPL is unable to predict what actions, if any, the Wisconsin DNR or the public commenters may take in response to any public comments, petitions for existing permits or draft renewal permits.

In December 2008, WPL received the EPA Region V’s request under Section 114 of the CAA for certain information relating to the historical operation of WPL’s Columbia, Edgewater and Nelson Dewey coal-fired generating units in Wisconsin. WPL is in the process of responding to this data request. WPL cannot presently predict the impact of the EPA’s request on its financial condition or results of operations.

GHG Emissions - Climate change continues to garner public attention along with support for policymakers to take action to mitigate global warming. There is considerable debate regarding the public policy response that the U.S. should adopt, involving both domestic actions and international efforts. Several members of Congress have proposed legislation to regulate GHG emissions, primarily targeting reductions of carbon dioxide (CO2) emissions. In addition, efforts are underway by the EPA to respond to a court ruling that could require rules to reduce GHG emissions, including assessment of whether or how the agency should regulate GHG emissions. State and regional initiatives to address GHG emissions are also underway in Wisconsin. Specifically, governors from nine Midwest states, including Wisconsin, signed the Midwestern GHG Accord in November 2007. The participants were expected to develop a proposed cap-and-trade agreement and a model rule within 12 months of the date of this accord. However, the Midwestern GHG Accord recently released a revised timeline indicating a proposed cap and trade agreement and model rule will not be available until mid-2009. The accord also provides for an 18-month implementation period following completion of the cap-and-trade agreement and model rule. Refer to “Rates and Regulatory Matters - Recent Regulatory-related Legislative Developments” for state initiatives to address GHG emissions.

WPL continues to take voluntary measures to reduce its emissions including CO2 and other GHG as prudent steps to address potential climate change regulation. In the third quarter of 2008, WPL completed the formal application process and third party audit for participation in the Phase I period of the Chicago Climate Exchange (CCX). CCX is a voluntary market-based emissions cap and trade program for reducing GHG emissions including CO2. Strategically, WPL focuses on the following areas to reduce GHG: 1) installation of commercially proven controls for air emissions and continued operational excellence to achieve further generating facility efficiency improvements; 2) demand-side management including energy conservation programs; 3) expansion of company-owned renewable energy sources; 4) continued use of PPAs and investments that focus on lower or non-emitting generation resources; and 5) development of technology solutions through funding of collaborative research programs for advanced clean coal generation as well as potential options for carbon sequestration.

WPL’s Board of Directors has assigned oversight of environmental policy and planning issues, including climate change, to the Environmental, Nuclear, Health and Safety (ENHS) Committee. The ENHS committee is comprised solely of independent directors. The ENHS Committee reports on its reviews and, as appropriate, makes recommendations to WPL’s Board of Directors.

Given the highly uncertain outcome and timing of future regulations regarding the control of GHG emissions, WPL currently cannot predict the financial impact of any future climate change regulations on its operations but the capital expenditures to comply with any new emissions controls could be significant.

Water Quality -

Federal Clean Water Act - The Federal Clean Water Act requires the EPA to regulate cooling water intake structures to assure that these structures reflect the “best technology available” for minimizing adverse environmental impacts to fish and other aquatic life. In 2004, the second phase of this EPA rule became effective and is generally referred to as Section 316(b) of the Clean Water Act (316(b)). 316(b) applies to existing cooling water intake structures at large steam-electric generating

facilities. WPL has identified three generating facilities that are believed to be impacted by 316(b). In January 2007, a court opinion invalidated aspects of the 316(b) rule that allowed for consideration of cost-effectiveness when determining the appropriate compliance measures. In July 2007, the EPA formally suspended the Phase II 316(b) rule. In December 2008, the U.S. Supreme Court heard arguments on whether the EPA may compare costs to benefits when setting technology-based requirements to minimize environmental impacts at cooling water intake structures. A decision in this case is anticipated in the first half of 2009. WPL is currently unable to predict the final requirements, but expects that capital investments and/or modifications resulting from the regulation could be significant.

Proposed Wisconsin State Thermal Rule - In February 2008, WPL submitted comments to the Wisconsin DNR on the proposed rule regarding the amount of heat that WPL’s generating facilities can discharge into Wisconsin waters. The Wisconsin DNR has reviewed all comments and is completing its revision of the proposed rule. A final rule may be approved by the Wisconsin Natural Resources Board as early as the first half of 2009. At this time, WPL is unable to predict the final outcome of the proposed rule, but believes that required capital investments and/or modifications resulting from this rule could be significant.

Hydroelectric Fish Passages and Fish Protective Devices - In 2004, FERC issued an order requiring WPL to take the following actions regarding one of WPL’s hydroelectric generating facilities: 1) develop a detailed engineering and biological evaluation of potential fish passages for the facility; 2) install an agency-approved fish-protective device at the facility within one year and 3) install an agency-approved fish passage at the facility within three years. In 2005, WPL filed an extension request with FERC for the detailed engineering and biological evaluation of potential fish passages and installation of an agency-approved fish-protective device. In 2006, FERC approved extending the evaluation and installation for the downstream fish passage to April 2008 and upstream fish passage to April 2009. In January 2007, the U.S. Fish and Wildlife Service and Wisconsin DNR requested additional changes and further analysis on the fish passage design, delaying the construction plan. The fish protection equipment construction and installation plans were approved by the U.S. Fish and Wildlife Service and Wisconsin DNR in December 2007. In March 2008, FERC approved a request to extend the deadlines to complete the construction and installation of a fish protective device to the end of 2008. Due to unforeseen additional work for the installation of the fish protective device, WPL has submitted a request to FERC for approval for an additional extension to complete the construction and installation of the fish protective device by the end of 2010. The design, construction and installation of the fish passages are expected to be completed by the end of 2012. WPL believes that required capital investments and/or modifications resulting from these issues could be significant.

Land and Solid Waste -

Manufactured Gas Plant (MGP) Sites - WPL has current or previous ownership interests in 14 MGP sites previously associated with the production of gas for which it may be liable for investigation, remediation and monitoring costs relating to the sites. WPL is working pursuant to the requirements of various federal and state agencies to investigate, mitigate, prevent and remediate, where necessary, the environmental impacts to property, including natural resources, at and around the sites in order to protect public health and the environment. Refer to Note 12(e) of the “Notes to Consolidated Financial Statements” for estimates of the range of remaining costs to be incurred for the investigation, remediation and monitoring of WPL’s MGP sites.

Ash Ponds - WPL is monitoring potential regulatory changes that may affect the rules for operation and maintenance of ash ponds and/or landfills, in the wake of recent ash pond failures at another utility. WPL is currently unable to predict the outcome of any potential regulatory changes at this time.

Land and Solid Waste Regulatory Issues - WPL is also monitoring various other land and solid waste regulatory changes. This includes a potential EPA regulation for management of coal combustion product in landfills and surface impoundments that could require installation of monitoring wells at some facilities and an ongoing expanded groundwater monitoring program. Compliance with the polychlorinated 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 has drafted a new rule related to flammable, combustible and hazardous liquids stored in above ground storage tanks. This draft rule has not yet been finalized. The primary financial impact of this new rule would be from a secondary containment requirement for all new hazardous materials tanks and for new hazardous material unloading areas. WPL is unable to predict the outcome of these possible regulatory changes at this time, but currently believes that the required capital investment and/or modifications resulting from these potential regulations could be significant.

Refer to Note 12(e) of the “Notes to Consolidated Financial Statements,” “Strategic Overview” and “Cash Flows - Investing Activities - Construction and Acquisition Expenditures” for further discussion of environmental matters.

OTHER MATTERS

Market Risk Sensitive Instruments and Positions -WPL’s primary market risk exposures are associated with commodity prices, investment prices currency exchange rates and interest rates. WPL 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(i) and 11 of the “Notes to Consolidated Financial Statements” for further discussion of WPL’s derivative instruments.

Commodity Price Risk -WPL is exposed to the impact of market fluctuations in the commodity price and transportation costs of electric, coal and natural gas productscommodities 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 durations for the forward sale and purchase of these commodities. Specifically, WPL has entered into several commodity derivative instruments and physical fixed-price commodity purchases to substantially hedge its open positions related to electric supply in 2009. However, WPL still has some exposure to commodity risk as a result of changes in its forecasted electric demand and expected availability of its generating units, among other issues. WPL’s exposure to commodity price risks is also significantly mitigated by current rate making structures in place for recovery of its electric production fuel and purchased energy costsexpenses (fuel-related costs) as well as its cost of natural gas purchased for resale. WPL’s gaselectric and wholesale electricgas tariffs provide for subsequent adjustments to its rates for material changes in prudently incurred commodity costs. WPL’s rate mechanisms, combined with commodity derivatives, significantly reduce commodity risk associated with its electric and gas margins.

WPL’s retail electric margins have the most exposure to the impact of changes in commodity prices due largely to the current retail recovery mechanism in place in Wisconsin for fuel-related costs.costs, which became effective on Jan. 1, 2011. The cost recovery mechanism applicable for WPL’s retail electric rates arecustomers is based on forecasts of fuel-related costs expected to be incurred during forward-looking test year periods and include estimates of future fuel-related costs per MWh anticipatedfuel monitoring ranges determined by the PSCW during the test periods. During each electric retail rate proceeding for WPL that includesor in a separate fuel costs, the rate orders approved by the PSCW set cost per MWh fuel monitoring ranges. If WPL’s actual fuel-related costs fall outside these fuel monitoring ranges during the test period, WPL can request and the PSCW can authorize an adjustment to future retail electric rates. As part of this process, the PSCW may authorize an interim fuel-related rate increase or decrease until final rates are approved. However, if an interim rate increase is granted and the final rate increase is less than the interim rate increase, WPL would refund the excess collection to customers, including interest, at the current authorized return on equity rate. As part of WPL’s 2009/plan approval proceeding. In December 2010, retail rate case order effective Jan. 1, 2009, the PSCW approved annual forecasted fuel-related costs per MWh of $30.97$25.12 based on $465$346 million of variable fuel costs for WPL’s 20092011 test period and left unchanged the annual fuel monitoring range of plus or minus 2%.

Under the new cost recovery mechanism, if WPL’s actual fuel-related costs fall outside this fuel monitoring range during the test period, WPL is authorized to defer the incremental over- or under-collection of fuel-related costs from electric retail customers that are outside the approved ranges. Any over- or under-collection of fuel-related costs for each year are reflected in future billings to customers. Based on the current retailthis new cost recovery mechanism in Wisconsin and the annual forecasted fuel-related costs and fuel monitoring range approved by the PSCW in December 2010, WPL hascurrently estimates the commodity risk exposure to its retail electric margins from increases in fuel-related costs above the forecasted fuel-related costs per MWh used2011 is approximately $5 million.

Refer to determine electric rates to the extent such increases are not recovered through prospective fuel only retail rate changes. WPL has additional commodity price risk resulting from the lag inherent in obtaining any approved retail rate relief for potential increases in fuel-related costs above the fuel monitoring ranges“Rate Matters” and the prospective nature of any retail rate relief, which precludes it from recovering under-recovered costs from ratepayers in the future. WPL is unable to determine the anticipated impact of changes in commodity prices on its future retail electric margins given the uncertainty of how future fuel-related costs will correlate with the retail electric rates in place and the outcomeNote 1(h) of the proposed changes“Notes to the current retail electric fuel-related cost recovery rules in Wisconsin. Refer to “Rates and Regulatory Matters”Consolidated Financial Statements” for additional details of the retail rate recovery mechanism in Wisconsin for electric fuel-related costs including potential changes to WPL’s electric fuel-relatedutility cost recovery mechanism and the PSCW’s approval ofmechanisms that significantly reduce WPL’s electric risk management plan in October 2008.

WPL also has exposure to market fluctuations in commodity prices of certain materials procured for its infrastructure investment program. In 2008, Corporate Services, as agent for IPL and WPL, entered into a master supply agreement with Vestas to purchase 500 MW of wind turbine generator sets and related equipment. The master supply agreement includes pricing terms which are subject to change if steel prices change by more than 10% between measurement dates defined in the master supply agreement. Assuming changes in steel prices are sufficient to warrant a change in the pricing terms, the impact of each incremental 10% increase (decrease) in steel prices will increase (decrease) WPL’s anticipated purchase price of its portion of the wind turbine generator sets and related equipment as of Dec. 31, 2008 by approximately $2.4 million.risk.

Investment Price Risk- - WPL is exposed to investment price risk as a result of its investments in debt and equity securities, largely related to securities held by its pension and other postretirement benefits plans.

Currency Exchange Rate Risk - WPL is exposed Refer to risk resulting from changes in currency exchange rates as a result of Corporate Services’ master supply agreement with Vestas to purchase wind turbine generator sets and related equipment. A portionNote 6(a) of the future payments under the master supply agreement are denominated in Euros, and therefore, are subject“Notes to currency exchange risk with fluctuations in currency exchange rates. The impact of a hypothetical 10% increase (decrease) in currency exchange rates on the future Euro-denominated payments under the master supply agreement would increase (decrease) WPL’s anticipated purchase price of its portionConsolidated Financial Statements” for details of the wind turbine generator setsdebt and related equipment as of Dec. 31, 2008equity securities held by approximately $8.2 million.its pension and other postretirement benefit plans.

Interest Rate Risk -WPL is exposed to risk resulting from changes in interest rates as a result of its issuance of variable-rate short-term borrowings. Assuming the impact of a hypothetical 100 basis point increase (decrease) in interest rates on consolidated variable-rate short-term borrowings held at Dec. 31, 2008,2010, WPL’s annual pre-tax expense would increase (decrease) by approximately $0.4$0.5 million. Refer to Note 8(a) of the “Notes to Consolidated Financial Statements” for additional information on variable-rate short-term borrowings.

New Accounting Pronouncements -Refer to Note 1(q)1(r) of the “Notes to Consolidated Financial Statements” for discussion of new accounting pronouncements impacting WPL.

Critical Accounting Policies and Estimates -The preparation of consolidated financial statements in conformity with accounting principles generally accepted in the U.S. (GAAP) requires that management apply accounting policies and make estimates that affect results of operations and the amounts of assets and liabilities reported in the financial statements. Based on historical experience and various other factors, WPL believes the following accounting policies and estimates are critical to its business and the understanding of its financial results as they require critical assumptions and judgments by management. The results of these assumptions and judgments form the basis for making estimates regarding the results of operations and the amounts of assets and liabilities that are not readily apparent from other sources. Actual financial results may differ materially from these estimates. WPL’s management has discussed these critical accounting policies and estimates with the Audit Committee of its Board of Directors. Refer to Note 1 of the “Notes to Consolidated Financial Statements” for additional discussion of WPL’s accounting policies and the estimates used in the preparation of the consolidated financial statements.

Accounting for Contingencies -WPL makes assumptions and judgments each reporting period regarding the future outcome of contingent events and records loss contingency amounts for any contingent events that are both probable and reasonably estimatableestimated based upon current available information. The amounts recorded may differ from the actual income or expense that occurs when the uncertainty is resolved. The estimates that WPL makes in accounting for contingencies, and the gains and losses that it records upon the ultimate resolution of these uncertainties, could have a significant effect on the results of operations and the amount of assets and liabilities in its financial statements. Refer to Note 12 of the “Notes to Consolidated Financial Statements” forprovides discussion of current contingencies assessed at Dec. 31, 2010 including various pending legal proceedings that may have a material impact on WPL’s financial condition or results of operations, or cash flows.operations.

Regulatory Assets and Regulatory Liabilities -WPL is regulated by various federal and state regulatory agencies. As a result, it qualifiesis subject to accounting guidance for the application of Statement of Financial Accounting Standards (SFAS) 71, “Accounting for the Effects of Certain Types of Regulation.” SFAS 71regulated operations, which recognizes that the actions of a regulator can provide reasonable assurance of the existence of an asset or liability. Regulatory assets or regulatory liabilities arise as a result of a difference between GAAP 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 future customer rates. Regulatory liabilities generally represent obligations to make refunds to customers and amounts collected in rates for which the related costs have not yet been incurred.

WPL recognizes regulatory assets and regulatory 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 WPL’s regulatory assets and regulatory liabilities. Management periodically assesses

WPL makes assumptions and judgments each reporting period regarding whether theits regulatory assets are probable of future recovery and theits regulatory liabilities are probable of future obligations by considering factors such as regulatory environment changes, and recent rate orders issued by the applicable regulatory agencies.agencies and historical decisions by applicable regulatory agencies regarding similar regulatory assets and regulatory liabilities. 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 WPL’s results of operations and the amount of assets and liabilities in its financial statements. Refer to Note 1(b) of the “Notes to Consolidated Financial Statements” forprovides details of the nature and amounts of WPL’s regulatory assets and regulatory liabilities as ofassessed at Dec. 31, 2008 and 2007.2010.

Asset Valuations of Long-Lived Assets to be Held and Used- - The Consolidated Balance Sheets include significant long-lived assets, which are not subjectyet being recovered from WPL’s customers or may cease to recovery under SFAS 71.be recovered from its customers as a result of regulatory decisions in the future. As a result, WPL must determine whether it will be able to generate sufficient future cash flows from such assets in a non-regulated environment to ensure recovery of the carrying value is not impaired.of the long-lived assets. WPL assesses the carrying amount and potential impairment of these assets whenever events or changes in circumstances indicate that the carrying value may not be recoverable. Factors considered in determining if an impairment review is necessary include a significant underperformance of the assets relative to historical or projected future operating results, a significant change in the use of the acquired assets or business strategy related to such assets, and significant negative industry, regulatory or economic trends. When an impairment review is deemed necessary, a comparison is made between the expected undiscounted future cash flows and the carrying amount of the asset. If the carrying amount of the asset is the larger of the two balances, an impairment loss is recognized equal to the amount the carrying amount of the asset exceeds the fair value of the asset. The fair value is determined by the use of quoted market prices, appraisals, or the use of valuation techniques such as expected discounted future cash flows.

WPL must makemakes assumptions and judgments each reporting period regarding these estimatedthe recoverability of certain long-lived assets including assets held for sale and assets not yet being recovered from its customers. WPL’s assets assessed at Dec. 31, 2010 include the wind sites and wind turbine generators currently expected to be used to develop future cash flows and other factors to determine the fair valuewind projects. Note 1(e) of the assets.“Notes to Consolidated Financial Statements” and “Strategic Overview- Generation Plans” provide details of wind sites and wind turbine generators currently expected to be used to develop future wind projects.

Unbilled Revenues- Energy sales to individual customers are based on the reading of theircustomers’ meters, which occurs on a systematic basis throughout the month. At the end of each month, amountsAmounts of energy delivered to customers since the date of the last meter reading are estimated at the end of each reporting period and the corresponding estimated unbilled revenue is recorded. The unbilled revenue estimate is based on daily system demand volumes, estimated customer usage by class, weather impacts, line losses and the most recent customer rates. Such process involves the use of various estimates, thusjudgments and assumptions and significant changes in the estimatesthese judgments and assumptions could have a material impact on WPL’s results of operations.

At Dec. 31, 20082010 and 2007,2009, WPL’s unbilled revenues were $92$82 million and $86$87 million, respectively. Refer to “Results of Operations - Electric Margins -Margins- Unbilled Revenue Estimates” forprovides discussion of annual adjustments to unbilled electric revenue estimates in the second quarters of 2008, 20072010, 2009 and 2006.2008.

Accounting for Pensions and Other Postretirement Benefits - - WPL accounts for pensionssponsors various defined benefit pension and other postretirement benefits under SFAS 87, “Employers’ Accounting for Pensions,” SFAS 106, “Employers’ Accounting for Postretirement Benefits Other Than Pensions,”plans that provide benefits to a significant portion of its employees. WPL makes assumptions and SFAS 158, “Employers’ Accounting for Defined Benefit Pensionjudgments periodically to estimate the obligations and Other Postretirement Plans - an amendment of FASB Statements No. 87, 88, 106 and 132(R).” Under these rules, certain assumptions are made which represent significant estimates.costs related to its retirement plans. There are many factorsjudgments and assumptions 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 benefits costs. AssumptionsJudgments and assumptions are supported by historical data and reasonable projections and are reviewed annually. As of Dec. 31, 2008 (WPL’s most recent measurement date), future assumptions included a 6.15% discount rate to calculate benefit obligations and a 8.5% annual expected rate of return on investments. In selecting an assumed discount rate, management reviews various corporate Aa bond indices. The 8.5% annual expected rate of return is based on projected long-term equity and bond returns, maturities and asset allocations.

Refer to Notes 1(j) andNote 6(a) of the “Notes to Consolidated Financial Statements” forprovides additional discussiondetails of the accounting for pensionspension and other postretirement benefits. Refer tobenefits plans. “Other Future Considerations - Pension and Other Postretirement Benefits Costs for 2009” forRetirement Plan Costs” provides discussion of anticipated material increasesdecreases in pension and other postretirement benefits expensescosts in 20092011 due to lower amortization of actuarial losses and higher expected returns on plan assets resulting from decreasesincreases in retirement plans’plan assets during 2008.2010. Note 12(c) of the “Notes to Consolidated Financial Statements” provides discussion of a class action lawsuit filed against the Alliant Energy Cash Balance Pension Plan in 2008 and the IRS review of the tax qualified status of the Plan.

Income Taxes -WPL accounts foris subject to income taxes under FIN 48in various jurisdictions. WPL makes assumptions and SFAS 109, “Accounting for Income Taxes.” Under these rules, certain assumptions are made which represent significant estimates usedjudgments each reporting period to determine an entity’sestimate its income tax assets, liabilities, benefits and expenses each period. These assumptions include projections of the impacts from the completion of audits of the tax treatment of certain transactions. WPL’sexpenses. Judgments and assumptions are supported by historical data and reasonable projections and are reviewed quarterly by management.projections. Significant changes in these judgments and assumptions could have a material impact on WPL’s financial condition and results of operations. WPL’s critical assumptions and judgments for 2010 include projections of its future taxable income used to determine its ability to utilize loss and credit carryforwards prior to their expiration and the interpretation of tax laws regarding uncertain tax positions.

Refer to NoteNotes 1(c) and 5 of the “Notes to Consolidated Financial Statements” for additionalfurther discussion of regulatory accounting for taxes and details regarding unrecognizedof uncertain tax benefitspositions, respectively. Refer to “Other Future Considerations - Tax Accounting for Mixed Service Costs” for discussion of a proposed change in tax accounting for mixed service costs that may result in significant tax deductions for WPL.

Other Future Considerations -In addition to items discussed earlier in MDA and in the “Notes to Consolidated Financial Statements,” the following items could impact WPL’s future financial condition or results of operations or cash flows:operations:

PensionElectric Transmission Service Charges -

MISO Transmission Cost Allocation - In July 2010, MISO filed a proposed revised tariff with FERC for a new category of transmission projects called Multi-Value Projects (MVPs). MVPs include new large scale transmission projects that enable the reliable and Other Postretirement Benefits Costs for 2009 - WPL’s pensioneconomic delivery of energy in support of documented energy policy mandates or provide economic value across multiple pricing zones within MISO. The MVP category is intended to facilitate the integration of large amounts of location-constrained resources including renewable resources, support MISO member and other postretirement benefitscustomer compliance with evolving state and federal energy policy requirements, enable MISO to address multiple reliability needs and provide economic opportunities through regional transmission development. The proposed revised tariff would allow certain costs of MVPs to be socialized across the entire MISO footprint based on energy usage by the MISO participants to ensure that areas within the MISO footprint that have large amounts of generation and a small share of load are not allocated a disproportionate amount of the costs for 2009 are currently expected to be higher than 2008 costs by approximately $30 million. The higher pension and other postretirement benefits costs are primarily due to significant decreases in plan assets resulting from financial market conditions during 2008. Refer to Note 6(a) of the “Notes to Consolidated Financial Statements” for information on the funded status of WPL’s pension and other postretirement benefits plans.

MVPs. In December 2008, WPL received approval from the PSCW to defer, and record carrying costs on, the retail portion of 2009 pension and other postretirement benefits costs in excess of the $4 million used to set retail rates for 2009. WPL will seek recovery of any deferred costs in its next retail base rate case. WPL’s wholesale portion of 2009 pension and other postretirement benefits costs will be pursued for recovery under established formulaic ratemaking procedures.

Electric Sales Projections - WPL is expecting lower retail electric sales demand in 2009 compared to 2008 partially due to economic conditions in its service territory. Electric sales demand from industrial customers in 2009 is expected to be impacted the most by economic conditions as a result of bankruptcies, plant closures and shift reductions at several manufacturing customers in WPL’s service territory that were announced in 2008 and early 2009. WPL is currently unable to estimate the impacts of economic conditions on its future electric sales demand and electric margins.

Incentive Compensation Plans -Alliant Energy’s total compensation program includes an incentive compensation program (ICP) which provides substantially all of its non-bargaining employees (including WPL employees) an opportunity to receive annual short-term incentive cash payments based on the achievement of specific annual corporate goals for Alliant Energy including, among others, earnings per share from continuing operations and cash flows from operations. Funding of the ICP is designed so that Alliant Energy retains all earnings up to a pre-established earnings target. After achieving such target, there is a sharing mechanism of earnings between Alliant Energy and employees up to an established maximum funding amount2010, FERC conditionally approved MISO’s proposal for the ICP. In addition, the total compensation program for certain key employees includes long-term incentive awards issued under an Equity Incentive Plan (EIP). Refer to Note 6(b) of the “Notes to Consolidated Financial Statements” for additional discussion of outstanding awards issued under the EIP.MVP transmission cost allocation. WPL is currently unable to determine what impacts these incentive compensation plans willthe ultimate impact that the revised tariff may have on its future financial condition orand results of operations.operations, but believes the outcome could be material to its future electric transmission service expense.

Production Tax CreditsGovernment Incentives for Wind Projects - - WPL’s corporate strategy includes building or acquiring severaland owning wind projects to produce electricity to meet customer demand and renewable portfolio standards. In addition to producing electricity, these wind projects may also generate material production tax creditsincentives depending on when they begin commercial operations and the electricity output generated by the wind projects.generating electricity. The American Recovery and Reinvestment BillAct of 2009 (ARRB)(ARRA) enacted in February 2009 provides production tax creditsprovided incentives to owners of wind projects placed into service between Jan. 1, 2009 and Dec. 31, 2012. The incentive options available to qualified wind projects under the ARRA include production tax credits for a 10-year period based on the electricity output generated by the wind project, an investment tax credit equal to 30% of the qualified cost basis of the wind project, or a government grant equal to 30% of the qualified cost basis of the wind project. In December 2010, the Tax Relief, Unemployment Insurance Reauthorization and Job Creation Act of 2010 modified the requirements for the government grant incentive. The government grant incentive is now available for qualified wind projects that are placed into service in 2009, 2010 or 2011 and qualified wind projects that began construction in 2009, 2010 and 2011 and are placed into service by Dec. 31, 2012.

WPL’s generation plan has two wind projects whichthat currently qualify orfor one of the government incentives. The two wind projects are expected to qualify, for production tax credits based on the provisions of ARRB.

WPL’s Cedar Ridge wind project (68 MW capacity) that began commercial operationsgenerating electricity in December 2008. Based on current electricity production levels anticipated fromlate 2008 and the project, WPL expects production tax credits from its Cedar Ridge wind project of approximately $3 million to $5 million per year for 10 years following the project’s commercial operation date.

WPL’s Bent Tree - Phase I wind project (200 MW capacity) is expected to begin commercial operationthat began generating electricity in 2010 pending regulatory approvals for the project.fourth quarter of 2010. Based on electricity production levels anticipated froman evaluation of the project,most beneficial alternative for customers, WPL estimates potentialhas chosen to recognize production tax credits from its Bent Treefor the two eligible wind projectprojects that are already generating electricity. The amount of approximately $10 million to $15 million per year for 10 years following the project’s commercial operation date.

Any production tax credits is dependent on the level of electricity output generated by each wind project, which is impacted by a variety of operating and economic parameters including transmission availability. Any incentives for WPL’s wind projects are expected to be utilized in determining customers’ rates. Production tax credits earned for 2009 and 2010 along with estimates of production tax credits currently expected to be earned in 2011 for these wind projects are as follows (in millions):

   2009   2010   2011

Cedar Ridge

  $4    $3    $3 - $4

Bent Tree - Phase I

   —       1    7 - 8
             
  $4    $4    $10 - $12
             

Tax Accounting for Mixed Service Costs -In September 2010, Alliant Energy, on behalf of WPL, filed a request with the IRS for a change in its tax method of accounting for mixed service costs. The requested change would allow WPL to currently deduct a portion of its mixed service costs, which have historically been capitalized for tax purposes. If approved by the IRS, this proposed change could be applied retroactively to mixed service costs incurred since 1987. WPL recently completed an assessment of its eligible mixed service costs for the period from 1987 through 2009 and currently believes it will include approximately $190 million of mixed service costs deductions for these years in its 2010 federal income tax return if the proposed change is approved by the IRS. These mixed service cost deductions are expected to contribute to a federal net operating loss in 2010. WPL’s federal net operating losses incurred through 2010 (including the impacts of mixed service costs deductions) are currently expected to offset future federal taxable income resulting in minimal federal cash tax payments to the IRS by WPL through 2015. In accordance with accounting rules, WPL will not reflect the impact of this proposed change to mixed service costs in its financial statements until Alliant Energy receives consent from the IRS for the change in tax method of accounting for mixed service costs.

MISO MarketRetirement Plan Costs- - In January 2009, MISO launchedWPL’s net periodic benefit costs related to its defined benefit pension and other postretirement benefits plans are currently expected to be lower in 2011 than 2010 by approximately $4 million. The decrease in expected net periodic benefit costs is primarily due to lower amortization of actuarial losses and higher expected returns on plan assets resulting from increases in retirement plan assets during 2010. Approximately 30% to 40% of net periodic benefit costs are allocated to capital projects each year. As a result, the ancillary services market, which includes systemsdecrease in net periodic benefit costs is not expected to result in a comparable decrease in other operation and business processes,maintenance expenses. Refer to complementNote 6(a) of the existing wholesale energy market that MISO implemented“Notes to Consolidated Financial Statements” for additional details of WPL’s defined benefit pension and other postretirement benefits plans.

Electric Sales Projections- WPL is currently expecting modest (approximately 1% to 1.5%) increases in April 2005.weather-normalized retail electric sales in 2011 compared to 2010 largely due to a slow economic recovery and low customer growth.

Maintenance Costs for Wind Projects -Wind projects require periodic maintenance to ensure reliability of operations. WPL has monitoredentered into agreements with outside vendors to provide these services for its Bent Tree - Phase I wind project. WPL currently estimates approximately $7 million to $8 million of annual maintenance expenses for its Bent Tree - Phase I wind project after it begins generating electricity.

Incentive Compensation Plans -Alliant Energy’s total compensation package includes an incentive compensation program, which provides substantially all of Alliant Energy’s non-bargaining employees an opportunity to receive annual short-term incentive cash payments based on the developmentachievement of specific annual operational and financial performance measures. The operational performance measures for 2011 relate to diversity, safety, customer satisfaction, service reliability and generating facilities’ availability, and the financial performance measures for 2011 relate to utility earnings per share from continuing operations and cash flows from operations generated by WPL, IPL and Corporate Services. In addition, the total compensation program for certain key employees includes long-term incentive awards issued under an equity incentive plan. Alliant Energy allocates a portion of incentive compensation plan costs to WPL. Refer to “Results of Operations - Other Operation and Maintenance Expenses” for discussion of higher incentive-related compensation expenses in 2010 and Note 6(b) of the market“Notes to ensure that the rules associated with the market are reasonable and that costs and revenues associated with the market receive appropriate regulatory cost recovery treatment. Given the changing allocationConsolidated Financial Statements” for additional discussion of generation assets among a fluctuating set of MISO reserve zones,long-term incentive awards. WPL is currently unable to determine what impacts this new marketthese incentive compensation plans will have on its future financial condition or results of operations or cash flows.operations.

MANAGEMENT’S ANNUAL REPORT ON INTERNAL CONTROL OVER FINANCIAL REPORTING

The management of Wisconsin Power and Light Company and subsidiaries (WPL) is responsible for establishing and maintaining adequate internal control over financial reporting, as such term is defined in Rules 13a-15(f) and 15d-15(f) under the Securities Exchange Act of 1934. WPL’s internal control over financial reporting is designed to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with accounting principles generally accepted accounting principles.in the United States of America.

Because of the inherent limitations of internal control over financial reporting, misstatements may not be prevented or detected on a timely basis. Also, projections of any evaluation of the effectiveness of the internal control over financial reporting to future periods are subject to the risk that the controls may become inadequate because of changes in conditions, or that the degree of compliance with the policies or procedures may deteriorate.

WPL’s management assessed the effectiveness of itsWPL’s internal control over financial reporting as of December 31, 20082010 using the criteria set forth inInternal Control - Integrated Framework issued by the Committee of Sponsoring Organizations of the Treadway Commission. Based on this assessment, WPL’s management believesconcluded that, as of December 31, 2008, its2010, WPL’s internal control over financial reporting was effective based on those criteria.effective.

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William D. Harvey

Chairman and Chief Executive Officer

 

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William D. Harvey
Chairman and Chief Executive Officer
LOGO
Patricia L. Kampling
Vice President-Chief Financial Officer and Treasurer
LOGO
Thomas L. Hanson
Vice President-Controller and Chief Accounting Officer
February 27, 2009

LOGO

Thomas L. Hanson

Vice President-Chief Financial Officer and Treasurer

LOGO

Robert J. Durian

Controller and Chief Accounting Officer

February 28, 2011

REPORT OF INDEPENDENT REGISTERED PUBLIC ACCOUNTING FIRM

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

Madison, Wisconsin

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, 20082010 and 2007,2009, and the related consolidated statements of income, changes in common equity, and cash flows for each of the three years in the period ended December 31, 2008.2010. These financial statements are the responsibility of the Company’s management. Our responsibility is to express an opinion on the financial statements based on our audits.

We conducted our audits in accordance with the standards of the 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, 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, 20082010 and 2007,2009, and the results of its operations and its cash flows for each of the three years in the period ended December 31, 2008,2010, in conformity with accounting principles generally accepted in the United States of America.

As discussed in Notes 1(q) and 5 to the consolidated financial statements, as a result of the adoption of new accounting standards the Company changed its method of accounting for defined benefit pension and postretirement plans on December 31, 2006 and for uncertainty in income taxes on January 1, 2007.

 

/s/ DELOITTE & TOUCHE LLP

DELOITTE & TOUCHE LLP

Milwaukee, Wisconsin
February 27, 200928, 2011

CONSOLIDATED FINANCIAL STATEMENTS

CONSOLIDATED STATEMENTS OF INCOME

 

  Year Ended December 31,   Year Ended December 31, 
  2008 2007 2006   2010 2009 2008 
  (in millions)   (in millions) 

Operating revenues:

        

Electric utility

  $1,153.0  $1,140.7  $1,111.4   $1,209.9   $1,160.3   $1,153.0  

Gas utility

   300.0   265.7   273.9    206.3    216.5    300.0  

Other

   12.8   10.4   16.0    7.4    9.3    12.8  
                    

Total operating revenues

   1,423.6    1,386.1    1,465.8  
   1,465.8   1,416.8   1,401.3           
          

Operating expenses:

        

Electric production fuel and purchased power

   579.3   584.1   578.5 

Electric production fuel and energy purchases

   401.2    451.3    434.2  

Purchased electric capacity

   134.7    144.6    145.1  

Electric transmission service

   93.2   81.0   71.0    100.4    94.2    93.2  

Cost of gas sold

   213.6   175.0   174.8    125.3    138.1    213.6  

Other operation and maintenance

   232.3   236.2   245.3    232.7    234.3    232.3  

Depreciation and amortization

   101.7   109.9   107.3    108.6    115.4    101.7  

Taxes other than income taxes

   40.8   39.9   39.5    41.9    41.2    40.8  
                    

Total operating expenses

   1,144.8    1,219.1    1,260.9  
   1,260.9   1,226.1   1,216.4           
          

Operating income

   204.9   190.7   184.9    278.8    167.0    204.9  
          
          

Interest expense and other:

        

Interest expense

   62.2   49.6   48.3    78.6    74.8    62.2  

Equity income from unconsolidated investments

   (33.9)  (28.4)  (27.0)   (37.8  (37.0  (33.9

Allowance for funds used during construction

   (9.6)  (2.6)  (2.6)   (12.5  (5.7  (9.6

Interest income and other

   (0.6)  (0.7)  (1.3)   (0.1  (0.4  (0.6
                    

Total interest expense and other

   28.2    31.7    18.1  
   18.1   17.9   17.4           
          

Income before income taxes

   186.8   172.8   167.5    250.6    135.3    186.8  
                    

Income taxes

   68.4   59.3   62.2    98.3    45.8    68.4  
          
          

Net income

   118.4   113.5   105.3    152.3    89.5    118.4  
                    

Preferred dividend requirements

   3.3   3.3   3.3    3.3    3.3    3.3  
          
          

Earnings available for common stock

  $115.1  $110.2  $102.0   $149.0   $86.2   $115.1  
                    

Earnings per share data is not disclosed given Alliant Energy Corporation is the sole shareowner of all shares of WPL's common stock outstanding during the periods presented.

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

CONSOLIDATED BALANCE SHEETS

 

  December 31, 
  2008 2007 
  (in millions)   December 31, 

ASSETS

    2010 2009 
  (in millions) 

Property, plant and equipment:

      

Electric plant in service

  $2,500.3  $2,214.4   $3,114.6   $2,726.5  

Gas plant in service

   370.1   347.6    411.4    393.8  

Other plant in service

   198.1   184.8    219.0    219.8  

Accumulated depreciation

   (1,165.9)  (1,108.2)   (1,243.8  (1,185.8
              

Net plant

   1,902.6   1,638.6    2,501.2    2,154.3  

Leased Sheboygan Falls Energy Facility, less accumulated amortization of $22.1 and $15.9

   101.7   107.9 

Construction work in progress

   88.4   102.6 

Other, less accumulated depreciation of $1.1 and $0.8

   3.8   2.6 

Leased Sheboygan Falls Energy Facility, less accumulated amortization of $34.4 and $28.2

   89.4    95.5  

Construction work in progress:

   

Bent Tree - Phase I wind project

   154.5    165.5  

Other

   81.0    39.4  

Other, less accumulated depreciation of $2.2 and $1.6

   20.0    21.0  
              

Total property, plant and equipment

   2,846.1    2,475.7  
   2,096.5   1,851.7        
       

Current assets:

      

Cash and cash equivalents

   4.5   0.4    0.1    18.5  

Accounts receivable:

      

Customer, less allowance for doubtful accounts of $1.8 and $1.3

   83.4   82.4 

Customer, less allowance for doubtful accounts

   84.2    80.8  

Unbilled utility revenues

   92.5   86.2    82.3    86.7  

Other, less allowance for doubtful accounts of $- and $0.1

   75.9   14.5 

Other, less allowance for doubtful accounts

   38.1    45.7  

Income tax refunds receivable

   40.6    81.3  

Production fuel, at weighted average cost

   40.4   37.0    42.7    39.1  

Materials and supplies, at weighted average cost

   22.8   21.5    25.7    22.7  

Gas stored underground, at weighted average cost

   47.9   37.9    26.8    27.4  

Regulatory assets

   21.8   27.3    50.0    78.6  

Prepaid gross receipts tax

   37.8   36.7    38.6    38.5  

Derivative assets

   10.7   14.9    6.5    11.2  

Other

   34.0   24.5    9.4    30.3  
              

Total current assets

   445.0    560.8  
   471.7   383.3        
       

Investments:

      

Investment in American Transmission Company LLC

   195.1   172.2    227.9    218.6  

Other

   22.2   23.1    20.8    22.7  
              

Total investments

   248.7    241.3  
   217.3   195.3        
       

Other assets:

      

Regulatory assets

   378.6   196.9    292.1    331.3  

Deferred charges and other

   101.4   161.4    57.7    72.3  
              

Total other assets

   349.8    403.6  
   480.0   358.3        
       

Total assets

  $3,265.5  $2,788.6   $3,889.6   $3,681.4  
              

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

CONSOLIDATED BALANCE SHEETS (Continued)

 

  December 31,
  2008  2007
  (in millions, except per
share and share amounts)
  December 31, 

CAPITALIZATION AND LIABILITIES

      2010   2009 

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
  (in millions, except per 
  share and share amounts) 

Capitalization:

    

Wisconsin Power and Light Company common equity:

    

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

  $66.2    $66.2  

Additional paid-in capital

   668.9   568.8   844.0     768.9  

Retained earnings

   424.4   401.8   459.1     419.6  
              

Total common equity

   1,159.5   1,036.8
      

Total Wisconsin Power and Light Company common equity

   1,369.3     1,254.7  

Cumulative preferred stock

   60.0   60.0   60.0     60.0  

Long-term debt, net (excluding current portion)

   782.9   537.0   1,081.7     931.6  
              

Total capitalization

   2,511.0     2,246.3  
   2,002.4   1,633.8        
      

Current liabilities:

        

Current maturities of long-term debt

   —     60.0   —        100.0  

Commercial paper

   43.7   81.8   47.4     —     

Accounts payable

   130.9   109.6   118.5     99.6  

Accounts payable to associated companies

   26.1   38.3   16.0     15.7  

Regulatory liabilities

   17.9     32.5  

Accrued interest

   17.9   13.5   21.6     24.1  

Regulatory liabilities

   50.9   49.2

Derivative liabilities

   8.6   7.7   32.3     51.0  

Other

   26.4   20.9   38.9     39.5  
              

Total current liabilities

   292.6     362.4  
   304.5   381.0        
      

Other long-term liabilities and deferred credits:

        

Deferred income taxes

   329.3   269.9   570.4     490.8  

Regulatory liabilities

   174.1   173.9   154.3     159.6  

Capital lease obligations - Sheboygan Falls Energy Facility

   113.4   116.1   107.0     110.4  

Pension and other benefit obligations

   185.1   71.0   119.2     121.7  

Other

   156.7   142.9   135.1     190.2  
              

Total long-term liabilities and deferred credits

   1,086.0     1,072.7  
   958.6   773.8        
      

Commitments and contingencies (Note 12)

        

Total capitalization and liabilities

  $3,265.5  $2,788.6  $3,889.6    $3,681.4  
              

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

CONSOLIDATED STATEMENTS OF CASH FLOWS

 

  Year Ended December 31,   Year Ended December 31, 
  2008 2007 2006   2010 2009 2008 
  (in millions)   (in millions) 

Cash flows from operating activities:

        

Net income

  $118.4  $113.5  $105.3   $152.3   $89.5   $118.4  

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

        

Depreciation and amortization

   101.7   109.9   107.3    108.6    115.4    101.7  

Other amortizations

   38.4   38.7   33.5    39.5    35.2    38.4  

Deferred tax expense (benefit) and investment tax credits

   36.1   (6.9)  41.6 

Deferred tax expense and investment tax credits

   98.5    157.7    36.1  

Equity income from unconsolidated investments

   (33.9)  (28.4)  (27.0)   (37.8  (37.0  (33.9

Distributions from equity method investments

   27.8   21.7   23.2    32.2    29.9    27.8  

Other

   (6.6)  (1.6)  (1.4)

Equity component of allowance for funds used during construction

   (8.2  (4.0  (6.4

Non-cash valuation and regulated-related charges and other

   —      12.5    (0.2

Other changes in assets and liabilities:

        

Accounts receivable

   (68.7)  19.6   4.8    4.6    31.3    (68.7

Income tax refunds receivable

   40.7    (72.9  (5.8

Prepaid pension costs

   37.2   (24.2)  (11.1)   —      —      37.2  

Regulatory assets

   (192.3)  44.3   (39.7)   28.7    (54.2  (192.3

Accounts payable

   27.2   2.6   (17.6)   (0.4  (16.0  27.2  

Regulatory liabilities

   2.3   3.7   (58.1)   (9.1  (22.2  2.3  

Derivative liabilities

   7.1   (38.8)  26.0    (23.0  51.5    7.1  

Deferred income taxes

   (20.0  2.5    22.4  

Non-current taxes payable

   (38.5  36.2    (0.2

Pension and other benefit obligations

   112.3   0.4   (15.3)   (2.5  (63.4  112.3  

Other

   32.7   3.5   (8.9)   6.8    13.8    16.3  
                    

Net cash flows from operating activities

   239.7   258.0   162.6    372.4    305.8    239.7  
                    

Cash flows used for investing activities:

        

Utility construction and acquisition expenditures

   (363.1)  (203.1)  (162.5)

Proceeds from asset sales

   2.6   23.6   4.1 

Utility construction and acquisition expenditures:

    

Neenah Energy Facility and related assets

   —      (92.4  —    

Other

   (450.5  (416.0  (363.1

Advances for customer energy efficiency projects

   (34.5)  (44.9)  (36.7)   (16.0  (28.1  (34.5

Collections of advances for customer energy efficiency projects

   33.1   30.7   40.3    30.3    58.6    33.1  

Changes in restricted cash within nuclear decommissioning trusts

   —     —     23.5 

Other

   (14.1)  (13.3)  (17.7)   (13.1  (15.5  (11.5
                    

Net cash flows used for investing activities

   (376.0)  (207.0)  (149.0)   (449.3  (493.4  (376.0
                    

Cash flows from (used for) financing activities:

    

Cash flows from financing activities:

    

Common stock dividends

   (91.3)  (191.1)  (92.2)   (109.5  (91.0  (91.3

Preferred stock dividends

   (3.3)  (3.3)  (3.3)   (3.3  (3.3  (3.3

Capital contribution from parent

   100.0   —     42.6 

Capital contributions from parent

   75.0    100.0    100.0  

Proceeds from issuance of long-term debt

   250.0   300.0   39.1    150.0    250.0    250.0  

Reductions in long-term debt

   (60.0)  (105.0)  (39.1)

Payments to retire long-term debt

   (100.0  —      (60.0

Net change in short-term borrowings

   (38.1)  (53.1)  41.4    47.4    (43.7  (38.1

Other

   (16.9)  0.3   (0.5)   (1.1  (10.4  (16.9
                    

Net cash flows from (used for) financing activities

   140.4   (52.2)  (12.0)

Net cash flows from financing activities

   58.5    201.6    140.4  
          
          

Net increase (decrease) in cash and cash equivalents

   4.1   (1.2)  1.6    (18.4  14.0    4.1  
          

Cash and cash equivalents at beginning of period

   0.4   1.6   —      18.5    4.5    0.4  
                    

Cash and cash equivalents at end of period

  $4.5  $0.4  $1.6   $0.1   $18.5   $4.5  
                    

Supplemental cash flows information:

        

Cash paid during the period for:

    

Cash paid (refunded) during the period for:

    

Interest

  $57.6  $42.5  $48.7   $80.9   $69.6   $57.6  
                    

Income taxes, net of refunds

  $30.7  $62.5  $31.4   ($3.8 ($76.1 $30.7  
                    

Significant noncash investing and financing activities:

    

Accrued capital expenditures

  $27.4   $16.4   $19.8  
          

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

CONSOLIDATED STATEMENTS OF CAPITALIZATION

   December 31, 
   2008  2007 
   (dollars in millions, except
per share amounts)
 

Common equity (Refer to Consolidated Balance Sheets)

  $1,159.5  $1,036.8 
         

Cumulative preferred stock:

   

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

   

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

   10.0   10.0 

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

   7.5   7.5 

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

   6.5   6.5 

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

   3.0   3.0 

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

   3.0   3.0 

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

   15.0   15.0 

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

   15.0   15.0 
         
   60.0   60.0 
         

Long-term debt, net:

   

Debentures:

   

7.625%, due 2010

   100.0   100.0 

6.25%, due 2034

   100.0   100.0 

6.375%, due 2037

   300.0   300.0 

7.6%, due 2038

   250.0   —   

5.7%, matured in 2008

   —     60.0 
         
   750.0   560.0 

Pollution Control Revenue Bonds:

   

5%, due 2014 and 2015

   24.5   24.5 

5.375%, due 2015

   14.6   14.6 
         
   39.1   39.1 
         

Total, gross

   789.1   599.1 

Less:

   

Current maturities

   —     (60.0)

Unamortized debt discount, net

   (6.2)  (2.1)
         

Total long-term debt, net

   782.9   537.0 
         

Total capitalization

  $2,002.4  $1,633.8 
         

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

CONSOLIDATED STATEMENTS OF CHANGES IN COMMON EQUITY

 

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

2006:

        

Beginning balance (a)

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

Earnings available for common stock

       102.0    102.0 

Minimum pension liability adjustment, net of tax of $0.7

        0.8   0.8 
           

Total comprehensive income

         102.8 

Common stock dividends

       (92.2)   (92.2)

Capital contribution from parent

     42.6     42.6 

SFAS 158 transition adjustment, net of tax of ($4.2)
(Note 1(q))

        (5.2)  (5.2)

Other

     0.2     0.2 
                     

Ending balance

   66.2   568.6   483.5   (7.5)  1,110.8 

2007:

        

Earnings available for common stock

       110.2    110.2 

Pension and other postretirement benefits amortizations and reclassification to regulatory assets, net of tax of $5.7

        7.5   7.5 
           

Total comprehensive income

         117.7 

Common stock dividends

       (191.1)   (191.1)

Adoption of FIN 48 (Note 5)

       (0.8)   (0.8)

Other

     0.2     0.2 
                     

Ending balance

   66.2   568.8   401.8   —     1,036.8 

2008:

        

Earnings available for common stock and total comprehensive income

       115.1    115.1 

Common stock dividends

       (91.3)   (91.3)

Capital contribution from parent

     100.0     100.0 

SFAS 158 measurement date adjustment, net of tax of ($1.2) (Note 1(q))

       (1.2)   (1.2)

Other

     0.1     0.1 
                     

Ending balance

  $66.2  $668.9  $424.4  $—    $1,159.5 
                     

(a)Accumulated other comprehensive loss at Jan. 1, 2006 consisted entirely of minimum pension liability adjustments.
   Common
Stock
   Additional
Paid-In
Capital
   Retained
Earnings
  Total
WPL
Common
Equity
 
   (in millions) 

2008:

       

Beginning balance

  $66.2    $568.8    $401.8   $1,036.8  

Earnings available for common stock

       115.1    115.1  

Common stock dividends

       (91.3  (91.3

Capital contribution from parent

     100.0      100.0  

Adoption of new measurement date for retirement plans, net of tax of ($1.2) (Note 6(a))

       (1.2  (1.2

Other

     0.1      0.1  
                   

Ending balance

   66.2     668.9     424.4    1,159.5  

2009:

       

Earnings available for common stock

       86.2    86.2  

Common stock dividends

       (91.0  (91.0

Capital contribution from parent

     100.0      100.0  
                   

Ending balance

   66.2     768.9     419.6    1,254.7  

2010:

       

Earnings available for common stock

       149.0    149.0  

Common stock dividends

       (109.5  (109.5

Capital contribution from parent

     75.0      75.0  

Other

     0.1      0.1  
                   

Ending balance

  $66.2    $844.0    $459.1   $1,369.3  
                   

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

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

(1) SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES

(a) General -

Description of Business- The consolidated financial statements include the accounts of Wisconsin Power and Light Company (WPL) and its primary consolidated subsidiary, WPL Transco LLC.LLC, which holds WPL’s investment in the American Transmission Company LLC (ATC). WPL is a direct subsidiary of Alliant Energy Corporation (Alliant Energy) and is engaged principally in the generation and distribution of electric energy,electricity and the distribution and transportation of natural gas, and various other energy-related services.gas. WPL’s service territories are located in southsouthern and central Wisconsin.

Basis of Presentation- The consolidated financial statements reflect investments in controlled subsidiaries on a consolidated basis and WPL’s proportionate share of jointly owned utility facilities. Unconsolidated investments, which WPL does not control, but does have the ability to exercise significant influence over operating and financial policies, (generally, 20% to 50% voting interest), are accounted for under the equity method of accounting. Investments that do not meet the criteria for consolidation or the equity method of accounting are accounted for under the cost method. WPL did not reflect any variable interest entities on a consolidated basis in its consolidated financial statements. Refer to Notes 9(a) and 18 for further discussion of equity method investments and variable interest entities, respectively.

All significant intercompany balances and transactions have been eliminated from the consolidated financial statements. The consolidated financial statements are prepared in conformity with accounting principles generally accepted in the United States of America (U.S.) (GAAP), which give recognition to the rate making and accounting practices of the Federal Energy Regulatory Commission (FERC) and state commissions having regulatory jurisdiction.the Public Service Commission of Wisconsin (PSCW). Certain prior period amounts have been reclassified on a basis consistent with the current period financial statement presentation.

Use of Estimates- 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.

(b) Regulatory Assets and Liabilities -WPL is subject to regulation by FERC and the Public Service Commission of Wisconsin (PSCW).PSCW. As a result, WPL is subject to theGAAP provisions of Statement of Financial Accounting Standards (SFAS) 71, “Accounting for the Effects of Certain Types of Regulation,”regulated operations, which providesprovide 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 generally recognized in the Consolidated Statements of Income at the time they are reflected in rates.

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

 

   2008  2007

Pension and other postretirement benefits (Note 6(a))

  $266.8  $91.8

Costs for proposed base-load, clean air compliance and wind projects

   45.2   23.4

Asset retirement obligations (Note 17)

   13.4   12.6

Derivatives (Note 11(a))

   13.0   7.7

Tax-related (Note 1(c))

   10.6   10.9

Midwest Independent Transmission System Operator (MISO)-related

   10.0   11.1

Debt redemption costs (Note 1(p))

   8.2   8.6

Environmental-related (Note 12(e))

   8.1   8.4

Kewaunee Nuclear Power Plant (Kewaunee) sale

   4.1   9.5

Kewaunee outage in 2005

   —     10.6

Other

   21.0   29.6
        
  $400.4  $224.2
        
   2010   2009 

Pension and other postretirement benefits costs

  $201.5    $222.3  

Derivatives

   42.8     65.1  

Tax-related

   18.7     11.8  

Asset retirement obligations (AROs)

   16.4     14.7  

Benefits costs

   8.8     12.0  

Proposed base-load project costs

   8.4     12.7  

Proposed clean air compliance projects costs

   8.4     10.3  

Wholesale customer rate recovery

   7.9     6.5  

Debt redemption costs

   7.2     7.7  

Environmental-related costs

   6.3     6.5  

Midwest Independent Transmission System Operator (MISO)-related costs

   —       5.0  

Other

   15.7     35.3  
          
  $342.1    $409.9  
          

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 WPL. At Dec. 31, 2008,2010, WPL had $17$22 million of regulatory assets representing past expenditures that were not earning a return, consistingwhich consisted primarily of amounts related to wholesale customer rate recovery, debt redemption costs and the wholesale portion of costs for proposed base-load, clean air compliance and wind projects and debt redemption costs.projects. The recovery period for costs of proposed base-load, clean air compliance and wind projects will generally be determined by regulators in future rate proceedings. Debt redemption costs are recovered over the applicable lives of the debt. All other regulatory assets reported in the above table either earn a return or the cash has not yet been expended, in which case the assets are offset by liabilities that also do not incur a carrying cost.

CostsPension and other postretirement benefits -The PSCW has authorized WPL to record the retail portion of its previously unrecognized net actuarial gains and losses, prior service costs and credits, and transition assets and obligations as regulatory assets in lieu of accumulated other comprehensive loss on the Consolidated Balance Sheets. WPL also recognizes the wholesale portion of its previously unrecognized net actuarial gains and losses, prior service costs and credits and transition assets and obligations as regulatory assets on the Consolidated Balance Sheets because these costs are expected to be recovered in rates in future periods under the formula rate structure implemented in 2007. These regulatory assets will be increased or decreased as the net actuarial gains or losses, prior service costs or credits, and transition assets or obligations are subsequently amortized and recognized as a component of net periodic benefit costs.

Pension and other postretirement benefits costs are included within the recoverable cost of service component of rates charged to WPL’s customers. The recoverable costs included in customers’ rates are based upon pension and other postretirement benefits costs determined in accordance with GAAP and are calculated using different methods for the various regulatory jurisdictions in which WPL operates. The methods for WPL’s primary regulatory jurisdictions are described below. The PSCW authorized WPL in its most recent retail rate case order to recover from its electric and gas retail customers an allocated portion of annual costs equal to the estimated costs expected during its forward-looking test year (2010). WPL is authorized to recover from its wholesale customers an allocated portion of actual pension costs incurred each year. In accordance with FERC-approved formula rates, any over- or under-collection of these costs each year are refunded to or recovered from customers through subsequent changes to wholesale customer rates. WPL is authorized to recover from its wholesale customers an allocated portion of other postretirement benefits costs based on the amount of other postretirement benefits costs incurred in 2006.

Refer to Note 6(a) for additional details regarding WPL’s pension and other postretirement benefits costs.

Derivatives- In accordance with WPL’s fuel and natural gas recovery mechanisms, prudently incurred costs from derivative instruments are recovered from customers in the future when any losses are realized. Based on these recovery mechanisms, the changes in the fair value of derivative liabilities resulted in comparable changes to regulatory assets on the Consolidated Balance Sheets during 2010. Refer to Note 11(a) for additional details of WPL’s derivative liabilities.

AROs- WPL believes it is probable that any differences between expenses accrued for legal AROs related to its regulated operations and expenses recovered currently in rates will be recoverable in future rates, and is deferring the differences as regulatory assets. Refer to Note 17 for additional details of WPL’s AROs.

Benefits costs- In 2008, WPL received approval from the PSCW to defer the retail portion of pension and other benefit costs charged to other operation and maintenance expenses during 2009 in excess of $4 million. WPL’s retail portion of pension and other benefit costs expensed during 2009 were $16 million resulting in the recognition of a regulatory asset of $12 million in 2009 for the deferred portion of these costs. In December 2009, WPL received approval from the PSCW to recover the deferred costs over a five-year period ending December 2014.

Proposed Base-load, Clean Air Compliance and Wind Projectsbase-load project - NewIn 2008, the PSCW issued an order denying WPL’s application to construct a 300 MW coal-fired electric generating facilitiesfacility in Cassville, Wisconsin referred to as Nelson Dewey #3. Costs included in the above table reflect the remaining retail and Clear Air Compliance Programwholesale portions of costs related to this project.

Retail portion - In 2009, WPL received approval from the PSCW to recover $11 million of project costs from its retail customers over a five-year period ending December 2014. In 2009, the PSCW also denied WPL recovery of the remaining project costs, which represent all project costs incurred by WPL after June 2008 and one-half of the pre-construction project costs incurred by WPL prior to July 2008. As a result of this PSCW order, WPL recorded a pre-tax regulatory-related charge of $11 million in “Other operation and maintenance” in the Consolidated Statement of Income in 2009.

Wholesale portion - In 2009, WPL executed an agreement with its wholesale customers to recover $4 million of the wholesale portion of the capitalized expenditures for the Nelson Dewey #3 project that were incurred by WPL through December 2008. The agreement allowed WPL to recover the $4 million of capitalized expenditures from its wholesale customers over a 12-month period ending May 2010. As a result of this agreement, WPL recorded a pre-tax regulatory-related charge of $4 million in “Other operation and maintenance” in the Consolidated Statement of Income in 2008.

Proposed clean air compliance plan (CACP) projects -CACP projects require material expenditures for activities related to determining the feasibility of utilityenvironmental compliance projects under consideration. These expenditures commonly called

preliminary survey and investigation charges are generally recorded as “Regulatory assets”regulatory assets on the Consolidated Balance Sheets in accordance with FERC regulations. The retail portion of these amounts is expensed immediately unless otherwise authorized by the PSCW. However, since these amounts are material for WPL’s Cedar Ridge wind project, WPL’s proposed Nelson Dewey #3 generating unit and WPL’s CACP projects, WPL requested and received deferral accounting approval to record the retail portion of these costs as “Regulatory assets” on the Consolidated Balance Sheet. In the fourth quarter of 2008, the PSCW denied continuation of the Nelson Dewey #3 generating unit project. As a result, no material additional costs for this project are expected to be deferred.

In addition to the expenditures noted above, certain projects needing regulatory approval may also require that payments for long-lead materials be incurred prior to project approval in order to meet anticipated completion schedules. These expenditures have been identified as pre-construction expenditures by WPL. The retail portion of pre-construction expenditures for the projects described in the previous paragraph has also been approved for deferral as regulatory assets. All remaining pre-construction expenditures are recorded as “Regulatory assets”assets on the Consolidated Balance Sheets.

The wholesale portion of amounts deferred and recorded as preliminary survey and investigation charges do not include any accrual of carrying costs or allowance for funds used during construction (AFUDC). TheWPL’s retail portion of deferred preliminary survey and investigation charges (commonly referred to as pre-certification expenditures) and pre-constructionconstruction expenditures incurred prior to project approval that are recorded in regulatory assets include accrual of carrying costs as prescribed in the approved deferral order. Upon regulatory approval of the project, the wholesale portion of deferred preliminary survey and investigation charges as well as all pre-construction expenditures are transferred to construction work in progress (CWIP) and begin to accrue AFUDC. The retail portion of deferred preliminary survey and investigation charges or pre-certification expenditures remain as regulatory assets until they are approved for inclusion in revenue requirements and amortized to expense. In 2009, WPL believes amounts currentlyreceived approval from the PSCW to recover $4 million from its retail customers over a three-year period ending December 2012 for a portion of the pre-certification expenditures incurred through December 2008.

In May 2010, WPL received an order from the PSCW authorizing the installation of a selective catalytic reduction (SCR) system at the Edgewater Generating Station Unit 5 (Edgewater Unit 5) to reduce nitrogen oxide (NOx) emissions at the facility. Upon regulatory approval of the project, $4 million of project costs incurred to-date including all pre-construction expenditures and the wholesale portion of deferred as either preliminary survey and investigation expenditures or pre-construction expenditurescharges were transferred from “Regulatory assets” to “Construction work in progress” on the Consolidated Balance Sheets in 2010.

WPL anticipates that all remaining costs for proposed CACP projects are probable of recovery from customers through changes in future rates. WPL is currently recovering through retail rates the amounts for the Cedar Ridge wind project and a portion of the Nelson Dewey #3 pre-certification expenditures. Remaining deferred amounts for Nelson Dewey #3 and the CACP projects are expected to be included in rates charged to customers. The recovery period for these remaining costs will generally be determined by regulators in future rate proceedings.

Wholesale customer rate recovery- WPL accrues revenues from its wholesale customers to the extent that the actual net revenue requirements calculated in accordance with FERC-approved formula rates for the reporting period are higher than the amounts billed to wholesale customers during such period. In accordance with authoritative guidance, regulatory assets are recorded as the offset for these accrued revenues under formulaic rate making programs. WPL’s estimated recovery amount is recorded in the future.current period of service and subject to final adjustments after a customer audit period in the subsequent year. Final settled recovery amounts are reflected in WPL’s customer bills within two years under the provisions of approved formula rates.

At Dec. 31,In 2009, WPL filed a request with FERC seeking approval of changes to WPL’s wholesale formula rates in order to implement for billing purposes the cumulativefull impact of accounting for defined benefit postretirement plans. In July 2010, FERC approved a settlement agreement reached between WPL and the wholesale customers regarding the formula rate change. WPL recorded an additional $4 million of electric revenues and regulatory assets in 2010 to reflect the settlement and is reducing the regulatory asset concurrently with collections from customers.

Debt redemption costs -For debt retired early with no subsequent re-issuance, WPL defers any debt repayment premiums and unamortized debt issuance costs and discounts as regulatory assets. These regulatory assets are amortized over the remaining original life of the debt retired early. Debt repayment premiums and other losses resulting from the refinancing of debt are deferred as regulatory assets and amortized over the life of the new debt issued.

Environmental-related costs- Under the current rate making treatment approved by the PSCW, the manufactured gas plants (MGP) expenditures of WPL are deferred and collected from retail gas customers over a five-year period after new rates are implemented. Regulatory assets have been recorded by WPL, which reflect the probable future rate recovery of MGP expenditures. Refer to Note 12(e) for these projects were as follows (in millions):additional details of WPL’s environmental-related costs.

   2008  2007

Base-load project (a)

  $35.6  $17.3

Clean air compliance projects

   8.2   4.7

Wind projects

   1.4   1.4
        
  $45.2  $23.4
        

(a)MISO-related costs-In December 2008, the PSCW issued a written order denying WPL’s Nelson Dewey #3 application for approval to proceed with construction of a new facility at a preferred site adjacent to the existing Nelson Dewey Generating Facility in Cassville, Wisconsin. Costs included in the above table reflect the retail and wholesale portions of costs related to this project. The stipulated agreement related to WPL’s 2009/2010 retail rate case, which was approved by the PSCW in December 2008, included the recovery of $9 million of pre-certification costs that had been incurred through December 2007. These costs will be recovered from WPL’s retail customers over a two-year period ending December 2010. WPL will seek recovery of the remaining costs from its retail and wholesale customers in future rate case proceedings and recognized these remaining costs in “Regulatory assets” on the Consolidated Balance Sheet pending these future rate proceedings.

MISO-related - In August 2007, the PSCW issued an order requiring WPL to discontinue, effective Dec. 31, 2007, the deferral of the retail portion of certain costs incurred by WPL to participate in the MISO market. Beginning Jan. 1, 2008, these MISO costs are subject to recovery through WPL’s retail electric fuel-related cost recovery mechanism. At Dec. 31, 2008, WPL hadincurred $10 million of deferred retail costs incurred prior to 2008 to participate in the MISO market that were recognized in “Regulatory assets”regulatory assets on the Consolidated Balance Sheet.Sheets. In December 2008, WPL received approval from the PSCW as part of the stipulated agreement reached regarding the 2009/2010 retail rate case to recover the $10 million of deferred retail costs over a two-year period ending December 2010. MISO costs incurred after Dec. 31, 2007 are subject to recovery through WPL’s retail electric fuel-related cost recovery mechanism.

Kewaunee SaleOther- WPL received approval from the PSCW to defer the retail portion of any gains, losses, and transaction costs associated with the sale of Kewaunee. In 2005, WPL completed the sale of its interest in Kewaunee and incurred a loss (including transaction costs but excluding the benefits of the non-qualified decommissioning trust assets returned to customers) of $16 million from the sale. WPL expensed a portion of the loss and recognized a “Regulatory asset” for $9 million of the loss based on a PSCW order issued in December 2005 regarding the recovery of losses incurred by a co-owner of the Kewaunee facility. In 2006, WPL reached a settlement with its wholesale customers allowing recovery of $2 million of the loss. In January 2007, WPL received approval from the PSCW to recover $3 million of the loss from retail customers over a two-year period ending December 2008. In December 2008, WPL received approval from the PSCW to recover another $2 million of the loss from retail customers over a six-year period ending December 2014. WPL will seek recovery of the remaining $2 million loss from its retail customers in a future rate case.

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 Feb. 2005 to early July 2005. The PSCW also approved deferral of incremental operation and maintenance costs related to the unplanned outage. In January 2007, WPL received approval from the PSCW to recover $20 million of these costs over a two-year period ending December 2008.

Other - WPL periodically assesses whether its regulatory assets are probable of future recovery by considering factors such as applicable regulations, recent orders by the applicable regulatory environment changes, previous orders issuedagencies, historical treatment of similar costs by the applicable regulatory agencies and the status of any pending or potential deregulation legislation.regulatory environment changes. Based on these assessments, WPL recognizes an expense forbelieves the regulatory assets that are no longer determined to be probablerecognized as of future recoveryDec. 31, 2010 in the period of such determination. While WPL feels its remaining regulatory assetsabove table are probable of future recovery,recovery. However, no assurance can be made that WPL will recover all of these regulatory assets in future rates. If future recovery of a regulatory asset ceases to be probable, the regulatory asset will be charged to expense in the period in which future recovery ceases to be probable.

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

 

   2008  2007

Cost of removal obligations

  $150.6  $149.8

Fuel cost recovery (Note 1(h) and 2)

   38.2   16.9

Tax-related

   12.0   13.5

Derivatives (Note 11(a))

   8.9   14.9

Emission allowances (Note 15)

   7.3   8.1

Gas performance incentive (Notes 1(h))

   4.5   12.3

Other

   3.5   7.6
        
  $225.0  $223.1
        
       2010           2009     

Cost of removal obligations

  $137.8    $143.0  

Tax-related

   12.2     12.2  

Derivatives

   6.7     12.2  

Commodity cost recovery

   5.2     4.2  

Emission allowances

   0.5     6.2  

Other

   9.8     14.3  
          
  $172.2    $192.1  
          

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.

Cost of Removal Obligationsremoval obligations -WPL collects in rates future removal costs for many assets that do not have an associated legal asset retirement obligation.AROs. 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.

Derivatives- In accordance with WPL’s fuel and natural gas recovery mechanisms, gains from derivative instruments are refunded to customers in the future when any gains are realized. Based on these recovery mechanisms, the changes in the fair value of derivative assets resulted in comparable changes to regulatory liabilities on the Consolidated Balance Sheets during 2010. Refer to Note 11(a) for additional details of WPL’s derivative assets.

Commodity cost recovery -WPL’s wholesale electric rates and retail gas rates provide for subsequent adjustments to rates for changes in prudently incurred commodity costs used to serve customers. The cumulative under-/over-collection of these commodity costs are recorded as regulatory assets/regulatory liabilities until they are automatically reflected in future billings to customers. Refer to Note 1(h) for additional details of WPL’s cost recovery mechanisms. Refer to Note 2 for discussion of certain utility rate refund reserves recorded as regulatory liabilities on the Consolidated Balance Sheets.Sheets related to the commodity cost recovery mechanism used to determine WPL’s retail electric rates.

Emission allowances -WPL has entered into various transactions for the purchase and sale or non-monetary exchange of sulfur dioxide (SO2) and NOx emission allowances. The emission allowances acquired in these transactions were recorded as intangible assets. The value received from these transactions was recorded as regulatory liabilities given the emission allowances relinquished had a zero-cost basis. The amortization of these intangible assets and regulatory liabilities are equal and offsetting and based on the amount of the emission allowances acquired that were utilized each reporting period. Refer to Note 15 for additional details regarding WPL’s emission allowances.

(c) Income Taxes -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 income tax assets and liabilities, as appropriate, for temporary differences between the tax basis of assets and liabilities and the amounts reported in the consolidated financial statements. Deferred income taxes are recorded using currently enacted tax rates. 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. The PSCW has allowed rate recovery of deferred taxes on all temporary differences since August 1991.

WPL is also subject to the provisions of Financial Accounting Standards Board (FASB) Interpretation No. (FIN) 48, “Accounting for Uncertainty in Income Taxes.” FIN 48 establishes standards for measurement and recognition in financial statements of taxrecognizes positions taken, or expected to be taken, in income tax returns that are more-likely-than-not to be realized, assuming that the position will be examined by tax authorities with full knowledge of all relevant information. If it is more-likely-than-not that a tax return.position, or some portion thereof, will not be sustained, the related tax benefits are not recognized in the financial statements. For the majority of uncertain tax positions, the ultimate deductibility is highly certain, but there is uncertainty about the timing of such deductibility. Uncertain tax positions may result in an increase in income taxes payable,

a reduction of income tax refunds receivable or changes in deferred taxes. Also, when uncertainty about the deductibility of an amount is limited to the timing of such deductibility, the increase in taxes payable (or reduction in tax refunds receivable) is accompanied by a decrease in deferred tax liabilities. Generally WPL recognizes net interest and penaltiescurrent taxes payable related to unrecognizeduncertain tax benefitspositions in “Income“Accrued taxes” and non-current taxes payable related to uncertain tax positions in “Other long-term liabilities and deferred credits” on the Consolidated StatementsBalance Sheets. However, if the uncertain tax position would be settled through the reduction of Income.a net operating loss rather than through the payment of cash, the uncertain tax position is reflected in “Deferred income taxes” on the Consolidated Balance Sheets. Refer to Note 5 for further discussion of WPL’s adoptionuncertain tax positions.

WPL defers investment tax credits and amortizes the credits to income over the average lives of FIN 48.the related property. Other tax credits for WPL reduce income tax expense in the year claimed.

WPL has elected the alternative transition method described in FASB Staff Position (FSP) 123(R)-3, “Transition Election Related to Accounting for the Tax Effects of Share-Based Payment Awards,” to calculate its beginning pool of excess tax benefits available to absorb any tax deficiencies associated with recognition of share-based payment awards recognized in accordance with SFAS 123(R), “Share-Based Payment.”awards.

(d) Cash and Cash Equivalents -Cash and cash equivalents include short-term liquid investments that have original maturities of less than 90 days.

(e) Utility Property, Plant and Equipment -

General - Plant in service is recorded at the original cost of acquisition or construction, which includes material, labor, contractor services, AFUDC and allocable overheads, such as supervision, engineering, benefits, certain taxes and transportation. Repairs, replacements and renewals of items of property determined to be less than a unit of property or that do not increase the property’s life or functionality are charged to maintenance expense. Ordinary retirements of plant in service and salvage value are netted and charged to accumulated depreciation upon removal from plant in service accounts and no gain or loss is recognized. Removal costs incurred are charged to areduce the regulatory liability.

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

 

  2008  2007  2010   2009 

Distribution

  $1,402.2  $1,297.4  $1,621.5    $1,529.0  

Generation (a)

   1,043.7   882.2   1,431.2     1,138.9  

Other

   54.4   34.8   61.9     58.6  
              
  $2,500.3  $2,214.4  $3,114.6    $2,726.5  
              

The increase in WPL’s generation portion of electric plant in service during 2010 was primarily due to the impact of placing a portion of the Bent Tree - Phase I wind project into service in 2010.

(a)The increase during 2008 was largely due to $156 million, including AFUDC, of plant placed in service in the fourth quarter of 2008 for WPL’s Cedar Ridge wind project.

Wind Generation Projects -

Bent Tree Wind Site - In 2009, WPL acquired approximately 400 megawatts (MW) of wind site capacity in Freeborn County, Minnesota, referred to as the Bent Tree wind site. The initial 200 MW of the wind site was utilized to construct the Bent Tree - Phase I wind project, which began generating electricity in 2010. Future development of the balance of the wind site will depend on numerous factors such as renewable portfolio standards, availability of wind turbines and transmission capabilities. As of Dec. 31, 2010, WPL’s capitalized costs related to the remaining approximately 200 MW of wind site capacity at Bent Tree were $13 million and were recorded in “Other property, plant and equipment” on the Consolidated Balance Sheet.

Bent Tree - Phase I Wind Project - In 2009, WPL received approval from the Minnesota Public Utilities Commission and PSCW to construct the initial 200 MW of the wind project. As of Dec. 31, 2010, WPL incurred capitalized expenditures of $406 million and recognized $13 million of AFUDC related to the 200 MW wind project. WPL placed a portion of the project into service in 2010, which resulted in a transfer of $265 million of capitalized project costs from “Construction work in progress - Bent Tree - Phase I wind project” to “Electric plant in service” on the Consolidated Balance Sheets in 2010. These capitalized costs for the project are being depreciated using a straight-line method of depreciation over a 30-year period. The remainder of the capitalized expenditures and AFUDC are recorded in “Construction work in progress - Bent Tree - Phase I wind project” on the Consolidated Balance Sheets at Dec. 31, 2010 and 2009. Refer to Note 17 for discussion of AROs recorded by WPL in 2010 related to its Bent Tree - Phase I wind project.

Green Lake and Fond du Lac Counties Wind Site - In 2009, WPL purchased development rights to an approximately 100 MW wind site in Green Lake and Fond du Lac Counties in Wisconsin. As of Dec. 31, 2010, WPL’s capitalized costs related to this wind project were $5 million and were recorded in “Other property, plant and equipment” on the Consolidated Balance Sheet.

Wind Turbine Generators - In 2008, Alliant Energy entered into a master supply agreement with Vestas-American Wind Technology, Inc. (Vestas) to purchase 500 MW of wind turbine generator sets and related equipment. Alliant Energy utilized 400 MW of these wind turbine generator sets and related equipment to construct IPL’s Whispering Willow - East wind project and WPL’s Bent Tree - Phase I wind project. Alliant Energy believes the Whispering Willow wind site in Iowa is the best location to deploy the remaining 100 MW of wind turbine generator sets and related equipment and is currently evaluating which of its subsidiaries will construct the 100 MW wind project. Refer to Note 12(a) for WPL’s remaining future obligations under the master supply agreement with Vestas.

Environmental Compliance Plans Projects -

Edgewater Unit 5 Emission Controls - In 2010, WPL began construction on the installation of an SCR system at Edgewater Unit 5 to reduce NOx emissions at the generating facility. As of Dec. 31, 2010, WPL recorded $17 million of capitalized expenditures related to this project in “Construction work in progress - other” on the Consolidated Balance Sheet.

Depreciation - WPL uses a combination of remaining life and straight-line depreciation methods as approved by the PSCW. The composite or group method of depreciation is used, in which a single depreciation rate is applied to the gross investment in a particular class of property. This method pools similar assets and then depreciates each group as a whole. Periodic depreciation studies are performed to determine the appropriate group lives, net salvage and group deprecationdepreciation rates. These depreciation studies are subject to review and approval by the PSCW. Depreciation expense is included within the recoverable cost of service component of rates charged to customers. The average rates of depreciation for electric, gas and gasother properties, consistent with current rate making practices, were as follows:

 

   2008(a)  2007  2006 

Electric

  3.2% 3.5% 3.5%

Gas

  3.1% 3.6% 3.7%

(a)Effective July 1, 2008, WPL implemented updated depreciation rates as a result of a new depreciation study. These updated depreciation rates increased WPL’s earnings available for common stock in 2008 as compared to 2007 by approximately $5.3 million.
       2010          2009          2008     

Electric:

    

Generation

   2.9  3.2  3.0

Distribution

   2.6  3.0  3.1

Gas

   2.2  2.8  3.1

Other

   6.5  6.4  5.4

AFUDC - AFUDC represents costs to finance construction additions including a return on equity component and cost of debt component as required by regulatory accounting. The concurrent credit for the amount of AFUDC capitalized is recorded as “Allowance for funds used during construction” in the Consolidated Statements of Income. The amount of AFUDC generated by equity and debt components was as follows (in millions):

 

   2008  2007  2006

Equity

  $6.4  $1.5  $2.0

Debt

   3.2   1.1   0.6
            
  $9.6  $2.6  $2.6
            

       2010           2009           2008     

Equity

  $8.2    $4.0    $6.4  

Debt

   4.3     1.7     3.2  
               
  $12.5    $5.7    $9.6  
               

The increaseWPL recognized $10 million and $3 million of AFUDC in 2010 and 2009, respectively, for its Bent Tree - Phase I wind project, a portion of which was placed in service in 2010. WPL recognized $6 million of AFUDC in 2008 was largely due to construction of WPL’sfor its Cedar Ridge wind project.project, which was placed in service in 2008.

AFUDC for WPL’s retail and wholesale jurisdiction construction projects is calculated in accordance with PSCW and FERC guidelines, respectively. The AFUDC recovery rates, computed in accordance with the prescribed regulatory formula, were as follows:

 

  2008 2007 2006       2010         2009         2008     

PSCW formula - retail jurisdiction(a)

  9.0% 9.0% 15.1%   8.8  9.0  9.0

FERC formula - wholesale jurisdiction

  6.8% 5.5% 5.0%   7.2  6.7  6.8

(a)Consistent with the PSCW’s retail rate case order issued in December 2009, WPL earned a current return on 50% of the estimated CWIP related to its Bent Tree - Phase I wind project for 2010 and accrued AFUDC on the remaining 50% in 2010. In addition, the PSCW’s order changed WPL’s AFUDC recovery rate to 8.8% from 9.0% effective Jan. 1, 2010.

(f) Other Property, Plant and Equipment- Other property, plant and equipment is recorded at the original cost of acquisition or construction, which includes material, labor and contractor services. Repairs, replacements and renewals of items of property determined to be less than a unit of property or that do not increase the property’s life or functionality are charged to maintenance expense. The majority of other property is depreciated using the straight-line method over periods ranging from five to 15 years. Upon retirement or sale of other property, plant and equipment, the original cost and related accumulated depreciation are removed from the accounts and any gain or loss is included in the Consolidated Statements of Income. Refer to Note 1(e) for discussion of wind site costs recorded in “Other property, plant and equipment” on the Consolidated Balance Sheets.

(g) Operating Revenues -

General - Revenues are primarily from electricelectricity and natural gas sales and are recognized on an accrual basis as services are rendered or commodities are delivered to customers. WPL recognizes unbilled revenuesEnergy sales to individual customers are based on estimated amountsthe reading of electricity and natural gascustomers’ meters, which occurs on a systematic basis throughout each reporting period. Amounts of energy delivered but not yet billed to customers since the date of the last meter reading are estimated at the end of each reporting period.period and the corresponding estimated unbilled revenue is recorded. The unbilled revenue estimate is based on daily system demand volumes, estimated customer usage by class, weather impacts, line losses and the most recent customer rates.

WPL participates in a bid-basedbid/offer-based wholesale energy marketand ancillary services markets operated by MISO. The marketWPL’s customers and generating resources are located in the MISO region. MISO requires that all market participants,load serving entities and generation owners, including WPL, submit hourly day-ahead and/or real-time bids and offers for energy at locations across theand ancillary services. The MISO region. The day-ahead and real-time transactions are grouped together, resulting in a net supply to or net purchase from MISO of megawatt-hours (MWhs) for each hour of each day. The net supply to MISO is recorded in “Electric operating revenues” and the net purchase from MISO is recorded in “Electric production fuel and purchased power”energy purchases” in the Consolidated Statements of Income. WPL also periodically engages in related transactions in PJM Interconnection, LLC’s bid/offer-based wholesale energy market, which are accounted for similar to the MISO transactions.

Taxes Collected from Customers- WPL serves as a collection agent for sales or various other taxes and recordsrecord revenues on a net basis. Operating revenues do not include the collection of the aforementioned taxes.

(h) Utility Fuel Cost Recovery Mechanisms -

Electric Production Fuel and Energy Purchases-WPL burns coal and other fossil fuels to produce electricity at its generating facilities to meet the demand of its customers and charges the cost of fossil fuels used during each period to “Electric production fuel and energy purchases” in the Consolidated Statements of Income. WPL also purchases electricity to meet the demand of its customers and charges the costs to purchase the electricity during each period to “Electric production fuel and energy purchases” in the Consolidated Statements of Income.

The cost recovery mechanisms applicable for WPL’s wholesale electric customers provide for subsequent adjustments to its electric rates for changes in electric production fuel and purchased energy expenses (fuel-related costs). Changes in the under-/over-collection of these costs each period are also recognized in “Electric production fuel and energy purchases” in the Consolidated Statements of Income. The cumulative effects of the under-/over-collection of these costs are recorded in current “Regulatory assets” or current “Regulatory liabilities” on the Consolidated Balance Sheets until they are reflected in future billings to customers.

The cost recovery mechanism applicable for WPL’s retail electric customers was changed effective Jan. 1, 2011. For periods prior to Jan. 1, 2011, WPL’s retail electric rates approved by the PSCW arewere based on forecasts of forward-looking test periods and includeincluded estimates of future fuel and purchased energyfuel-related costs anticipated during the test period. During each electric retail rate proceeding, the PSCW setsset fuel monitoring ranges based on the forecasted fuelfuel-related costs used to determine retail base rates. If WPL’s actual fuelfuel-related costs fallfell outside these fuel monitoring ranges during the test period, WPL and/or other parties cancould request, and the PSCW cancould authorize, an adjustment to future retail electric rates based on changes in fuelfuel-related costs only. The PSCW may authorizealso could have authorized an interim retail rate increase; however,increase. However, if the final retail rate increase iswas less than the monitoring range threshold required to be met in order to request interim retail rate increase, WPL mustrelief, all interim rates collected would be subject to refund the excess collection to WPL’s retail customers with interest at the current authorized return on common equity rate. RecoveryIn addition, if the final retail rate increase was less than the interim retail rate increase, WPL must refund any excess collections above the final rate increase to its retail customers with interest at the current authorized return on common equity rate.

For periods after Dec. 31, 2010, the cost recovery mechanism applicable for WPL’s retail electric customers will continue to be based on forecasts of capacity-related charges associated withfuel-related costs expected to be incurred during forward-looking test year periods and fuel monitoring ranges determined by the PSCW during each electric retail rate proceeding or in a separate fuel cost plan approval

proceeding. However, under the new cost recovery mechanism if WPL’s actual fuel-related costs fall outside these fuel monitoring ranges during the test period, WPL is authorized to defer the incremental over- or under-collection of fuel costs that are outside the approved ranges. Such deferred amounts will be recognized in “Electric production fuel and energy purchases” in the Consolidated Statements of Income each period. The cumulative effects of these deferred amounts will be recorded in current “Regulatory assets” or current “Regulatory liabilities” on the Consolidated Balance Sheets until they are reflected in future billings to customers.

Purchased Electric Capacity - WPL enters into purchased power costs and transmission service costsagreements (PPAs) to help meet the electricity demand of its customers. Certain of these PPAs include minimum payments for WPL’s rights to electric generating capacity, which are charged each period to “Purchased electric capacity” in the Consolidated Statements of Income. Purchased electric capacity expenses are recovered from WPL’s retail electric customers through changes in retail base rates.rates determined during periodic rate proceedings. Purchased electric capacity expenses are recovered from WPL’s wholesale electric customers through annual changes in base rates determined by a formula rate structure.

Electric Transmission Service -WPL incurs costs for the transmission of electricity to its customers and charges these costs each period to “Electric transmission service” in the Consolidated Statements of Income. Electric transmission service expenses are recovered from WPL’s retail electric customers through changes in base rates determined during periodic rate proceedings. Electric transmission service expenses are recovered from WPL’s wholesale electric customers through annual changes in base rates determined by a formula rate structure.

Cost of Gas Sold - WPL incurs costs for the purchase, transportation and storage of natural gas to serve its gas customers and charges the costs associated with the natural gas delivered to customers during each period to “Cost of gas sold” in the Consolidated Statements of Income. The tariffs for WPL’s retail gas customers provide for subsequent adjustments to its rates for changes in the cost of fuel and purchased energy.

WPL’s retail gas tariffs provide for subsequent adjustments to its natural gas rates for changessold. Changes in the current monthly natural gas commodity price index. During 2006, WPL had a gas performance incentive which included a sharing mechanism whereby 50%under-/over-collection of gains or losses relative to current commodity prices and benchmarks were retained by WPL, with the remainder refunded to or recovered from customers. Startingthese costs are also recognized in 2007, the program was modified by the PSCW such that 35% of all gains and losses from WPL’s gas performance incentive sharing mechanism were retained by WPL, with 65% refunded to or recovered from customers. In October 2007, the PSCW issued an order providing WPL the option to choose to utilize a modified gas performance incentive sharing mechanism or switch to a modified one-for-one pass through“Cost of gas costs to retail customers using benchmarks. WPL evaluated the alternatives and chose to implement the modified one-for-one pass through of gas costs. This change was effective Nov. 1, 2007. WPL’s gas performance incentive sharing mechanism resulted in gains recorded as “Gas operating revenues”sold” in the Consolidated Statements of IncomeIncome. The cumulative effects of $5 millionthe under-/over-collection of these costs are recorded in current “Regulatory assets” or current “Regulatory liabilities” on the Consolidated Balance Sheets until they are reflected in future billings to customers.

Energy Efficiency Costs -WPL incurs costs to fund energy efficiency programs and $13 millioninitiatives that help customers reduce their energy usage and charges these costs incurred each period to “Other operation and maintenance” in 2007the Consolidated Statements of Income. Energy efficiency costs incurred by WPL are recovered from retail electric and 2006, respectively.gas customers through changes in base rates determined during periodic rate proceedings and include a reconciliation to eliminate any over-/under-collection of energy efficiency costs from prior periods. Changes in the under-/over-collection of energy efficiency costs each period are recognized in “Other operation and maintenance” in the Consolidated Statements of Income. The cumulative effects of the under-/over-collection of these costs are recorded in current “Regulatory assets” or current “Regulatory liabilities” on the Consolidated Balance Sheets until they are reflected in future billings to customers.

Refer to NoteNotes 1(b) and 2 for additional information regarding fuelthese utility cost recovery.recovery mechanisms.

(i) Financial Instruments -WPL periodically uses financial instruments for risk management purposes to hedgemitigate exposures to fluctuations in certain commodity prices, volatility in a portion of electric and natural gas sales volumes due to weather, transmission congestion costs and currency exchange rates. The fair value of allthose financial instruments that are determined to be derivatives are recorded as assets or liabilities on the Consolidated Balance Sheets. Gains and losses related to derivatives thatDerivative instruments representing unrealized gain positions are designated and qualify as cash flow 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. WPL does not offset fair value amounts recognized for the right to reclaim cash collateral (receivable) or the obligation to return cash collateral (payable) against fair value amounts recognized for derivatives executed with the same counterparty under the same master netting arrangement.

Based on the fuel and natural gas cost recovery mechanisms in place, as well as other specific regulatory authorizations, changes in fair values of WPL’s derivatives generally have no impact on its results of operations, as they are generally reported as changes in regulatoryderivative assets, and liabilities.derivative instruments representing unrealized loss positions are reported as derivative liabilities at the end of each reporting period. WPL also has somecertain commodity purchase and sales contracts that have been designated, and qualify for, the normal purchase and sale exception and based on this designation, these contracts are accounted for on the accrual basis of accounting. WPL does not offset fair value amounts recognized for the right to reclaim cash collateral (receivable) or the obligation to return cash collateral (payable) against fair value amounts recognized for derivative instruments executed with the same counterparty under the same master netting arrangement. Refer to Note 1(b) for discussion of the recognition of regulatory assets and regulatory liabilities related to the unrealized losses and unrealized gains on WPL’s derivative instruments. Refer to Notes 11 and 12(f) for further discussion of WPL’s derivatives and related credit risk, respectively.

(j) Pension and Other Postretirement Benefits Plans -For the defined benefit pension and other postretirement benefits plans sponsored by Alliant Energy Corporate Services, Inc. (Corporate Services), Alliant Energy allocates costs to WPL based on labor costs of plan participants.

(k) Asset ValuationsImpairments -

Property, Plant and Equipment of Regulated Operations -Long-livedProperty, plant and equipment of regulated operations are reviewed for possible impairment whenever events or changes in circumstances indicate all or a portion of the carrying value of the assets may be disallowed for rate-making purposes. If WPL is diasallowed recovery of any portion of the carrying value of its regulated property, plant and equipment, an impairment charge is recognized equal to be heldthe amount of the carrying value that was disallowed. If WPL is disallowed a full or partial return on the carrying value of its regulated property, plant and used, excluding regulatoryequipment, an impairment charge is recognized equal to the difference between the carrying value and the present value of the future revenues expected from its regulated property, plant and equipment.

Property, Plant and Equipment of Non-regulated Operations and Intangible Assets -Property, plant and equipment of non-regulated operations and intangible 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. Refer to Note 1(b)15 for additional discussion of long-lived assets classified as regulatoryintangible assets.

Unconsolidated Equity Investments -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 fair value of these investments to their carrying values as well as assessing if a decline in fair value is temporary. If an impairment is indicated, a charge is recognized equal to the amount the carrying value exceeds the investment’s fair value. Refer to Note 9(a) for additional discussion of investments accounted for under the equity method of accounting.

(l) Operating Leases - - WPL has certain purchased power agreements (PPAs)PPAs that provide it exclusive rights to all or a substantial portion of the output from the specific generating facility over the contract term and therefore are accounted for as operating leases. Costs associated with these PPAs are included in “Electric production fuel and purchased power”energy purchases” and “Purchased electric capacity” in the Consolidated Statements of Income based on monthly payments for these PPAs. Monthly capacity payments related to one of these PPAs 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 expected market pricing trends and the expected usage of energy from the facility.

(m) Emission Allowances - - Emission allowances are granted by the U.S. Environmental Protection Agency (EPA) at zero cost and permit the holder of the allowances to sourcesemit certain gaseous by-products of pollution that allow the release of a prescribed amount of pollution each year.fossil fuel combustion, including SO2 and NOx. Unused emission allowances may be bought and sold or carried forward to be utilized in future years. Purchased emission allowances are recorded as intangible assets at their original cost and evaluated for impairment as long-lived assets to be held and usedused. Emission allowances allocated to or acquired by WPL are held primarily for consumption. Amortization of emission allowances is based upon a weighted average cost for each category of vintage year utilized during the reporting period and is recorded in accordance with SFAS 144, “Accounting for“Electric production fuel and energy purchases” in the Impairment or DisposalConsolidated Statements of Long-lived Assets.”Income. Cash inflows and outflows related to sales and purchases of emission allowances are recorded as investing activities in the Consolidated Statements of Cash Flows. Emission allowances granted by the EPA 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. Refer to Note 15 for additional discussion of emission allowances and Note 1(b) for information regarding regulatory liabilities related to emission allowances.

(n) Electric Transmission Service Expenses Presentation - WPL reports electric transmission service expenses billed from third parties in “Electric transmission service” on the Consolidated Statements of Income.

(o) Asset Retirement ObligationsAROs -The presentfair value of any retirement costs associated with an asset for which WPL has a legal obligation is recorded as a liability with an equivalent amount added to the asset cost when an asset is placed in service.service or when sufficient information becomes available to determine a reasonable estimate of the fair value of future retirement costs. The fair value of AROs is generally determined using discounted cash flow analyses. The liability is accreted to its present value each period and the capitalized cost is depreciated over the useful life of the related asset. For WPL, accretion and depreciation expense related to its regulated operations is recorded to regulatory assets on the Consolidated Balance Sheets. Upon settlement of the liability, an entity settles the obligation for its recorded amount or incurs a gain or loss. For WPL, any gain or loss related to its regulated operations is recorded to regulatory liabilities or regulatory assets on the Consolidated Balance Sheet.Sheets. Refer to Note 17 for additional discussion of asset retirement obligations.AROs.

(p)(o) Debt Issuance and Retirement Costs -WPL defers and amortizes debt issuance costs and debt premiums or discounts over the expected lives of the respective debt issues, considering maturity dates and, if applicable, redemption rights held by others. ForRefer to Note 8(b) for details on long-term debt and Note 1(b) for information on regulatory assets related to debt retired early with no subsequent re-issuance,or refinanced.

(p) Allowance for Doubtful Accounts- WPL defers any unamortized debt issuance costs, premiums or discounts as regulatory assets or regulatory liabilities, which are amortized over the remaining original life of the debt retired early. Gains ormaintains allowances for doubtful accounts for estimated losses resulting from the refinancinginability of debt byits customers to make required payments. WPL are deferredestimates the allowance for doubtful accounts based on historical write-offs, customer arrears and other economic factors within its service territory. Allowance for doubtful accounts at Dec. 31 was as regulatory liabilities or regulatory assetsfollows (in millions):

       2010           2009     

Customer

  $1.4    $1.6  

Other

   0.3     0.4  
          
  $1.7    $2.0  
          

(q) Comprehensive Income -In 2010, 2009 and amortized over the life of the new debt issued.2008, WPL had no other comprehensive income; therefore its comprehensive income was equal to its earnings available for common stock for such periods.

(q)(r) New Accounting Pronouncements -

FSP SFAS 132(R)-1, “Employers’ Disclosures about Postretirement Benefit Plan Assets”Variable Interest Entities (VIEs)

In December 2008,2009, the FASBFinancial Accounting Standards Board (FASB) issued FSP SFAS 132(R)-1, which amends SFAS 132(R), “Employers’ Disclosures about Pensionsauthoritative guidance changing the approach to determine a VIE’s primary beneficiary and Other Postretirement Benefits,” to providerequiring ongoing assessments of whether an enterprise is the primary beneficiary of a VIE. This guidance also requires additional disclosures about plan assets of a defined benefit pension or other postretirement plan. Disclosures include investment policiescompany’s involvement with VIEs and strategies, categories of plan assets, fair value of plan assets andany significant concentrations of risk.changes in risk exposure due to that involvement. WPL is required to adopt FSP SFAS 132(R)-1 by Dec. 31, 2009. FSP SFAS 132(R)-1 is not expected to have anyadopted this guidance on Jan. 1, 2010 with no material impact on its financial condition and results of operations. Refer to Note 18 for disclosures about VIEs.

FSP SFAS 140-4 and FIN 46(R)-8, “Disclosures by Public Entities (Enterprises) about Transfers of Financial Assets and Interests in Variable Interest Entities”

In December 2008,2009, the FASB issued FSP SFAS 140-4 and FIN 46(R)-8, which amends SFAS 140, “Accounting for Transfers and Servicing of Financial Assets and Extinguishments of Liabilities,” to require public entities to provideauthoritative guidance requiring additional disclosures about transfers of financial assets. It also amends FIN 46(R), “Consolidation of Variable Interest Entities,” to require additional disclosures about variable interest entities. WPL adopted FSP SFAS 140-4assets, including securitization transactions, and FIN 46(R)-8 on Dec. 31, 2008. FSP SFAS 140-4 and FIN 46(R)-8 did notwhere companies have any impact on its financial condition and results of operations.

Emerging Issues Task Force (EITF) Issue 08-6, “Equity Method Investment Accounting Considerations”

In November 2008, the FASB issued EITF Issue 08-6, which considered the effects of the issuances of SFAS 141(R) and SFAS 160 on an entity’s application of the equity method under Accounting Principles Board Opinion 18, “The Equity Method of Accounting for Investments in Common Stock.” EITF Issue 08-6 addresses questions that have arisen regarding the application of equity method accounting guidance because of the significant changescontinuing exposure to the guidance on business combinations and subsidiary equity transactions and the increased use of fair value measurements as a result of these pronouncements. WPL is required to adopt EITF Issue 08-6 beginning with transactions occurring in 2009. Because the provisions of EITF Issue 08-6 are only applied prospectively to transactions after adoption, the impact to WPL cannot be determined until any such transactions occur.

SFAS 162, “The Hierarchy of Generally Accepted Accounting Principles”

In May 2008, the FASB issued SFAS 162, which identifies the sources of accounting principles and the framework for selecting the principles used in the preparation of financial statements of nongovernmental entities that are presented in conformity with GAAP. WPL adopted SFAS 162 in November 2008 with no impact on its financial condition or results of operations.

FSP SFAS 142-3, “Determination of the Useful Life of Intangible Assets”

In April 2008, the FASB issued FSP SFAS 142-3, which amends the factors that should be considered in developing renewal or extension assumptions used in determining the useful life of recognized intangible assets under SFAS 142, “Goodwill and Other Intangible Assets,” and requires expanded disclosuresrisks related to intangibletransferred financial assets. This guidance also eliminates the concept of a “qualifying special-purpose entity” and changes the requirements for derecognizing financial assets. WPL adopted FSP SFAS 142-3this guidance on Jan. 1, 2009 with no material impact on its financial condition or results of operations.

SFAS 161, “Disclosures about Derivative Instruments and Hedging Activities - an amendment of FASB Statement No. 133”

In March 2008, the FASB issued SFAS 161, which requires enhanced qualitative and quantitative disclosures about an entity’s derivative and hedging activities. WPL adopted SFAS 161 on Jan. 1, 2009 with no impact on its financial condition or results of operations.

SFAS 141(R), “Business Combinations”

In December 2007, the FASB issued SFAS 141(R), which establishes principles and requirements for how the acquiring entity in a business combination: recognizes and measures in its financial statements the identifiable assets acquired, the liabilities assumed, and any noncontrolling interest in the acquiree; recognizes and measures the goodwill acquired in the business combination or a gain from a bargain purchase; and determines what information to disclose to enable users of the financial statements to evaluate the nature and financial effects of the business combination. WPL adopted SFAS 141(R) on Jan. 1, 2009. Because the provisions of SFAS 141(R) are only applied prospectively to business combinations after adoption, the impact to WPL cannot be determined until any business combinations occur.

SFAS 160, “Noncontrolling Interests in Consolidated Financial Statements - an amendment of ARB No. 51”

In December 2007, the FASB issued SFAS 160, which amends accounting and reporting standards for the noncontrolling interest in a subsidiary and for the deconsolidation of a subsidiary. SFAS 160 also clarifies that a noncontrolling interest in a subsidiary is an ownership interest in the consolidated entity that should be reported as equity in the consolidated financial statements. SFAS 160 also changes the way the consolidated income statement is presented, establishes a single method of accounting for changes in a parent’s ownership interest in a subsidiary that do not result in deconsolidation, requires that a parent recognize a gain or loss in net income when a subsidiary is deconsolidated and requires expanded disclosures in the consolidated financial statements that clearly identify and distinguish between the interests of the parent’s owners and the interests of the noncontrolling owners of a subsidiary. WPL adopted SFAS 160 on Jan. 1, 2009 with no impact on its financial condition and results of operations.

FSP FIN 39-1, “Amendment of FIN 39, Offsetting of Amounts Related to Certain Contracts”

In April 2007, the FASB issued FSP FIN 39-1, which amends FIN 39 to permit the offsetting of amounts recognized for the right to reclaim cash collateral or the obligation to return cash collateral against amounts recognized for derivative instruments executed with the same counterparty under the same master netting arrangement that have been offset. WPL adopted FSP FIN 39-1 on Jan. 1, 20082010 with no material impact on its financial condition and results of operations.

(2) UTILITY RATE CASES

SFAS 159, “The Fair Value OptionRetail Electric Rate Case (2011 Test Year) -In April 2010, WPL filed a request with the PSCW to reopen the rate order for Financial Assetsits 2010 test year to increase annual retail electric rates for 2011 by $35 million, or approximately 4%. The request was based on a forward-looking test period that included 2011. The key drivers for the filing include recovery of investments in WPL’s Bent Tree - Phase I wind project and Financial Liabilities - Including an amendment of FASB Statement No. 115”expiring deferral credits, partially offset by lower variable fuel expenses.

In February 2007,August 2010, WPL revised its request for an annual retail electric rate increase to $19 million, or approximately 2%. The primary differences between WPL’s original request in April 2010 and its revised request filed in August 2010 relates to reduced variable fuel expenses, increased wind generation production tax credits and the FASB issued SFAS 159,impact of the $9 million annual rate increase implemented in June 2010 with the interim order in WPL’s 2010 test year retail fuel-related rate filing, which provided companies withis discussed below.

In December 2010, WPL received an option to report selected financial assets and liabilities at fair value and establishes presentation and disclosure requirements designed to facilitate comparisons between companies that choose different measurement attributes for similar typesorder from the PSCW authorizing an annual retail electric rate increase of assets and liabilities. WPL concluded as of$8 million, or approximately 1%, effective Jan. 1, 2008 that it would not record any eligible items at fair value2011. This $8 million increase in accordance with SFAS 159 and therefore there was no impact on its financial condition and results of operations.

SFAS 157, “Fair Value Measurements”

In September 2006, the FASB issued SFAS 157, which defines fair value, establishes a framework for measuring fair value in accordance with GAAP and expands disclosures about fair value measurements. WPL adopted SFAS 157 onannual rates effective Jan. 1, 20082011 combined with the termination of the $9 million interim fuel-related rate increase effective Dec. 31, 2010 will result in a net $1 million decrease in annual electric retail rates charged to customers effective January 2011. Refer to “Retail Fuel-related Rate Case (2010 Test Year)” below for financial instruments with no material impact on its financial conditionadditional details of the interim fuel-related rate increase implemented in 2010 and results of operations. a $5 million reduction to the 2011 test year base rate increase for refunds owed to electric retail customers related to interim fuel cost collections in 2010.

Retail Rate Case (2010 Test Year) -In February 2008, the FASB issued FSP SFAS 157-1, “Application of SFAS 157 to SFAS 13 and Other Accounting Pronouncements That Address Fair Value Measurements for Purposes of Lease Classification or Measurement under Statement 13,” and FSP SFAS 157-2, “Effective Date of SFAS 157.” In October 2008, the FASB issued FSP SFAS 157-3, “Determining the Fair Value of a Financial Asset When the Market for That Asset Is Not Active.” FSP SFAS 157-1 removes leasing transactions accounted for under SFAS 13, “Accounting for Leases,”December 2009, WPL received an order from the scopePSCW authorizing an annual retail electric rate increase of SFAS 157. WPL adopted FSP SFAS 157-2 on Jan. 1, 2009 for all nonrecurring fair value measurements$59 million, or approximately 6%, and an annual retail natural gas rate increase of nonfinancial assets and nonfinancial liabilities with no material impact on its financial condition and results of operations. FSP SFAS 157-3 clarifies the application of SFAS 157 in a market that is not active.$6 million, or approximately 2%, effective January 2010. Refer to Note 101(b) for expanded disclosures about fair value measurements required by SFAS 157.

SFAS 158, “Employers’ Accounting for Defined Benefit Pension and Other Postretirement Plans - an amendmentdiscussion of FASB Statements No. 87, 88, 106, and 132(R)”

In September 2006, the FASB issued SFAS 158, which requires an employer to recognize the overfunded or underfunded status of its benefit plans as an asset or liability on its balance sheet and to recognize the changesPSCW’s decision in the funded statusDecember 2009 order regarding recovery of its benefit plans inpreviously incurred costs for the year in which they occur as a component of other comprehensive income. WPL adopted the recognition provision of SFAS 158 in 2006, which resulted in reductions to its Dec. 31, 2006 balance of accumulated other comprehensive loss of $5.2 million. SFAS 158 also requires an employer to measure benefit plan assets and obligations as of the end of its fiscal year. WPL adopted the measurement date transition provision of SFAS 158 in 2008, which resulted in reductions to its Jan. 1, 2008 balance of retained earnings of $1.2 million.

(2) UTILITY RATE REFUNDScancelled Nelson Dewey #3 base-load project.

WPL’s 2008Retail Fuel-related Retail Rate Case (2010 Test Year)- In March 2008,April 2010, WPL filed a request with the PSCW to increase annual retail electric rates by $16$9 million to recover anticipated increased electric production fuel and purchased energy costspurchases (fuel-related costs). in 2010. Actual fuel-related costs through February 2008,March 2010, combined with projections of continued higher fuel-related costs for the remainder of 2008,2010, significantly exceeded the amounts being recovered in retail electric rates at the time of the

filing. In the second quarter of 2008, WPL received an orderapproval from the PSCW authorizing the requested $16to implement an interim rate increase of $9 million, interim increase, subject to refund,on an annual basis, effective in April 2008.June 2010. Updated annual 2010 fuel-related costs during the proceeding resulted in WPL no longer qualifying for a fuel-related rate increase for 2010. In December 2010, the PSCW issued an order authorizing no increase in retail electric rates in 2010 related to fuel-related costs and required the interim rate increase to terminate at the end of 2010. The order also authorized WPL to use $5 million of the interim fuel rates collected in 2010 as a reduction to the 2011 test year base rate increase. As of Dec. 31, 2010, WPL reserved $5 million, including interest, for interim fuel cost collections in 2010.

Retail Fuel-related Rate Case (2009 Test Year) -Retail fuel-related costs incurred by WPL in 2008 subsequent toduring the implementation of the interim rate increaseperiod from Sep. 1, 2009 through Dec. 31, 2009 were significantly lower than anticipatedretail fuel-related costs used to determine rates during such period resulting in refunds owed to its retail electric customers. In January 2009, WPL received approval from the PSCW to pay an $18 million interim refund to retail electric customers in the first quarter of 2009. In January 2009, WPL also filed a final fuel refund report, including interest less the interim refund amount, resulting in a final residual refund of $5 million in addition to the interim refund. Pending PSCW approval, WPL will refund the remaining $5 million, including interest, in the second quarter of 2009. As of Dec. 31, 2008,2009, WPL reserved $23$4 million, including interest, for refunds anticipated to be paid to its retail electric customers. In 2010, WPL refunded $4 million, including interest, to its retail electric customers based upon its estimate of the final order. WPL anticipatesafter receiving the final order from the PSCW in the first quarter of 2009 and completing any remaining refunds in the second quarter of 2009.

WPL’s 2007 Retail Rate Case - In August 2007, WPL received approval from the PSCW to refund to its retail electric customers any over-recovery of retail fuel-related costs duringcomplete the period June 1, 2007 through Dec. 31, 2007. As of Dec. 31, 2008, WPL estimated the over-recovery of retail fuel-related costs during this period to be $22 million, including interest. WPL refunded to its retail electric customers $4 million in 2007 and $16 million in 2008. As of Dec. 31, 2008, WPL reserved $2 million for the remaining refund amounts, including interest, anticipated to be paid to its retail electric customers in the second quarter of 2009 related to these refunds. WPL expects to receive the PSCW’s decision on the remaining refund amount in the first quarter of 2009.refund.

Refer to Note 1(h) for further discussion of WPL’s fuel cost recovery mechanism and Note 1(b) for discussion of various other rate matters.

(3) LEASES

(a) Operating Leases- WPL has 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 PPAs. These PPAs contain fixed rental payments related to capacity and transmission rights and contingent rental payments related to the energy portion (actual MWh)MWhs) of the respective agreements.PPAs. Rental expenses associated with WPL’s operating leases were as follows (in millions):

 

  2008  2007  2006      2010           2009           2008     

Operating lease rental expenses (excluding contingent rentals)

  $77  $96  $90  $63    $68    $77  

Contingent rentals related to certain PPAs

   7   19   23   4     7     7  

Other contingent rentals

   —     1   1
                     
  $84  $116  $114  $67    $75    $84  
                     

At Dec. 31, 2008, WPL’s2010, future minimum operating lease payments, excluding contingent rentals, were as follows (in millions):

 

  2009  2010  2011  2012  2013  Thereafter  Total      2011           2012           2013           2014           2015           Thereafter           Total     

Riverside Energy Center (Riverside) PPA(a)

  $57  $57  $58  $59  $17  $—    $248  $59    $60    $17    $—      $—      $—      $136  

RockGen Energy Center (RockGen) PPA

   7   —     —     —     —     —     7

Synthetic leases

   3   5   1   1   1   6   17

Synthetic leases (b)

   1     1     2     4     1     —       9  

Other

   1   6   2   1   1   1   12   3     6     1     1     —       1     12  
                                                 
  $68  $68  $61  $61  $19  $7  $284  $63    $67    $20    $5    $1    $1    $157  
                                                 

The synthetic leases in the above table relate to the financing of certain utility railcars. The entities that lease these assets to WPL do not meet the consolidation requirements per FIN 46R, “Consolidation of Variable Interest Entities,” and are not included on the Consolidated Balance Sheets. WPL has guaranteed the residual value of the related assets, which total $7 million in the aggregate. The guarantees extend through the maturity of each respective underlying lease with remaining terms up to seven years. Residual value guarantee amounts have been included in the above table.

(a)The Riverside PPA contains a provision granting WPL the option to purchase this facility in 2013. Refer to Note 18 for additional information on this PPA.
(b)The synthetic leases relate to the financing of certain utility railcars. The entities that lease these assets to WPL do not meet consolidation requirements and are not included on the Consolidated Balance Sheets. WPL has guaranteed the residual value of the related assets, which total $4 million in the aggregate. The guarantees extend through the maturity of each respective underlying lease with remaining terms up to five years. Residual value guarantee amounts have been included in the future minimum operating lease payments.

(b) Capital LeaseLeases -In 2005, WPL entered into a 20-year agreement with Alliant Energy Resources, LLC’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 2005 when SFEF began commercial operations.operation. WPL is responsible for the operation of SFEF and has exclusive rights to its output. In 2005, the PSCW approved this affiliated lease agreement with initial monthly payments of approximately $1.3 million. The lease payments were 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 2005 and certain costs incurred to construct the facility. In accordance with its order approving the lease agreement, the PSCW willreserved the right to review the capital structure, return on equity and cost of debt every five years from the date of the order. No revisions to the lease were made in 2010. The capital lease asset is amortized using the straight-line method over the 20-year lease term. Since the inception of the lease in 2005, WPL’s retail rate cases, beginning with the 2005/2006 retail rate case that became effective in July 2005, includeand wholesale rates have included recovery of the monthly SFEF lease payment amounts from WPL’s customers.payments. In 2008, 20072010, 2009 and 2006,2008, SFEF lease expenses were $18.2 million, $18.5 million and $18.8 million $19.0($12.0 million, $12.3 million and $19.3 million ($12.6 million, $12.8 million and $13.1$12.6 million included in “Interest expense” and $6.2 million, $6.2 million and $6.2 million included in “Depreciation and amortization” in the Consolidated Statements of Income),

respectively. At Dec. 31, 2008,2010, WPL’s estimated future minimum capital lease payments for SFEF were as follows (in millions):

 

2009  2010  2011  2012  2013  Thereafter  Total  Less: amount
representing
interest
  Present value of net
minimum capital
lease payments
$15  $15  $15  $15  $15  $173  $248  $132  $116
      2011       2012       2013       2014       2015     Thereafter   Total   Less:  amount
representing

interest
   Present value of net
minimum capital

lease payments
 

SFEF

  $15    $15    $15    $15    $15    $143    $218    $108    $110  

(4) RECEIVABLES

Cash CollateralAdvances for Customer Energy Efficiency Projects- As of Dec. 31, 2008, WPL had entered into numerous agreementsoffers energy efficiency programs to purchase electricity and natural gas to servecertain of its customers. Exposure under certainThe energy efficiency programs provide low-cost financing to help customers identify, purchase and install energy efficiency improvement projects. The customers repay WPL with monthly payments over a term up to five years. The advances for and collections of these agreements exceeded contractual limits, requiring WPL to provide cash collateral to certain counterparties. At Dec. 31, 2008, cash collateralcustomer energy efficiency projects are recorded as investing activities in the Consolidated Statements of $15 million wasCash Flows. The current portion and non-current portion of outstanding advances for customer energy efficiency projects are recorded in “Accounts receivable - other”“Other accounts receivable” and “Deferred charges and other,” respectively, on the Consolidated Balance Sheet. There was no outstanding cash collateral as ofSheets. At Dec. 31, 2007.2010 and 2009, outstanding advances for customer energy efficiency projects were as follows (in millions):

       2010           2009     

Current portion

  $25.0    $29.0  

Non-current portion

   43.7     54.0  
          
  $68.7    $83.0  
          

(5) INCOME TAXES

Income Tax Expense (Benefit)Taxes -The components of “Income taxes” in the Consolidated Statements of Income were as follows (in millions):

 

  2008 2007 2006   2010 2009 2008 

Current tax expense:

    

Current tax expense (benefit):

    

Federal

  $22.1  $55.8  $18.4   $26.8   ($137.7 $22.4  

State

   10.5   10.2   2.1    14.7    (14.3  10.5  

Deferred tax expense (benefit):

    

Deferred tax expense:

    

Federal

   34.2   (4.0)  36.6    63.3    153.6    34.2  

State

   3.3   (1.3)  6.6    6.6    9.3    3.3  

Production tax credits

   (3.5  (3.9  (0.3

Investment tax credits

   (1.4)  (1.5)  (1.5)   (1.2  (1.3  (1.4

Provision recorded as a change in uncertain tax benefits

   0.1   —     —   

Provision recorded as a change in uncertain tax positions:

    

Current

   (41.7  39.7    0.1  

Deferred

   33.3    —      —    

Provision recorded as a change in accrued interest

   (0.4)  0.1   —      —      0.4    (0.4
                    
  $68.4  $59.3  $62.2   $98.3   $45.8   $68.4  
                    

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

 

  2008 2007 2006   2010 2009 2008 

Statutory federal income tax rate

  35.0% 35.0% 35.0%   35.0  35.0  35.0

State income taxes, net of federal benefits

  4.6  4.8  5.6    5.0    4.4    4.6  

Federal health care legislation

   1.2    —      —    

Adjustment of prior period taxes

  0.2  (0.1) —      2.0    0.7    0.2  

State filing changes

   —      (1.8  —    

Amortization of excess deferred taxes

   (0.2  (0.2  (0.7

Amortization of investment tax credits

  (0.7) (0.8) (0.9)   (0.5  (1.0  (0.7

Amortization of excess deferred taxes

  (0.7) (1.0) (0.6)

Effect of rate making on property related differences

   (1.0  (0.8  (0.9

Production tax credits

   (1.4  (2.9  (0.2

Other items, net

  (1.8) (3.6) (2.0)   (0.9  0.5    (0.7
                    

Overall effective income tax rate

  36.6% 34.3% 37.1%

Overall income tax rate

   39.2  33.9  36.6
                    

Federal Health Care Legislation -In March 2010, the Patient Protection and Affordable Care Act, and Health Care and Education Reconciliation Act of 2010 (Federal Health Care Legislation) were enacted. One of the most significant provisions

of the Federal Health Care Legislation for WPL requires a reduction in its tax deductions for retiree health care costs beginning in 2013, to the extent its drug expenses are reimbursed under the Medicare Part D retiree drug subsidy program. The reduction in the future deductibility of retiree health care costs accrued as of Dec. 31, 2009 required WPL to record deferred income tax expense of $3 million in 2010.

State filing changes - In 2009, the Wisconsin Senate Bill 62 (SB 62) was enacted. The most significant provision of SB 62 for WPL required combined reporting for corporate income taxation in Wisconsin beginning with tax returns filed for the calendar year 2009. This provision requires all legal entities in which Alliant Energy owns a 50% or more interest to file as members of a unitary return in Wisconsin. As a result of this provision in SB 62 and in order to take advantage of efficiencies that may be available as a result of WPL and Interstate Power and Light Company (IPL) sharing resources and facilities, WPL filed as a member of Iowa consolidated tax returns beginning with calendar year 2009. Changes in state apportioned income tax rates resulting from Wisconsin combined reporting requirements and WPL’s plans to be included in Iowa consolidated tax returns required WPL to adjust the carrying value of its deferred income tax assets and liabilities in 2009. WPL recognized net income tax benefits in 2009 of $2 million from the changes in state apportioned income tax rates and additional valuation allowances.

Production tax credits - WPL earns production tax credits from the wind projects it owns and operates. Production tax credits are generated during the first 10 years of operations and are based on the electricity output generated by each wind project. WPL has two wind projects that are currently generating production tax credits including the 68 MW Cedar Ridge wind project, which began generating electricity in late 2008, and the 200 MW Bent Tree - Phase I wind project, which began generating electricity in late 2010. Production tax credits (net of state tax impacts) generated during 2010, 2009 and 2008 by these wind projects were as follows (in millions):

       2010          2009           2008     

Cedar Ridge

  $3   $4    $—    

Bent Tree - Phase I

   1    —       —    
              
   4    4     —    

Deferral (a)

   (1  —       —    
              
  $3   $4    $—    
              

(a)In accordance with its December 2009 order, the PSCW authorized WPL to defer any production tax credits generated from its Bent Tree - Phase I wind project in 2010.

Deferred Tax Assets and Liabilities- Consistent with rate making treatment, deferred taxes are offset in the tabletables below for temporary differences whichthat have related regulatory assets and regulatory liabilities. The deferred income tax (assets) and liabilities included on the Consolidated Balance Sheets at Dec. 31 arise from the following temporary differences (in millions):

 

  2008 2007   2010 2009 
  Deferred
Tax Assets
 Deferred
Tax Liabilities
  Net Deferred
Tax Assets
 Deferred
Tax Liabilities
  Net   Deferred
Tax Assets
 Deferred Tax
Liabilities
   Net Deferred
Tax Assets
 Deferred Tax
Liabilities
   Net 

Property

  $—    $232.5  $232.5  $—    $205.3  $205.3   $—     $494.8    $494.8   $—     $389.0    $389.0  

Investment in American Transmission Co. LLC (ATC)

   —     52.2   52.2   —     47.3   47.3 

Investment in ATC

   —      83.9     83.9    —      71.5     71.5  

Pension and other postretirement benefits obligations

   —     33.5   33.5   —     17.5   17.5    —      32.1     32.1    —      31.4     31.4  

Prepaid gross receipts tax

   —     15.1   15.1   —     15.5   15.5 

Regulatory asset - WPL base-load project

   —     11.0   11.0   —     3.8   3.8 

Net operating losses carryforward - state

   —      —       —      (9.2  —       (9.2

Investment tax credits

   (9.0)  —     (9.0)  (10.0)  —     (10.0)   (7.4  —       (7.4  (8.2  —       (8.2

Federal credit carryforward (a)

   (11.5  —       (11.5  (11.2  —       (11.2

Customer advances

   (13.6)  —     (13.6)  (14.3)  —     (14.3)   (13.1  —       (13.1  (14.6  —       (14.6

Regulatory liability - reserve for customer refund

   (18.1)  —     (18.1)  (9.5)  —     (9.5)

Net operating losses carryforward - federal (b)

   (38.2  —       (38.2  (15.4  —       (15.4

Other

   (8.2)  13.0   4.8   (14.8)  17.7   2.9    (12.0  37.2     25.2    (13.0  45.8     32.8  
                                        
   ($48.9) $357.3  $308.4   ($48.6) $307.1  $258.5   ($82.2 $648.0    $565.8   ($71.6 $537.7    $466.1�� 
                                        
       2008      2007             2010               2009     

Other current assets

      ($20.9)     ($11.4)     ($4.6    ($24.7

Deferred income taxes

      329.3      269.9       570.4       490.8  
                          

Total deferred tax (assets) and liabilities

     $308.4     $258.5      $565.8      $466.1  
                          

(a)Earliest expiration date is 2022

(b)Earliest expiration date is 2029

Unrecognized Tax BenefitsProperty - WPL adopted In September 2010, the Small Business Jobs Act of 2010 (SBJA) was enacted. One of the most significant provisions of FIN 48the SBJA for WPL provides a one-year extension of the 50% bonus depreciation deduction for certain expenditures for property that is acquired or constructed in 2010. In December 2010, the Tax Relief, Unemployment Insurance Reauthorization and Job Creation Act of 2010 (the Act) was enacted. One of the most significant provisions of the Act for WPL provides 100% bonus depreciation on Jan. 1, 2007. WPL’s cumulative effect of adopting FIN 48qualifying expenditures through 2011 for property placed in service by Dec. 31, 2012. In addition, 50% bonus depreciation will be allowed on qualifying expenditures through 2012 for property that is placed in service by Dec. 31, 2013. Based on capital projects placed into service in 2010, WPL estimates its total 2010 bonus tax depreciation deduction under the SBJA and the Act to be approximately $215 million. This 2010 bonus tax depreciation deduction was anthe primary reason for the increase in its net liability for unrecognizeddeferred tax benefits and a reductionliabilities related to its Jan. 1, 2007 balance of retained earnings of $0.8 million. The $0.8 million increaseproperty in the net liability for unrecognized tax benefits was recorded as a $2.8 million increase in other long-term liabilities, a $1.1 million decrease in deferred income taxes, a $0.6 million decrease in accrued taxes and a $0.3 million increase in non-current regulatory assets on the Consolidated Balance Sheet. At the date of adoption, WPL’s unrecognized tax benefits and related interest were $2.8 million ($2.4 million of unrecognized tax benefits and $0.4 million of interest) including $1.5 million of tax benefits that, if recognized, would favorably impact WPL’s effective income tax rate.2010.

Uncertain Tax Positions -A reconciliation of the beginning and ending amounts of unrecognizeduncertain tax benefits,positions, excluding interest, for WPL for 2008 and 2007 is as follows (in millions):

 

  2008 2007       2010         2009         2008     

Balance at Jan. 1

  $2.4  $2.4 

Balance, Jan. 1

  $42.1   $2.5   $2.4  

Additions based on tax positions related to the current year

   0.4   0.1    1.3    2.5    0.4  

Reductions based on tax positions related to the current year

   —     —      —      —      —    

Additions for tax positions of prior years(a)

   2.5   —      5.2    37.3    2.5  

Reductions for tax positions of prior years(b)

   (0.3)  (0.1)   (8.0)   (0.2  (0.3

Settlements with taxing authorities

   (2.5)  —      (6.9)   —      (2.5

Lapse of statute of limitations

   —     —      —      —      —    
                 

Balance at Dec. 31

  $2.5  $2.4 

Balance, Dec. 31

  $33.7   $42.1   $2.5  
                 
  Dec. 31,
2008
 Dec. 31,
2007
 

Tax positions favorably impacting future effective tax rates

  $1.7  $1.5 

Interest accrued

   0.3   0.5 

Penalties accrued

   —     —   

WPL is subject to U.S. federal income

(a)The additions of tax positions of prior years were primarily related to positions taken by WPL on its federal and state tax returns related to the capitalization and dispositions of property.
(b)The reductions of tax positions of prior years during 2010 were primarily related to deductions taken by WPL on its federal and state tax returns that were settled under audit for amounts less than the recorded amounts.

   Dec. 31, 
       2010           2009           2008     

Tax positions favorably impacting future effective tax rates for continuing operations

  $—      $1.4    $1.7  

Interest accrued

   —       2.1     0.3  

Penalties accrued

   —       —       —    

Open tax as well as income tax in multiple state jurisdictions, including the state of Wisconsin. WPL has concluded all U.S. federal income tax matters for calendar years through 2004. The IRS is currently auditing WPL’s U.S. federal income tax returns for calendar-Tax years 2005 through 2007. Audit adjustments from U.S. federal income tax returns are required to be reported to the respective state taxing authorities within varying prescribed timelines

following the completion of each U.S. federal income tax audit. The Wisconsin statute of limitations is closed for calendar years through 2003. U.S. federal and state income tax returns for the remaining calendar years are stillthat remain subject to examination by the respective taxing authorities. major jurisdictions are as follows:

Major Jurisdiction

Open Years

Consolidated federal income tax returns

2005-2009 (a) 

Consolidated Iowa income tax returns

2009

Wisconsin income tax returns

2005-2008

Wisconsin combined tax return

2009

(a)The statute of limitations for 2005 through 2007 has been extended to the end of 2011.

Reasonably possible changes to uncertain tax positions in 2011 -In 2009,2011, statutes of limitations will expire for WPL’s tax returns in multiple state jurisdictions. The impact of the statutestatutes of limitations expiring is not anticipated to be material. In September 2010, the Internal Revenue Service (IRS) completed the audits of Alliant Energy’s U.S. federal income tax returns for calendar years 2005 through 2008. Alliant Energy agreed to all the IRS’ proposed adjustments for deductions and credits included in the 2005 through 2008 income tax returns with the exception of the deduction for the repairs expenditure change in method of tax accounting included in Alliant Energy’s 2008 income tax return. The IRS denied the full amount ($301 million for WPL) of the deduction for the repairs expenditures included in Alliant Energy’s 2008 income tax return given the absence of current IRS guidelines regarding this deduction. Alliant Energy is appealing the IRS’ denial of this deduction. The federal income tax return for calendar year 2009 is part of the Compliance Assurance Program of the IRS and as a result, the IRS audit of such return is expected to be completed in 2011. The IRS has consented to a majority of the deductions and credits included by Alliant Energy in its 2009 income tax return. Based on the effective settlement with the IRS of various deductions and credits included in Alliant Energy’s federal income tax returns for calendar years 2005 through 2009, WPL reversed certain uncertain tax positions in 2010. Unrecognized tax benefits for WPL are expected to increase within the next

12 months upon receipt of consent from the IRS related to a change in tax method of accounting for mixed service costs. In accordance with accounting rules, WPL will not reflect the impact of this proposed change to mixed service costs in its financial statements until consent is rendered by the IRS. In addition, unrecognized tax benefits for WPL will decrease within the next 12 months if an expected revenue procedure clarifying the treatment of repairs for distribution property is published. An estimate of the expected changes for 2011 cannot be determined at this time.

Income Tax Refunds Receivable- WPL received $37 million of income tax refunds from the IRS in the fourth quarter of 2010 related to claims filed with the IRS to carryback net operating losses to prior years. These refunds were the primary reason for the decrease in “Income tax refunds receivable” on the Consolidated Balance Sheets of $41 million during 2010.

Other Income Tax Matters- Alliant Energy files a consolidated federal income tax return, which includes the aggregate taxable income or loss of Alliant Energy and its subsidiaries. In addition, a combined state incomereturn including Alliant Energy and all of its subsidiaries was filed in Wisconsin beginning with the tax returns, where applicable.return for calendar year 2009. Alliant Energy subsidiaries with a presence in Iowa file as part of a consolidated return in Iowa. Under the terms of a tax allocationsharing agreement signed in 2009 between Alliant Energy and its subsidiaries, the subsidiaries calculate their respectivebegan calculating state income tax using consolidated apportionment rates applied to separate company taxable income in 2009. Prior to 2009, WPL calculated income tax provisions and make payments to or receive payments from Alliant Energy as if they were separate taxable entities. Any differences between thisusing the separate return methodology and the actual filed consolidated income tax return is allocated as prescribed in Alliant Energy’s tax allocation agreement.methodology. Separate return amounts are alsoprior to 2009 were adjusted for state apportionment benefits, net of federal tax.tax, with any difference between the separate return methodology and the actual consolidated return allocated as prescribed in the prior tax allocation agreement. In 2010, 2009 and 2008, WPL’s foreign sources of income were not material.

(6) BENEFIT PLANS

(a) Pension and Other Postretirement Benefits Plans -SubstantiallyWPL provides retirement benefits to substantially all of WPL’sits employees are covered bythrough various non-contributory defined benefit pension plans.plans, and through a defined contribution plan (401(k) savings plan). WPL’s non-contributory defined benefit pension plans are currently closed to new hires. Benefits of the non-contributory defined benefit pension plans are based on the employees’plan participant’s years of service, age and compensation. Benefits of the defined contribution plans are based on the plan participant’s years of service, age, compensation and contributions. WPL also provides certain defined benefit postretirement health care and life benefits to eligible retirees. In general, the health care plans are contributory with participants’ contributions adjusted regularly and the life insurance plans are non-contributory.

Assumptions- The assumptions for WPL’s qualified and non-qualifieddefined benefit pension benefits and other postretirement benefits plans at the measurement datesdate of Dec. 31 2008, Sep. 30, 2007 and Sep. 30, 2006 were as follows (Not Applicable (N/A)):

 

  Pension Benefits Other Postretirement Benefits   Qualified Defined Benefit
Pension Plan
 Other Postretirement
Benefits Plans
 
  2008 2007 2006 2008 2007 2006   2010 2009 2008 2010 2009 2008 

Discount rate for benefit obligations

  6.15% 6.2% 5.85% 6.15% 6.2% 5.85%   5.7  5.8  6.15  5.25  5.55  6.15

Discount rate for net periodic cost

  6.2% 5.85% 5.5% 6.2% 5.85% 5.5%   5.8  6.15  6.2  5.55  6.15  6.2

Expected rate of return on plan assets (a)

  8.5% 8.5% 8.5% 8.5% 8.5% 8.5%   8  8.25  8.5  6.3  8.25  8.5

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  8% 8% 9%   N/A    N/A    N/A    7.5  7.5  8

Ultimate trend rate

  N/A  N/A  N/A  5% 5% 5%   N/A    N/A    N/A    5  5  5

(a)The expected rate of return on plan assets is determined by analysis of forecasted asset class returns. The related 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.

Expected rate of return on plan assets - The expected rate of return on plan assets is determined by analysis of projected asset class returns based on the target asset class allocations. WPL uses a portfolio return simulator and also reviews historical returns, survey information and capital market information to support the expected rate of return on plan assets assumption. Refer to Note 1(q)“Investment Policy and Strategy for discussionPlan Assets” below for additional information related to WPL’s investment policy and strategy and mix of WPL’s adoptionassets for the pension and other postretirement benefits plans.

Medical cost trend on covered charges -The assumed medical trend rates are critical assumptions in determining the service and interest cost and accumulated postretirement benefit obligation related to postretirement benefits costs. A 1% change in the medical trend rates for 2010, holding all other assumptions constant, would have the following effects (in millions):

   1% Increase   1% Decrease 

Effect on total of service and interest cost components

  $0.5    ($0.5

Effect on postretirement benefit obligation

   4.5     (4.7

Measurement dates -In 2006, the FASB issued authoritative guidance requiring an employer to measure benefit plan assets and obligations as of the recognition provisionend of SFAS 158its fiscal year. WPL adopted this guidance in 20062008 and the change in WPL’schanged its measurement date from Sept.Sep. 30 to Dec. 31, effectivewhich resulted in 2008.a reduction to its Jan. 1, 2008 balance of retained earnings of $1.2 million.

Net Periodic Benefit Costs-The components of WPL’s net periodic benefit costs for its qualified defined benefit pension benefits and other postretirement benefits costsplans were as follows (in millions):

 

  Qualified Pension Benefits Other Postretirement Benefits   Qualified Defined Benefit Pension Plan Other Postretirement Benefits Plans 
  2008 2007 2006 2008 2007 2006   2010 2009 2008 2010 2009 2008 

Service cost

  $5.3  $5.6  $6.1  $3.3  $3.3  $4.2   $4.9   $4.9   $5.3   $3.6   $3.4   $3.3  

Interest cost

   15.0   13.7   13.2   5.5   5.2   5.4    15.7    15.5    15.0    5.5    5.5    5.5  

Expected return on plan assets (a)

   (21.4)  (19.2)  (17.9)  (1.9)  (1.8)  (1.8)   (19.1)   (14.1  (21.4  (1.3  (1.1  (1.9

Amortization of (b):

              

Transition obligation

   —     —     —     —     —     0.8 

Prior service cost (credit)

   0.8   0.8   0.8   (1.0)  (1.0)  (0.1)   0.5    0.5    0.8    (0.7  (0.9  (1.0

Actuarial loss

   1.0   2.9   4.5   1.0   1.1   1.2    8.5    10.4    1.0    2.5    1.3    1.0  

Curtailment loss (c)

         0.7    —      —      —      —    

Special termination benefits costs (d)

         0.9    —      —      —      —    
                                      

Income statement impacts

  $0.7  $3.8  $6.7  $6.9  $6.8  $9.7 
                     $10.5   $18.8   $0.7   $9.6   $8.2   $6.9  
                   

 

(a)The expected return on plan assets is based on the expected rate of return on plan assets and the fair value approach to the market-related value of plan assets.

(b)Unrecognized net actuarial losses in excess of 10% of the projected benefit obligation and unrecognized prior service costs (credits) are generally amortized over the average future service lives of the participants.participants for each plan.

WPL’s net periodic benefit cost is primarily included in “Operating expenses - other operation and maintenance” in the Consolidated Statements of Income.

(c)In 2007, members of the International Brotherhood of Electrical Workers Local 965 ratified a four-year collective bargaining agreement reached with WPL, resulting in changes to WPL’s qualified pension plan (Plan). One of these changes provided Plan participants an option to cease participating in the Plan and begin participating in the Alliant Energy 401(k) Savings Plan with increased levels of contribution by Alliant Energy. The election of this option did not impact a participant’s eligibility for benefits previously vested under the Plan. In 2009, certain of these employees elected to cease participating in the Plan, resulting in WPL recognizing a curtailment loss related to the Plan of $0.7 million in 2009.
(d)WPL recognized special termination benefits costs related to the qualified defined benefit pension plan that is sponsored by WPL of $0.9 million in 2009 as a result of the elimination of certain operations positions in 2009.

In the above table, the qualified defined benefit pension benefitsplan costs represent only those respective costs for bargaining unit employees of WPL covered under the bargaining unit pension plan that is sponsored by WPL. The other postretirement benefits costs represent costs for all WPL employees. Alliant Energy Corporate Services Inc. (Corporate Services) provides services to WPL, and as a result, WPL is allocated pension and other postretirement benefits costs (credits) associated with Corporate Services.Services employees. The following table includes qualified pension benefits costs (credits) for WPL’s non-bargaining employees who are participants in other Alliant Energy plans, and the allocated qualified pension and other postretirement benefits costs (credits) associated with Corporate Services foremployees providing services to WPL as follows (in millions):

 

   Pension Benefits  Other Postretirement Benefits
   2008  2007  2006  2008  2007  2006

Non-bargaining WPL employees participating in other plans

  ($2.9) ($0.8) $0.9   N/A   N/A   N/A

Allocated Corporate Services costs (a)

  0.7  2.8   2.2  $1.0  $0.8  $1.3
   Qualified Pension Benefits  Other Postretirement Benefits 
       2010           2009           2008          2010           2009           2008     

Costs (credits)

  $0.7    $4.5    ($2.2 $1.3    $1.2    $1.0  

Alliant Energy sponsors several non-qualified defined benefit pension plans that cover certain current and former key employees. In 2010, 2009 and 2008, the pension costs allocated to WPL for these plans were $2.1 million, $2.1 million and $2.0 million, respectively.

(a)Included in pension benefits for allocated Corporate Services costs for 2007 was a settlement loss of $0.8 million related to payments made to a retired executive.

The assumed medical trend rates are critical assumptionsestimated amortization from “Regulatory assets” on the Consolidated Balance Sheets into net periodic benefit cost in determining the service and interest cost and accumulated postretirement benefit obligation related to other postretirement benefits costs. A 1% change in the medical trend rates for 2008, holding all other assumptions constant, would have the following effects2011 is as follows (in millions):

 

   1% Increase  1% Decrease 

Effect on total of service and interest cost components

  $0.6  ($0.6)

Effect on postretirement benefit obligation

   4.6  (4.4)
   Qualified Defined Benefit   Other Postretirement 
   Pension Plan   Benefits Plans 

Actuarial loss

  $7.1    $2.1  

Prior service cost (credit)

   0.5     (1.1
          
  $7.6    $1.0  
          

In addition to the estimated amortizations from “Regulatory assets” in the above table, $3.6 million of amortizations are expected in 2011 from “Regulatory assets” associated with WPL’s non-bargaining employees who are participants in other Alliant Energy plans and Corporate Services employees participating in Alliant Energy sponsored plans allocated to WPL.

WPL’s net periodic benefit costs are primarily included in “Other operation and maintenance” in the Consolidated Statements of Income.

Benefit Plan Assets and Obligations-The benefit obligationsplan assets and assetsobligations associated with WPL’s non-bargaining employees who are participants in other Alliant Energy plans are not reported in the following tables.table. A reconciliation of the funded status of WPL’s qualified defined benefit pension benefits and other postretirement benefits plans to the amounts recognized on the Consolidated Balance Sheets at Dec. 31 was as follows (Not Applicable (N/A); in(in millions):

 

  Qualified Defined  Benefit
Pension Plan
  Other Postretirement
Benefits Plans
 
  Qualified Pension Benefits Other Postretirement Benefits   
  2008 2007 2008 2007   2010 2009 2010 2009 

Change in projected benefit obligation:

          

Net projected benefit obligation at beginning of year

  $238.6  $233.4  $87.7  $89.0 

Effect of change from Sep. 30 to Dec. 31 measurement date

   2.8   —     0.4   —   

Net projected benefit obligation at Jan. 1

  $271.6   $252.9   $99.1   $89.3  

Service cost

   5.3   5.6   3.3   3.3    4.9    4.9    3.6    3.4  

Interest cost

   15.0   13.7   5.5   5.2    15.7    15.5    5.5    5.5  

Plan participants’ contributions

   —     —     3.0   2.2    —      —      3.2    2.9  

Plan amendments(a)

   —     —     —     0.3    —      —      (1.5  —    

Actuarial (gain) loss

   0.7   (5.4)  (0.1)  1.0 

Transfer to other Alliant Energy plans

   —     —     —     (4.5)

Actuarial loss

   2.5    7.5    1.9    7.9  

Gross benefits paid

   (9.5)  (8.7)  (11.0)  (9.4)   (11.4  (10.1  (9.0  (10.4

Federal subsidy on other postretirement benefits paid

   —     —     0.5   0.6    —      —      0.5    0.5  

Special termination benefits

   —      0.9    —      —    
                          

Net projected benefit obligation at measurement date

   252.9   238.6   89.3   87.7 

Net projected benefit obligation at Dec. 31

   283.3    271.6    103.3    99.1  
                          

Change in plan assets:

          

Fair value of plan assets at beginning of year

   253.3   225.3   20.9   21.5 

Effect of change from Sep. 30 to Dec. 31 measurement date

   3.0   —     0.1   —   

Fair value of plan assets at Jan. 1

   236.6    164.6    18.8    14.6  

Actual return on plan assets

   (82.2)  30.7   (5.9)  3.2    30.0    39.7    2.1    3.2  

Employer contributions

   —     6.0   7.5   7.9    —      42.4    9.9    8.5  

Plan participants’ contributions

   —     —     3.0   2.2    —      —      3.2    2.9  

Transfer to other Alliant Energy plans

   —     —     —     (4.5)

Gross benefits paid

   (9.5)  (8.7)  (11.0)  (9.4)   (11.4  (10.1  (9.0  (10.4
                          

Fair value of plan assets at measurement date

   164.6   253.3   14.6   20.9 

Fair value of plan assets at Dec. 31

   255.2    236.6    25.0    18.8  
                          

Over/(under) funded status at measurement date

   (88.3)  14.7   (74.7)  (66.8)

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

   N/A   —     N/A   1.5 

Federal subsidy on other postretirement benefits paid

   N/A   —     N/A   (0.1)

Under funded status at Dec. 31

  ($28.1 ($35.0 ($78.3 ($80.3
             

Amounts recognized on the Consolidated Balance Sheets consist of:

     

Other current liabilities

  $—     $—     $—     ($3.5

Pension and other benefit obligations

   (28.1  (35.0  (78.3  (76.8
                          

Net amount recognized at Dec. 31

   ($88.3) $14.7   ($74.7)  ($65.4)  ($28.1 ($35.0 ($78.3 ($80.3
                          

Amounts recognized in Regulatory Assets (b):

     

Net actuarial loss

  $95.6   $112.5   $27.2   $28.6  

Prior service cost (credit)

   2.9    3.4    (2.5  (1.7
             
  $98.5   $115.9   $24.7   $26.9  
             

(a)In 2010, the plan amendments for other postretirement benefits plans related to Federal Health Care Legislation enacted in March 2010. In 2010, Alliant Energy approved an amendment to its health and welfare benefit plan, which will split the plan into two separate plans consisting of a plan for active employees and a plan for retirees beginning in 2011.
(b)Refer to Note 1(b) for amounts recognized in “Regulatory assets” on the Consolidated Balance Sheets.

   Qualified Pension Benefits  Other Postretirement Benefits 
   2008  2007  2008  2007 

Amounts recognized on the Consolidated

      

Balance Sheets consist of:

      

Deferred charges and other

  $—    $14.7  $—    $3.0 

Other current liabilities

   —     —     (4.5)  (3.9)

Pension and other benefit obligations

   (88.3)  —     (70.2)  (64.5)
                 

Net amount recognized at Dec. 31

   ($88.3) $14.7   ($74.7)  ($65.4)
                 

Amounts recognized in Regulatory Assets:

      

Net actuarial loss

  $140.9  $37.9  $23.7  $17.2 

Prior service cost (credit)

   4.7   5.6   (2.6)  (3.8)
                 
  $145.6  $43.5  $21.1  $13.4 
                 

The PSCW has authorized WPL to record the retail portion of its previously unrecognized net actuarial gains and losses and prior service costs and credits as “Regulatory assets” in lieu of “Accumulated other comprehensive loss” on the Consolidated Balance Sheet. WPL also recognizes the wholesale portion of its previously unrecognized net actuarial gains and losses and prior service costs and credits as “Regulatory assets” on the Consolidated Balance Sheet because these costs are expected to be recovered in rates in future periods under the formula rate structure implemented in 2007. These regulatory assets will be increased or decreased as the net actuarial gains or losses and prior service costs or credits are subsequently amortized and recognized as a component of net periodic benefit costs. In addition to the amounts recognized in “Regulatory assets” in the above table, $100$78 million and $39$79 million of “Regulatory assets” were recognized for amounts associated with WPL’s non-bargaining employees who are participants in other Alliant Energy plans and Corporate Services employees participating in Alliant Energy sponsored benefit plans that were allocated to WPL at Dec. 31, 20082010 and 2007,2009, respectively.

Included in the following table are WPL’s accumulated benefit obligations, aggregate amounts applicable to qualified defined benefit pension and other postretirement benefits plans with accumulated benefit obligations in excess of plan assets, as well as the qualified defined benefit pension plansplan with projected benefit obligations in excess of plan assets as of the measurement dates of Dec. 31 2008 and Sep. 30, 2007 (inmeasurement date (Not Applicable (N/A); in millions):

 

  Qualified Pension Benefits  Other Postretirement Benefits  Qualified Defined Benefit
Pension Plan
   Other Postretirement
Benefits Plans
 
  2008  2007  2008  2007  2010   2009   2010   2009 

Accumulated benefit obligations

  $230.1  $218.9  $89.3  $87.7  $270.2    $253.2    $103.3    $99.1  

Plans with accumulated benefit obligations in excess of plan assets:

                

Accumulated benefit obligations

   230.1   —     89.3   80.4   270.2     253.2     103.3     99.1  

Fair value of plan assets

   164.6   —     14.6   10.6   255.2     236.6     25.0     18.8  

Plans with projected benefit obligations in excess of plan assets:

                

Projected benefit obligations

   252.9   —     N/A   N/A   283.3     271.6     N/A     N/A  

Fair value of plan assets

   164.6   —     N/A   N/A   255.2     236.6     N/A     N/A  

Other postretirement benefits plans are funded via specific assets within certain retirement plans (401(h) assets) as well as Voluntary Employees’ Beneficiary Association (VEBA) trusts. The asset allocation of the 401(h) assets mirrorEstimated Future Employer Contributions and Benefit Payments -WPL estimates that funding for the qualified defined benefit pension plan assets and the asset allocation of the VEBA trusts are reflected in the following table under “Other Postretirement Benefits Plans.” The asset allocation for WPL’s qualified pension and other postretirement benefits plans at Dec. 31, 2008during 2011 will be $0 and Sep. 30, 2007,$8 million, respectively.

WPL’s expected benefit payments and the qualified pension plan target allocation for 2008 wereMedicare subsidies, which reflect expected future service, as follows:appropriate, are as follows (in millions):

 

   Pension Plans  Other Postretirement
Benefits Plans
 
   Target  Percentage of
Plan Assets
  Percentage of
Plan Assets
 
   Allocation  Dec. 31,  Sep. 30,  Dec. 31,  Sep. 30, 

Asset Category

  2008  2008  2007  2008  2007 

Equity securities

  65-75% 70% 73% 43% 49%

Debt securities

  20-35% 30% 27% 12% 20%

Other

  0-5% —    —    45% 31%
              
   100% 100% 100% 100%
              

   2011  2012  2013  2014  2015  2016 - 2020 

Qualified defined benefit pension benefits

  $11.8   $12.5   $13.3   $14.3   $15.3   $93.7  

Other postretirement benefits

   7.1    7.1    7.5    7.9    8.3    46.7  

Medicare subsidies

   (0.5  (0.6  (0.6  (0.7  (0.7  (4.8
                         
  $18.4   $19.0   $20.2   $21.5   $22.9   $135.6  
                         

Investment Policy and Strategy for Plan Assets -WPL’s investment strategy and its policies employed with respect to assets of defined benefit pension and other postretirement benefits assets isplans are to combine both preservation of principal and prudent and reasonable risk-taking to protect the integrity of theplan assets, in meetingorder to meet the obligations to theplan participants while achieving the optimal return possible over the long-term.long-term to minimize benefit costs. 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 including both U.S. and international equity exposure, the number of individual investments, and sector and industry limits when applicable. WPL believes that any risk associated with the various plan assets is minimized by this diversification. WPL also uses an overlay management service to help maintain target allocations, liquidity needs and intended exposures to the plan assets. The overlay manager is authorized to use derivative financial instruments to facilitate this service.

Defined Benefit Pension Plans Assets -For theassets of defined benefit pension plan,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 maximizeof maximizing returns and minimize riskminimizing risks over the long-term, the defined benefit pension plan hasplans have a long-term investment posture more heavily weighted towards equity holdings. The asset allocation mix is monitored regularly and appropriate action is taken as needed to rebalance the assets within the prescribed range. Prohibited investment vehicles include, but may not be limited to, direct ownership of real estate, options and futures (unless specifically approved as is the case of the overlay manager), margin trading, oil and gas limited partnerships, commodities, short selling and securities of the managers’ firms or affiliate firms. At Dec. 31, 2010, the current target range and actual allocations for WPL’s defined benefit pension plan assets were as follows:

Target Range
Allocation
Actual
Allocation

Cash and equivalents

0%-5%1

Equity securities:

U.S. large cap core

10%-20%14

U.S. large cap value

8%-16%12

U.S. large cap growth

8%-16%12

U.S. small cap value

0%-6%4

U.S. small cap growth

0%-4%2

International - developed markets

12%-24%17

International - emerging markets

0%-8%4

Fixed income securities

20%-40%34

Other Postretirement Benefits Plans Assets related to other-Other postretirement benefits plans assets are comprised of specific assets within certain defined benefit pension plans (401(h) assets) as well as assets held in Voluntary Employees’ Beneficiary Association (VEBA) trusts. The investment policy and strategy of the 401(h) assets mirrors those of the defined benefit pension plans, which are discussed above. The assets in the VEBA trusts 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. ProhibitedThere are no specific target allocations for the VEBA trusts as a whole. Separate investment vehicles relatedguidelines have been established for the VEBA trusts which are actively managed. At Dec. 31, 2010, WPL’s other postretirement benefits plan assets consisted of 39% equity securities, 19% fixed income securities and 42% cash and equivalents.

Securities Lending Program- WPL has a securities lending program with the trustee that allows the trustee to thelend certain securities from WPL’s qualified defined benefit pension and other postretirement benefits plans to selected entities against receipt of collateral (in the form of cash, government securities or letters of credit) as provided for and determined in accordance with its securities loan agreement. Initial collateral levels are no less than 102% and 105% of the market value of the borrowed securities for collateral denominated in U.S. and foreign currency, respectively. Refer to “Fair Value Measurements” below for details of WPL’s fair value of invested collateral and amounts due to borrowers for the securities lending program.

Fair Value Measurements -The following tables report a framework for measuring fair value. The fair value hierarchy prioritizes the inputs to valuation techniques used to measure fair value. The three levels of the fair value hierarchy are as follows:

Level 1- Pricing inputs are unadjusted quoted prices available in active markets for identical assets or liabilities as of the reporting date. WPL’s investments in registered investment companies and common and preferred stocks are valued at the closing price reported in the active market in which the individual securities are traded. Level 1 plan assets also include butinterest-bearing cash, which is held in money market accounts managed by an affiliate of the trustee.

Level 2- Pricing inputs are quoted prices for similar asset or liabilities in active markets, quoted prices for identical or similar assets or liabilities in inactive markets, inputs other than quoted prices that are observable for the asset or liability and inputs that are derived principally from or corroborated by observable market data by correlation or other means. WPL’s investments in corporate bonds and government and agency obligations are valued at the closing price reported in the active market for similar assets in which the individual securities are traded or based on yields currently available on comparable securities of issuers with similar credit ratings. WPL’s investments in common/collective trusts are valued at the net asset value of shares held by the plans, which is based on the fair market value of the underlying investments in equity and fixed income securities of the common/collective trusts. Level 2 plan assets also consist of asset backed securities, commercial paper and repurchase agreements within their securities lending invested collateral.

Level 3 -Pricing inputs are unobservable inputs for assets or liabilities for which little or no market data exist and require significant management judgment or estimation. WPL’s Level 3 plan assets include certain asset backed securities and corporate bonds within its securities lending invested collateral.

The fair value hierarchy gives the highest priority to unadjusted quoted prices in active markets (Level 1) and the lowest priority to unobservable data (Level 3). In some cases, the inputs used to measure fair value might fall in different levels of the fair value hierarchy. The lowest level input that is significant to a fair value measurement in its entirety determines the applicable level in the fair value hierarchy. Assessing the significance of a particular input to the fair value measurement in its entirety requires judgment, considering factors specific to the asset or liability.

The methods described above may produce a fair value calculation that may not be limitedindicative of net realizable value or reflective of future fair values. Furthermore, while WPL believes its valuation methods are appropriate and consistent with other market participants, the use of different methodologies or assumptions to direct ownershipdetermine the fair value of real estate, optionscertain financial instruments could result in a different fair value measurement at the reporting date.

At Dec. 31, 2010 and futures unless specifically approved, margin trading, oil and gas limited partnerships, commodities, short selling and securities2009, the fair values of the managers’ firms or affiliate firms.

Alliant Energy sponsors several non-qualified pension plans that cover certain current and former key employees. In 2008, 2007 and 2006, the pension expense allocated to WPL for these plans was $2.0 million, $2.7 million and $2.1 million, respectively. Included for 2007 was the settlement loss of $0.8 million related to payments made to a retired executive.

WPL estimates that funding for theWPL’s qualified defined benefit pension plan for its bargaining unit employeesassets by asset category and other postretirement benefits plans during 2009 will be $17 million and $8 million, respectively.

The expected benefit payments and Medicare subsidies, which reflect expected future service, as appropriate, arefair value hierarchy level were as follows (in millions):

 

   2009  2010  2011  2012  2013  2014 - 2018 

Pension benefits

  $9.6  $10.2  $10.8  $11.6  $12.6  $83.0 

Other postretirement benefits

   7.0   6.6   7.0   7.3   7.7   44.7 

Medicare subsidies

   (0.5)  (0.5)  (0.5)  (0.5)  (0.5)  (3.2)
                         
  $16.1  $16.3  $17.3  $18.4  $19.8  $124.5 
                         
   Dec. 31, 2010   Dec. 31, 2009 
   Fair
Value
  Level
1
   Level
2
     Level  
3
   Fair
Value
  Level
1
   Level
2
     Level  
3
 
               

Cash and equivalents

  $3.4   $3.4    $—      $—      $11.0   $11.0    $—      $—    

Equity securities:

              

U.S. large cap core

   36.7    36.7     —       —       31.8    31.8     —       —    

U.S. large cap value

   31.2    —       31.2     —       26.6    —       26.6     —    

U.S. large cap growth

   31.3    —       31.3     —       26.4    —       26.4     —    

U.S. small cap value

   9.0    —       9.0     —       7.1    —       7.1     —    

U.S. small cap growth

   5.2    5.2     —       —       4.2    4.2     —       —    

International - developed markets

   44.1    23.6     20.5     —       39.9    20.8     19.1     —    

International - emerging markets

   10.6    10.6     —       —       12.0    12.0     —       —    

Fixed income securities:

              

Corporate bonds

   16.8    —       16.8     —       18.9    —       18.9     —    

Government and agency obligations

   24.5    —       24.5     —       21.6    —       21.6     —    

Fixed income funds

   44.2    —       44.2     —       40.0    0.5     39.5     —    

Securities lending invested collateral

   5.4    1.0     3.5     0.9     7.6    2.0     4.6     1.0  
                                      
   262.4   $80.5    $181.0    $0.9     247.1   $82.3    $163.8    $1.0  
                                

Accrued investment income

   0.3          0.5       

Due to brokers, net (a)

   (0.2        (1.0     

Due to borrowers for securities lending program

   (7.3        (10.0     
                    

Total pension plan assets

  $255.2         $236.6       
                    

The estimated amortization from “Regulatory assets” on the Consolidated Balance Sheet into net periodic

(a)This category represents pending trades with brokers.

Additional information for fair value measurements of WPL’s qualified defined benefit cost inpension plans assets using significant unobservable inputs (Level 3 inputs) for 2010 and 2009 is as follows (in millions):

 

   Qualified
Pension
Benefits
  Other
Postretirement
Benefits
 

Actuarial loss

  $11.3  $1.3 

Prior service cost (credit)

   0.6   (0.9)
         
  $11.9  $0.4 
         

Securities Lending Invested Collateral

      2010          2009     

Beginning balance, Jan. 1

  $1.0   $2.2  

Actual return on plan assets:

   

Relating to assets still held at the reporting date

   0.2    (0.1

Relating to assets sold during the period

   —      0.1  

Purchases, sales and settlements, net

   —      (1.3

Transfers in and/or out of Level 3

   (0.3  0.1  
         

Ending balance, Dec. 31

  $0.9   $1.0  
         

In addition to

At Dec. 31, 2010 and 2009, the estimated amortizations from “Regulatory assets” infair values of WPL’s other postretirement benefits plans assets by asset category and fair value hierarchy level were as follows (in millions):

   Dec. 31, 2010   Dec. 31, 2009 
   Fair
Value
  Level
1
     Level  
2
     Level  
3
   Fair
Value
  Level
1
     Level  
2
     Level  
3
 
               

Cash and equivalents

  $10.7   $10.7    $—      $—      $5.0   $5.0    $—      $—    

Equity securities:

              

U.S. large cap core

   1.3    1.3     —       —       1.1    1.1     —       —    

U.S. large cap value

   1.1    —       1.1     —       0.9    —       0.9     —    

U.S. large cap growth

   1.1    —       1.1     —       0.9    —       0.9     —    

U.S. small cap core

   3.8    3.8     —       —       4.7    4.7     —       —    

U.S. small cap value

   0.3    —       0.3     —       0.2    —       0.2     —    

U.S. small cap growth

   0.2    0.2     —       —       0.1    0.1     —       —    

International - developed markets

   1.6    0.8     0.8     —       1.4    0.7     0.7     —    

International - emerging markets

   0.4    0.4     —       —       0.4    0.4     —       —    

Fixed income securities:

              

Corporate bonds

   1.4    —       1.4     —       1.3    —       1.3     —    

Government and agency obligations

   1.0    —       1.0     —       1.1    —       1.1     —    

Fixed income funds

   2.3    0.7     1.6     —       1.8    0.4     1.4     —    

Securities lending invested collateral

   0.2    0.1     0.1     —       0.2    0.1     0.1     —    
                                      
   25.4   $18.0    $7.4    $—       19.1   $12.5    $6.6    $—    
                                

Due to brokers, net (a)

   (0.1        —         

Due to borrowers for securities lending program

   (0.3        (0.3     
                    

Total other postretirement benefits plan assets

  $25.0         $18.8       
                    

(a)This category represents pending trades with brokers.

Additional information for WPL’s fair value measurements of other postretirement benefits plans assets using significant unobservable inputs (Level 3 inputs) for 2010 and 2009 is as follows (in millions):

Securities Lending Invested Collateral

      2010           2009     

Beginning balance, Jan. 1

  $—      $0.1  

Purchases, sales and settlements, net

   —       (0.1
          

Ending balance, Dec. 31

  $—      $—    
          

For the above table, $7 millionvarious defined benefit pension and other postretirement benefits plans, Alliant Energy’s common stock represented less than 1% of amortizations are expected in 2009 from “Regulatory assets” associated with Corporate Services employees participating in Alliant Energy sponsored plans allocated to WPL.total plan assets at Dec. 31, 2010 and 2009.

Cash Balance Pension Plan -Alliant Energy’s defined benefit pension plans include a cash balance plan that covers substantially all of itsprovides benefits for certain non-bargaining unit employees. The cash balance plan has been closed to new hires since 2005. Effective August 2008, Alliant Energy amended the cash balance plan by discontinuing additional contributions into employees’ cash balance plan accounts. Also effective August 2008, Alliant Energy increased its level of contributions to theits 401(k) Savings Plan, which offset the impact of discontinuing additional contributions into the employees’ cash balance plan accounts. These amendments are designed to provide employees portability and self-directed flexibility of their retirement benefits. These changes did not have a significant impact on WPL’s results of operations. In 2009, Alliant Energy amended the cash balance plan by changing the participants’ future interest credit formula to use the annual change in consumer price index as the interest credit. This amendment is designed to provide participants an interest crediting rate that will always be 3% more than the annual change in the cost of living. Refer to Note 12(c) for discussion of a class action lawsuit filed against the Alliant Energy Cash Balance Pension Plan in 2008 and the IRS review of the tax qualified status of the Plan.

401(k) Savings Plan -A significant number of WPL employees participate in a defined contribution retirement plan (401(k) Savings Plan)savings plan). The number of employees participating in this plan has increased recently as certain bargaining unit employees have elected to participate in defined contribution retirement plans instead of defined benefit pension plans. In 2009, WPL implemented several cost saving initiatives to reduce other operation and maintenance expenses, including suspension of a portion of 401(k) savings plan contributions during the second half of 2009. In 2010, 2009 and 2008, 2007 and 2006, WPL’s contributionscosts related to

the 401(k) savings plan, which are partially based on the participants’ level of contribution, were $8.9 million, $4.3 million and $3.7 million, $2.5 million and $2.5 million, respectively.

(b) Equity Incentive Plans -In May 2010, Alliant Energy’s 2002 Equityshareowners approved the Alliant Energy 2010 Omnibus Incentive Plan (EIP)(OIP), which permits the grant of incentive stock options, non-qualified stock options, stock appreciation rights, restricted stock, restricted stock units, performance shares, and performance units, and other stock-based awards and cash incentive awards to key employees. The OIP authorizes the issuance of up to 4,500,000 shares of Alliant Energy’s common stock. As of Dec. 31, 2010, there were no grants issued under the OIP. Upon shareowner approval of the OIP, the Alliant Energy 2002 Equity Incentive Plan (EIP) terminated resulting in no new awards authorized to be granted under the EIP. All awards previously granted under the EIP that are still outstanding remain valid and continue to be subject to all of the terms and conditions of the EIP. At Dec. 31, 2008,2010, non-qualified stock options, restricted stock and performance shares were outstanding under the EIP and aanother predecessor plan under which new awards can no longer be granted.

A summary of share-based compensation expense related to grants under the EIP that was allocated to WPL and the related income tax benefits recognized for share-based compensation awards was as follows (in millions):

 

  2008  2007  2006      2010           2009           2008     

Share-based compensation expense

  $1.2  $3.6  $4.5  $3.0    $1.1    $1.2  

Income tax benefits

   0.5   1.4   1.8   1.2     0.4     0.5  

Share-based compensation expense is recognized on a straight-line basis over the requisite service periods.

(7) COMMON EQUITY AND PREFERRED STOCK

(a) Common StockEquity -

Dividend Restrictions - - WPL has common stock dividend payment restrictions based on the terms of its outstanding preferred stock and applicable regulatory limitations. InAt Dec. 31, 2010, WPL was in compliance with all such dividend restrictions.

WPL is restricted from paying common stock dividends to its January 2007 rateparent company, Alliant Energy, if for any past or current dividend period, dividends on its preferred stock have not been paid, or declared and set apart for payment. WPL has paid all dividends on its preferred stock through 2010.

WPL’s most significant regulatory limitation on distributions to its parent company is included in an order issued by the PSCW statedin December 2009 that prohibits WPL may not payfrom paying annual common stock dividends including pass-through of subsidiary dividends, in excess of $91$112 million to Alliant Energy if WPL’s actual average common stock equity ratio on a financial basis, is or will fall below the test year authorized level of 51.0%51.01%. WPL’s dividends are also restricted to the extent that such dividend would reduce theWPL’s common stock equity ratio to less than 25%. AtAs of Dec. 31, 2008, 2010, WPL’s amount of retained earnings that were free of restrictions was $112 million for 2011.

Restricted Net Assets -WPL does not have regulatory authority to lend or advance any amounts to its parent company. As of Dec. 31, 2010 and 2009, the amount of WPL’s net assets that were not available to be transferred to its parent company in the form of loans, advances or cash dividends without the consent of WPL’s regulatory authorities was in compliance with all such dividend restrictions.$1.3 billion and $1.1 billion, respectively.

Capital Transactions -In 2010, 2009 and 2008, WPL paid common stock dividends of $110 million, $91 million $191and $91 million, respectively, to its parent. In 2010, 2009 and $92 million to Alliant Energy during 2008, 2007 and 2006, respectively. In 2007, WPL’s common stock dividends to Alliant Energy included a $100 million dividend to realign WPL’s capital structure. WPL received capital contributions of $75 million, $100 million $0 and $43$100 million, respectively, from its parent, Alliant Energy, during 2008, 2007 and 2006, respectively.parent.

(b) Preferred Stock- The Information related to the carrying value of WPL’s cumulative preferred stock (none are mandatorily redeemable) at both Dec. 31 2008was as follows (dollars in millions):

Liquidation Preference/
Stated Value

  Authorized
Shares
  Shares
Outstanding
  Series  Redemption      2010          2009     
$100    (a)    99,970    4.50  Any time   $10.0   $10.0  
$100    (a)    74,912    4.80  Any time    7.5    7.5  
$100    (a)    64,979    4.96  Any time    6.5    6.5  
$100    (a)    29,957    4.40  Any time    3.0    3.0  
$100    (a)    29,947    4.76  Any time    3.0    3.0  
$100    (a)    150,000    6.20  Any time    15.0    15.0  
$25    (a)    599,460    6.50  Any time    15.0    15.0  
            
     $60.0   $60.0  
            

(a)WPL has 3,750,000 authorized shares in total.

The articles of incorporation of WPL contain a provision that grants the holders of its preferred stock voting rights to elect a majority of WPL’s Board of Directors if preferred dividends equal to the annual dividend requirements are in arrears. The exercise of such voting rights would provide the holders of WPL’s preferred stock control of the decision on redemption of WPL’s preferred stock and 2007 was $60 million. could force WPL to exercise its call option. Therefore, the contingent control right and the embedded call option cause WPL’s preferred stock to be presented outside of total equity on the Consolidated Balance Sheets in a manner consistent with temporary equity.

Refer to Note 10 for information on the fair value of WPL’s cumulative preferred stock.

(8) DEBT

(a) Short-Term Debt - - WPL maintains committed bank lines of credit to provide short-term borrowing flexibility and securitybackstop liquidity for commercial paper outstanding. At Dec. 31, 2008,2010, WPL’s short-term borrowing arrangements included a $240 million revolving credit facility, which expires in November 2012. During the fourth quarter of 2008, WPL became aware that Lehman Brothers Bank (Lehman) may not be able to fund its portion of the commitments under WPL’s credit facility agreement. Therefore Lehman’s total commitment to WPL’s credit facility of $10 million is excluded from the amounts above. Information regarding commercial paper issued under this facility was as follows (dollars(Not Applicable (N/A); dollars in millions):

 

  2008 2007       2010           2009     

At Dec. 31:

       

Commercial paper outstanding

  $43.7  $81.8   $47.4    $—    

Weighted average interest rates - commercial paper

   1.4%  4.7%   0.3%     N/A  

For the year ended:

       

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

  $63.7  $68.0 

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

  $170.2    $103.1  

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

  $36.6    $26.4  

Weighted average interest rates - total short-term debt

   3.0%  5.4%   0.3%     0.5%  

WPL’s credit facility agreement contains a financial covenant that requires it to maintain a debt-to-capital ratio of less than 58% in order to borrow under the credit facility. At Dec. 31, 2010, WPL’s actual debt-to-capital ratio was 46%.

The debt component of the capital ratio includes long- and short-term debt (excluding non-recourse debt and hybrid securities to the extent such hybrid securities do not exceed 15% of consolidated capital of the borrower), capital lease obligations, letters of credit, guarantees of the foregoing and new synthetic leases. The equity component excludes accumulated other comprehensive income (loss).

(b) Long-Term Debt - The carrying value of

WPL’s long-term debt, (including current maturities) atnet as of Dec. 31 2008 and 2007 was $783 million and $597 million, respectively. Refer to the Consolidated Statements of Capitalization for details of WPL’s long-term debt and Note 10 for information on the fair value of its long-term debt.

In October 2008, WPL issued $250 million of 7.60% debentures due 2038 and used the proceeds to invest in short-term assets, repay short-term debt and repay at maturity its $60 million, 5.7% debentures. In March 2008, WPL converted pollution control revenue bonds from variable interest rates to fixed interest rates as follows (dollars in millions):

 

Amount
Converted
  Due Dates  Fixed Interest Rate 
$24.5  2014 and 2015  5%
$14.6  2015  5.375%
   2010  2009 

Debentures:

   

5%, due 2019

  $250.0   $250.0  

4.6%, due 2020 (a)

   150.0    —    

6.25%, due 2034

   100.0    100.0  

6.375%, due 2037

   300.0    300.0  

7.6%, due 2038

   250.0    250.0  

7.625% (b)

   —      100.0  
         
   1,050.0    1,000.0  

Pollution Control Revenue Bonds:

   

5%, due 2014 and 2015

   24.5    24.5  

5.375%, due 2015

   14.6    14.6  
         
   39.1    39.1  
         

Subtotal

   1,089.1    1,039.1  

Current maturities

   —      (100.0

Unamortized debt (discount) and premium, net

   (7.4  (7.5
         

Long-term debt, net

  $1,081.7   $931.6  
         

WPL’s unamortized debt issuance costs recorded in “Deferred charges and other” on the Consolidated Balance Sheets at Dec. 31, 2008 and 2007 were $7.1 million and $4.8 million, respectively.
(a)In June 2010, WPL issued $150 million of 4.6% debentures due 2020. The proceeds from the June 2010 debt issuance were used initially to repay short-term debt and invest in short-term assets, and thereafter to fund capital expenditures and for general working capital purposes.
(b)In March 2010, WPL retired $100 million of its 7.625% debentures.

Five-Year Schedule of Debt Maturities - At Dec. 31, 2008,2010, WPL’s debt maturities for 20092011 to 20132015 were $0, $100 million, $0, $0, $8 million and $0,$31 million, respectively. Depending upon market conditions, it is currently anticipated that a majority of the maturing debt will be refinanced with the issuance of long-term securities and/or the issuance of short-term debt. At Dec. 31, 2008, there were no significant sinking fund requirements

Indentures - WPL maintains an indenture related to the long-term term debt on the Consolidated Balance Sheet.its debentures due 2019 through 2038.

WPL maintains indentures related to the issuance of unsecured debt securities. Optional Redemption Provisions -WPL has certain issuances of long-term debt that contain optional redemption provisions which, if elected by WPL,the issuer at its sole discretion, could require material redemption premium payments by WPL.the issuer. The redemption premium payments under these optional redemption provisions are variable and dependent on applicable U.S. Treasury rates at the time of redemption. At Dec. 31, 2008,2010, the debt issuances that contained these optional redemption provisions included WPL’s debentures due 20342019 through 2038.

Unamortized Debt Issuance Costs - WPL’s unamortized debt issuance costs recorded in “Deferred charges and other” on the Consolidated Balance Sheets at Dec. 31, 2010 and 2009 were $9.1 million and $8.5 million, respectively.

Carrying Amount and Fair Value of Long-term Debt - Refer to Note 10 for information on the carrying amount and fair value of WPL’s long-term debt outstanding at Dec. 31, 2010 and 2009.

(9) INVESTMENTS

(a) Unconsolidated Equity Investments -WPL’s unconsolidated investments accounted for under the equity method of accounting are as follows (dollars in millions):

 

  Ownership Carrying Value     
  Ownership
Interest at

Dec. 31, 2008
  Carrying Value
at Dec. 31,
  Equity Income   Interest at at Dec. 31,   Equity (Income) / Loss 
   2008  2007  2008 2007 2006   Dec. 31, 2010   2010       2009       2010     2009     2008   

ATC (a)

  16% $195  $172  ($32) ($27) ($24)   16%   $228    $219    ($37 ($36 ($32

Wisconsin River Power Company

  50%  9   10  (2) (1) (3)   50%    8     8     (1  (1  (2
                                    
   $204  $182  ($34) ($28) ($27)   $236    $227    ($38 ($37 ($34
                                    

 

(a)WPL has the ability to exercise significant influence over ATC’s financial and operating policies through its participation on ATC’s Board of Directors. Refer to Note 19 for information regarding related party transactions with ATC.

Summary financial information from the financial statements of these investments is as follows (in millions):

 

  2008  2007  2006  2010   2009   2008 

Operating revenues

  $474  $416  $347  $564    $529    $474  

Operating income

   260   213   163   308     294     260  

Net income

   192   157   128   221     215     192  

As of Dec. 31:

            

Current assets

   53   52     63     54    

Non-current assets

   2,499   2,208     2,906     2,786    

Current liabilities

   253   318     429     286    

Non-current liabilities

   1,233   1,010     1,263     1,340    

(b) Cash Surrender Value of Life Insurance Policies - - WPL has various life insurance policies that cover certain current and former employees and directors. At Dec. 31, 20082010 and 2007,2009, the cash surrender value of these investments was $13.4$12.4 million and $13.1$14.0 million, respectively.

(10) FAIR VALUE MEASUREMENTS

Fair Value of Financial Instruments -The carrying amountamounts of WPL’s current assets and current liabilities approximatesapproximate fair value because of the short maturity of such financial instruments. Carrying amounts and the related estimated fair values of other financial instruments at Dec. 31, are2010 and 2009 were as follows (in millions):

  2008  2007  Carrying
Amount
   Fair
Value
 

Dec. 31, 2010

    

Assets:

    

Derivative assets (Note 11(a))

  $8.0    $8.0  

Capitalization and liabilities:

    

Long-term debt (Note 8(b))

   1,081.7     1,219.6  

Cumulative preferred stock (Note 7(b))

   60.0     56.0  

Derivative liabilities (Note 11(a))

   43.3     43.3  
  Carrying
Amount
  Fair
Value
  Carrying
Amount
  Fair
Value

Dec. 31, 2009

    

Assets:

            

Cash equivalents

   18.1     18.1  

Derivative assets (Note 11(a))

  $20  $20  $15  $15   15.3     15.3  

Capitalization and liabilities:

            

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

   783   862   597   621   1,031.6     1,125.9  

Cumulative preferred stock (Note 7(b))

   60   50   60   55   60.0     50.6  

Derivative liabilities (Note 11(a))

   15   15   8   8   66.3     66.3  

Valuation Techniques -

Cash equivalents- Cash equivalents include money market fund investments, which are measured at fair value each reporting date using quoted market prices on listed exchanges.

Derivative assets and derivative liabilities - DerivativeAs of Dec. 31, 2010 and 2009, derivative assets and derivative liabilities include electricityincluded swap contracts, option contracts, and physical forward purchase and sale contracts for electricity and natural gas, swap contracts, financial transmission rights (FTRs) and embedded foreign currency derivatives. Substantially all of WPL’s electricityswap, option and natural gas swapphysical forward commodity contracts arewere non-exchange-based derivativesderivative instruments valued using indicative price quotations available through a pricing vendor that provides daily exchange forward price settlements, from broker or dealer quotations or from on-line exchanges. The indicative price quotations reflected the average of the bid-ask mid-point prices and were obtained from sources believed to provide the most liquid market for the commodity. WPL corroboratescorroborated a portion of these indicative price quotations using quoted prices for similar assets or liabilities in active markets. Themarkets and categorized derivative instruments based on such indicative price quotations reflect the average of the bid-ask midpoint pricesas Level 2. WPL’s commodity contracts that were valued using indicative price quotations based on significant assumptions such as seasonal or monthly shaping and are obtained from sources believed to provide the most liquid market for the commodity.indicative price quotations that could not be readily corroborated were categorized as Level 3. WPL’s electricityswap, option and natural gas swaps arephysical forward commodity contracts were predominately at liquid trading points. WPL’s financial transmission rights areFTRs were measured at fair value each reporting perioddate using monthly or annual auction shadow prices from relevant auctions. The embedded foreign currency derivatives related to Euro-denominated payment terms included in the wind turbine supply contract with Vestas-American Wind Technology, Inc. (Vestas) areVestas were measured at fair value each reporting period using an extrapolation of forward currency rates. Refer to Note 11(a) for additional details of WPL’s derivative assets and derivative liabilities.

Long-term debt (including current maturities) - TheFor long-term debt instruments that are actively traded, the fair value was based upon quoted market prices each year end.reporting date. For long-term debt instruments that are not actively traded, the fair value was based on discounted cash flow methodology and utilizes assumptions of current market pricing curves. Refer to Note 8(b) and the Consolidated Statements of Capitalization for additional details of WPL’sinformation regarding long-term debt.

Cumulative preferred stock -The fair value of WPL’s 4.50% cumulative preferred stock was based on the closing market prices quoted by the NYSE Alternext USAmex LLC each year end.reporting date. The fair value of WPL’s remaining preferred stock was calculated based on the market yield of similar securities. Refer to Note 7(b) for additional details of WPL’sinformation regarding cumulative preferred stock.

Adoption of SFAS 157Valuation Hierarchy -Effective Jan. 1, 2008, WPL partially adopted SFAS 157, which primarily requires expanded disclosure for assets and liabilities recorded on the balance sheet at fair value. As permitted by FSP SFAS 157-2, WPL has elected to defer the adoption of the nonrecurring fairFair value measurement disclosures of nonfinancial assets and liabilities, such as asset retirement obligations, until Jan. 1, 2009. The partial adoption of SFAS 157 did not have a material impact on WPL’s financial condition and results of operations. Refer to Note 1(q) for additional information on SFAS 157.

Valuation Hierarchy -SFAS 157accounting establishes a fair value hierarchy that prioritizes the inputs to valuation techniques used to measure fair value. The three levels of the fair value hierarchy and examples of each are as follows:

Level 1 -Pricing inputs are quoted prices available in active markets for identical assets or liabilities as of the reporting date. Level 1 assets as of Dec. 31, 2009 included cash equivalents.

Level 2 -Pricing inputs are quoted prices for similar asset or liabilities in active markets or quoted prices for identical or similar assets or liabilities in markets that are not active as of the reporting date. Level 2 assets and liabilities includeas of Dec. 31, 2010 and 2009 included non-exchange traded derivatives such as electricity and natural gas swapcommodity contracts utilized by WPL.valued using indicative price quotations that are corroborated with quoted prices for similar assets or liabilities in active markets.

Level 3 -Pricing inputs are unobservable inputs for assets or liabilities for which little or no market data exist and require significant management judgment or estimation. Level 3 assets and liabilities include WPL’s financial transmission rightsas of Dec. 31, 2010 and 2009 included FTRs, natural gas option contracts, embedded foreign currency derivatives.derivatives and certain commodity contracts that are valued using indicative price quotations based on significant assumptions such as seasonal or monthly shaping.

The fair value hierarchy gives the highest priority to quoted prices in active markets (Level 1) and the lowest priority to unobservable data (Level 3). In some cases, the inputs used to measure fair value might fall in different levels of the fair value hierarchy. The lowest level input that is significant to a fair value measurement in its entirety determines the applicable level in the fair value hierarchy. Assessing the significance of a particular input to the fair value measurement in its entirety requires judgment, considering factors specific to the asset or liability.

Recurring Fair Value Measurements -Disclosure requirements for WPL’s recurring items subject to fair value measurements subject to the disclosure requirements of SFAS 157 at Dec. 31, 20082010 and 2009 were as follows (in millions):

 

   Fair Value
Measurements
at Dec. 31, 2008
  Level 1  Level 2  Level 3

Derivative assets

  $19.6  $—    $1.0  $18.6

Derivative liabilities

   14.8   —     10.6   4.2
   Dec. 31, 2010   Dec. 31, 2009 
   Fair
  Value  
     Level  
1
     Level  
2
     Level  
3
   Fair
  Value  
     Level  
1
     Level  
2
     Level  
3
 

Assets:

                

Cash equivalents

  $—      $—      $—      $—      $18.1    $18.1    $—      $—    

Derivative assets:

                

Commodity contracts

   8.0     —       6.4     1.6     15.3     —       11.5     3.8  

Liabilities:

                

Derivative liabilities:

                

Commodity contracts

   43.2     —       40.1     3.1     64.8     —       62.2     2.6  

Foreign exchange contracts

   0.1     —       —       0.1     1.5     —       —       1.5  
                                        

Total derivative liabilities

   43.3     —       40.1     3.2     66.3     —       62.2     4.1  

Additional information for WPL’s recurring fair value measurements using significant unobservable inputs (Level 3 inputs) for 2008 is as2010 and 2009 was follows (in millions):

 

   Derivative Assets
and Liabilities, net
 

Beginning balance, Jan. 1, 2008

  $12.7 

Total gains or (losses) (realized/unrealized) included in changes in net assets (a)

   20.6 

Purchases, sales, issuances and settlements, net

   (18.9)
     

Ending balance, Dec. 31, 2008

  $14.4 
     

The amount of total gains or (losses) for the period included in changes in net assets attributable to the change in unrealized gains or (losses) relating to assets and liabilities held at Dec. 31, 2008 (a)

  $14.4 
     
   Derivative Assets and (Liabilities), net 
   Commodity
Contracts
  Foreign
Contracts
 
   2010  2009  2010  2009 

Beginning balance, Jan. 1

  $1.2   $8.9   ($1.5 $5.5  

Total gains or (losses) (realized/unrealized) included in changes in net assets (a)

   (1.3  (0.3  —      (0.4

Transfers in and/or out of Level 3 (b)

   (0.3  —      —      —    

Purchases, sales, issuances and settlements, net

   (1.1  (7.4  1.4    (6.6
                 

Ending balance, Dec. 31

  ($1.5 $1.2   ($0.1 ($1.5
                 

The amount of total gains or (losses) for the period included in changes in net assets attributable to the change in unrealized gains or (losses) relating to assets and liabilities held at Dec. 31 (a)

  ($1.3 ($0.3 $—     ($0.4
                 

 

(a)RecordedGains and losses related to derivative assets and derivative liabilities are recorded in “Regulatory assets” and “Regulatory liabilities” on the Consolidated Balance Sheet.Sheets.
(b)Observable market inputs became available for certain commodity contracts previously classified as Level 3. The transfers were valued as of the beginning of the period.

Refer to Notes 1(q) and 10 of the “Notes to Consolidated Financial Statements” for additional information on SFAS 157.

(11) DERIVATIVE INSTRUMENTS

(a) AccountingCommodity and Foreign Exhange Derivatives -

Purpose - WPL periodically uses derivative instruments for Derivative Instrumentsrisk management purposes to mitigate exposures to fluctuations in certain commodity prices, transmission congestion costs and Hedging Activitiescurrency exchange rates. WPL’s derivative instruments as of Dec. 31, 2010 and 2009 were not designated as hedging instruments. WPL’s derivative instruments as of Dec. 31, 2010 and 2009 included electric physical forward purchase contracts and swap contracts to mitigate pricing volatility for the electricity purchased to supply to its customers; electric physical forward sale contracts to offset long positions created by reductions in electricity demand forecasts; natural gas swap contracts to mitigate pricing volatility for the fuel used to supply to the natural gas-fired electric generating facilities it operates; natural gas options to mitigate price increases during periods of high demand or lack of supply; FTRs acquired to manage transmission congestion costs; natural gas physical forward purchase and swap contracts to mitigate pricing volatility for natural gas supplied to its retail customers; and embedded foreign currency derivatives related to Euro-denominated payment terms included in the wind turbine supply contract with Vestas.

Notional Amounts - As of Dec. 31, 2010, WPL had notional amounts related to outstanding swap contracts, option contracts, physical forward contracts and FTRs that were accounted for as derivative instruments as follows (units in thousands):

       2011           2012           2013           Total     

Commodity:

        

Electricity (MWhs)

   2,062     248     204     2,514  

FTRs (MWs)

   12     —       —       12  

Natural gas (dekatherms)

   16,736     9,832     1,060     27,628  

The notional amounts in the above table were computed by aggregating the absolute value of purchase and sale positions within commodities for each year. In 2010, Euro-denominated payment terms included in the wind turbine supply contract with Vestas were converted to U.S. dollars.

Financial Statement Presentation -WPL records derivative instruments at fair value each reporting date on the balance sheet as assets or liabilities. WPL generally records changes in the derivatives’ fair values with offsets to regulatory assets or liabilities, based on the fuel and natural gas cost recovery mechanisms in place, as well as other specific regulatory authorizations. At Dec. 31, 20082010 and 2007,2009, the fair values of current derivative assets were included in “Derivative assets,” non-current derivative assets were included in “Deferred charges and other,” current derivative liabilities were included in “Derivative liabilities” and non-current derivative liabilities were included in “Other long-term liabilities and deferred credits” on the Consolidated Balance Sheets as follows (in millions):

 

  2008  2007      2010           2009     

Current derivative assets

  $10.7  $14.9    

Commodity contracts

  $6.5    $11.2  

Non-current derivative assets

   8.9   —      

Commodity contracts

  $1.5    $4.1  

Current derivative liabilities

   8.6   7.7    

Commodity contracts

  $32.2    $49.5  

Foreign exchange contracts

   0.1     1.5  
        
  $32.3    $51.0  
        

Non-current derivative liabilities

   6.2   —      

Commodity contracts

  $11.0    $15.3  

Changes inWPL generally records gains and losses from its derivative instruments with offsets to regulatory assets or regulatory liabilities, based on its fuel and liabilitiesnatural gas cost recovery mechanisms, as well as other specific regulatory authorizations. Gains and losses from derivative instruments not designated as hedging instruments were recorded as follows (in millions):

   

Location Recorded

on Balance Sheets

  Gains (Losses) 
         2010          2009     

Commodity contracts

  Regulatory assets  ($30.6 ($68.1

Commodity contracts

  Regulatory liabilities   0.9    12.7  

Foreign exchange contracts

  Regulatory liabilities   —      (0.4

Losses from commodity contracts during 20082010 and 2009 were primarily due to impacts of decreases in electricity and natural gas and electricity price fluctuations, financial transmission rights acquired in the second quarter of 2008 and foreign currency exchange rate fluctuations.prices during such periods.

Derivatives Not Designated in Hedge RelationshipsCredit Risk-related Contingent Features -WPL has periodically utilizedentered into various agreements that contain credit risk-related contingent features including requirements for it to maintain certain credit ratings from each of the major credit rating agencies and limitations on its liability positions under the various agreements based upon its credit ratings. In the event of a downgrade in its credit ratings or if its liability positions exceed certain contractual limits, WPL may need to provide credit support in the form of letters of credit or cash collateral up to the amount of its exposure under the contracts, or may need to unwind the contracts and pay the underlying liability positions.

Certain of these agreements with credit risk-related contingency features are accounted for as derivative instruments, which have not been designatedinstruments. The aggregate fair value of all derivatives with credit risk-related contingent features that were in hedge relationships. WPL’sa net liability position on Dec. 31, 2010 was $43.3 million. At Dec. 31, 2010, WPL had investment-grade credit ratings. If the most restrictive credit risk-related contingent features for derivative instruments include electricity swap contractsagreements in a net liability position were triggered on Dec. 31, 2010, WPL would be required to mitigate pricing volatility for electricity suppliedpost $43.3 million of credit support to its customers, natural gas swap contracts to supply fixed-price natural gas for the natural gas-fired electric generating facilities it operates, financial transmission rights acquired to manage transmission congestion costs, natural gas swap contracts to mitigate pricing volatility for natural gas supplied to its retail customers and embedded foreign currency derivatives related to Euro-denominated payment terms included in the wind turbine supply contract with Vestas.counterparties.

(b) Weather Derivatives -WPL periodically uses non-exchange traded swap agreements based on cooling degree days (CDD) and heating degree days (HDD) measured in or near its service territory to reduce the impact of weather volatility on its electric and natural gas sales volumes. These weather derivatives are accounted for using the intrinsic value method. Any premiums paid related to these weather derivative agreements are expensed over each respective contract period. WPL’s ratepayers do not pay any of the premiums nor do they share in the gains or losses realized from these weather derivatives.

Summer weather derivatives- WPL periodically utilizes weather derivatives based on CDD to reduce the impact of weather volatility on its electric margins for June 1 tothrough Aug. 31 each year. Beginning in the second quarter of 2007, the weatherWeather derivatives wereare based on CDD measured in Madison, Wisconsin. Previously, the weather derivatives were based on CDD measured in Chicago, Illinois. The actual CDD measured during these periods resulted in settlements with the counterparties under the agreements, which included receipts of $2.0 million payments of $2.0 millionin 2008. WPL did not enter into CDD swap agreements in 2010 and payments of $2.9 million in the third quarter of 2008, 2007 and 2006, respectively.2009.

Winter weather derivatives - WPL periodically utilizes weather derivatives based on HDD to reduce the impact of weather volatility on its electric and gas margins for Jan. 1 tothrough March 31 and Nov. 1 tothrough Dec. 31 each calendar year. Beginning in the fourth quarter of 2006, the weatherWeather derivatives wereare based on HDD measured in Madison, Wisconsin. Previously, the weather derivatives were based on HDD measured in Chicago, Illinois. The actual HDD measured during these periods resulted in settlements with the counterparties under the agreements, which included payments of $3.4 million and $3.6 million payments of $0.1 millionin 2009 and receipts of $3.2 million2008, respectively. WPL did not enter into any HDD swap agreements in the first half of 2008, 2007 and 2006, respectively. The actual HDD for Nov. 1, 2008 to Dec. 31, 2008 were higher than those specified in the contracts, resulting in WPL paying the counterparty $1.4 million in January 2009. In addition, WPL will receive or pay up to $2.0 million from or to the counterparty in the second quarter of 2009 if actual HDD for Jan. 1, 2009 to March 31, 2009 are less or greater than the HDD specified in the contract.2010.

The counterparties to certain of these contracts were required to provide cash collateral to WPL. At both Dec. 31, 2008 and 2007, outstanding cash collateral received by WPL of $1.4 million was recorded in “Accounts payable” on the Consolidated Balance Sheets.

Summary information relating to the summer and winter weather derivatives was as follows (in millions):

 

  2008 2007 2006       2010           2009         2008     

Gains (losses):

         

Electric utility operating revenues

  $0.6  ($3.0) ($1.4)  $—      ($0.8 $0.6  

Gas utility operating revenues

   (2.2) (1.9)  3.8    —       (1.2  (2.2

Settlements (paid to) / received from counterparties, net

   (1.6) (2.1)  0.3    —       (3.4  (1.6

Premiums expensed

   —    0.5   0.3    —       —      —    

Premiums paid to counterparties

   —    0.5   0.5    —       —      —    

(12) COMMITMENTS AND CONTINGENCIES

(a) Capital Purchase Obligations -WPL has entered into capital purchase obligations that contain minimum future commitments related to certain capital expenditures for its proposed wind projects. The obligations are primarily related to capital purchase obligations under a master supply agreement executed in the second quarter of 2008 with Vestas for the purchase of 500 MW of wind turbine generator sets and related equipment to support IPL’s and WPL’s wind generation plans. A portion of the future payments are denominated in Euros and therefore are subject to change with fluctuations in currency exchange rates. In addition, the master supply agreement includes pricing terms that are subject to change if steel prices change by more than 10% between measurement dates defined in the master supply agreement. The amounts included in the table below reflect currency exchange rates and steel prices at Dec. 31, 2008. At Dec. 31, 2008,2010, WPL’s minimum future commitments related to these capital expenditures were as follows
(in millions):$25 million for 2011.

2009  2010  2011  Total
$132  $301  $43  $476

In September 2008 and April 2008, WPL received approval from FERC and the PSCW, respectively, to purchase Resources’ 300 MW, simple-cycle, dual-fueled (natural gas/diesel) electric generating facility in Neenah, Wisconsin. WPL currently plans to acquire the Neenah Energy Facility for $95 million effective June 1, 2009.

(b) Operating Expense Purchase Obligations -Alliant Energy, through its subsidiaries Corporate Services, Interstate Power and Light Company (IPL) and WPL entershas entered into various commodity supply, transportation and storage contracts to meet its obligationobligations to deliver energyelectricity and natural gas to its customers. WPL also enters into other operating expense purchase obligations with various vendors for other goods and services. At Dec. 31, 2008,2010, WPL’s minimum future commitments related to these operating expense purchase obligations were as follows (in millions):

  2009  2010  2011  2012  2013  Thereafter  Total      2011           2012           2013           2014           2015       Thereafter   Total 

Purchased power (a):

                            

Kewaunee

  $83  $83  $62  $73  $79  $—    $380

Kewaunee Nuclear Power Plant (Kewaunee)

  $61    $72    $77    $—      $—      $—      $210  

Other

   132   74   12   —     —     —     218   16     3     —       —       —       —       19  
                                                 
   215   157   74   73   79   —     598   77     75     77     —       —       —       229  

Natural gas

   149   42   22   21   18   46   298   76     43     27     17     13     21     197  

Coal (b)

   11   10   7   7   14   —     49   7     7     7     8     —       —       29  

Other (c)

   5   3   1   —     —     —     9   9     8     7     1     —       —       25  
                                                 
  $380  $212  $104  $101  $111  $46  $954  $169    $133    $118    $26    $13    $21    $480  
                                                 

 

(a)Includes payments required by purchased power contractsPPAs for capacity rights and minimum quantities of MWh required to be purchased. Based on a system coordination and operating agreement, Alliant Energy periodically allocates purchased power contracts to WPL, based on various factors such as resource mix, load growth and resource availability. The amounts in the table reflect these allocated contracts. Refer to Note 19 for additional information regarding the allocation ofon purchased power transactions.

 

(b)WPL enters into coal transportation contracts that are directly assigned to its specific generating stations, the amounts of which are included in the table. In addition, Corporate Services entered into system-wide coal contracts on behalf of WPL and IPL of $111$119 million, $99 million, $87$48 million and $7$39 million for 20092011 to 2012,2013, respectively, to allow flexibility for the changing needs of the quantity of coal consumed by each. Coal contract quantities are allocated to specific WPL or IPL 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 WPL and IPL since the specific needs of each utility arewere not yet known as of Dec. 31, 2010 and therefore are excluded from the table.

 

(c)Includes individual commitments incurred during the normal course of business that exceeded $1 million at Dec. 31, 2008.2010.

WPL enters into certain contracts that are considered leases and are therefore not included here, but are included in Note 3.

(c)(c) Legal Proceedings -

Air Permitting Violation Claims -In September 2010, Sierra Club filed in U.S. District Court for the Western District of Wisconsin a complaint against WPL, as owner and operator of the Nelson Dewey Generating Station (Nelson Dewey) and the Columbia Energy Center (Columbia), based on allegations that modifications were made at the facilities without complying with the Prevention of Significant Deterioration (PSD) program requirements, Title V Operating Permit requirements of the Clean Air Act (CAA) and state regulatory counterparts contained within the Wisconsin state implementation plans (SIPs) designed to implement the CAA. In October 2010, WPL responded to these claims related to Nelson Dewey and Columbia by filing with the U.S. District Court an answer denying the Columbia allegations and a motion to dismiss the Nelson Dewey allegations based on statute of limitations arguments. In November 2010, WPL filed a motion to dismiss the Nelson Dewey and Columbia allegations based on lack of jurisdiction. Sierra Club has responded to the motions. WPL and Sierra Club are currently exchanging and responding to discovery requests. In February 2011, WPL and Sierra Club filed a joint motion for stay of proceedings for 90 days to explore settlement options, which the U.S. District Court granted in part and denied in part. The trial date has been rescheduled to April 2012. In September 2010, Sierra Club filed in U.S. District Court for the Eastern District of Wisconsin a complaint against WPL, as owner and operator of the Edgewater Generating Station (Edgewater), which contained similar allegations regarding air permitting violations at Edgewater. In February 2011, WPL responded to these claims related to Edgewater by filing with the U.S. District Court an answer denying the allegations and a motion to dismiss the allegations based on lack of jurisdiction. In February 2011, WPL and Sierra Club filed a joint motion for stay of proceedings for 90 days to explore settlement options, of which the U.S. District Court has not yet ruled. No trial date or scheduling order has yet been set. The complaints filed by Sierra Club allege that various projects performed at Nelson Dewey, Columbia and Edgewater in the past were major modifications, as defined in the CAA, and that the owners violated the CAA when they undertook those projects without obtaining permits and installing the best available emission controls for SO2, NOx and particulate matter. In the Edgewater complaint, additional allegations were made regarding violations of emission limits for visible emissions.

In December 2009, the EPA sent a Notice of Violation (NOV) to WPL as an owner and the operator of Edgewater, Nelson Dewey and Columbia. The NOV alleges that the owners failed to comply with appropriate pre-construction review and permitting requirements and as a result violated the PSD program requirements, Title V Operating Permit requirements of the CAA and the Wisconsin SIP.

In response to similar EPA CAA enforcement initiatives, certain utilities have elected to settle with the EPA, while others have elected to litigate. If the EPA and/or Sierra Club successfully prove their claims that projects completed in the past at Edgewater, Nelson Dewey and Columbia required either a state or federal CAA permit, WPL may, under the applicable statutes, be required to pay civil penalties in amounts of up to $37,500 per day for each violation and/or complete actions for injunctive relief. Payment of fines and/or injunctive relief could be included in a settlement outcome. Injunctive relief contained in settlements or court-ordered remedies for other utilities required the installation of pollution control technology, changed operating conditions including use of alternative fuels other than coal, caps for emissions and limitations on generation including retirement of generating units, and other supplemental environmental projects. Should similar remedies be required for final resolution of these matters at Edgewater, Nelson Dewey and Columbia, WPL would incur additional capital and operating expenditures. WPL is currently reviewing the allegations and is unable to predict the impact of the allegations on its financial condition or results of operations, but believes that an adverse outcome could be significant. WPL and the other owners of Edgewater and Columbia are exploring settlement options while simultaneously defending against these allegations. WPL believes the projects at Edgewater, Nelson Dewey and Columbia were routine or not projected to increase emissions and therefore did not violate the permitting requirements of the CAA. WPL does not currently believe any losses from these allegations are both probable and reasonably estimated and therefore has not recognized any related loss contingency amounts as of Dec. 31, 2010.

Alliant Energy Cash Balance Pension Plan (Plan) -In February 2008, a class action lawsuit was filed against the Plan.Plan in U.S. District Court for the Western District of Wisconsin (Court). The complaint alleges that certain Plan participants who received a lump sum distributiondistributions prior to their normal retirement age did not receive the full benefit to which they were entitled in violation of the Employee Retirement Income Security Act of 1974 because the Plan applied an improper interest crediting rate to project the cash balance account to their normal retirement age. These Plan participants are limited to individuals who, prior to normal retirement age, received a lump sum distribution and/or received any form of distribution calculated under the Plan’s prior formula after that benefit was determined to be more valuable than their benefit calculated under the Plan’s cash balance formula. The courtCourt has certified two subclasses of plaintiffs that in aggregate include all persons vested or partially vested in the Plan who received a lump sum distributionthese distributions from Jan. 1, 1998 through Aug. 17, 2006 including: 1) persons who received distributions from Jan. 1, 1998 through Feb. 28, 2002; and 2) persons who received distributions from Feb. 29, 2002 through Aug. 17, 2006. In June 2010, the Court issued an opinion and order that granted the plaintiffs’ motion for summary judgment on liability in the lawsuit and decided with respect to damages that prejudgment interest on damages will be allowed at the prime rate at the time of the judgment. A bench trial on the issue of damages was held in June 2010, at which the Court heard evidence on issues related to the amount of damages. In December 2010, the Court issued an opinion and order that decided the interest crediting rate that the Plan used to project the cash balance formula benefit since January 1998. The first subclass includes individuals who received lump-sum payouts before Feb. 29, 2002, whose claimsaccounts of the plaintiffs during the class period should have been 8.2% and a pre-retirement mortality discount will not apply to the damages calculation. Based on this opinion and order, the Plan currently believes that the final judgment of damages by the Court may be susceptibleup to a statute of limitations defense.$23 million, which does not include any award for plantiff’s attorney’s fees or costs. The second subclass includes individuals who received payouts on or after Feb. 29, 2002. An adverse outcome of this lawsuit could affect retirement plan funding and expense for WPL. The lawsuit is currently in the discovery phase. Alliant EnergyPlan is contesting the caseCourt’s decision and intends to pursue appropriate appeals after the final judgment is rendered by the Court. WPL has not recognized any potential liability for damages from the lawsuit while this matter is being contested. WPL is currently unable to predict the final outcome of the class action lawsuit or the ultimate impact on WPL’sits financial condition or results of operations orbut believes an adverse outcome could have a material effect on its retirement plan funding and expense.

The interest crediting rate used to project the cash flows. WPL does not currently believe any lossesbalance account to participants’ normal retirement age has also been considered by the IRS as part of its review of Alliant Energy’s request for a favorable determination letter with respect to the tax-qualified status of the Plan. Alliant Energy has reached an agreement with the IRS, which is expected to result in a favorable determination letter for the Plan. The agreement with the IRS is expected to require an amendment to the Plan, which will likely result in future payments to certain Plan participants. Any future payments to Plan participants resulting from this lawsuit are probable and therefore has notan amendment to the Plan will be recognized any related loss contingency amounts as of Dec. 31, 2008.in the period the amendment is executed.

OtherOther- - WPL is involved in other 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, WPL 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 or cash flows.operations.

(d)Guarantees and Indemnifications - - Refer to Note 3(a) for discussion of WPL’s residual value guarantees of its synthetic leases.

(e) Environmental Matters -WPL is subject to environmental regulations as a result of its current and past operations. These regulations are designed to protect public health and the environment and have resulted in compliance, remediation, containment and monitoring obligations, which are recorded as environmental liabilities. At Dec. 31, current environmental liabilities were included in “Other current liabilities” and non-current environmental liabilities were included in “Other long-term liabilities and deferred credits” on the Consolidated Balance Sheets as follows (in millions):

 

  2008  2007      2010           2009     

Current environmental liabilities

  $0.7  $0.7  $0.3    $0.5  

Non-current environmental liabilities

   5.2   5.5   4.1     4.0  
              
  $5.9  $6.2  $4.4    $4.5  
              

Manufactured gas plant (MGP)MGP Sites -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. WPL has received letters from state environmental agencies requiring no further action at seveneight sites. WPL is working pursuant to the requirements of various federal and state agencies to investigate, mitigate, prevent and remediate, where necessary, the environmental impacts to property, including natural resources, at and around the sites in order to protect public health and the environment.

WPL records environmental liabilities related to these MGP sites based upon periodic studies, most recently updated in the third quarter of 2008.studies. 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. There are inherent uncertainties associated with the estimated remaining costs for MGP projects primarily due to unknown site conditions and potential changes in regulatory agency requirements. 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 incurred 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 WPL’s sites to be $5$3 million to $7$5 million. At Dec. 31, 2008,2010, WPL had recorded $6$4 million in current and non-current environmental liabilities for its remaining costs to be incurred for these MGP sites.

Under the current rate making treatment approved by the PSCW, the MGP expendituresRefer to Note 1(b) for discussion of WPL, net of any insurance proceeds, are deferred and collected from gas customers over a five-year period after new rates are implemented. Regulatoryregulatory assets have been recorded by WPL, which reflect the probable future rate recovery where applicable.of MGP expenditures. Considering the current rate treatment, and assuming no material change therein, WPL 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 WPL’s insurance carriers regarding reimbursement for its MGP-related costs and such amounts have been accounted for as directed by the applicable regulatory jurisdiction.

Other Environmental Contingencies -In addition to the environmental liabilities discussed above, WPL is also monitorsmonitoring various environmental regulations whichthat may have a significant impact on its future operations. Given uncertainties regarding the outcome, timing and compliance plans for these environmental regulations, WPL is currently not able to determine the complete financial impact of these regulations but does believe that future capital investments and/or modifications to its electric generating facilities to comply with these regulations could be significant. Specific current, proposed or proposedpotential environmental regulations that may require significant future expenditures by WPL include, among others: Clean Air Interstate Rule (CAIR), Clean Air Visibility Rule (CAVR), Clean Air Mercury Rule (CAMR), Wisconsin Reasonably Available Control Technology (RACT) Rule, Wisconsin State Mercury Rule, Ozone National Ambient Air Quality Standards Rule, Fine Particle National Ambient Air Quality Standards Rule, Industrial Boiler and Process Heater Case-by-Case Maximum Achievable Control Technology (MACT) Rule, Section 316(b) of the Clean Water Act, the Wisconsin State Thermal Rule and various legislation being considered to regulate the emission of greenhouse gases (GHG). The following providesare included below along with a brief description of these environmental regulations.

Air Quality -

CAIRClean Air Interstate Rule (CAIR) is an emissions trading program that is expected to require sulfur dioxide (SO2)requires SO2 and nitrogen oxides (NOx)NOx emissions reductions at WPL’s fossil fuel-fired electric generating units (EGUs) with greater than 25 MW capacity through installation of air pollutionemission controls and/or purchases of allowances. The requirements for NOx and SO2 reductions started in 2009 and 2010, respectively. The requirements of this ruleCAIR remain subject to further review by the federal courts and the EPA.

Clean Air Transport Rule (CATR)is the EPA’s proposed CAIR replacement rule that would require SO2 and NOx emissions reductions from WPL’s fossil-fueled EGUs with greater than 25 MW of capacity. Existing CAIR compliance requirements remain effective until the final CATR compliance requirements supersedes them, which the EPA currently estimates will occur in 2012. The compliance deadline for CATR is expected to begin in 2012.

CAVRClean Air Visibility Rule (CAVR) addresses regional haze at national parks and wilderness areas and is expected to require reductions in visibility-impairing emissions, including SO2, NOx and particulate SO2, and NOx,matter, from certain electric generating unitsEGUs by installing air pollutionemission controls including those determined to be Best Available Retrofit Technology. The requirements of this ruleCAVR remain subject to further review by the federal courts and the EPA. The CAVR SIPs will determine required compliance actions and deadlines.

CAMRUtility Maximum Achievable Control Technology (MACT) Rule is an emissions trading program that is expected to require standards for the control of mercury emissions reductions at WPL’s electric generating unitsand other federal hazardous air pollutants for coal- and oil-fired EGUs with greater than 25 MW capacity through installation of air pollution controls or purchases of allowances.capacity. The requirements of thisfinal rule remain subjecthas not been issued; however, compliance is currently expected to further reviewbe required by the federal courts and the EPA.2014.

Wisconsin RACTState Mercury Rule is expectedrequires WPL’s existing coal-fired EGUs to requirereduce annual mercury emissions by 40% from a historic baseline beginning in 2010, and to either achieve a 90% annual mercury emissions reduction standard or limit the annual concentration of mercury emissions to 0.008 pounds of mercury per gigawatt-hour beginning in 2015.

Wisconsin Reasonably Available Control Technology Rule requires NOx emissions reductions at WPL’s Edgewater generating facilityto achieve compliance with 2013 requirements since it is located in Sheboygan County, which is currently designated as a non-attainment area for the existing eight-hour ozone standard.

Wisconsin State Mercury Rule requires WPL’s existing coal-fired electric generating facilities to achieve mercury emissions reductions of up to 90% through installation of air pollution controls by 2015, or alternately, an additional six years is allowed for compliance if a multi-pollutant approach is selected that also includes SO2 and NOx emissions reductions.

OzoneOxone National Ambient Air Quality StandardsStandard (NAAQS). WPL installed NOx emission control technologies at Edgewater to meet 2009 to 2012 compliance requirements under this rule.

Ozone NAAQS Rule is expected to reduce the primary standard to a level within a range of 0.06 to 0.07 parts per million and establish a new seasonal secondary standard for EGUs located in areas designated as non-attainment. The final rule is expected to be issued by July 2011 and the schedule for compliance with the Ozone NAAQS Rule has not yet been established.

Fine Particle NAAQS Rule is expected to require SO2 and NOx emissionsemission reductions from electric generating units located in areas designated as non-attainmentnon-attainment. The EPA lowered the 24-hour standard and left the annual standard unchanged. In response to a court decision, the EPA is reviewing whether the annual fine particulate matter standard should also be lowered. The schedule for compliance with the Fine Particle NAAQS Rule has not yet been established.

Nitrogen Dioxide (NO2) NAAQS Rule requires a more stringent eight-hour ozonenew one-hour NAAQS for NO2 at a level of 100 parts per billion (ppb) and associated ambient air monitoring requirements, while maintaining the current annual standard adopted in 2008.of 53 ppb. The EPA’s final designations identifying non-attainment areas for the revised ozone standardNO2 NAAQS are expected to be issued in 2010.2012. The requirements of the NO2 NAAQS Rule remain subject to further review by the federal courts and the EPA and the schedule for compliance has not yet been established.

Fine Particle National Ambient Air Quality StandardsSO2 NAAQS Rule is expected to requirerequires a new one-hour NAAQS for SO2 and NOx emissions reductions in areas designated as non-attainment with the EPA’s 2006 revised fine particulate standard.at a level of 75 ppb. The EPA’s final designations identifying non-attainment areas for the revised fine particulate matter standardSO2 NAAQS are expected beginningto be issued in April 2009.2012. The compliance deadline for SO2 NAAQS is currently expected to be required by 2017 for non-attainment areas.

Industrial Boiler and Process Heater Case-by-Case MACT Rule may requirerequires reductions of emissions of hazardous air pollutants at smaller electric generating unitsEGUs with less than 25 MW capacity, and auxiliary boilers and process heaters located at power plants.EGUs. The requirements of this rule remain subject to further review by the federal courts, the EPA and state environmental agencies.

Proposed GHG Emission Legislation - Public awareness of climate change continues The compliance deadline for the Industrial Boiler and Process Heater MACT rule is currently expected to grow along with support for policymakers to take action to mitigate global warming. Several members of Congress have proposed legislation to regulate GHG emissions, primarily targeting reductions of carbon dioxide (CO2) emissions. State and regional initiatives to address GHG emissions are also underway in states covering WPL’s service territory. WPL continues to take voluntary measures to reduce its GHG emissions, including CO2, as prudent steps to address potential climate change regulations.be 2014.

Water Quality -

Section 316(b) of the Federal Clean Water Act is expected to require modifications to cooling water intake structures at three of WPL’s electric generating facilities to assure that these structures reflect the “best technology available” for minimizing adverse environmental impacts to fish and other aquatic life. The requirements of this rule remain subject to further review by the federal courts and the EPA.EPA and the schedule for compliance has not yet been established. The EPA expects to issue a proposed rule in 2011 and a final rule in 2012.

Wisconsin State Thermal Rule is expected tomay require modifications to certain of WPL’s electric generating facilitiesEGUs to limit the amount of heat those facilities can discharge into Wisconsin waters. Compliance with the thermal rule will be evaluated on a case-by-case basis as discharge permits for WPL’s EGUs are renewed.

Hydroelectric Fish Passages and Fish Protective Devices - FERC issued an order requiring WPL’s Prairie du Sac hydro plant to install an agency-approved fish passage at the facility by December 2012. WPL currently expects to request an extension from FERC in 2011.

Land and Solid Waste -

Coal Combustion Residuals (CCR)could impose additional requirements for CCR management, beneficial use applications and disposal including operation and maintenance of active surface impoundments (ash ponds) and/or landfills. The requirementsEPA issued a proposed regulation for public comment in 2010, and a final rule is expected by early 2012. The schedule for compliance with the CCR Rule has not yet been established.

Polychlorinated Biphenyls (PCB) - The EPA is re-examining the current authorized uses of thisPCB in electrical equipment and other applications to determine if these uses present an unreasonable risk of injury to health and the environment. The EPA is expected to issue proposed PCB rules for public comment in 2012 and could include a possible mandate to phase out all PCB-containing equipment. The schedule for compliance with the PCB Rule has not yet been established.

Greenhouse Gas (GHG) Emissions -

EPA Mandatory GHG Reporting Rule requires that sources above certain threshold levels monitor and report GHG emissions. The annual reporting compliance requirement begins for the calendar year 2010 with the first GHG emissions reports due by March 2011.

EPA New Source Performance Standard (NSPS) for GHG Emissions from Electric Utilities is expected to require performance standards for GHG emissions from new and existing fossil fuel-fired EGUs. The EPA is expected to propose NSPS by July 2011 and finalize NSPS by May 2012. For existing EGUs, state agencies must submit their plans for reducing EGU GHG emissions to the EPA within nine months after publication of the NSPS. The schedule for compliance with the NSPS has not yet been established.

EPA GHG Tailoring Rule establishes GHG emissions thresholds for construction and operation of facilities emitting GHG incorporated with air permits applied for after January 2011. The rule remain subjectalso requires new and significantly modified facilities to further review bydemonstrate use of the Wisconsin Department of Natural Resources.Best Available Control Technologies and energy efficiency measures to minimize GHG emissions.

(f) Credit Risk - - WPL serves a diversified baseis subject to credit risk related to the ability of counterparties to meet their contractual payment obligations or the potential non-performance of counterparties to deliver contracted commodities, other goods or services at the contracted price.

WPL provides regulated electricity and natural gas services to residential, commercial, industrial and wholesale customers andin the Midwest region of the U.S. The geographic concentration of its customers did not contribute significantly to its overall exposure to credit risk. In addition, as a result of its diverse customer base, WPL did not have any significant concentration of credit risk for receivables arising from the sale of electricity and natural gas services.

WPL is typically a net buyer of commodities (primarily electricity, coal and natural gas) required to provide regulated electricity and natural gas services to its customers. As a result, WPL is also subject to credit risk related to its counterparties’ failures to deliver commodities at the contracted price.

WPL maintains credit policies to minimize its credit risk. These credit policies include evaluation of the financial condition of counterparties, use of credit risk-related contingent provisions in certain commodity agreements that require credit support from counterparties that exceed certain exposure limits, diversification of counterparties to minimize concentrations of credit risk and the use of standardized agreements that facilitate the netting of cash flows associated with regards to its customers. In addition, WPL has limiteda single counterparty. Based on these credit exposure from non-performancepolicies, it is unlikely that a material adverse effect on WPL’s financial condition or results of contractual obligations by its counterparties. WPL maintains credit risk oversightoperations would occur as a result of its commodities and derivatives contracts and sets limits and policies with regards to its counterparties based on counterparty credit ratings and financial strength. Management reviews these limits and policies regularly and believes they reduce overall credit risk exposure and negative impacts should any counterparty default on its obligations.non-performance. However, there is no assurance that such limits and policies will protect WPL against all losses from non-performance by counterparties.

Refer to Notes 1(p) and 11(a) for details of allowances for doubtful accounts and credit risk-related contingent features, respectively.

(g) MISO Revenue Sufficiency Guarantee (RSG) SettlementsEdgewater Unit 5 Purchase Agreement -WPL and Wisconsin Electric Power Company (WEPCO) entered into an agreement, which became effective in March 2010, for WPL to purchase WEPCO’s 25% ownership interest in Edgewater Unit 5 for WEPCO’s net book value, including working capital. In June 2010, FERC authorized the transaction. In

November 2010, the PSCW approved the transaction and WPL’s request to defer all costs and benefits related to the purchase and operation of Edgewater Unit 5 between the time of the transaction and WPL’s next base rate case. WEPCO is currently working with the Michigan Public Service Commission to obtain satisfactory approval for the transaction. WPL currently expects the transaction to close in the first half of 2011 at an approximate purchase price of $40 million to $45 million depending on WEPCO’s working capital balances and level of capital investment in Edgewater Unit 5 prior to the sale. If the purchase is completed, WPL would own 100% of Edgewater Unit 5.

(h) Collective Bargaining Agreements -In November 2008, FERC issued written orders which resulted in the need for MISO to resettle RSG charges in its wholesale energy market. The resettlement process will result in MISO collecting RSG charges from some market participants and refunding the collected amounts to other participants. Based upon preliminary information, WPL anticipates it will be a net recipientMay 2011, WPL’s only collective bargaining agreement, International Brotherhood of RSG charge revenues upon completionElectrical Workers (IBEW) Local 965, expires representing 92% of

the resettlement process. WPL expects the retail portion of any net benefit from the RSG resettlement process will be considered as a reduction of monitored fuel expense and may result in changes in retail electric rates. WPL expects the wholesale portion of any net benefit from the RSG resettlement process will be refunded to wholesale customers through WPL’s wholesale fuel-related cost recovery mechanism. MISO has indicated it may not be able to recover a portion of the net RSG resettlements due to historical market participants no longer existing, no longer participating in the MISO market, or having insufficient capital to accommodate resettlement. In addition, numerous parties have appealed for rehearing of FERC’s decision, and it is expected that numerous parties will seek judicial review of FERC’s decision. Given the uncertainty regarding the ultimate resolution of this issue, WPL has not recorded any assets or liabilities associated with the potential RSG resettlements as oftotal employees at Dec. 31, 2008. In addition,2010. While negotiations to renew the contract with IBEW Local 965 are underway, WPL is not ablecurrently unable to estimatepredict the potential impact of this gain contingency given the uncertainty regarding the amount of net RSG resettlements that MISO may not be able to recover from historical market participants.outcome.

(13) JOINTLY-OWNED ELECTRIC UTILITY PLANT

(13)JOINTLY-OWNED ELECTRIC UTILITY PLANT

Under joint ownership agreements with other utilities, WPL has undivided ownership interests in jointly-owned electric generating facilities. Each of the respective owners is responsible for the financing of its portion of the construction costs. Kilowatt-hour generation and operating expenses are primarily divided between the joint owners on the same basis as ownership. WPL’s share of expenses from jointly-owned electric generating facilities is included in the corresponding operating expenses (e.g. electric production fuel, other operation and maintenance, etc.) on thein its Consolidated Statements of Income. Refer to Note 1(b) for further discussion of cost of removal obligations. Information relative to WPL’s ownership interest in these jointly-owned electric generating facilities at Dec. 31, 20082010 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
  In-service
Dates
   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(a)

  Coal  75.0  $251.7  $142.7  $3.0  $11.4   1985     Coal     75.0 $260.4    $147.8    $17.4    $11.8  

Columbia Energy Center

  Coal  46.2   231.5   140.2   3.8   9.8

Columbia Units 1-2

   1975-1978     Coal     46.2  241.4     148.3     2.7     9.7  

Edgewater Unit 4

  Coal  68.2   74.5   41.1   6.0   2.4   1969     Coal     68.2  86.7     44.6     0.3     2.6  
                                     
      $557.7  $324.0  $12.8  $23.6       $588.5    $340.7    $20.4    $24.1  
                                     

(a)Refer to Note 12(g) for discussion of WPL’s agreement to purchase the remaining 25% ownership interest in Edgewater Unit 5 from WEPCO.

(14) SEGMENTS OF BUSINESS

WPL is a utility serving customers in Wisconsin and includes three reportable 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 only in “Total.” 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   Electric Gas   Other Total 

2008

       

2010

      

Operating revenues

  $1,153.0  $300.0  $12.8  $1,465.8   $1,209.9   $206.3    $7.4   $1,423.6  

Depreciation and amortization

   89.3   12.4   —     101.7    98.0    10.6     —      108.6  

Operating income

   167.1   35.6   2.2   204.9 

Operating income (loss)

   250.1    29.8     (1.1  278.8  

Interest expense, net of AFUDC

        52.6        66.1  

Equity income from unconsolidated investments

   (33.9)  —     —     (33.9)   (37.8  —       —      (37.8

Interest income and other

        (0.6)       (0.1

Income taxes

        68.4        98.3  

Net income

        118.4        152.3  

Preferred dividends

        3.3        3.3  

Earnings available for common stock

        115.1        149.0  

Total assets

   2,492.5   367.1   405.9   3,265.5    3,201.9    357.3     330.4    3,889.6  

Investments in equity method subsidiaries

   203.6   —     —     203.6    236.0    —       —      236.0  

Construction and acquisition expenditures

   336.3   25.3   1.5   363.1    430.3    19.9     0.3    450.5  

2007

      
  Electric Gas   Other Total 

2009

            

Operating revenues

  1,140.7  265.7  10.4  1,416.8   $1,160.3   $216.5    $9.3   $1,386.1  

Depreciation and amortization

  95.7  14.2  —    109.9    103.2    12.2     —      115.4  

Operating income (loss)

  157.7  37.9  (4.9) 190.7    145.4    24.6     (3.0  167.0  

Interest expense, net of AFUDC

      47.0        69.1  

Equity income from unconsolidated investments

  (28.4) —    —    (28.4)   (37.0  —       —      (37.0

Interest income and other

      (0.7)       (0.4

Income taxes

      59.3        45.8  

Net income

      113.5        89.5  

Preferred dividends

      3.3        3.3  

Earnings available for common stock

      110.2        86.2  

Total assets

  2,215.5  341.1  232.0  2,788.6    2,891.0    341.7     448.7    3,681.4  

Investments in equity method subsidiaries

  182.0  —    —    182.0    227.1    —       —      227.1  

Construction and acquisition expenditures

  179.8  23.1  0.2  203.1    480.5    27.7     0.2    508.4  

2006

      

Operating revenues

  1,111.4  273.9  16.0  1,401.3 

Depreciation and amortization

  92.8  14.5  —    107.3 

Operating income

  143.9  40.0  1.0  184.9 

Interest expense, net of AFUDC

      45.7 

Equity income from unconsolidated investments

  (27.0) —    —    (27.0)

Interest income and other

      (1.3)

Income taxes

      62.2 

Net income

      105.3 

Preferred dividends

      3.3 

Earnings available for common stock

      102.0 

Total assets

  2,131.4  351.9  215.8  2,699.1 

Investments in equity method subsidiaries

  175.3  —    —    175.3 

Construction and acquisition expenditures

  141.8  18.9  1.8  162.5 

    Electric  Gas   Other   Total 

2008

               

Operating revenues

  $1,153.0   $300.0    $12.8    $1,465.8  

Depreciation and amortization

   89.3    12.4     —       101.7  

Operating income

   167.1    35.6     2.2     204.9  

Interest expense, net of AFUDC

        52.6  

Equity income from unconsolidated investments

   (33.9  —       —       (33.9

Interest income and other

        (0.6

Income taxes

        68.4  

Net income

        118.4  

Preferred dividends

        3.3  

Earnings available for common stock

        115.1  

Total assets

   2,492.5    367.1     405.9     3,265.5  

Investments in equity method subsidiaries

   203.6    —       —       203.6  

Construction and acquisition expenditures

   336.3    25.3     1.5     363.1  

(15) OTHER INTANGIBLE ASSETS

Emission Allowances -At both Dec. 31, 2008The gross carrying amount and 2007, purchasedaccumulated amortization of emission allowances were $7 million and were recorded as intangible assets in “Other assets - deferred charges and other” on the Consolidated Balance Sheets.Sheets at Dec. 31 as follows (in millions):

       2010           2009     

Gross carrying amount

  $3.9    $9.0  

Accumulated amortization

   3.4     4.9  

Amortization expense for emission allowances was recorded in “Electric production fuel and energy purchases” in the Consolidated Statements of Income. In 2008, 20072010, 2009 and 2006, there was no2008, amortization expense for purchased emission allowances.allowances was $3.4 million, $4.9 million and $0. At Dec. 31, 2008,2010, estimated amortization expense for 20092011 to 20132015 for purchased emission allowances was $5 million, $2$0.5 million, $0, $0, $0 and $0, respectively.$0.

(16) SELECTED CONSOLIDATED QUARTERLY FINANCIAL DATA (UNAUDITED)

 

  2008  2007  2010   2009 
  March 31  June 30  Sep. 30  Dec. 31  March 31  June 30  Sep. 30  Dec. 31  March 31   June 30   Sep. 30   Dec. 31   March 31   June 30   Sep. 30   Dec. 31 
  (in millions)  (in millions) 

Operating revenues

  $420.8  $328.0  $353.9  $363.1  $398.6  $312.3  $357.6  $348.3  $392.9    $312.9    $369.6    $348.2    $411.3    $300.4    $326.6    $347.8  

Operating income

   54.4   36.3   69.6   44.6   56.7   33.1   52.4   48.5   69.7     52.3     86.7     70.1     52.1     25.7     41.5     47.7  

Net income

   31.1   20.4   42.6   24.3   34.6   18.6   30.8   29.5   37.0     30.2     50.0     35.1     31.3     11.6     21.0     25.6  

Earnings available for common stock

   30.3   19.5   41.8   23.5   33.8   17.7   30.0   28.7   36.2     29.3     49.2     34.3     30.5     10.7     20.2     24.8  

(17) ASSET RETIREMENT OBLIGATIONS (AROs)

WPL’s AROs relate to legal obligations for the removal, closure or dismantlement of several assets including, but not limited to, active ash landfills, water intake facilities, above ground and under ground storage tanks, groundwater wells, distribution equipment, easement improvements, leasehold improvements, wind projects and certain hydro facilities. WPL’s AROs also include legal obligations for the management and final disposition of asbestos, lead-based paint and polychlorinated biphenyls (PCB) and closure of coal yards and ash ponds. WPL believes it is probable that any differences between expenses accrued for legal AROs related to its regulated operations and expenses recovered currently in rates will be recoverable in future rates, and is deferring the difference as a regulatory asset. Refer to Note 1(b) for additional information regarding AROs recorded as regulatory assets.PCB. WPL’s AROs are recorded in “Other long-term liabilities and deferred credits” on the Consolidated Balance Sheets. Refer to Note 1(b) for information regarding regulatory assets related to AROs. A reconciliation of the changes in AROs associated with long-lived assets is as follows (in millions):

  2008 2007       2010         2009     

Balance at Jan. 1

  $11.9  $11.4 

Balance, Jan. 1

  $21.4   $17.9  

Liabilities incurred (a)

   4.6   —      9.8    —    

Revisions in estimated cash flows

   1.1   0.1 

Accretion expense

   0.7   0.7    1.3    1.1  

Liabilities settled

   (0.4)  (0.3)   (0.2  (0.3

Revisions in estimated cash flows (b)

   —      2.7  
              

Balance at Dec. 31

  $17.9  $11.9 

Balance, Dec. 31

  $32.3   $21.4  
              

 

(a)In 2008,2010, WPL recorded an AROAROs of $4.6$9.8 million related to its Cedar RidgeBent Tree - Phase I wind project.
(b)In 2009, WPL recorded revisions in estimated cash flows of $2.7 million based on revised remediation timing and cost information for its Columbia landfill ARO.

(18) VARIABLE INTEREST ENTITIES

FIN 46R requires consolidation where thereAn entity is considered a controlling financial interest in a variable interest entity or where the variable interest entity doesVIE if its equity investors do not have sufficient equity at risk for the entity to finance its activities without additional subordinated financial support from other parties. parties or its equity investors lack any one of the following three characteristics: (1) power, through voting rights or similar rights, to direct the activities of the entity that most significantly impact the entity’s economic performance; (2) the obligation to absorb expected losses of the entity; or (3) the right to receive expected benefits of the entity. The primary beneficiary of a VIE is required to consolidate the financial statements of the VIE.

After making an ongoing exhaustive effort, WPL concluded it was unable to obtain the information necessary from the counterparties (subsidiariescounterparty (subsidiary of Calpine Corporation) for the Riverside and RockGen PPAsPPA for WPL to determine whether the counterparties are variable interest entities per FIN 46Rcounterparty is a VIE and if WPL is the primary beneficiary. These PPAs areThis PPA is currently accounted for as an operating leases.lease. The counterparties sell some or allcounterparty for the Riverside PPA sells a portion of theirits generating capacity to WPL and can sell theirits energy output to WPL. WPL’s maximum exposure to loss from these PPAsthis PPA is undeterminable due to the inability to obtain the necessary information to complete such evaluation. In 2008, 20072010, 2009 and 2006,2008, Alliant Energy’s (primarily WPL’s) costs, excluding fuel costs, related to the Riverside PPA were $61 million, $63 million $64and $63 million, and $61 million, respectively. In each

Refer to Note 1(r) for discussion of 2008, 2007 and 2006, WPL’s costs, excluding fuel costs, related tonew accounting standards effective Jan. 1, 2010 that impact the RockGen PPA were $16 million.accounting for VIEs.

(19) RELATED PARTIES

System Coordination and Operating Agreement -WPL and IPL are parties to a system coordination and operating agreement.agreement whereby Corporate Services serves as agent on behalf of WPL and IPL. The agreement, which has been approved by FERC, provides a contractual basis for coordinated planning, construction, operation and maintenance of the interconnected electric generation systems of WPL and IPL. Prior to June 1, 2008,As agent of the agreement, allowed the interconnected system to be operated as a single entity with off-systemCorporate Services enters into energy, capacity, ancillary services, and transmission sale and purchase transactions. Corporate Services allocates such sales and purchases made to market excess system capability or to meet system capability deficiencies. Such sales and purchases were allocated among WPL and IPL based on procedures included in the agreement. Under the agreement prior to June 1, 2008, WPL and IPL were 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 were distributed to WPL and IPL in proportion to each utility’s share of electric production at the time of the sale. The procedures were approved by FERC and all state regulatory bodies having jurisdiction over these sales.

Effective June 1, 2008, a change was made to designate WPL and IPL as two separate entities transacting with MISO. This change eliminated the need for internal allocations based on procedures in the agreement and resulted in separate statements from MISO of sales and purchases for WPL and IPL.jurisdiction. The sales credited to WPL were $24 million, $72 million and $22 million $16 millionfor 2010, 2009 and $24 million for 2008, 2007 and 2006, respectively. The purchases billed to WPL were $73 million, $121 million and $371 million $449 millionfor 2010, 2009 and $444 million for 2008, 2007 and 2006, respectively.

Service Agreement -Pursuant to a service agreement, WPL receives various administrative and general services from an affiliate, Corporate Services. These services are billed to WPL at cost based on payroll and other expenses incurred by Corporate Services for the benefit of WPL. These costs totaled $127 million, $112 million and $120 million $135 millionfor 2010, 2009 and $124 million for 2008, 2007 and 2006, respectively, and consisted primarily of employee compensation, benefits and fees associated with various professional services. AtAs of Dec. 31, 20082010 and 2007,2009, WPL had a net intercompany payablepayables to Corporate Services of $68$42 million and $74$45 million, respectively.

Refer to Note 3(b) for discussion of WPL’s SFEF lease.

ATC -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. ATCThe related amounts billed WPL $82 million, $72 million and $59 million in 2008, 2007 and 2006, respectively. WPL billed ATC $9.0 million, $8.6 million and $9.9 million in 2008, 2007 and 2006, respectively. Atbetween the parties were as follows (in millions):

     2010       2009       2008   

ATC billings to WPL

  $92    $83    $82  

WPL billings to ATC

   11     13     9  

As of Dec. 31, 20082010 and 2007,2009, WPL owed ATC net amounts of $5.9$7 million and $5.3$5 million, respectively.

Acquisition of the Neenah Energy Facility -In 2009, WPL acquired a 300 MW, simple-cycle, dual-fueled (natural gas/diesel) electric generating facility and related inventories (diesel fuel and materials and supplies) located in Neenah, Wisconsin from Resources for $92 million. The purchase price was allocated to property, plant and equipment ($90 million), production fuel ($1 million) and materials and supplies ($1 million) based on the net book value of the assets acquired.

Sheboygan Falls Energy Facility Lease -Refer to Note 3(b) for discussion of WPL’s Sheboygan Falls Energy Facility lease.

SHAREOWNER INFORMATION

Market Information- The 4.50% series of preferred stock is listed on the NYSE Alternext USAmex LLC, with the trading symbol of WIS_PR. All other series of preferred stock are traded on the over-the-counter market. As of Dec. 31, 2008, 66%2010, 71% of WPL’s individual preferred shareowners were Wisconsin residents.

Dividend Information -Preferred stock dividends paid per share for each quarter during 20082010 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  

As authorized by the WPL Board of Directors, preferred stock dividend record and payment dates for 20092011 are as follows:

 

Record Date

 

Payment Date

February 27

28
 March 1315

May 29

31
 June 15

August 31

 September 15

November 30

 December 15

Stock Transfer Agent and Registrar

Wells Fargo Shareowner Services

161 North Concord Exchange

P.O. Box 64854

St. Paul, MN 55164-0854

Form 10-K Information -A copy of the combined Annual Report on Form 10-K for the year ended Dec. 31, 20082010 as filed with the SEC will be provided without charge upon request. Requests may be directed to Alliant Energy Shareowner Services, P.O. Box 14720, Madison, Wisconsin53708-0720.

EXECUTIVE OFFICERS AND DIRECTORS

Executive Officers - - Numbers following the names represent the officer’s age as of Dec. 31, 2008.2010.

William D. Harvey 59,, 61, was elected Chairman of the Board effective February 2006 and Chief Executive Officer effective July 2005 and has been a board memberdirector since January 2005.

John O. Larsen, 47, was elected President effective December 2010. He previously served as Chief Operating OfficerSenior Vice President-Generation since January 2010, as Vice President-Generation from August 2008 to January 2010 and as Vice President-Technical and Integrated Services from January 2004 to July 2005.August 2008.

Barbara J. Swan,Patricia L. Kampling57, was elected President effective January 2004.

Eliot G. Protsch, 55,, 51, was elected Chief Operating Officer effective January 2009. HeFebruary 2011. She previously served as Executive Vice President and Chief Financial Officer since September 2010, as Executive Vice President-Chief Financial Officer and Treasurer from January 2004.2010 to September 2010, as Vice President-Chief Financial Officer and Treasurer from January 2009 to January 2010, as Vice President and Treasurer from January 2007 to January 2009, and as Vice President-Finance from August 2005 to January 2007.

Thomas L. Aller 59,, 61, was elected Senior Vice President-Energy Resource Development effective January 2009. He previously served as Senior Vice President-Energy Delivery since January 2004.

Dundeana K. Doyle 50,, 52, was elected Senior Vice President-Energy Delivery effective January 2009. She previously served as Vice President-Strategy and Regulatory Affairs since January 2007 and as Vice President-Strategy and Risk from May 2003 to January 2007.

PatriciaJames H. Gallegos, 50, was elected Vice President and General Counsel effective November 2010. He previously served as Vice President and Corporate General Counsel of BNSF Railway Company, a subsidiary of Burlington Northern and Santa Fe Corporation from April 2003 to April 2010.

Thomas L. Kampling,Hanson 49,, 57, was elected Vice President-Chief Financial Officer and Treasurer effective January 2009. SheFebruary 2011. He previously served as Vice PresidentPresident-Chief Accounting Officer and Treasurer since January 2007,September 2010, as Vice President-Finance from August 2005 to January 2007 and as Treasurer of IPSCO Inc. from September 2004 to August 2005.

Thomas L. Hanson, 55, was elected Vice President-Controller and Chief Accounting Officer effectivefrom January 2007. He previously served2007 to September 2010 and as Vice President and Treasurer sincefrom April 2002.2002 to January 2007.

Peggy Howard Moore,Wayne A. Reschke 58,, 55, was elected Vice President-FinancePresident-Human Resources effective January 2007. SheSeptember 2009. He was previously a Partner of the Center for Organization Effectiveness, Inc. since 1996.

Joel J. Schmidt, 47, was elected Vice President-Regulatory and Financial Planning effective September 2010. He previously served as Vice President-CustomerDirector-Financial Planning and Analysis since May 2009, as Regional Director-Customer Service Operations from March 2008 to May 2009, as Chief Audit Executive from January 2008 to March 2008, as Chief Audit, Ethics, Risk and Operations SupportCompliance Officer from January 2007 to January 2008 and as Chief Audit and Risk Officer from January 2005 to January 2007.

Robert J. Durian, 40, was elected Controller and Chief Accounting Officer effective February 2011. He previously served as Controller since 2004.September 2010, as Assistant Controller from March 2009 to September 2010 and as Director of Financial Reporting from February 2006 to March 2009.

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

LOGO

2011 ANNUAL MEETING - MAY 17, 2011

 

The Board of Directors recommends a vote “FOR” all nominees listed in Proposal 1, “FOR” Proposal 2, for
“1 YEAR” on Proposal 3 and “FOR” Proposal 4.

1. Election of directors:

Nominees for terms ending in 2014:¨

FOR all nominees (except as marked to

the contrary below)

¨WITHHOLD AUTHORITY (to vote for all nominees)
(01) William D. Harvey
(02) Singleton B. McAllister

(Instructions: To withhold authority to vote for any individual

nominee, write that nominee’s number in the box.)

È Please fold here – Do not separateÈ

2. Advisory vote on approval of the compensation of the Company’s named executive officers.

¨For¨Against¨Abstain ��

3. Advisory vote on the frequency of advisory votes on the compensation of the Company’s named executive officers.

¨1 Year¨2 Years¨3 Years¨Abstain

4. Ratification of the appointment of Deloitte & Touche LLP as the Company’s independent registered public accounting firm for 2011.

¨For¨Against¨Abstain
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, then the proxy will be voted “FOR” all nominees listed in Proposal 1, “FOR” Proposal 2, for “1 YEAR” on Proposal 3, “FOR” Proposal 4 and in the discretion of the proxies upon such other matters what may properly come before the meeting or any adjournment or postponement thereof.
(Important information contained on reverse side; please read.)
Date

Signature (s) in Box

Please sign exactly as your name(s) appears on Proxy. If held in joint tenancy, all persons should sign. Trustees, administrators, etc., should include title and authority. Corporations should provide full name of corporation and title of authorized officer signing the Proxy.


WISCONSIN POWER AND LIGHT COMPANY

2011 Annual Meeting of Shareowners

Tuesday, May 17, 2011,

at 2:00 p.m.(Central Daylight Time)

Alliant Energy Corporate Headquarters

Sandy River Conference Room

4902 N. Biltmore Lane

Madison, Wisconsin

Photo ID required for entry.

 

 

© 2009 Alliant Energy 294601 71-1373 3/09 JS


LOGOLOGO

www.wellsfargo.com/shareownerservices

1-800-356-5343

To access the Wisconsin Power and Light Company Annual Report and Proxy Statement, as well as the Alliant Energy Corporation Annual Report and Proxy Statement, on the Internet, please go towww.alliantenergy.com/WPLproxy. We encourage you to check out Alliant Energy’s website to see how easy and convenient it is. You may print or just view these materials.

È Please fold here – Do not separateÈ

Wells Fargo Shareowner Services

P.O. Box 64873

St. Paul, MN 55164-0873

proxy

The undersigned appoints John O. Larsen and F. J. Buri, or either of them, attorneys and proxies with the power of substitution to vote all shares of stock of Wisconsin Power and Light Company (the “Company”), held of record in the name of the undersigned at the close of business on March 30, 2011, at the Annual Meeting of Shareowners of the Company to be held at 4902 N. Biltmore Lane, Madison, Wisconsin on May 17, 2011 at 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, Proxy Statement and Annual Report, dated April 8, 2011, subject to any directions indicated on the reverse side of this card.

VOTE BY MAIL

Mark, sign and date your proxy card and return it in the postage-paid envelope we’ve provided.

Your proxy card must be received by May 19, 2009.

È Please detach here DateÈ

The Board of Directors Recommends a Vote FOR All Listed Director Nominees and FOR Proposal 2.

1. Election of directors:

Nominees for terms ending in 2012:¨FOR all nominees (except as marked)¨WITHHOLD authority to vote for all nominees
(01) Ann K. Newhall(02) Dean C. Oestreich
(03) Carol P. Sanders

(Instructions: To withhold authority to vote for any individual nominee,

write the number(s) of the nominee(s) in the box provided to the right.)

2. Proposal to ratify the appointment of Deloitte & Touche LLP as the Company’s independent registered public accounting firm for 2009.

¨FOR¨AGAINST¨ABSTAIN
THIS PROXY WHEN PROPERLY EXECUTED WILL BE VOTED AS DIRECTED. IF NO DIRECTION IS GIVEN, WILL BE VOTED “FOR” ALL LISTED DIRECTOR NOMINEES AND “FOR” THE RATIFICATION OF THE APPOINTMENT OF DELOITTE & TOUCHE LLP AS THE COMPANY’S INDEPENDENT PUBLIC ACCOUNTING FIRM FOR 2009.
Address Change? Mark Box¨Indicate changes below:Date

Signature(s) in Box

Please sign exactly as name appears on Proxy. If held in joint tenancy, all persons should sign. Trustees, administrators, etc., should include title and authority. Corporations should provide full name of corporation and title of authorized officer signing the proxy.


WISCONSIN POWER AND LIGHT COMPANY

2009 ANNUAL MEETING OF SHAREOWNERS

Wednesday, May 20, 2009

2:00 p.m.(Central Daylight Time)

Alliant Energy Corporate Headquarters

Mississippi Meeting Room

4902 N. Biltmore Lane

Madison, Wisconsin

To access the Wisconsin Power and Light Company Annual Report and Proxy Statement, as well as the Alliant Energy Corporation Annual Report and Proxy Statement, on the Internet, please go towww.alliantenergy.com/WPLproxy. We encourage you to check out Alliant Energy’s website to see how easy and convenient it is. You may print or just view these materials.

Wells Fargo Shareowner Services
P.O. Box 64873
St. Paul, MN 55164-0873proxy

The undersigned appoints Thomas L. Hanson and F. J. Buri, or either of them, attorneys and proxies with the power of substitution to vote all shares of stock of Wisconsin Power and Light Company (the “Company”), held of record in the name of the undersigned at the close of business on April 7, 2009, at the Annual Meeting of Shareowners of the Company to be held at 4902 N. Biltmore Lane, Madison, Wisconsin on May 20, 2009 at 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, Proxy Statement and Annual Report, dated April 16, 2009, 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 as recommended by the Board of Directors. The Board of Directors recommends a vote “FOR” all listed director nominees and “FOR” the ratification of the appointment of Deloitte & Touche LLP as the Company’s independent registered public accounting firm for 2009.

See reverse for voting instructions.2011.

ECRM158493 REV.2REV. 4 03/0911