ALLIANT ENERGY CORP (LNT, NYSE)
Annual report, fiscal year 2012













Alliant Energy

2012 ANNUAL REPORT









We're on for you.



## CONTENTS

<table><tr><td>A Letter to Shareowners</td><td>1</td></tr><tr><td>Financial Overview</td><td>2</td></tr><tr><td>Preparing for the Future</td><td>3</td></tr><tr><td>Our Leaders</td><td>8</td></tr><tr><td>2012 Financial Information</td><td>F-1</td></tr><tr><td>Management&#x27;s Discussion and Analysis of Financial Condition and Results of Operations</td><td>F-2</td></tr><tr><td>Management&#x27;s Annual Report on Internal Control over Financial Reporting</td><td>F-50</td></tr><tr><td>Reports of Independent Registered Public Accounting Firm</td><td>F-51</td></tr><tr><td>Consolidated Financial Statements</td><td>F-53</td></tr><tr><td>Notes to Consolidated Financial Statements</td><td>F-58</td></tr><tr><td>Selected Financial and Operating Statistics</td><td>F-110</td></tr><tr><td>Shareowner Information</td><td>Inside back cover</td></tr></table>

## WHO WE ARE

Alliant Energy is approximately 4,000 employees proudly serving nearly 1 million electric and more than 415,000 gas customers in over 1,300 communities throughout Iowa, Wisconsin and Minnesota. We
are supporting our customers from over 200 facility locations across our service territory; delivering the energy and exceptional service that our customers and communities count on – safely, efficiently and responsibly.



Alliant Energy has more than $10 billion in assets and operates as a regulated investor-owned public utility holding company. Alliant Energy’s subsidiaries include Interstate Power and Light Company (IPL), Wisconsin Power and Light Company (WPL) and Alliant Energy Resources (AER). IPL serves most of Iowa and parts of southern Minnesota, and WPL serves parts of southern and central Wisconsin. AER is the parent company of our non-regulated businesses, which includes a short-line railroad, a barge terminal and hauling business, and two non-regulated generation facilities.

Forward-Looking Statements: This annual report contains forward-looking statements. These forward-looking statements should be considered in light of the disclaimer on pages F-2 and F-3. The information contained in the section titled “2012 Financial Information” was filed with the Securities and Exchange Commission (SEC) on February 26, 2013 and was complete and accurate as of that date. Alliant Energy disclaims any responsibility to update that information in this annual report.







*All or some of the renewable energy attributes associated with generation from these sources may be: (a) used in future years to comply with renewable energy standards or other regulatory requirements or (b) sold to third parties in the form of renewable energy credits or other environmental commodities.



## Dear fellow Shareowners,

Alliant Energy turned in a solid financial and operational performance in 2012 while delivering on our commitment to our customers and our shareowners. We improved reliability, customer service, generation availability and safety. At Alliant Energy, our first priority is that nobody gets hurt, and nothing is more important than employee safety. And I’m proud to say that our employees’ focus and commitment made 2012 our safest year ever.

Earnings this past year were certainly driven in part by the hot summer we experienced. However, if you exclude weather impacts, our earnings growth over the past three years has been consistent with our 5% to 7% growth target of weather normalized annual earnings. And consistent with our long-standing dividend payout ratio target of 60% to 70% of earnings, our Board raised the annual dividend target to $1.88 per share for 2013. Our utility companies, Interstate Power and Light Company and Wisconsin Power and Light Company, are implementing comprehensive, multi-year energy resource and generation plans that will prepare us for the future. We plan to invest $3.5 billion over the next four years to provide new generation sources, emission reduction projects, plant efficiency upgrades, and infrastructure investments. These plans continue our commitment to renewable resources and energy efficiency. In addition, these investments will create hundreds of jobs in our service territories.



The 2013 Annual Meeting of Shareowners will be held at the Cedar Rapids Marriott, 1200 Collins Road NE, Cedar Rapids, Iowa, on Thursday, May 9, 2013, at 10:30 a.m., Central Daylight Time. We encourage you to attend, meet your Board of Directors and management team, and allow us to answer any questions you may have.

Keeping the lights on and the gas flowing is vital to our customers. Our energy delivery system continues to provide reliable, 24/7 electric and gas service to nearly 1.4 million customers in more than 1,300 communities. Our company is making significant investments in upgrading overhead and underground electric lines,
electric substations and natural gas infrastructure to improve system reliability. At the same time, we are implementing new communications and customer service technologies to serve our customers more effectively and help reduce the number and duration of service outages.



While we continue to pursue a disciplined approach to investing in energy resources and delivery, we understand that cost is – and will remain – a critical aspect of the energy we provide to our customers. It’s important for us to manage costs to ensure we provide competitive customer rates. Budgets are tight, and the economy is still recovering in our service territory, so our approach is to keep rate increases to a minimum.

I am honored to have the opportunity to lead this great organization. I have a deep passion for the success of our company and enormous respect for our employees and customers. We remain committed to providing exceptional service to our customers and communities, while our actions will continue to drive long-term growth and value for our shareowners.

Our entire Alliant Energy family says thank you to our shareowners for supporting our vision and commitment to our company and its customers.



Patricia Leonard Kampling
Chairman, President and CEO
March 8, 2013



## FINANCIAL OVERVIEW

<table><tr><td>(Dollars in millions, except per share data)</td><td>2012</td><td>2011</td><td>Change</td></tr><tr><td>Operating revenues</td><td>$3,095</td><td>$3,221</td><td>(4%)</td></tr><tr><td colspan="4">Amounts attributable to Alliant Energy common shareowners:</td></tr><tr><td>Income from continuing operations, net of tax</td><td>$325</td><td>$323</td><td>1%</td></tr><tr><td>Loss from discontinued operations, net of tax</td><td>($5)</td><td>($19)</td><td>(74%)</td></tr><tr><td>Net income</td><td>$320</td><td>$304</td><td>5%</td></tr><tr><td colspan="4">Diluted earnings per weighted average common share attributable to Alliant Energy common shareowners:</td></tr><tr><td>Income from continuing operations, net of tax</td><td>$2.93</td><td>$2.92</td><td>-</td></tr><tr><td>Loss from discontinued operations, net of tax</td><td>($0.04)</td><td>($0.18)</td><td>(78%)</td></tr><tr><td>Net income</td><td>$2.89</td><td>$2.74</td><td>5%</td></tr><tr><td>Utility electric sales to retail customers (thousands of megawatt-hours)</td><td>25,586</td><td>25,497</td><td>-</td></tr><tr><td>Total utility electric sales (thousands of megawatt-hours)</td><td>30,357</td><td>30,777</td><td>(1%)</td></tr><tr><td>Utility natural gas sold and transported (thousands of dekatherms)</td><td>100,786</td><td>102,220</td><td>(1%)</td></tr><tr><td>Cash flows from operating activities</td><td>$841</td><td>$703</td><td>20%</td></tr><tr><td>Construction and acquisition expenditures</td><td>$1,158</td><td>$673</td><td>72%</td></tr><tr><td>Total assets at year-end</td><td>$10,786</td><td>$9,688</td><td>11%</td></tr><tr><td>Common shares outstanding at year-end (in thousands)</td><td>110,987</td><td>111,019</td><td>-</td></tr><tr><td>Dividends declared per common share (a)</td><td>$1.80</td><td>$1.70</td><td>6%</td></tr><tr><td>Market value per share at year-end</td><td>$43.91</td><td>$44.11</td><td>-</td></tr><tr><td>Book value per share at year-end</td><td>$28.25</td><td>$27.14</td><td>4%</td></tr><tr><td>Market capitalization at year-end</td><td>$4,873</td><td>$4,897</td><td>-</td></tr></table>

(a) Effective with the dividend declared and paid in the first quarter of 2013, Alliant Energy’s targeted annualized common stock dividend was increased from $1.80 to $1.88 per share.

The financial data should be read in conjunction with the audited consolidated financial statements and related notes of Alliant Energy. The reported financial data are not necessarily indicative of future operating results or financial position.

Earnings per share – net income



Dividends per share



*Annual common stock dividend target. Payment of the 2013 dividends is subject to the actual dividend declaration by the Board of Directors.

Five-year return



Comparison of cumulative five-year total return when investing $100 on December 31, 2007.

Alliant Energy Corporation

S&P 500 Index

S&P 400 Utilities Index

EEI Stock Index



# Preparing
for the future

## Improving the environment

Caring for the environment is an important part of our future plan. We continue to invest in our newer, larger and more efficient coal-fired generating facilities. By investing in environmental controls for these units, we are significantly reducing emissions. These projects will also ensure our compliance with existing and expected future state and federal environmental rules so we can continue to meet customers' energy needs with safe, reliable, cost-effective and environmentally responsible energy. While we've already made great strides in decreasing the environmental impact of these power facilities, these added air quality control systems are expected to result in up to a 90% decrease in mercury and sulfur dioxide emissions and a 65% decrease in nitrogen oxide emissions.

Renewable energy also remains an important part of our generation portfolio. Our renewable energy portfolio consists primarily of wind energy. Our residential and business customers can also support electricity generated from renewable resources by participating in our Second Nature \( ^{™} \)  program. Those who participate pay an extra amount monthly to cover the added cost of harvesting the wind, solar and biomass energy used in the program. Currently, nearly 16,000 customers purchase renewable energy through this program.

Our Alliant Energy family takes pride and places importance on our responsibility as environmental stewards. One example is our nearly 40-year partnership with the Nature Conservancy and support of their efforts to protect ecologically important lands and waters around the world. In the past five years alone, we have invested a half million dollars in Nature Conservancy watershed planning and grassland conservation projects in our service territories.

These continue to be challenging times for our industry, and there is always more work to do, but we willingly accept the challenges we face and are dedicated to providing solutions that will benefit our environment now and for generations to come. For more information on our environmental activities and to view our 12th annual environmental report, please visit alliantenergy.com/environmentalreport.
Peregrine falcon nesting boxes are located at seven Alliant Energy power plants. In 2012, a total of 21 falcon chicks hatched at our generating stations.









Alliant Energy currently owns and operates four wind farms with a total nameplate capacity of over 550 megawatts. In addition, we purchase nearly 600 megawatts of wind energy from facilities across Iowa, southern Minnesota and Wisconsin.




Construction of an emission control project at the Edgewater Generating Station Unit 5 in Sheboygan, Wis. was completed during 2012. When combined with an earlier project, we have reduced nitrogen oxide emissions by approximately 65%.

## Transforming our generating fleet

In addition to the environmental and efficiency investments we are making to our newer, larger and more efficient power facilities, Alliant Energy is taking steps to transform our generating fleet to reduce long-term customer costs. We are increasing the use of cleaner energy sources while maintaining our commitment to energy efficiency and renewable resources. In 2012, both of our utility companies announced energy resource plans to meet customers' energy needs now and into the future.

WPL’s plan highlights include the purchase of the Riverside Energy Center, which was completed at the end of 2012, and the expected orderly retirement of its three oldest and smallest coal-fired generating units by the end of 2015. IPL’s plan includes the planned construction of a new, approximately 600-megawatt natural gas-fired power plant in Marshalltown, Iowa, which is expected to be placed in service in 2017. IPL previously announced the planned retirement of older, smaller and less efficient power facilities over the next few years. Both utilities remain committed to the development and use of renewable resources and their energy-efficiency programs.



Riverside Energy Center, purchased by WPL in December 2012, is a 600-megawatt natural gas-fired electric generating facility located in Beloit, Wis.




During 2013-2016, Alliant Energy plans to invest approximately $3.5 billion in our electric and gas infrastructure.



## Providing non-stop service and system investment

At Alliant Energy, we provide non-stop service for our customers. There are no “business hours” when it comes to providing electric and gas service – that is the reality of the utility business. We operate 24 hours a day / 7 days a week / 365 days a year. Our Company maintains, improves and installs new equipment throughout the communities we serve on a continual basis. Our investment in property, plant and equipment is significant – more than seven billion dollars – and it’s all there to keep the lights on and gas flowing to our customers.

Across our service territory, we own more than 36,000 miles of overhead electric distribution line, 7,700 miles of underground electric distribution cable and 9,300 miles of gas mains. Our more than two dozen power facilities help supply power to customers throughout the Upper Midwest, and we have employees available in over 200 office locations and operating centers ready to respond when they are needed. Our customers are most familiar with seeing our 2,000 trucks and service vehicles that travel throughout their neighborhoods and communities bringing workers to their daily assignment of ensuring our system’s reliability.

While the time commitment on behalf of our employees and financial investment from our Company is considerable, serving our customers is most important. We understand that quality of life and the health of the economy in our service territory are dependent upon Alliant Energy providing continual and cost-effective energy services – and we take that responsibility very seriously.











New technology will help our crews in the field work more safely and efficiently.





## Implementing new technology

The cell phones we use on a daily basis are more powerful than the computers NASA used to put humans on the moon. That’s an amazing fact and proof that technology is reducing cost and opening new opportunities every day. Our use of technology continues to expand at Alliant Energy. Much of that effort is designed to help our employees work more efficiently, while also assuring that the investment made on behalf of our customers is done in a wise manner.

We are installing new equipment in many of our trucks that will provide our crews with better information, navigation and faster dispatching to emergency calls. Another technology project is helping to improve the precision and completeness of our design and construction information. This will enhance our efficiency and can reduce delays when constructing new gas and electric infrastructure.

Finally, 2012 brought the launch of a new project to modernize our utility customer information system. This multi-year project will replace more than 50 different applications that maintain customer information and billing data and replace them with a single modern system. This new system will allow our employees to provide faster and more complete information to customers while reducing long-term costs compared to the current, out-dated applications. Our goal is to have this new, unified customer information system online in 2015.



## Supporting people and our communities

The utility business is a people business, and supporting people and investing in our communities provides returns that are immeasurable. While Alliant Energy was formed in 1998, our predecessor companies have a corporate giving tradition that goes back over a century. In 2013, the Alliant Energy Foundation is celebrating its 15th year of helping improve the quality of life in the communities where Alliant Energy, our employees and our retirees have a presence. Our employees and retirees have also spent countless hours volunteering and providing their own financial contributions to worthy causes.

In 2012, our support extended beyond the borders of our utility service territory. Alliant Energy sent 215 electric and gas workers to New York to help restore electric service and ensure gas safety in the aftermath of Superstorm Sandy. Our employees provided support to three different utilities from late October up until the week of Thanksgiving, with most of our employees averaging 14- to 16-hour days. It was the largest mutual assistance effort ever by Alliant Energy workers. Employees who did not make the trip out East picked up added duties to keep our Company running effectively and efficiently.



Alliant Energy was one of the first energy companies to respond to the call for help in the Superstorm Sandy recovery effort. In December 2012, the Edison Electric Institute recognized our company with an Emergency Assistance Award for the support we provided to other utilities’ restoration efforts.
“IT WAS JUST QUITE AN EXPERIENCE. ANY TIME YOU CAN GO AND HELP PEOPLE OUT, IT MAKES YOU FEEL GOOD.”



“THE FRIENDLINESS OF
THE PEOPLE AND THE
GRATEFULNESS FOR WHEN
THEIR POWER CAME ON
WAS AMAZING.”

-RICK SCHNEIDER,
WPL LINE TECHNICIAN



## OUR LEADERS

## Board of Directors



Patricia L. Kampling
Chairman of the Board
Director since 2012
Age 53



Patrick E. Allen
Director since 2011
Age 48



Michael L. Bennett
Director since 2003
Age 59



Darryl B. Hazel
Director since 2006
Age 64



Singleton B.
McAllister
Director since 2001
Age 61



Ann K. Newhall
Director since 2003
Age 62



David A. Perdue
Director since 2001
Age 63



Judith D. Pyle
Director since 1992
Age 69



Carol P. Sanders
Director since 2005
Age 46

Ages are as of April 1, 2013. Each election date represents the first year of board affiliation with the company or a predecessor company that ultimately became part of Alliant Energy.
For detailed information on each board member, please refer to the proxy statement for the 2013 annual meeting of shareowners.

## Alliant Energy Corporate Officers

Patricia L. Kampling, 53 [2005]*
Chairman, President and CEO

Thomas L. Hanson, 59 [1980]*
Senior Vice President
and Chief Financial Officer

Thomas L. Aller, 64 [1993]*
Senior Vice President-Operations Support,
President-Interstate Power and Light

John O. Larsen, 49 [1988]*
Senior Vice President-Generation,
President-Wisconsin Power and Light

James H. Gallegos, 52 [2010]*
Vice President and General Counsel

Vern A. Gebhart, 59 [1975]
Vice President-Business Infrastructure and Technology

Douglas R. Kopp, 59 [1992]
Vice President-Environmental Affairs

John E. Kratchmer, 50 [1985]
Vice President and Treasurer

Gregg E. Lawry, 53 [1983]
Vice President-Customer Service

Linda K. Mattes, 52 [1982]
Vice President-Energy Delivery Operations

Wayne A. Reschke, 57 [2009]
Vice President-Human Resources

Joel J. Schmidt, 49 [1988]
Vice President-Regulatory Affairs

Robert J. Durian, 42 [1992]*
Controller and Chief Accounting Officer

F. J. Buri, 58 [1999]
Corporate Secretary
and Assistant General Counsel

Enrique Bacalao, 64 [1998]
Assistant Treasurer

Benjamin M. Bilitz, 38 [2011]
Assistant Controller

## Non-regulated Business Officer

Kevin P. Burke, 54 [1981]
President-Alliant Energy Transportation

 \( ^{*} \) Executive Officers

Officers and ages are as of April 1, 2013.

Dates in brackets represent the year each person joined the company or a predecessor company that ultimately became part of Alliant Energy.



Alliant Energy Corporation

## 2012

Financial
Information



ALLIANT ENERGY



# MANAGEMENT'S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS (MDA)

The following discussion and analysis should be read in conjunction with the Consolidated Financial Statements and Notes to Consolidated Financial Statements included in this report. Unless otherwise noted, all “per share” references in MDA refer to earnings per diluted share.

## 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 the risks and uncertainties of Alliant Energy Corporation (Alliant Energy) that could materially affect actual results include:

- federal and state regulatory or governmental actions, including the impact of energy, tax, financial and health 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 remaining costs related to generating units that may be permanently closed, the earning of reasonable rates of return, and the payments of expected levels of dividends;

• the ability to continue cost controls and operational efficiencies;

• the impact of Interstate Power and Light Company’s (IPL’s) retail electric base rate freeze in Iowa through 2013;

- the impact of Wisconsin Power and Light Company’s (WPL’s) retail electric and gas base rate freeze in Wisconsin through 2014;

- weather effects on results of utility operations, including the impacts of temperature changes and drought conditions in its service territories on customers' demand for electricity and gas;

- the state of the economy in its service territories 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 with new emission controls equipment for various coal-fired electric generating facilities of IPL and WPL, IPL's construction of its proposed natural gas-fired electric generating facility in Iowa, IPL's recently approved purchased power agreement (PPA) with NextEra Energy Resources, LLC (NER), Alliant Energy Resources, LLC's (Resources') selling price of the electricity output from its new 100 megawatt (MW) Franklin County wind project, and the potential decommissioning of certain generating facilities of IPL and WPL;

- issues related to the availability of generating facilities and the supply and delivery of fuel and purchased electricity and the 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 may have on its customers’ demand for utility services;

- the 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 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 litigation associated with changing environmental laws and regulations;

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

• the direct or indirect effects resulting from terrorist incidents, including cyber terrorism, or responses to such incidents;

- impacts of future tax benefits from deductions for repairs expenditures and mixed service costs and temporary differences from historical tax benefits from such deductions that are included in rates when the differences reverse in future periods;

• any material post-closing adjustments related to any past asset divestitures, including the sale of RMT, Inc. (RMT);

• continued access to the capital markets on competitive terms and rates, and the actions of credit rating agencies;

• inflation and interest rates;

- changes to the creditworthiness of counterparties with which Alliant Energy has contractual arrangements, including participants in the energy markets and fuel suppliers and transporters;



- issues related to electric transmission, including operating in Regional Transmission Organization (RTO) energy and ancillary services markets, the impacts of potential future billing adjustments and cost allocation changes from RTOs and recovery of costs incurred;

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

- its ability to successfully 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 the Alliant Energy Cash Balance Pension Plan (Cash Balance Plan);

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

• its ability to sustain its dividend payout ratio goal;

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

- impacts that storms or natural disasters, including forest or prairie fires, in its service territories may have on its operations and recovery of, and rate relief for, costs associated with restoration activities;

• access to technological developments;

• material changes in retirement and benefit plan costs;

• the impact of performance-based compensation plans accruals;

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

• the impact of changes to government incentives for wind projects;

• the impact of adjustments made to deferred tax assets and liabilities from state apportionment assumptions;

- the ability to utilize tax credits and net operating losses generated to date, and those that may be generated in the future, before they expire;

- the ability to successfully complete tax audits, changes in tax accounting methods and appeals with no material impact on earnings and cash flows; and

• factors listed in MDA.

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

## CONTENTS OF MDA

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

• Critical Accounting Policies and Estimates

• Other Future Considerations

## EXECUTIVE SUMMARY

## Description of Business

General - Alliant Energy is an investor-owned public utility holding company whose primary subsidiaries are IPL, WPL, Resources and Alliant Energy Corporate Services, Inc. (Corporate Services). IPL is a public utility engaged principally in the generation and distribution of electricity and the distribution and transportation of natural gas in selective markets in Iowa and southern Minnesota. WPL is a public utility engaged principally in the generation and distribution of electricity and the distribution and transportation of natural gas in selective markets in southern and central Wisconsin. WPL also owns an approximate 16% interest in the American Transmission Company LLC (ATC), a transmission-only utility operating in Wisconsin, Michigan, Illinois and Minnesota. Resources is the parent company for Alliant Energy's non-regulated businesses. Corporate Services provides administrative services to Alliant Energy and its subsidiaries. An illustration of Alliant Energy's primary businesses is shown below.




(a) In January 2013, Alliant Energy sold its remaining interest in RMT.

Utility and Corporate Services - IPL and WPL own a portfolio of electric generating facilities located in Iowa, Wisconsin and Minnesota 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 1 million electric customers in the upper Midwest. The utility business also procures natural gas from various suppliers to provide service to approximately 415,000 retail gas customers in the upper Midwest. Alliant Energy’s utility business is its primary source of earnings and cash flows. The earnings and cash flows from the utility and Corporate Services business are sensitive to various external factors including, but not limited to, the amount and timing of rates 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.”

Non-regulated Business and Parent - Resources manages various businesses including Transportation (short-line railway and barge transportation services), Non-regulated Generation (electric generating facilities management) and several other modest investments. Parent includes the operations of Alliant Energy (parent holding company).

Financial Results - Alliant Energy’s earnings per weighted average common share (EPS) attributable to Alliant Energy common shareowners for 2012 and 2011 were as follows:

<table><tr><td></td><td>2012</td><td>2011</td></tr><tr><td>Income from continuing operations</td><td>$2.93</td><td>$2.92</td></tr><tr><td>Loss from discontinued operations</td><td>(0.04)</td><td>(0.18)</td></tr><tr><td>Net income</td><td>$2.89</td><td>$2.74</td></tr></table>

Additional details regarding Alliant Energy’s net income and EPS attributable to Alliant Energy common shareowners were as follows (dollars in millions, except per share amount):

<table><tr><td rowspan="2"></td><td colspan="2">2012</td><td colspan="2">2011</td></tr><tr><td>Net Income</td><td>EPS</td><td>Net Income</td><td>EPS</td></tr><tr><td>Continuing operations:</td><td></td><td></td><td></td><td></td></tr><tr><td>Utility and Corporate Services</td><td>$304.8</td><td>$2.75</td><td>$284.5</td><td>$2.57</td></tr><tr><td>Non-regulated and parent</td><td>20.1</td><td>0.18</td><td>38.6</td><td>0.35</td></tr><tr><td>Income from continuing operations</td><td>324.9</td><td>2.93</td><td>323.1</td><td>2.92</td></tr><tr><td>Loss from discontinued operations</td><td>(5.1)</td><td>(0.04)</td><td>(19.5)</td><td>(0.18)</td></tr><tr><td>Net income</td><td>$319.8</td><td>$2.89</td><td>$303.6</td><td>$2.74</td></tr></table>

The table above includes utility and Corporate Services, and non-regulated and parent EPS from continuing operations, which are non-GAAP (accounting principles generally accepted in the U.S.) financial measures. Alliant Energy believes utility and Corporate Services, and non-regulated and parent EPS from continuing operations are useful to investors because they facilitate an understanding of segment performance and trends and provide additional information about Alliant Energy’s operations on a basis consistent with the measures that management uses to manage its operations and evaluate its performance. Alliant Energy’s management also uses utility and Corporate Services EPS from continuing operations to determine performance-based compensation.



Utility and Corporate Services - Higher income from continuing operations in 2012 compared to 2011 was primarily due to:

• $0.12 per share related to income tax impacts at IPL due to Iowa rate-making practices associated with mixed service costs and repairs projects;

• $0.07 per share of impairment charges in 2011;

• $0.06 per share of net regulatory-related charges from IPL’s Minnesota retail electric rate case decision in 2011;

• $0.06 per share of lower generation operation and maintenance expenses;

• $0.05 per share of higher electric margins from changes in the recovery of electric production fuel and energy purchases costs at WPL;

• $0.05 per share of additional benefits costs related to an amendment to the Cash Balance Plan in 2011; and

- $0.05 per share of higher allowance for funds used during construction (AFUDC) in 2012 compared to 2011, primarily due to emission controls projects.

These items were partially offset by:

• $0.14 per share of state income tax charges in the first quarter of 2012 due to changes in state apportionment projections caused by Alliant Energy’s planned sale of the RMT business;

• $0.08 per share of higher depreciation expense in 2012 compared to 2011; and

• $0.07 per share of higher purchased electric capacity expenses related to nuclear PPAs in 2012 compared to 2011.

Non-regulated and parent - Lower income from continuing operations in 2012 compared to 2011 was primarily due to $0.17 per share of tax benefits in 2011 from Wisconsin tax legislation.

Refer to “Results of Operations” for additional details regarding the various factors impacting earnings during 2012, 2011 and 2010.

## Strategic Overview

Alliant Energy’s strategic plan focuses on its core business of delivering regulated electric and natural gas service in Iowa, Wisconsin, and Minnesota. The strategic plan is built upon three key elements: competitive costs, safe and reliable service and balanced generation. Key strategic plan developments impacting Alliant Energy during 2012 and early 2013 include:

- April 2012 - IPL and MidAmerican Energy Company (MidAmerican) each filed an updated Emissions Plan and Budget (EPB) with the Iowa Utilities Board (IUB). IPL’s EPB includes emission controls projects for Ottumwa Unit 1 and Lansing Unit 4. MidAmerican’s EPB includes emission controls projects for George Neal Units 3 and 4. Alliant Energy currently expects the IUB to issue its decisions on IPL’s and MidAmerican’s EPBs in the first quarter of 2013.

- July 2012 - WPL announced plans to retire Edgewater Unit 3 and Nelson Dewey Units 1 and 2 by December 31, 2015, and fuel switch or retire Edgewater Unit 4 by December 31, 2018, subject to necessary approvals.

- July 2012 - WPL filed a Certificate of Authority (CA) application with the Public Service Commission of Wisconsin (PSCW) to install a scrubber and bagnouse system at Edgewater Unit 5 to reduce sulfur dioxide (SO \( _{2} \) ) emissions at the generating facility. WPL expects a decision from the PSCW regarding this emission controls project by the second quarter of 2013. Subject to regulatory approval of the project and the timing of such approvals, WPL expects to begin construction of the project in 2014 and place it in service in 2016.

- November 2012 - IPL announced plans to retire Lansing Unit 3 and Dubuque Units 3 and 4 by December 31, 2014, and Fox Lake Units 1 and 3, Sutherland Units 1 and 3 and various other units by December 31, 2016. The retirement of IPL’s Fox Lake Units 1 and 3 and Sutherland Units 1 and 3 is contingent on the approval and construction of the proposed Marshalltown Generating Station, among other necessary approvals.

- November 2012 - IPL filed for regulatory approvals to construct an approximate 600 MW natural gas-fired combined-cycle electric generating facility in Marshalltown, Iowa, referred to as the Marshalltown Generating Station. These filings included an Application for a Generation Facility Citing Certificate and an advanced rate-making principles filing, which are both required to be approved by the IUB prior to construction of the new facility. The advanced rate-making principles filing included a fixed cost cap of $700 million, excluding AFUDC and transmission upgrade costs, and a return on common equity of 11.25%. IPL expects to receive decisions on the required regulatory approvals for the new facility in the fourth quarter of 2013. Subject to regulatory approvals of the new facility and the timing of such approvals, IPL expects to begin construction of the facility in 2014 and place it in service by the second quarter of 2017.

- November 2012 - IPL filed an Energy Efficiency Plan (EEP) for 2014 through 2018 with the IUB. The EEP includes proposed spending of approximately $400 million for electric and natural gas energy efficiency programs in Iowa from 2014 through 2018, and aspires to conserve electric and gas usage equal to that of more than 100,000 homes.

- December 2012 - WPL purchased the Riverside Energy Center (Riverside), a 600 MW natural gas-fired electric generating facility in Beloit, Wisconsin, from a subsidiary of Calpine Corporation. The purchase price, including certain



transaction-related costs, was $404 million. WPL’s purchase of Riverside replaced the 490 MW of electricity output previously obtained from the Riverside PPA to meet the long-term energy needs of its customers.

• December 2012 - Resources’ Franklin County wind project was completed and began generating electricity.

- January 2013 - The IUB issued an order allowing IPL to move forward with a proposed PPA that was recently negotiated with NER, a subsidiary of NextEra Energy, Inc., for the purchase of capacity and energy generated by the Duane Arnold Energy Center (DAEC) located near Palo, Iowa. The IUB’s January 2013 order authorized IPL to recover the Iowa retail portion of the cost of the proposed PPA from Iowa retail electric customers through the energy adjustment clause.

Refer to “Strategic Overview” for additional details regarding these and other strategic plan developments.

## Rate Matters

Alliant Energy’s utility subsidiaries, IPL and WPL, are subject to federal regulation by the Federal Energy Regulatory Commission (FERC), which has jurisdiction over wholesale electric rates, and state regulation in Iowa, Wisconsin and Minnesota for retail utility rates. Key regulatory developments impacting Alliant Energy during 2012 and early 2013 include:

- May 2012 - IPL filed a request with the IUB to increase annual rates for its Iowa retail gas customers. IPL’s request included a proposal to utilize approximately $36 million of regulatory liabilities over a three-year period to credit bills of Iowa retail gas customers to help mitigate the impact of the proposed final rate increase on such customers. In conjunction with the filing, IPL implemented an interim retail gas rate increase of $9 million, or approximately 3%, on an annual basis, effective June 4, 2012. In November 2012, the IUB approved a settlement agreement between IPL, the Iowa Office of Consumer Advocate (OCA) and the Iowa Consumers Coalition, which includes a final increase in annual rates for IPL’s Iowa retail gas customers of $11 million, or approximately 4%, effective January 10, 2013, a 9.6% return on common equity after the application of double leverage and adoption of IPL’s proposed gas tax benefit rider.

- May 2012 - The PSCW issued an order approving the implementation of updated depreciation rates for WPL effective January 1, 2013 as a result of a recently completed depreciation study. The updated depreciation rates reflect recovery of the remaining net book value of Nelson Dewey Units 1 and 2, and Edgewater Unit 3 over a 10-year period beginning January 1, 2013. In February 2013, the PSCW issued an order approving WPL’s request to implement new depreciation rates for Riverside, effective January 1, 2013.

- July 2012 - WPL received an order from the PSCW authorizing WPL to implement a decrease in annual base rates for WPL’s retail gas customers of $13 million effective January 1, 2013 followed by a freeze of such gas base rates through the end of 2014. The order also granted WPL authority to maintain customer base rates for its retail electric customers at their current levels through the end of 2014. Recovery of the costs for the planned acquisition of Riverside, the selective catalytic reduction (SCR) project at Edgewater Unit 5 and the scrubber and bagnouse projects at Columbia Units 1 and 2 is included in the order. The order also included a return on common equity of 10.4% and the following related provisions: (1) WPL may request a change in retail base rates if its annual return on common equity falls below 8.5%; and (2) WPL must defer a portion of its earnings if its annual return on common equity exceeds 10.65%. The amount of earnings WPL must defer is equal to 50% of its excess earnings between 10.66% and 11.40% and 100% of any excess earnings above 11.40%.

- December 2012 - WPL received an order from the PSCW authorizing an annual retail electric rate decrease of $29 million, or approximately 3%, effective January 1, 2013 as a result of decreases in fuel-related costs expected in 2013. WPL’s 2013 fuel-related costs will be subject to an annual bandwidth of plus or minus 2%.

- January 2013 - The IUB authorized IPL to recover the Iowa retail portion of the costs of its proposed DAEC PPA from Iowa retail electric customers through the energy adjustment clause beginning February 22, 2014. The IUB is encouraging IPL to continue discussions with parties to the proposed DAEC PPA proceeding to resolve concerns expressed by such parties during the proceeding. If IPL is unable to reach an agreement with the parties to resolve their concerns, IPL commits to file an Iowa retail electric base rate case in the first quarter of 2014 and agrees to subject its Iowa retail electric base rates to potential refund beginning February 22, 2014 if the IUB orders a rate decrease from such rate case. If IPL fails to file an Iowa retail electric base rate case in the first quarter of 2014, the amount of costs IPL will be allowed to recover from its Iowa electric retail customers through the energy adjustment clause will be reduced by $12 million each month until temporary rates are set in IPL’s next Iowa retail electric base rate proceeding.

- February 2013 - IPL received an order from the IUB approving the final amount of the regulatory liability from tax benefits for the electric tax benefit rider and a $24 million revenue requirement adjustment to be recognized during 2013. Refer to “Rate Matters” for additional details regarding these and other regulatory developments.

## Environmental Matters

Alliant Energy is subject to regulation of environmental matters by various federal, state and local authorities. Key environmental developments during 2012 that may impact Alliant Energy include:

- April 2012 - The EPA published proposed New Source Performance Standards (NSPS) for greenhouse gases (GHG), including carbon dioxide (CO \( _{2} \) ) emissions from new fossil-fueled electric generating units (EGUs) larger than 25 MW



(not including simple-cycle combustion turbines), with an output-based emissions rate limitation of 1,000 pounds of  \( CO_{2} \)  per megawatt-hour (MWh). This emissions rate limitation is expected to be effective upon the EPA’s issuance of the final rule in the second quarter of 2013. The proposed NSPS for new EGUs is expected to apply to IPL’s proposed construction of the Marshalltown Generating Station.

- May 2012 - The EPA issued a final ozone National Ambient Air Quality Standard (NAAQS) rule that classifies Sheboygan County in Wisconsin as marginal non-attainment, which requires this area to achieve the eight-hour ozone NAAQS of a level of 0.075 parts per million (ppm) by December 2015. WPL operates Edgewater and the Sheboygan Falls Energy Facility in Sheboygan County, Wisconsin.

- August 2012 - The U.S. Court of Appeals for the D.C. Circuit (D.C. Circuit Court) vacated the Cross-State Air Pollution Rule (CSAPR) and remanded it for further revision to the EPA. The D.C. Circuit Court order required the EPA to continue administering the Clean Air Interstate Rule (CAIR) pending the promulgation of a valid replacement for CSAPR. In January 2013, the D.C. Circuit Court denied the EPA’s request for rehearing of the decision that vacated and remanded CSAPR for further revision. Petitioners may seek the Supreme Court’s review of this decision, and during the interim, CAIR remains effective.

- December 2012 - The EPA issued a final rule revising the fine particle primary NAAQS (PM2.5 NAAQS), which strengthens the annual standard from 15 micrograms per cubic meter ( \( \mu \) g/m \( ^{3} \) ) to 12  \( \mu \) g/m \( ^{3} \) . The EPA is expected to designate non-attainment areas for the revised annual PM2.5 NAAQS by December 2015.

- December 2012 - The D.C. Circuit Court denied a request by petitioners for rehearing of the decision that upheld the EPA’s ability to regulate GHG. As a result, the EPA’s GHG regulations remain effective as well as the EPA’s ability to issue additional requirements to reduce GHG emissions. Petitioners may seek the Supreme Court’s review of this decision.

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

## Legislative Matters

Alliant Energy monitors various legislative developments, including those relating to energy, tax, financial and other matters. Recent key legislative developments impacting Alliant Energy during early 2013 include:

- January 2013 - The American Taxpayer Relief Act of 2012 (the ATR Act) was enacted. The most significant provision of the ATR Act for Alliant Energy relates to the extension of bonus depreciation deductions for certain expenditures for property that are incurred through December 31, 2013.

Refer to “Legislative Matters” for additional details regarding this legislative development.

## Liquidity and Capital Resources

Based on its current liquidity position and capital structure, Alliant Energy 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 Alliant Energy during 2012 and early 2013 include:

- March 2012 - IPL extended through March 2014 the purchase commitment from the third-party financial institution to which it sells its receivables.

- September 2012 - Corporate Services issued $75 million of 3.45% senior notes due 2022. The proceeds were used to repay short-term debt primarily incurred for the purchase of the corporate headquarters building and for general working capital purposes.

- November 2012 - Alliant Energy announced an increase in its targeted 2013 annual common stock dividend to $1.88 per share, which is equivalent to a quarterly rate of $0.47 per share, beginning with the February 15, 2013 dividend payment.

- November 2012 - WPL issued $250 million of 2.25% debentures due 2022. The proceeds were used by WPL to fund a portion of the purchase price of Riverside.

- December 2012 - Franklin County Holdings, LLC borrowed $60 million under a variable-rate term loan credit agreement that exists through 2014. The proceeds were used to fund a portion of the costs of the Franklin County wind project.

- December 2012 - At December 31, 2012, Alliant Energy and its subsidiaries had $733 million of available capacity under their revolving credit facilities, $20 million of available capacity at IPL under its sales of accounts receivable program and $21 million of cash and cash equivalents.

• January 2013 - Standard & Poor’s Ratings Services raised Alliant Energy’s, IPL’s and WPL’s credit ratings.

- February 2013 - IPL announced it will redeem all 6,000,000 outstanding shares of its 8.375% cumulative preferred stock in March 2013 at par value for approximately $150 million plus accrued and unpaid dividends to the redemption date. WPL announced it will redeem all 1,049,225 outstanding shares of its 4.40% through 6.50% cumulative preferred stock in March 2013 for approximately $61 million plus accrued and unpaid dividends to the redemption date.

Refer to “Liquidity and Capital Resources” for additional details regarding these and other financing developments and material commitments of capital expenditures.



## Other Matters

Other key developments in 2012 that could impact Alliant Energy’s future financial condition or results of operations are as follows:
• September 2012 - ITC Midwest LLC (ITC) and ATC finalized their respective Attachment “O” rates they propose to charge their customers in 2013 for electric transmission services. The increase in ITC’s and ATC’s Attachment “O” rates, as well as Midwest Independent Transmission System Operator (MISO) transmission charges for shared transmission projects, are expected to contribute to material increases in future electric transmission service charges for IPL and WPL. Alliant Energy, IPL and WPL currently estimate their electric transmission service expenses in 2013 will be approximately $70 million, $60 million and $10 million, respectively, higher than the comparable expenses in 2012. A significant portion of the increase in IPL’s electric transmission service expenses is expected to be offset with increases in electric revenues resulting from the automatic transmission cost recovery rider approved by the IUB and implemented in 2011. Recovery of a significant portion of the increases in WPL’s electric transmission service expenses for 2013 and 2014 was requested as part of WPL’s retail electric and gas rate case for the 2013/2014 test period.

Refer to “Other Matters” for additional details regarding potential impacts to future financial condition and results of operations.

## STRATEGIC OVERVIEW

Strategic Plan - Alliant Energy’s strategic plan focuses on its core business of delivering regulated electric and natural gas service in its Iowa, Wisconsin and Minnesota service territories. The strategic plan is built upon three key elements: competitive costs, safe and reliable service, and balanced generation.

Competitive Costs - Providing competitive and predictable energy costs for customers is a key element of the strategic plan. Alliant Energy is aware that the majority of IPL’s and WPL’s costs become part of rates charged to their customers and any rate increase has an impact on their customers. Given that potential public policy changes and resulting increases in future energy costs are possible, Alliant Energy is focused on controlling its costs with the intent of providing competitive rates to its customers. Alliant Energy and IPL have also proposed tax benefit riders, which utilize tax benefits from income tax strategies to provide credits on Iowa retail customers’ bills to help offset impacts of rate increases. Refer to Note 5 of the “Notes to Consolidated Financial Statements” and “Rate Matters” for further discussion of the electric and gas tax benefit riders. 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. Alliant Energy’s approach to energy efficiency is based on regulations in Iowa, Wisconsin and Minnesota. The objective in each of these states is to meet prescribed goals in the most cost-effective manner. Refer to “Energy Efficiency Programs” below for further discussion of energy efficiency programs used by Alliant Energy.

Safe and Reliable Service - The strategic plan is intended to focus resources on providing safe and reliable electricity and natural gas service. Investments are expected to be targeted in system improvements, replacing aging infrastructure and distribution grid efficiency to maintain strong reliability. Alliant Energy monitors system performance and takes the necessary steps to continually improve the safety and reliability of its service for its customers. Providing exceptional customer service, including emergency and outage response, is part of Alliant Energy’s mission and commitment to the customers it serves.

Balanced Generation - One of the key components of Alliant Energy’s strategic plan is focused on a balanced and flexible portfolio of energy resources that will meet its utility customers’ short- and long-term energy needs. Alliant Energy believes a diversified fuel mix for EGUs is important to meeting the needs of its customers, shareowners and the environment while preparing for a potentially carbon-constrained environment in the future. The current generation plan includes the following diversified portfolio of energy resources:

• Natural gas - purchasing and/or constructing new natural gas-fired EGUs;

- Coal - implementing emission controls and performance upgrades at its newer, larger and more efficient coal-fired EGUs, and fuel switching at, and retirement of, certain older, smaller and less efficient coal-fired EGUs;

• Nuclear - entering into a new nuclear generation PPA related to DAEC; and

- Renewable - completion of a new wind generating facility at Resources and evaluating potential future development of existing wind sites.

Additional details of changes to Alliant Energy’s generation portfolio, as well as discussion of investments in performance and reliability upgrades, are included in “Generation Plans” below. In addition, Alliant Energy’s strategic plan includes new emission controls at its more efficient coal-fired EGUs to continue producing affordable energy for customers and to benefit the environment, which are included in “Environmental Compliance Plans” below.



The strategic plan for Alliant Energy’s non-regulated operations involves maintaining a modest portfolio of businesses that are accretive to earnings but not significant users of capital. In January 2013, Alliant Energy sold the remainder of its RMT business.

Generation Plans - Alliant Energy reviews and updates, as deemed necessary and in accordance with regulatory requirements, its generation plans. Alliant Energy is currently evaluating the types of capacity and energy additions it will pursue to meet its customers' long-term energy needs and is monitoring several related external 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, forward market prices for fossil fuels, market conditions for obtaining financing, developments related to federal and state renewable portfolio standards, environmental requirements, such as any future requirements relating to GHG emissions or renewable energy sources, and federal and state tax incentives.

## Natural Gas-Fired Generation -

IPL’s Proposed Construction of Marshalltown Generating Station - In November 2012, IPL filed for regulatory approvals to construct an approximate 600 MW natural gas-fired combined-cycle electric generating facility in Marshalltown, Iowa, referred to as the Marshalltown Generating Station. These filings included an Application for a Generation Facility Citing Certificate and an advanced rate-making principles filing, which are both required to be approved by the IUB prior to construction of the new facility. The advanced rate-making principles filing included requests for a fixed cost cap of $700 million, excluding AFUDC and transmission upgrade costs, and a return on common equity of 11.25%. In addition, the filing included a request that any costs incurred in excess of the cost cap be incorporated into rates if determined to be reasonable and prudent. This new facility is expected to meet a portion of IPL’s long-term energy resource requirements caused by projected growth in customer demand and the impacts of anticipated retirements of IPL’s older, smaller and less efficient coal-fired and peaking EGUs due to the age of such units and operational and environmental compliance considerations. IPL expects to receive decisions on the required regulatory approvals for the new facility in the fourth quarter of 2013. Subject to regulatory approvals of the new facility and the timing of such approvals, IPL expects to begin construction of the facility in 2014 and place it in service by the second quarter of 2017. Refer to “Liquidity and Capital Resources - Construction and Acquisition Expenditures” for details regarding the capital expenditures in 2013 through 2016 currently anticipated for this facility.

WPL’s Purchase of Riverside - In December 2012, WPL purchased Riverside, a 600 MW natural gas-fired electric generating facility in Beloit, Wisconsin, from a subsidiary of Calpine Corporation. The purchase price, including certain transaction-related costs, was $404 million. WPL’s purchase of Riverside replaced the 490 MW of electricity output previously obtained from the Riverside PPA to meet the long-term energy needs of its customers. Refer to Note 1(e) of the “Notes to Consolidated Financial Statements” for further discussion of WPL’s purchase of Riverside. Refer to “Rate Matters” for discussion of the recovery of the Riverside acquisition costs from WPL’s retail electric customers addressed in the PSCW’s order issued in July 2012 related to WPL’s Wisconsin retail electric and gas rate case (2013/2014 test period).

## Coal-Fired Generation -

Emission Controls Projects - Alliant Energy’s strategic plan includes new emission controls at its newer, larger and more efficient coal-fired EGUs to continue producing affordable energy for customers and to benefit the environment. Refer to “Environmental Compliance Plans” below for details regarding these emission controls projects including the capital expenditures in 2013 through 2016 currently anticipated for these projects.

Generation Improvement Projects - Alliant Energy’s strategic plan includes investments in performance and reliability improvements at its newer, larger and more efficient coal-fired EGUs including IPL’s Lansing Unit 4 and Ottumwa Unit 1, and WPL’s Edgewater Unit 5, and Columbia Units 1 and 2. Refer to “Liquidity and Capital Resources - Construction and Acquisition Expenditures” for details regarding the capital expenditures in 2013 through 2016 currently anticipated for these generation performance improvement projects.

Plant Retirements or Fuel Switching - Alliant Energy’s current strategic plan includes the retirement of, and fuel switching at, several older, smaller and less efficient EGUs. The following table provides a list of the EGUs recently retired as well as EGUs that may be retired or changed from coal-fired to an alternative fuel source in the next five years.



<table><tr><td>EGU (In-Service Year)</td><td>Nameplate Rated Capacity (a)</td><td>Actual / Expected Action (b)</td></tr><tr><td>IPL:</td><td></td><td></td></tr><tr><td>Sixth Street (1900-1950)</td><td>85 MW</td><td>Retired in 2010</td></tr><tr><td>Dubuque Unit 2 (1929)</td><td>15 MW</td><td>Retired in 2010</td></tr><tr><td>M.L. Kapp Unit 1 (1947)</td><td>19 MW</td><td>Retired in 2010</td></tr><tr><td>Prairie Creek Unit 2 (1951)</td><td>23 MW</td><td>Retired in 2010</td></tr><tr><td>Sutherland Unit 2 (1955)</td><td>38 MW</td><td>Retired in 2010</td></tr><tr><td>Lansing Unit 2 (1949)</td><td>12 MW</td><td>Retired in 2010</td></tr><tr><td>Montgomery Unit 1 (1974)</td><td>29 MW</td><td>Retired in 2012</td></tr><tr><td>Lansing Unit 3 (1957)</td><td>38 MW</td><td>Retire by December 31, 2014</td></tr><tr><td>Dubuque Unit 3 (1952)</td><td>29 MW</td><td>Retire by December 31, 2014 (c) (d)</td></tr><tr><td>Dubuque Unit 4 (1959)</td><td>38 MW</td><td>Retire by December 31, 2014 (c) (d)</td></tr><tr><td>Fox Lake Unit 1 (1950)</td><td>12 MW</td><td>Retire by December 31, 2016</td></tr><tr><td>Fox Lake Unit 3 (1962)</td><td>82 MW</td><td>Retire by December 31, 2016 (c) (e)</td></tr><tr><td>Sutherland Unit 1 (1955)</td><td>38 MW</td><td>Retire by December 31, 2016 (e) (f)</td></tr><tr><td>Sutherland Unit 3 (1961)</td><td>82 MW</td><td>Retire by December 31, 2016 (e) (f)</td></tr><tr><td>Other units</td><td>Approximately 200 MW</td><td>Retire by December 31, 2016 (e)</td></tr><tr><td>WPL:</td><td></td><td></td></tr><tr><td>Edgewater Unit 3 (1951)</td><td>60 MW</td><td>Retire by December 31, 2015 (c)</td></tr><tr><td>Nelson Dewey Unit 1 (1959)</td><td>100 MW</td><td>Retire by December 31, 2015 (c)</td></tr><tr><td>Nelson Dewey Unit 2 (1962)</td><td>100 MW</td><td>Retire by December 31, 2015 (c)</td></tr><tr><td>Edgewater Unit 4 (1969)</td><td>225 MW (g)</td><td>Fuel switch or retire by December 31, 2018</td></tr></table>

(a) Nameplate rated capacity represents the nominal amount of electricity an EGU is designed to produce. Each EGU is also assessed a generating capacity amount from MISO through its annual resource adequacy process. The generating capacity amount assessed by MISO is subject to change each year and is based upon the current performance capability of the EGU and is reduced based on historical forced outages.

(b) As of December 31, 2012, the aggregate net book value of EGUs that may be retired or refueled in the future was $68 million for IPL and $97 million for WPL.

(c) Final MISO studies could indicate that the retirement of Dubuque Units 3 and 4, Fox Lake Unit 3, Edgewater Unit 3 and Nelson Dewey Units 1 and 2 may result in reliability issues and that transmission upgrades are necessary to enable the retirement. Under the current MISO tariff, the specific timing for the retirement of these EGUs could depend on the timing of the required transmission upgrades as well as various operational, market and other factors.

(d) Dubuque Units 3 and 4 ceased coal firing in 2011 and are currently fueled with natural gas.

(e) The retirement of IPL’s Fox Lake Unit 3, Sutherland Units 1 and 3 and other units is contingent on the approval and construction of the proposed Marshalltown Generating Station.

(f) Sutherland Units 1 and 3 ceased coal firing in 2012 and are currently fueled with natural gas.

(g) Reflects WPL's 68.2% ownership interest in Edgewater Unit 4.

Alliant Energy will work with MISO, state regulatory commissions and other regulatory agencies, as required, to determine the final timing of these actions. The expected dates for the retirement and fuel switching of these units are subject to change depending on operational, regulatory, market and other factors. Alliant Energy will also continue to evaluate the potential retirement of other EGUs within its generation fleet.

## Nuclear Generation -

IPL’s DAEC PPA - In August 2012, IPL filed for regulatory approvals to enter into a proposed PPA that was negotiated with NER, a subsidiary of NextEra Energy, Inc., for the purchase of capacity and energy generated by DAEC located near Palo, Iowa. In January 2013, the IUB issued an order allowing IPL to proceed with its proposed PPA and authorizing IPL to recover the Iowa retail portion of the cost of the proposed PPA from Iowa retail electric customers through the energy adjustment clause. The terms of the PPA provide IPL the right to NER’s entire output quantities (70% of the total plant output) in exchange for payment from IPL to NER based on the amount of MWhs received by IPL. IPL has agreed to purchase 431 MWs of capacity and the resulting energy from DAEC for a term from the expiration of the existing PPA in February 2014 through December 31, 2025. Among the terms and conditions of the PPA are guarantees by NER to provide minimum amounts of capacity and energy. The PPA also contains provisions for the replacement of energy from alternative sources under certain conditions as well as provisions that convey to IPL the potential environmental attributes associated with its portion of the output from DAEC. Refer to “Rate Matters” for further discussion of the IUB’s January 2013 order approving the DAEC PPA.



WPL’s Kewaunee Nuclear Power Plant (Kewaunee) PPA - In October 2012, Dominion Resources, Inc. (Dominion) announced plans to shut down Kewaunee in the second quarter of 2013. WPL currently expects that Dominion will provide WPL replacement energy and capacity under the terms of the Kewaunee PPA after the Kewaunee plant is shut down through the end of the PPA term in December 2013. As a result, WPL currently expects no material changes to the expected energy and capacity payments under the PPA.

## Wind Generation -

Resources’ Franklin County Wind Project - In 2011, Alliant Energy decided to build the Franklin County wind project, which began generating electricity in the fourth quarter of 2012. Resources is currently selling the electricity output from the wind project into the MISO market as a merchant generator, and is evaluating different options to sell the electricity output from this wind project. Such options include entering into a PPA with an independent third-party, entering into a PPA with either IPL or WPL and/or continuing to sell the output into the MISO market as a merchant generator. Refer to Notes 1(e), 1(f) and 4(d) of the “Notes to Consolidated Financial Statements” for further discussion of the Franklin County wind project. Refer to “Critical Accounting Policies and Estimates - Long-lived Assets” for details of a recent assessment of the recoverability of the carrying amount of the Franklin County wind project.

Undeveloped Wind Sites - IPL has approximately 200 MW of wind site capacity remaining in Franklin County, Iowa. WPL has approximately 200 MW of wind site capacity remaining in Freeborn County, Minnesota. Future development of the balance of these wind sites will depend on numerous factors such as changes in customer demand, renewable portfolio standards, environmental requirements, electricity and fossil fuel prices, wind project costs, technology advancements and transmission capabilities. Refer to Note 1(e) of the “Notes to Consolidated Financial Statements” for further discussion of IPL’s Franklin County wind site.

Environmental Compliance Plans - Alliant Energy has developed environmental compliance plans to help ensure cost effective compliance with current and proposed environmental laws and regulations. Alliant Energy expects these environmental laws and regulations will require significant reductions of future emissions of nitrogen oxide (NOx), SO2, particulate matter (PM), mercury and other hazardous air pollution (HAPs) at its generating facilities. Alliant Energy reviews and updates, as deemed necessary and in accordance with regulatory requirements, its environmental compliance plans to address various external factors. Some of these external factors include regulatory decisions regarding proposed emission controls projects, developments related to environmental regulations, outcomes of legal proceedings, settlements reached with environmental agencies and citizens groups, availability and cost effectiveness of different emission reduction technologies, market prices for electricity and fossil fuels, market prices for emission allowances, market conditions for obtaining financings, and federal and state tax incentives. Refer to “Environmental Matters” for details of certain current and proposed environmental regulations, including regulations for which these plans are expected to support compliance obligations. The following table provides current estimates of capital expenditures planned for 2013 through 2016 as well as the total project costs for emission controls projects included in Alliant Energy’s current environmental compliance plans (in millions):

<table><tr><td>Generating Unit</td><td>Expected In-service Date</td><td>Technology (a)</td><td>2013</td><td>2014</td><td>2015</td><td>2016</td><td>Total Project Cost</td></tr><tr><td>IPL:</td><td></td><td></td><td></td><td></td><td></td><td></td><td></td></tr><tr><td>George Neal Units 3 &amp; 4 (b)</td><td>2013/2014</td><td>Scrubber &amp; Baghouse</td><td>$60</td><td>$30</td><td>$—</td><td>$—</td><td>$120-$140</td></tr><tr><td>Ottumwa Unit 1</td><td>2014</td><td>Scrubber &amp; Baghouse</td><td>65</td><td>25</td><td>—</td><td>—</td><td>150-170</td></tr><tr><td>Lansing Unit 4</td><td>2015</td><td>Scrubber</td><td>15</td><td>30</td><td>10</td><td>—</td><td>50-60</td></tr><tr><td>Other</td><td></td><td>Various</td><td>45</td><td>35</td><td>5</td><td>5</td><td></td></tr><tr><td></td><td></td><td></td><td>185</td><td>120</td><td>15</td><td>5</td><td></td></tr><tr><td>WPL:</td><td></td><td></td><td></td><td></td><td></td><td></td><td></td></tr><tr><td>Columbia Units 1 &amp; 2</td><td>2014</td><td>Scrubber &amp; Baghouse</td><td>145</td><td>20</td><td>—</td><td>—</td><td>280-310</td></tr><tr><td>Edgewater Unit 5</td><td>2016</td><td>Scrubber &amp; Baghouse</td><td>15</td><td>70</td><td>185</td><td>140</td><td>390-430</td></tr><tr><td>Other</td><td></td><td>Various</td><td>10</td><td>—</td><td>—</td><td>20</td><td></td></tr><tr><td></td><td></td><td></td><td>170</td><td>90</td><td>185</td><td>160</td><td></td></tr><tr><td>Alliant Energy</td><td></td><td></td><td>$355</td><td>$210</td><td>$200</td><td>$165</td><td></td></tr></table>

(a) Baghouse, including 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. This process can remove more than 85% of mercury emissions.

Scrubber is a post-combustion process that injects lime or lime slurry into the stream of gases leaving the generating facility boiler to remove SO \( _{2} \)  and other acid gases (including hydrochloric acid) and capture them in a solid or liquid



waste by-product. A scrubber typically removes more than 90% of the SO \( _{2} \)  emissions regardless of generating facility boiler type or design.

(b) George Neal Units 3 and 4 are operated by MidAmerican. IPL owns a 28% interest in George Neal Unit 3 and a 25.695% interest in George Neal Unit 4.

These capital expenditure estimates represent IPL’s or WPL’s respective 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 controls technologies and environmental requirements. The August 2012 D.C. Circuit Court decision that vacated CSAPR and required the EPA to continue administering CAIR is not expected to impact Alliant Energy’s environmental controls projects included in its current environmental compliance plans, which are included in the table above. Refer to Note 1(e) of the “Notes to Consolidated Financial Statements” for further discussion of emission controls projects.

IPL’s Emission Controls Projects - Under Iowa law, IPL is required to file an EPB biennially. Filing of annual periodic reports regarding the implementation of IPL’s compliance plan and related budget identified in an EPB is also currently required under a settlement agreement between IPL and the OCA in Iowa. An EPB provides a utility’s compliance plan and related budget to meet applicable state environmental requirements and federal air quality standards. IUB approval of an EPB demonstrates that the IUB believes the EPB is reasonably expected to achieve cost-effective compliance with applicable state environmental requirements and federal air quality standards. In April 2012, IPL and MidAmerican each filed an updated EPB with the IUB. In September 2012, MidAmerican filed with the IUB a settlement on its EPB reached with the OCA, which includes emission controls projects for George Neal Units 3 and 4. In November 2012, IPL filed with the IUB a settlement on its EPB reached with the OCA, which includes emission controls projects for Ottumwa Unit 1 and Lansing Unit 4. Alliant Energy currently expects the IUB to issue its decisions on IPL’s and MidAmerican’s EPBs in the first quarter of 2013.

George Neal Units 3 and 4 - MidAmerican is currently constructing and installing scrubbers and baghouses at George Neal Units 3 and 4 to reduce SO \( _{2} \)  emissions and mercury emissions at the generating facility. The scrubbers and baghouses at George Neal Units 3 and 4 are expected to support compliance obligations for current and anticipated air quality regulatory requirements, including CAIR, a modified CSAPR or some alternative to these rules that may be implemented, and the Utility Maximum Achievable Control Technology (MACT) Rule.

Ottumwa Unit 1 - IPL is currently constructing a scrubber and baghouse at Ottumwa Unit 1 to reduce SO \( _{2} \)  and mercury emissions at the generating facility. The scrubber and baghouse at Ottumwa Unit 1 are expected to support compliance obligations for current and anticipated air quality regulatory requirements, including CAIR, a modified CSAPR or some alternative to these rules that may be implemented, and the Utility MACT Rule.

Lansing Unit 4 - IPL plans to install a scrubber at Lansing Unit 4 to reduce SO \( _{2} \)  emissions at the generating facility. The scrubber at Lansing Unit 4 is expected to support compliance obligations for current and anticipated air quality regulatory requirements, including CAIR, a modified CSAPR or some alternative to these rules that may be implemented, and the Utility MACT Rule.

Other - Alliant Energy’s current environmental compliance plans also include additional planned expenditures for certain of IPL’s electric generating facilities that Alliant Energy anticipates will be needed to comply with current and anticipated environmental rules, regulations and other compliance requirements related to air quality, water quality and land and solid waste. The environmental compliance plans associated with these additional planned expenditures are subject to change pending further clarity on various pending and anticipated regulatory requirements.

WPL’s Emission Controls Projects - WPL must file a CA and receive authorization from the PSCW to proceed with any individual emission controls project with an estimated project cost of $10 million or more. In 2007, the PSCW approved the deferral of the retail portion of WPL’s incremental pre-certification and pre-construction costs for current or future emission controls projects requiring PSCW approval, effective on the request date of November 2006. Alliant Energy currently anticipates that deferred costs as of December 31, 2012 and thereafter will be recovered in WPL’s future rates and therefore does not expect these costs to have an adverse impact on its financial condition or results of operations.

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. This SCR system at Edgewater Unit 5 was placed in-service in December 2012. This SCR system is expected to support compliance obligations for current and anticipated air quality



regulatory requirements, including CAIR, a modified CSAPR or some alternative to these rules that may be implemented, and the Wisconsin Reasonably Available Control Technology (RACT) Rule.

In July 2012, WPL filed a CA application with the PSCW to install a scrubber and baggage system at Edgewater Unit 5 to reduce SO2 emissions at the generating facility. WPL expects a decision from the PSCW regarding this emission controls project by the second quarter of 2013. Subject to regulatory approval of the project and the timing of such approvals, WPL expects to begin construction of the project in 2014 and place it in service in 2016. The scrubber and baggage system is expected to support compliance obligations for current and anticipated air quality regulatory requirements, including CAIR, a modified CSAPR or some alternative to these rules that may be implemented, the Utility MACT Rule and the Wisconsin State Mercury 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 SO \( _{2} \)  and mercury emissions at the generating facility. The scrubbers and baghouses at Columbia Units 1 and 2 are expected to support compliance obligations for current and anticipated air quality regulatory requirements, including CAIR, a modified CSAPR or some alternative to these rules that may be implemented, the Utility MACT Rule and the Wisconsin State Mercury Rule.

Other - Alliant Energy’s current environmental compliance plans also include additional planned expenditures for certain of WPL’s electric generating facilities that Alliant Energy anticipates will be needed to comply with current and anticipated environmental rules, regulations and other compliance requirements related to air quality, water quality and land and solid waste. The environmental compliance plans associated with these additional planned expenditures are subject to change pending further clarity on various pending and anticipated regulatory requirements.

Energy Efficiency Programs - Alliant Energy has several energy efficiency programs and initiatives that help customers reduce their energy usage and related costs through the use of new energy efficient equipment, products and practices. The following are Alliant Energy’s current key energy efficiency programs:

IPL EEP - In November 2012, IPL filed an EEP for 2014 through 2018 with the IUB. The EEP includes spending approximately $400 million for electric and natural gas energy efficiency programs in Iowa from 2014 through 2018, and aspires to conserve electric and gas usage equal to that of more than 100,000 homes. In accordance with Iowa law, IPL is required to file an EEP every five years. An EEP provides a utility’s plan and related budget to achieve specified levels of energy savings. IUB approval demonstrates that the IUB believes that IPL’s EEP is reasonably expected to achieve cost-effective delivery of the energy efficiency programs. To the extent approved by the IUB, costs associated with executing the EEP are recovered from ratepayers through an additional tariff called an Energy Efficiency Cost Recovery (EECR) factor. The EECR factors are revised annually and include a reconciliation to eliminate any over- or under-recovery of energy efficiency expenses from prior periods. There are no carrying costs associated with the cost recovery factors. The annual EECR factors are based on IPL’s approved budget as filed with its EEP, along with any over- or under-collection from prior periods, and therefore are not expected to have a material impact on Alliant Energy’s financial condition or results of operations.

Focus on Energy Program - In 2012 and 2011, WPL contributed 1.2% and 1.5%, respectively, of annual retail utility revenues to help fund Focus on Energy, Wisconsin’s state-wide energy efficiency and renewable energy resource program.

Shared Savings Programs - IPL and WPL offer energy efficiency programs to certain customers in Minnesota and Wisconsin 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 IPL and WPL with monthly payments over a term up to five years. Refer to Note 4(c) of the “Notes to Consolidated Financial Statements” for additional details of shared savings programs.

## RATE MATTERS

Overview - Alliant Energy has two utility subsidiaries, IPL and WPL. Alliant Energy’s utility subsidiaries are subject to federal regulation by FERC, which has jurisdiction over wholesale electric rates and certain natural gas facilities, and state regulation in Iowa, Wisconsin and Minnesota for retail utility rates and standards of service. Such regulatory oversight also covers IPL’s and WPL’s plans for construction and financing of new generation facilities and related activities.



Recent Retail Base Rate Filings - Details of Alliant Energy’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)):

<table><tr><td>Retail Base Rate Cases</td><td>Utility Type</td><td>Filing Date</td><td>Interim Increase Implemented (a)(b)</td><td>Interim Effective Date</td><td>Final Increase / (Decrease) Granted (b)</td><td>Final Effective Date</td></tr><tr><td>WPL:</td><td></td><td></td><td></td><td></td><td></td><td></td></tr><tr><td>Wisconsin 2013/2014 Test Period</td><td>E/G</td><td>May-12</td><td>N/A</td><td>N/A</td><td>E-$0; G-(\$13)</td><td>Jan-13</td></tr><tr><td>Wisconsin 2011 Test Year</td><td>E</td><td>Apr-10</td><td>N/A</td><td>N/A</td><td>8</td><td>Jan-11</td></tr><tr><td>IPL:</td><td></td><td></td><td></td><td></td><td></td><td></td></tr><tr><td>Iowa 2011 Test Year</td><td>G</td><td>May-12</td><td>$9</td><td>Jun-12</td><td>11</td><td>Jan-13</td></tr><tr><td>Minnesota 2009 Test Year</td><td>E</td><td>May-10</td><td>14</td><td>Jul-10</td><td>8</td><td>Feb-12 (c)</td></tr><tr><td>Iowa 2009 Test Year</td><td>E</td><td>Mar-10</td><td>119</td><td>Mar-10</td><td>114</td><td>Apr-11</td></tr></table>

(a) In Iowa, IPL’s interim rates can be implemented 10 days after the filing date, without regulatory review and are subject to refund, pending determination of final rates. In Minnesota, IPL’s interim rates can be implemented 60 days after the filing date, with regulatory review and are subject to refund, pending determination of final rates. The amount of the interim rates is replaced by the amount of final rates once the final rates are granted.

(b) Base rate changes reflect both returns on additions to infrastructure and recovery of changes in costs incurred or expected to be incurred. Given that a portion of the rate changes will offset changes in costs, revenues from rate changes should not be expected to result in an equal change in income for either IPL or WPL.

(c) In January 2013, IPL filed a request with the Minnesota Public Utilities Commission (MPUC) for full cost recovery of the Minnesota retail portion of IPL’s Whispering Willow - East wind project construction costs. IPL expects to receive a decision from the MPUC in 2013 for the final recovery amount of such costs.

WPL’s Wisconsin Retail Electric and Gas Rate Case (2013/2014 Test Period) - In May 2012, WPL filed a retail base rate filing based on a forward-looking test period that included 2013 and 2014. The filing requested approval for WPL to implement a decrease in annual base rates for WPL’s retail gas customers of $13 million effective January 1, 2013 followed by a freeze of such gas base rates through the end of 2014. The filing also requested authority to maintain customer base rates for WPL’s retail electric customers at their current levels through the end of 2014. Recovery of the costs for the acquisition of Riverside, the SCR project at Edgewater Unit 5 and the scrubber and baggage projects at Columbia Units 1 and 2 were included in the request. The recovery of the costs for these capital projects were offset by decreases in rate base resulting from increased net deferred tax liabilities, the impact of changes in the amortizations of regulatory assets and regulatory liabilities, and the reduction of capacity payments. WPL’s May 2012 retail base rate filing included continuation of a 10.4% return on common equity and the following related provisions: (1) WPL may request a change in retail base rates during the test period if its annual return on common equity falls below 8.5%; and (2) WPL must defer a portion of its earnings if its annual return on common equity exceeds 10.65% during the test period. The amount of earnings WPL must defer is equal to 50% of its excess earnings between 10.66% and 11.40% and 100% of any excess earnings above 11.40%. In addition, the filing requested WPL maintain its ability to request deferrals based on current practices. In July 2012, WPL received an order from the PSCW authorizing WPL to implement its retail base rate filing as requested.

Refer to “WPL’s Retail Fuel-related Rate Filings - 2013 Test Year” below for information on WPL’s retail fuel-related cost filing for 2013. WPL currently expects to make a retail fuel-related cost filing for 2014 in the second or third quarter of 2013. Refer to Note 1(b) of the “Notes to Consolidated Financial Statements” for details of impacts to “Regulatory assets” on the Consolidated Balance Sheet from the PSCW’s July 2012 order.

WPL’s Retail Electric Rate Case (2011 Test Year) - In 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. The request was based on a forward-looking test period that included 2011. The key drivers for the filing included recovery of investments in WPL’s Bent Tree - Phase I wind project and expiring deferral credits, partially offset by lower variable fuel expenses. In December 2010, WPL received an order from the PSCW authorizing an annual retail electric rate increase of $8 million, or approximately 1%, effective January 1, 2011. The annual retail electric rate increase of $8 million reflects a $38 million increase in the non-fuel component of rates and a $30 million decrease in the fuel component of rates. This $8 million increase in annual rates effective January 1, 2011, combined with the termination of the $9 million interim fuel-related rate increase after December 2010, resulted in a net $1 million decrease in annual retail electric rates charged to customers effective January 2011. Refer to “WPL’s Retail Fuel-related Rate Filings - 2010 Test Year” below for additional details of the interim fuel-related rate increase implemented in 2010 and a reduction to the 2011 test year base rate increase for refunds owed to retail electric customers related to interim fuel cost collections in 2010.



IPL’s Iowa Retail Gas Rate Case (2011 Test Year) - In May 2012, IPL filed a request with the IUB to increase annual rates for its Iowa retail gas customers based on a 2011 historical test year as adjusted for certain known and measurable changes occurring up to 12 months after the commencement of the proceeding. The key drivers for the filing included recovery of capital investments since IPL’s last Iowa retail gas rate case filed in 2005. In conjunction with the filing, IPL implemented an interim retail gas rate increase of $9 million, or approximately 3%, on an annual basis, effective June 4, 2012.

In August 2012, IPL, the OCA and the Iowa Consumers Coalition filed a unanimous settlement proposal with the IUB addressing all issues among these parties related to this rate case. In November 2012, the IUB approved the settlement agreement between the parties. The settlement agreement approved by the IUB included a final increase in annual rates for IPL’s Iowa retail gas customers of $11 million, or approximately 4%, effective January 10, 2013, a 9.6% return on common equity after the application of double leverage and adoption of IPL’s proposed gas tax benefit rider discussed below.

Gas Tax Benefit Rider - IPL’s May 2012 retail gas rate case filing with the IUB included a proposal to utilize regulatory liabilities to credit bills of Iowa retail gas customers to help mitigate the impact of the proposed final rate increase on such customers. IPL proposed to reduce customer bills utilizing a gas tax benefit rider over a three-year period by approximately $36 million in aggregate. In the unanimous settlement proposal filed with the IUB in August 2012, all parties agreed to IPL’s proposed utilization of a gas tax benefit rider over a three-year period. In November 2012, IPL received an order from the IUB approving the settlement agreement and authorizing the gas tax benefit rider. The IUB’s order authorized $12 million of regulatory liabilities from tax benefits to be credited to IPL’s retail gas customers’ bills in Iowa during 2013 through the gas tax benefit rider.

IPL’s Minnesota Retail Electric Rate Case (2009 Test Year) - In 2010, IPL filed a request with the MPUC to increase annual rates for its Minnesota retail electric customers based on a 2009 historical test year as adjusted for certain known and measurable items at the time of the filing. The key drivers for the filing included recovery of investments in IPL’s Whispering Willow - East wind project and emission controls projects at Lansing Unit 4, and recovery of increased electric transmission service costs. In conjunction with the filing, IPL implemented an interim retail rate increase of $14 million, on an annual basis, effective July 6, 2010.

In November 2011, IPL received an order from the MPUC establishing a final annual retail electric rate increase equivalent to $11 million. The final annual retail electric rate increase of $11 million includes $8 million of higher base rates, $2 million from the temporary renewable energy rider and $1 million from the utilization of regulatory liabilities to offset higher electric transmission service costs. Because the final rate increase level was below the interim retail rate increase level implemented in July 2010, IPL refunded $4 million, including interest, to its Minnesota retail electric customers in 2012. The MPUC’s order also included the following details:

- Approved IPL’s Minnesota renewable energy rider request on a temporary basis but deferred judgment on the prudence of the Whispering Willow - East wind project costs. Initial recovery amount of the project costs will be allowed through the temporary renewable energy rider at a levelized cost of $51 per MWh. In January 2013, IPL filed a request with the MPUC for full cost recovery of the Minnesota retail portion of IPL’s Whispering Willow - East wind project construction costs of approximately $30 million. IPL expects to receive a decision from the MPUC in 2013 for the final recovery amount for such costs.

- Approved recovery of IPL’s FERC-approved 2010 electric transmission service costs including ITC’s 2008 true-up costs billed to IPL in 2010.

- Approved an additional $5 million of regulatory liabilities owed to Minnesota retail electric customers from the gain on the sale of IPL’s electric transmission assets to ITC in 2007 to offset a portion of transmission rate increases. The MPUC approved the utilization of the $5 million of additional regulatory liabilities over a four-year period beginning with the effective date of interim rates in July 2010.

• Denied IPL’s proposed transmission cost recovery rider.

• Approved recovery of $2 million of Sutherland #4 cancellation costs over a 25-year period.

- Approved a return on common equity of 10.35% and a regulatory capital structure of 47.7% common equity, 43.9% long-term debt, 6.3% preferred equity and 2.1% short-term debt.

Refer to Note 1(b) of the “Notes to Consolidated Financial Statements” for discussion of changes to regulatory assets and regulatory liabilities in 2011 based on the MPUC’s November 2011 order. Refer to Note 1(e) of the “Notes to Consolidated Financial Statements” for discussion of an impairment recognized in 2011 based on the MPUC’s decision regarding the recovery of IPL’s Whispering Willow - East wind project costs.



IPL’s Iowa Retail Electric Rate Case (2009 Test Year) - In 2010, IPL filed a request with the IUB to increase annual rates for its Iowa retail electric customers based on a 2009 historical test year as adjusted for certain known and measurable changes occurring up to 12 months after the commencement of the proceeding. The key drivers for the filing included recovery of investments in the Whispering Willow - East wind project and emission controls projects at Lansing Unit 4, and recovery of increased electric transmission service costs. In conjunction with the filing, IPL implemented an interim retail electric rate increase of $119 million, or approximately 10%, on an annual basis, effective March 20, 2010.

In February 2011, IPL received an order from the IUB authorizing a final annual retail electric rate increase of $114 million, or approximately 10%. Because the final rate increase level was below the interim rate increase level of $119 million implemented on March 20, 2010, IPL refunded $5 million, including interest, to its Iowa retail electric customers in 2011. The IUB issued a separate order in January 2011 that included the following decisions for the 2009 test year rate case:

- Approved IPL’s proposed transmission cost rider conditional upon IPL’s agreement to not file an electric base rate case for three years from the date of the order.

- Disallowed return on investment treatment for the portion of Whispering Willow - East costs incurred above the cost cap associated with the wind turbine generators. In August 2011, the IUB clarified the treatment of these costs to be included in IPL’s rate base with a zero return on investment.

- Authorized use of regulatory liabilities to implement a tax benefit rider discussed below and offset certain electric transmission service costs expected in 2011 and certain capital costs for the Whispering Willow - East wind project.

• Limited recovery of and return on investment treatment to 52.5% of the remaining net book value of Sixth Street.

• Allowed recovery of $7 million of flood-related costs previously incurred in 2009.

Transmission Cost Rider - In January 2011, the IUB approved IPL’s proposal to implement a transmission cost rider for recovery of electric transmission service expenses incurred to provide electric service to IPL’s retail customers in Iowa. The IUB stipulated that the rider would be implemented on a pilot basis conditional upon IPL’s agreement to not file a retail electric base rate case for three years from the date of the order and meet additional reporting requirements. In January 2011, IPL accepted the transmission cost rider with the IUB’s conditions. The transmission cost rider will remain in effect until the IUB’s decision in IPL’s next retail electric base rate case, whereby the rider will be revisited. Effective February 2011, electric transmission service expenses were removed from base rates and billed to IPL’s Iowa retail electric customers through the transmission cost rider. This new cost recovery mechanism provides for subsequent adjustments to electric rates charged to Iowa retail electric customers for changes in electric transmission service expenses. The cumulative effects of the under-/over-collection of these costs will be recorded in regulatory assets or regulatory liabilities on the Consolidated Balance Sheets until they are reflected in future billings to customers.

Electric Tax Benefit Rider - In 2009, IPL filed a request with the IUB to create a regulatory liability account for potential tax benefits resulting from changes in tax accounting methodologies and tax elections available under the Internal Revenue Code. These potential tax benefits are related to the tax treatment of repair expenditures, allocation of insurance proceeds from floods in 2008 and allocation of mixed service costs. In December 2012, IPL filed a report with the IUB requesting approval of the final amount of the regulatory liability account based on the tax benefits generated from these changes in tax accounting methodologies and tax elections that were sustained under Internal Revenue Service (IRS) audit. The December 2012 report filed by IPL identified approximately $500 million of such tax benefits, which includes $452 million allocated for use with the electric tax benefit rider and $48 million allocated for use with the gas tax benefit rider discussed previously. The December 2012 report filed by IPL also requested authority from the IUB to utilize $24 million of the regulatory liability account in 2013 to recognize the revenue requirement impact of the changes in tax accounting methods. In February 2013, the IUB issued an order approving IPL’s December 2012 request, which will result in a revenue requirement adjustment expected to increase Alliant Energy’s electric revenues $24 million in 2013. Beginning in 2014, the revenue requirement adjustment is estimated to be $15 million per year until it is addressed in IPL’s next retail electric base rate case.

The electric tax benefit rider, which was approved by the IUB and implemented in early 2011, utilizes amounts from the regulatory liability account to credit bills of Iowa retail customers to help offset the impact of rate increases on such customers. These credits on customers' electric bills reduce electric revenues each quarter based on customers' kilowatt-hour (KWh) usage. In 2012 and 2011, the electric tax benefit rider utilized $83 million and $61 million of the regulatory liability account to credit IPL's customers' bills at a rate of 0.568 cents per KWh and 0.504 cents per KWh, respectively. In January 2013, the IUB issued an order approving IPL's 2013 electric tax benefit rider tariff, which proposes to utilize $56 million of regulatory liability account in 2013 to credit IPL's retail electric customers' bills at a rate of 0.386 cents per KWh.



The remaining $228 million of the regulatory liability account balance allocated for use with the electric tax benefit rider is currently expected to be utilized subsequent to 2013 and will be dependent on future decisions by the IUB. Refer to Notes 1(b) and 5 of the “Notes to Consolidated Financial Statements” and “Results of Operations - Income Taxes” for additional discussion of the impacts of the electric tax benefit rider on regulatory assets and regulatory liabilities, income tax expense and effective income tax rates.

Management Audit - As part of the IUB’s February 2011 order related to IPL’s Iowa retail electric rate case (2009 test year), the IUB outlined plans for IPL’s management activities to be audited by a third-party vendor. This audit commenced in the third quarter of 2011. In September 2012, the IUB accepted the final IPL management audit report issued by the third-party vendor. In response to the audit, IPL expects to file a progress report by April 1, 2013 and its initial status report by October 1, 2013. Alliant Energy does not currently believe that the final report will have a significant impact upon its financial condition or results of operations.

Refer to Note 1(b) of the “Notes to Consolidated Financial Statements” for additional details of the changes to regulatory assets and regulatory liabilities based on the IUB’s January 2011 order. Refer to Note 1(e) of the “Notes to Consolidated Financial Statements” for additional details of the IUB’s decision in the January 2011 order disallowing IPL a return on a portion of its Whispering Willow - East wind project costs.

## WPL's Retail Fuel-related Rate Filings -

2013 Test Year - In June 2012, WPL filed a request with the PSCW to decrease annual rates for WPL’s retail electric customers to reflect anticipated decreases in retail electric production fuel and energy purchases costs (fuel-related costs) in 2013 compared to the fuel-related cost estimates used to determine rates for 2012. In December 2012, WPL received an order from the PSCW authorizing an annual retail electric rate decrease of $29 million, or approximately 3%, effective January 1, 2013. WPL’s 2013 fuel-related costs will be subject to an annual bandwidth of plus or minus 2%.

2012 Test Year - In 2011, WPL filed a request with the PSCW to increase annual retail electric rates to recover anticipated increases in retail fuel-related costs in 2012 due to higher purchased power energy costs and emission compliance costs. In December 2011, WPL received an order from the PSCW authorizing an annual retail electric rate increase of $4 million, effective January 1, 2012, related to expected changes in retail fuel-related costs for 2012. The 2012 fuel-related costs were subject to an annual bandwidth of plus or minus 2%. Retail fuel-related costs incurred by WPL for 2012 were lower than the approved fuel monitoring level by more than the 2% bandwidth resulting in future refunds anticipated to be used to offset fuel-related cost changes in 2014. As of December 31, 2012, Alliant Energy recorded $11 million in regulatory liabilities on the Consolidated Balance Sheet for refunds anticipated to be used to offset fuel-related cost changes in 2014.

2010 Test Year - In 2010, WPL filed a request with the PSCW to increase annual retail electric rates to recover anticipated increased fuel-related costs in 2010. WPL received approval from the PSCW to implement an interim rate increase of $9 million, on an annual basis, effective in 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 required WPL to use $5 million of the interim fuel rates collected in 2010 as a reduction to the 2011 test year base rate increase.

Potential Future IPL Retail Electric Base Rate Case - In January 2013, the IUB issued an order allowing IPL to proceed with its proposed DAEC PPA and authorized IPL to recover the Iowa retail portion of the costs of such PPA from Iowa retail electric customers through the energy adjustment clause beginning February 22, 2014. The January 2013 order encourages IPL to continue discussions with parties to the proposed DAEC PPA proceeding to resolve concerns expressed by such parties during the proceeding. If IPL is unable to reach an agreement with the parties to resolve their concerns, IPL commits to file an Iowa retail electric base rate case in the first quarter of 2014 and agrees to subject its Iowa retail electric base rates to potential refund beginning February 22, 2014 if the IUB orders a rate decrease from such rate case. If IPL fails to file an Iowa retail electric base rate case in the first quarter of 2014, the amount of costs IPL will be allowed to recover from its Iowa electric retail customers through the energy adjustment clause will be reduced by $12 million each month until temporary rates are set in IPL's next Iowa retail electric base rate proceeding. In February 2013, one of the parties that participated in the proceeding filed a motion for reconsideration, which is still pending.

## Proposed Rule Changes -

Proposed Changes to Energy Adjustment Clause Rules in Iowa - In May 2012, IPL filed a request with the IUB for proposed changes to the energy adjustment clause rules in Iowa. IPL proposed modifications to include cost recovery of emission control chemicals and impacts of future EPA rule changes, including recovery of certain emission allowance costs.



IPL also proposed to allow the option of including production tax credits and renewable energy credit revenues in the energy adjustment clause rules. IPL’s production tax credits related to its Whispering Willow - East wind project are currently being recovered in base rates. In December 2012, the IUB issued an order terminating the rulemaking without adopting IPL’s proposed revisions. The IUB’s order allows IPL the opportunity to address the recovery of these costs through the energy adjustment clause in a future rate case proceeding or rulemaking when there is more certainty with regard to the associated costs.

Rate Case Details - Details of the currently effective rate orders in IPL’s and WPL’s key jurisdictions were as follows (Common Equity (CE); Preferred Equity (PE); Long-term Debt (LD); Short-term Debt (SD); Weighted-average Cost of Capital (WACC)):

<table><tr><td rowspan="2">Jurisdictions</td><td rowspan="2">Test Period</td><td rowspan="2">Authorized Return on Common Equity (a)</td><td colspan="4">Regulatory Capital Structure</td><td rowspan="2">After-tax WACC</td><td rowspan="2">Average Rate Base (in millions)</td></tr><tr><td>CE</td><td>PE</td><td>LD</td><td>SD</td></tr><tr><td>IPL:</td><td></td><td></td><td></td><td></td><td></td><td></td><td></td><td></td></tr><tr><td>Iowa retail (IUB):</td><td></td><td></td><td></td><td></td><td></td><td></td><td></td><td></td></tr><tr><td>Electric:</td><td></td><td></td><td></td><td></td><td></td><td></td><td></td><td></td></tr><tr><td>- Emery (b)</td><td>2009</td><td>11.58%</td><td>48.2%</td><td>6.5%</td><td>45.3%</td><td>N/A</td><td>8.85%</td><td>$281</td></tr><tr><td>- Whispering Willow - East (b)</td><td>2009</td><td>11.09%</td><td>48.2%</td><td>6.5%</td><td>45.3%</td><td>N/A</td><td>8.61%</td><td>266</td></tr><tr><td>- Other (b)</td><td>2009</td><td>9.53%</td><td>48.2%</td><td>6.5%</td><td>45.3%</td><td>N/A</td><td>7.86%</td><td>1,843</td></tr><tr><td>Gas (c)</td><td>2011</td><td>9.56%</td><td>48.8%</td><td>5.0%</td><td>46.2%</td><td>N/A</td><td>7.76%</td><td>255</td></tr><tr><td>Minnesota retail (MPUC):</td><td></td><td></td><td></td><td></td><td></td><td></td><td></td><td></td></tr><tr><td>Electric</td><td>2009</td><td>10.35%</td><td>47.7%</td><td>6.3%</td><td>43.9%</td><td>2.1%</td><td>8.11%</td><td>126 (d)</td></tr><tr><td>Gas</td><td>1994</td><td>10.75%</td><td>41.0%</td><td>7.4%</td><td>44.0%</td><td>7.6%</td><td>8.82%</td><td>7</td></tr><tr><td>Wholesale electric (FERC) (e)</td><td>2012</td><td>10.97%</td><td>48.7%</td><td>5.0%</td><td>46.3%</td><td>N/A</td><td>8.34%</td><td>30</td></tr><tr><td>WPL:</td><td></td><td></td><td></td><td></td><td></td><td></td><td></td><td></td></tr><tr><td>Wisconsin retail (PSCW):</td><td></td><td></td><td></td><td></td><td></td><td></td><td></td><td></td></tr><tr><td>Electric</td><td>2013</td><td>10.40%</td><td>49.3%</td><td>2.0%</td><td>45.5%</td><td>3.2%</td><td>7.81%</td><td>2,105 (f)</td></tr><tr><td>Electric</td><td>2014</td><td>10.40%</td><td>49.4%</td><td>1.9%</td><td>44.2%</td><td>4.5%</td><td>7.77%</td><td>2,240 (f)</td></tr><tr><td>Gas</td><td>2013</td><td>10.40%</td><td>49.3%</td><td>2.0%</td><td>45.5%</td><td>3.2%</td><td>7.81%</td><td>196 (f)</td></tr><tr><td>Gas</td><td>2014</td><td>10.40%</td><td>49.4%</td><td>1.9%</td><td>44.2%</td><td>4.5%</td><td>7.77%</td><td>199 (f)</td></tr><tr><td>Wholesale electric (FERC) (g)</td><td>2012</td><td>10.90%</td><td>55.0%</td><td>N/A</td><td>45.0%</td><td>N/A</td><td>8.65%</td><td>194 (h)</td></tr></table>

(a) Authorized returns on common equity may not be indicative of actual returns earned or projections of future returns.

(b) Authorized returns on common equity and after-tax WACC reflect application of double leverage pursuant to the IUB’s January 2011 order discussed above. Prior to the application of double leverage, authorized returns on common equity were: Emery Generating Station (Emery)-12.23%, Whispering Willow-East-11.7% and Other-10.0%, and after-tax WACC were: Emery-9.16%, Whispering Willow-East-8.91% and Other-8.09%.

(c) Authorized returns on common equity and after-tax WACC reflect application of double leverage pursuant to the unanimous settlement agreement approved in the IUB’s November 2012 order. Prior to the application of double leverage, authorized return on common equity was 10.0% and after-tax WACC was 8.0%.

(d) Average rate base amounts do not include Whispering Willow - East capital costs, which are currently being recovered through a temporary renewable energy rider approved by the MPUC. In January 2013, IPL filed a request with the MPUC for full cost recovery of the Minnesota retail portion of IPL’s Whispering Willow - East wind project construction costs. IPL expects to receive a decision from the MPUC in 2013 for the final recovery amount for such costs.

(e) IPL’s wholesale formula rates reflect annual changes in CE, PE, LD, WACC and rate base.

(f) Average rate base amounts do not include construction work in progress (CWIP) or a cash working capital allowance. The PSCW provides a return on selected CWIP and a cash working capital allowance by adjusting the percentage return on rate base.

(g) WPL’s wholesale formula rates reflect annual changes in WACC and rate base.

(h) WPL’s wholesale average rate base reflects production-related rate base calculated as the simple average of the beginning of year and end of year balances in accordance with WPL’s approved formula rates. The 2012 amount excludes the impact of WPL’s acquisition of Riverside in December 2012. The impact of WPL’s acquisition of Riverside will be included in WPL’s wholesale formula rates beginning in 2013.



## Other -

WPL Depreciation Study - In May 2012, the PSCW issued an order approving the implementation of updated depreciation rates for WPL effective January 1, 2013 as a result of a recently completed depreciation study. The updated depreciation rates reflect recovery of the remaining net book value of Nelson Dewey Units 1 and 2, and Edgewater Unit 3 over a 10-year period beginning January 1, 2013. In November 2012, WPL filed a request with the PSCW to revise previously approved depreciation rates applicable to Riverside based on updated information regarding the expected carrying value of the assets being purchased. In February 2013, the PSCW issued an order approving WPL's request to revise depreciation rates for Riverside, effective January 1, 2013. Refer to “Strategic Overview” for details of anticipated retirements of Nelson Dewey Units 1 and 2, and Edgewater Unit 3. Refer to Note 1(e) of the “Notes to Consolidated Financial Statements” for details of the depreciation study.

In December 2012, FERC issued an order approving the implementation and inclusion of the updated depreciation rates in WPL’s wholesale formula rates effective January 1, 2013. In February 2013, WPL filed a request with FERC for new depreciation rates associated with Riverside effective January 1, 2013.

FERC Audit - As part of routine procedures, in the fourth quarter of 2011, FERC commenced an audit of Alliant Energy, including its centralized service company (Corporate Services) and other affiliated companies. In January 2013, FERC issued a final report related to this audit. Alliant Energy does not believe that the final report will have a significant impact on its financial condition or results of operations.

## ENVIRONMENTAL MATTERS

Overview - Alliant Energy is subject to regulation of environmental matters by federal, state and local authorities as a result of its current and past operations. Alliant Energy monitors these environmental matters and addresses them with emission 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, Alliant Energy has established an integrated planning process that is used for environmental compliance for its operations. Alliant Energy anticipates future expenditures for environmental compliance will be material, including significant capital investments. Alliant Energy anticipates that prudent expenditures incurred by IPL and WPL to comply with environmental requirements likely would be recovered in rates from IPL's and WPL's customers. Refer to "Strategic Overview - Environmental Compliance Plans" for details of environmental compliance plans, including estimated capital expenditures. The following are major environmental matters that could potentially have a significant impact on Alliant Energy's financial condition and results of operations.

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 NAAQS rules, which serve to protect public health and welfare. These standards address six “criteria” pollutants, four of which (NOx, SO2, PM, and ozone) are particularly relevant to Alliant Energy’s electric utility operations. Ozone is not directly emitted from Alliant Energy’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 rules 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. Routinely monitored locations that do not comply with NAAQS rules 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 rules. The specific federal and state air quality regulations that may affect Alliant Energy’s operations are listed in the table below. Alliant Energy 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 (PSD) permitting programs and NSPS; and proposed legislation or other regulatory actions to regulate the emission of GHG. Refer to the sections below the following tables for detailed discussion of the following air quality regulations.



<table><tr><td>Environmental Regulation</td><td>Emissions Regulated</td><td>Alliant Energy&#x27;s Primary Facilities Potentially Affected</td><td>Actual/Anticipated Compliance Deadline</td></tr><tr><td>CAIR</td><td>SO2, NOx</td><td>Fossil-fueled EGUs over 25 MW capacity in IA and WI</td><td>Phase I - NOx (2009) and SO2 (2010); Phase II - 2015</td></tr><tr><td>CAVR</td><td>SO2, NOx, PM</td><td>Fossil-fueled EGUs built between 1962 and 1977 in IA, WI and MN</td><td>To Be Determined (TBD)</td></tr><tr><td>Utility MACT Rule</td><td>Mercury and other HAPs</td><td>Coal-fueled EGUs over 25 MW capacity in IA, WI and MN</td><td>April 2015 (a)</td></tr><tr><td>Wisconsin State Mercury Rule</td><td>Mercury</td><td>WPL&#x27;s coal-fueled EGUs over 25 MW capacity</td><td>Phase I - 2010; Phase II - 2015</td></tr><tr><td>Wisconsin RACT Rule</td><td>NOx</td><td>WPL&#x27;s Edgewater Units 3-5</td><td>Phase I - 2009; Phase II - 2013</td></tr><tr><td>Industrial Boiler and Process Heater MACT Rule</td><td>Mercury and other HAPs</td><td>IPL&#x27;s Prairie Creek boilers 1, 2 and 5</td><td>2016</td></tr><tr><td>Ozone NAAQS Rule</td><td>NOx</td><td>Fossil-fueled EGUs in non-attainment areas</td><td>December 2015</td></tr><tr><td>Fine Particle NAAQS Rule</td><td>SO2, NOx, PM</td><td>Fossil-fueled EGUs in non-attainment areas</td><td>2020</td></tr><tr><td>NO2 NAAQS Rule</td><td>NO2</td><td>Fossil-fueled EGUs in non-attainment areas</td><td>TBD</td></tr><tr><td>SO2 NAAQS Rule</td><td>SO2</td><td>Fossil-fueled EGUs in non-attainment areas</td><td>2017</td></tr></table>

(a) An additional year for compliance can be requested, which may be granted on a case-by-case basis by state permitting authorities.

The following table lists the fossil-fueled EGUs by primary fuel type that IPL and WPL currently own or operate with greater than 25 MW of nameplate capacity. All of IPL's EGUs listed below are located in Iowa except for Fox Lake Unit 3, which is located in Minnesota. All of WPL's EGUs listed below are located in Wisconsin. Refer to "Strategic Overview" for discussion of various EGUs that may be retired or changed from coal-fired to an alternative fuel source in the next five years.

<table><tr><td colspan="3">IPL</td><td colspan="2">WPL</td></tr><tr><td>Coal</td><td>Natural Gas</td><td>Oil</td><td>Coal</td><td>Natural Gas</td></tr><tr><td>Ottumwa 1</td><td>Emery 1-3</td><td>Marshalltown 1-3</td><td>Columbia 1-2</td><td>Sheboygan Falls 1-2</td></tr><tr><td>Lansing 3-4</td><td>Fox Lake 3</td><td>Lime Creek 1-2</td><td>Edgewater 3-5</td><td>Neenah 1-2</td></tr><tr><td>M.L. Kapp 2</td><td>Dubuque 3-4</td><td></td><td>Nelson Dewey 1-2</td><td>South Fond du Lac 1-4</td></tr><tr><td>Burlington 1</td><td>Sutherland 1,3 (a)</td><td></td><td></td><td>Rock River 3,5-6</td></tr><tr><td>George Neal 3-4</td><td></td><td></td><td></td><td>Sheepskin 1</td></tr><tr><td>Prairie Creek 3-4</td><td></td><td></td><td></td><td>Riverside 1-3</td></tr><tr><td>Louisa 1</td><td></td><td></td><td></td><td></td></tr></table>

(a) In 2012, IPL switched Sutherland Units 1 and 3 to using natural gas as their primary fuel type; however, Sutherland Units 1 and 3 are still permitted to burn coal and are subject to all of the coal-burning EGU air regulations.

As discussed in greater detail below, a number of these air regulations are subject to legal challenges, reconsideration and/or other uncertainties that affect Alliant Energy’s ability to predict with certainty what impact such regulations may have on its financial condition and results of operations.

CAIR/CSAPR - CAIR includes a regional cap-and-trade system covering the eastern U.S., where compliance may be achieved by either adding emission controls and/or purchasing emission allowances. In 2011, the EPA issued CSAPR as a replacement to resolve flaws with CAIR identified in a 2008 opinion issued in response to legal challenges to this rule. This rule similarly included requirements to reduce SO2 and NOx (both annual and ozone season) emissions. IPL's and WPL's fossil-fueled EGUs with greater than 25 MW of capacity located in Iowa, Minnesota and Wisconsin would have been impacted by CSAPR requirements. In August 2012, however, the D.C. Circuit Court vacated CSAPR, remanding it for further revision to the EPA. The D.C. Circuit Court order required the EPA to continue administering CAIR pending the promulgation of a valid replacement for CSAPR. In October 2012, the EPA, as well as several states, cities and other organizations, filed petitions for rehearing of the August 2012 decision that vacated CSAPR. In January 2013, the D.C. Circuit Court denied the EPA's request for rehearing of the decision that vacated and remanded CSAPR for further revision. Petitioners may seek the Supreme Court's review of this decision, and during the interim, CAIR remains effective. Given that these rules remain subject to potential further reconsideration by the EPA in response to legal challenges, Alliant Energy is currently unable to predict with certainty the impact on its financial condition or results of operations. Alliant Energy currently believes that CAIR will be replaced in the future, either by a modified CSAPR or another rule that addresses the interstate transport of air pollutants, and expects that capital investments and/or modifications to its EGUs to meet the final compliance requirements will be significant.



Clean Air Visibility Rule (CAVR) - CAVR requires states to develop and implement plans to address visibility impairment in designated national parks and wilderness areas across the country with a national goal of no impairment by 2064. These implementation plans require Best Available Retrofit Technology (BART) emission controls and other additional measures needed for reducing state contributions to regional haze. There are pending obligations under the EPA’s CAVR to complete BART determinations that would evaluate control options to reduce these emissions at certain fossil-fueled IPL and WPL EGUs that were under construction between 1962 and 1977. IPL’s facilities that may be impacted include Burlington Unit 1, George Neal Units 3 and 4, Prairie Creek Unit 4, M.L. Kapp Unit 2 and Lansing Unit 4. WPL’s facilities that may be impacted include Edgewater Unit 4, Nelson Dewey Unit 2, and Columbia Units 1 and 2.

In 2012, the EPA published a final rule that would allow BART obligations for SO2 and NOx emissions to be fulfilled by compliance with CSAPR. In 2012, the EPA also approved CAVR plans for Iowa, Wisconsin and Minnesota, which would require compliance with CSAPR to fulfill BART requirements for SO2 and NOx emission reductions. In August 2012, the EPA rule that allowed for CAVR BART obligations to be met by CSAPR was challenged in the D.C. Circuit Court. In October 2012, parties also filed legal challenges to the EPA’s final approvals of Iowa, Wisconsin and Minnesota CAVR plans including the application of CSAPR to meet BART requirements at affected EGUs. The D.C. Circuit Court has stayed action on these cases pending resolution of the legal challenges to CSAPR, which will determine if CAVR is upheld or remanded for reconsideration. It is unknown whether the EPA will allow BART to be fulfilled by CAIR, a modified CSAPR or another rule pending the ongoing D.C. Circuit Court’s review of these regulations and the EPA’s responses to resolve the court orders on these rules. If the EPA does not allow for BART to be fulfilled by CAIR, a modified CSAPR or another rule, then facility-specific BART evaluations will be needed for each impacted unit to determine what emission controls must be installed to address visibility improvements. In addition, there are uncertainties whether additional emission reductions could be required to address regional haze impacts beyond BART. Alliant Energy is unable to predict with certainty the impact that CAVR might have on the operations of its existing EGUs until the legal challenges to CAIR and CSAPR are resolved.

Utility MACT Rule - In 2011, the EPA issued the final Utility MACT Rule, also referred to as the Mercury and Air Toxic Standard. The final rule requires compliance with emission limits for mercury, filterable PM as a substitute for non-mercury metal HAPs and hydrogen chloride (HCl) as a substitute for acid gas HAPs. The EPA also proposed alternative standards for total or individual non-mercury metals emissions (instead of filterable PM) and SO2 emissions (instead of HCl for acid gases if a scrubber is installed). In addition, work practice standards were proposed for organic HAPs emissions to ensure proper combustion. Compliance is currently anticipated to be required by April 2015. However, an entity can request an additional year for compliance, which may be granted on a case-by-case basis by state permitting authorities for units that are needed to assure power reliability, units needed while building replacement generation or repowering to gas, or units that need additional time to install air emission controls technology. In November 2012, the EPA issued a proposed reconsideration to limited aspects to the Utility MACT rule including revisions to the startup and shutdown provisions for existing EGUs. The EPA plans to issue a final reconsideration rule by March 2013. The final Utility MACT Rule is subject to legal challenge that is pending in the D.C. Circuit Court. Given that this rule remains subject to legal challenge in the D.C. Circuit Court and possible revision due to the proposed reconsideration rule, Alliant Energy is unable to predict with certainty the impact of the final Utility MACT rule on its financial condition and results of operations, but expects that capital investments and/or modifications to its electric generating facilities could be significant to comply with the rule.

Wisconsin State Mercury Rule - The Wisconsin State Mercury Rule requires electric utility companies in Wisconsin to meet compliance requirements to reduce annual mercury emissions by 40% from a historic baseline beginning in 2010 (Phase I). In addition, this rule requires large coal-fueled 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-fueled EGUs between 25 MW and 150 MW of capacity must install Best Available Control Technology by January 2015 to reduce mercury emissions. As an alternative, this rule allows large and small EGUs to achieve compliance through averaging of covered emissions. In 2010, WPL filed its compliance plan with the Wisconsin Department of Natural Resources (DNR), which states WPL will utilize large and small EGU averaging to comply with the additional mercury rule emission reduction requirements that commence in 2015. The issuance of the final Utility MACT Rule is expected to initiate a review of, and may cause revisions to, the Wisconsin State Mercury Rule. Alliant Energy continues to evaluate the impact of this state mercury rule and the federal Utility MACT Rule discussed above on its financial condition and results of operations to determine further mercury emission reductions that would be required.

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 federal 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 controls technologies at Edgewater, which met the 2009 to 2012 compliance requirements (Phase I). In the fourth quarter of 2012, WPL completed the installation of an SCR system at Edgewater to support achieving compliance with the 2013 requirements, which include facility boiler NOx rate limitations and a mass emissions cap (Phase II). Refer to “Strategic Overview - Environmental Compliance Plans - WPL’s Emission Controls Projects” for further discussion of the Edgewater SCR system.

Industrial Boiler and Process Heater MACT Rule - In December 2012, the EPA issued a final reconsidered Industrial Boiler and Process Heater MACT Rule with a compliance deadline of early 2016 for major sources. The rule is expected to apply to IPL's Prairie Creek boilers 1, 2 and 5, and fossil-fueled auxiliary boilers and process heaters operated at other IPL and WPL fossil-fueled facilities. The rule requires compliance with HAPs emission limitations and work practice standards. The final rule remains subject to legal challenges in the D.C. Circuit Court. Alliant Energy is currently evaluating the final rule and plans to update its environmental compliance plans as needed. Given that this rule remains subject to legal challenges in the D.C. Circuit Court, Alliant Energy is currently unable to predict with certainty the impact of the Industrial Boiler and Process Heater MACT rule on its financial condition and results of operations, but expects that capital investments and/or modifications to its electric generating facilities to meet compliance requirements of the rule could be significant.

Ozone NAAQS Rule - In 2008, the EPA announced reductions in the primary NAAQS for eight-hour ozone to a level of 0.075 ppm from the previous standard of 0.08 ppm. In May 2012, the EPA issued a final rule that classifies Sheboygan County in Wisconsin as marginal non-attainment, which requires this area to achieve the eight-hour ozone NAAQS by December 2015. WPL operates Edgewater and the Sheboygan Falls Energy Facility in Sheboygan County, Wisconsin. The final rule does not list any areas as ozone non-attainment in Iowa or Minnesota that impact IPL. Another rule is currently expected to be issued by the EPA in 2013 to assist state agencies in developing SIPs. The SIPs will explain what actions and emission reductions may be required for compliance to achieve attainment. The Edgewater Unit 5 SCR system completed in the fourth quarter of 2012 is expected to assist with possible compliance obligations under an ozone NAAQS SIP for Wisconsin. Given the ozone NAAQS remains subject to legal challenges in the D.C. Circuit Court and the Wisconsin DNR has not yet issued an eight-hour ozone non-attainment SIP, Alliant Energy is currently unable to predict with certainty the impact of the ozone NAAQS changes for Sheboygan County, Wisconsin on its financial condition and results of operations.

Fine Particle NAAQS Rule - In December 2012, the EPA issued a final rule revising the PM2.5 NAAQS, which strengthens the annual standard from 15 ug/m3 to 12 ug/m3. The EPA is expected to designate non-attainment areas for the revised annual PM2.5 NAAQS by December 2015. States with areas designated as non-attainment will be required to submit PM2.5 NAAQS SIPs within three years of the effective date of area designations by the EPA. The SIPs will explain what actions are needed in the non-attainment areas to achieve compliance with annual PM2.5 NAAQS. Compliance with the final rule is expected to be required by 2020 for non-attainment areas designated in 2015. Given that the EPA has not yet designated non-attainment areas and the PM2.5 NAAQS SIPs have not been issued, Alliant Energy is currently unable to predict with certainty the impact of the final PM2.5 NAAQS rule on its financial condition and results of operations.

Nitrogen Dioxide (NO2) NAAQS Rule - In 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 parts per billion (ppb) and associated ambient air monitoring requirements, while maintaining the current annual standard of 53 ppb. In February 2012, the EPA issued a final response to state recommendations and is not proposing to designate any non-attainment areas in Iowa, Minnesota and Wisconsin. The EPA is expected to re-evaluate these designations in 2016 based on expanded monitoring data. The schedule for compliance with this rule has not yet been established. Given that the EPA has not yet re-evaluated designations, Alliant Energy is currently unable to predict with certainty the impact of any potential NO2 NAAQS changes on its financial condition and results of operations.

SO2 NAAQS Rule - In 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 plans to finalize non-attainment designations for certain areas in Iowa and Wisconsin in June 2013. IPL and WPL do not operate any EGUs in any areas expected to be designated as non-attainment in 2013. Compliance with the SO2 NAAQS rule is currently expected to be required by 2017 for non-attainment areas finalized in 2013. Non-attainment designations for the remainder of Iowa and Wisconsin have been delayed to allow for modeling and collection of additional monitoring data. Given that the EPA has not yet issued final non-attainment designations, Alliant Energy is currently unable to predict with certainty the impact of any potential SO2 NAAQS changes on its financial condition and results of operations.

Air Permit Renewal Challenges - Alliant Energy 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 WPL’s



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. Below are recent developments regarding air permit renewal challenges for Columbia, Edgewater and Nelson Dewey.

Columbia - In 2011, the Sierra Club filed a lawsuit against the EPA in the U.S. District Court for the Western District of Wisconsin seeking to have the EPA take over the Title V air permit process for Columbia. The Sierra Club alleges the EPA must now act on the reconsideration of the permit since the Wisconsin DNR has exceeded its timeframe in which to respond to an EPA order issued in 2009. In 2011, the Wisconsin DNR proposed a revised draft operation permit for Columbia and WPL and the Sierra Club submitted comments objecting to its appropriateness. In June 2012, Alliant Energy received a notice from the EPA of its proposal for WPL to apply for a Federal Part 71 operation permit since the Wisconsin DNR has not addressed the EPA’s objections to the Title V operation permit issued by the Wisconsin DNR to Columbia. Alliant Energy has until March 15, 2013 to comment on the EPA’s proposal. If the EPA decides to require the submittal of an operation permit, it would be due within six months of the EPA’s notice to Alliant Energy. Alliant Energy believes the Title V operation permit previously issued by the Wisconsin DNR for Columbia is still valid. Alliant Energy is currently unable to predict with certainty the outcome of this matter and the impact on its financial condition or results of operations.

Edgewater - In 2010, WPL received a copy of a notice of intent to sue 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 reconsideration of the Edgewater Title V air permit. Specifically, the Sierra Club alleges that because the Wisconsin DNR has exceeded its timeframe in which to respond to an earlier EPA order, the EPA must now act on the reconsideration of the permit. In October 2012, the Wisconsin DNR made a revised proposed Title V air permit for Edgewater available for public comment. WPL and Sierra Club submitted comments on the proposed permit revision. Alliant Energy believes the previously issued air permit for Edgewater is still valid. Alliant Energy is currently unable to predict with certainty the outcome of this matter and the impact on its financial condition and results of operations.

Nelson Dewey - In September 2010, the Sierra 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 by the Wisconsin DNR in 2008 should be corrected because certain modifications were made at the facility without complying with the PSD program requirements. In 2010, WPL filed a response to the petition with the EPA and the Wisconsin DNR objecting to its claims and supporting the Wisconsin DNR’s issuance of the current permit. No action on this petition has been taken by the EPA or the Wisconsin DNR. Alliant Energy believes the previously issued air permit for Nelson Dewey is still valid. Alliant Energy is currently unable to predict with certainty the outcome of this petition and the impact on its financial condition and results of operations.

Air Permitting Violation Claims - Refer to Note 13(c) of the “Notes to Consolidated Financial Statements” for discussion of a notice of violation issued by the EPA in 2009 and complaints filed by the Sierra Club in 2010 regarding alleged air permitting violations at Nelson Dewey, Columbia and Edgewater.

EPA Information Request - In October 2011, MidAmerican received an EPA Region VII request under Section 114 of the CAA for certain information relating to the historical operation of George Neal Units 3 and 4, and Louisa, which are coal-fueled generating units in Iowa that are jointly owned by IPL. IPL owns 28%, 25.695% and 4% of George Neal Unit 3, George Neal Unit 4 and Louisa, respectively. MidAmerican responded to this data request in December 2011. Depending upon the results of the EPA’s review of the information provided by MidAmerican, the EPA may perform any of the following: issue a notice of violation asserting that a violation of the CAA occurred; seek additional information from MidAmerican, IPL and/or third-parties who have information relating to the boilers; and/or close out the investigation. Alliant Energy cannot currently predict with certainty the impact of the EPA’s request and any subsequent action taken by the EPA or citizen groups on its financial condition and results of operations.

Other Air Quality Matters - IPL, the EPA, the State of Iowa and the Sierra Club are in discussions regarding CAA issues associated with IPL's Iowa operations. Alliant Energy believes that IPL is in compliance with the CAA. IPL is pursuing these discussions because IPL believes there is an opportunity to reach an agreement among the parties that avoids potential litigation and the long-term planning and operational uncertainty associated with such litigation. Alliant Energy believes that any agreement could contain terms similar to those seen in other EPA CAA settlements, including, among others, the installation of emission controls, the retirement or fuel switching of EGUs, compliance with specified emission rates and emission caps, beneficial environmental mitigation projects and penalties. Alliant Energy is currently unable to predict with certainty the outcome of these discussions and the impact on its financial condition or results of operations.



## 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 certain steam EGUs. In 2011, the EPA issued a revised proposed Section 316(b) Rule, which applies to existing and new cooling water intake structures at certain steam EGUs and manufacturing facilities. IPL and WPL have identified nine (Ottumwa 1, Prairie Creek Units 3-4, Fox Lake Units 1 and 3, Lansing Units 3-4, Dubuque Units 3-4, M.L. Kapp Unit 2, Burlington Unit 1, George Neal Units 3-4 and Louisa Unit 1) and three (Columbia Units 1-2, Nelson Dewey Units 1-2 and Edgewater Units 3-5) electric generating facilities, respectively, which may be impacted by the revised Section 316(b) Rule. A final rule is expected to be issued by the EPA in 2013. The schedule for compliance with this rule has not yet been finalized; however, compliance is currently expected to be required within eight years of the effective date of the final rule. Alliant Energy is currently unable to predict with certainty the impact of the EPA’s Section 316(b) rule on its financial condition and results of operations.

Wisconsin and Iowa State Thermal Rules - 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. All IPL and WPL facilities are subject to these standards upon state promulgation, which become applicable upon their incorporation into a facility’s wastewater discharge permit. States have authority to establish standards for these discharges in order to minimize adverse environmental impacts to aquatic life. In Iowa and Wisconsin, the Iowa DNR and Wisconsin DNR are required to regulate thermal impacts from wastewater discharges of industrial facilities in their respective states, including IPL and WPL facilities that discharge water into nearby rivers and streams. Compliance with the thermal rules will be evaluated on a case-by-case basis when wastewater discharge permits for IPL’s and WPL’s generating facilities are renewed. Alliant Energy continues to evaluate the thermal rule regulatory requirements and the compliance options available to meet the heat limitations for discharges from IPL’s and WPL’s EGUs. Alliant Energy is unable to predict with certainty the final requirements of these rules until wastewater discharge permits for impacted facilities are renewed. If capital investments and/or modifications are required, Alliant Energy believes these investments could be significant.

Hydroelectric Fish Passage Device - In 2002, FERC issued an order requiring WPL to develop a detailed engineering and biological evaluation of potential fish passages for its Prairie du Sac hydro plant and install an agency-approved fish passage at that facility. The U.S. Fish and Wildlife Service (FWS) and the Wisconsin DNR have requested additional information to support the conceptual plan for the fish passage. In March 2012, FERC approved an updated deadline to install an agency-approved fish passage device at the facility by July 1, 2015. Alliant Energy currently believes the required capital investments and/or modifications to install the fish passage device at the facility will be approximately $15 million. Alliant Energy is currently reviewing the project, which may change its expected capital investments. In January 2013, WPL requested the FWS to delay or withdraw the fish passage requirement due to recent concerns regarding Asian carp and other invasive species. The FWS agreed to prepare an environmental impact study, which may take up to a year to complete, during which time WPL is expected to request a further extension of the project deadline. As of December 31, 2012, Alliant Energy had $5 million recorded in “Utility property, plant and equipment” on the Consolidated Balance Sheet for the fish passage device project.

## Land and Solid Waste -

Coal Combustion Residuals (CCRs) - Alliant Energy is monitoring potential regulatory changes that may affect the rules for operation and maintenance of coal ash surface impoundments (ash ponds) and/or landfills, in the wake of a structural failure in the containment berm of a coal ash surface impoundment at a site operated by an unrelated, third-party utility. In 2009, IPL and WPL responded to information collection requests from the EPA for data on coal ash surface impoundments at certain of their facilities. The EPA continues to evaluate the responses and has been conducting site assessments of utilities' coal ash surface impoundments, including certain coal ash surface impoundments operated by IPL and WPL.

In 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. IPL and WPL have nine and four current or former coal generating facilities, respectively, with one or more existing coal ash surface impoundments at each location. In addition, IPL and WPL each have two active CCR company-owned landfills. All of these CCR disposal units would be subject to the proposed rule currently anticipated to be finalized in 2013. The schedule for compliance with this rule has not yet been established. Alliant Energy is currently unable to predict with certainty the impact of these information collection.



requests, site inspections, or potential regulations for the management of CCRs, but expects that capital investments, operating expenditures and/or modifications to comply with CCR rules could be significant.

Closed Ash Landfill Sites - In 2004, IPL received communication from the Iowa DNR regarding an evaluation of groundwater monitoring results for four of its closed ash landfills and a request to further evaluate potential offsite groundwater impacts at two of its closed landfills. IPL has implemented a monitoring plan to evaluate the potential offsite groundwater impacts at the two closed landfills with the installation of additional groundwater monitoring wells and corresponding groundwater sampling and analysis. In July 2012, IPL received a response from the Iowa DNR stating IPL should continue monitoring these two closed landfills per the current monitoring plan. Alliant Energy is currently unable to predict with certainty the outcome of this matter and the impact on its financial condition and results of operations.

Polychlorinated Biphenyls (PCB) - In 2010, the EPA published an Advance Notice of Proposed Rulemaking to support a re-evaluation of all existing use authorizations for PCB-containing equipment. Based on the EPA’s review of the information obtained in response to this notice, 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 by 2014. The schedule for compliance with this rule has not yet been established. Pending the development of a final rule, Alliant Energy is currently unable to predict with certainty 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 13(e) of the “Notes to Consolidated Financial Statements” for discussion of IPL’s and WPL’s MGP sites.

GHG Emissions - Climate change continues to be assessed by policymakers including consideration of the appropriate actions to mitigate global warming. There is continued debate regarding the public policy response that the U.S. should adopt, involving both domestic actions and international efforts. As discussed in greater detail below, 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 Iowa, Wisconsin and Minnesota. Given the highly uncertain outcome and timing of future regulations regarding the control of GHG emissions, Alliant Energy currently cannot predict with certainty 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.

EPA Endangerment and Cause or Contribute Findings - 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 CO \( _{2} \) , methane (CH \( _{4} \) ), nitrous oxide (N \( _{2} \) O), 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 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. These findings by the EPA enable it to regulate GHG stationary sources, including electric utility operations and natural gas distribution operations. In December 2012, the D.C. Circuit Court denied a request by petitioners for rehearing of the decision that upheld the EPA’s ability to regulate GHG. As a result, the EPA’s GHG regulations remain effective as well as the EPA’s ability to issue additional requirements to reduce GHG emissions. Petitioners may seek the Supreme Court’s review of this decision.

EPA NSPS for GHG Emissions from Electric Utilities - The EPA has announced that it will issue GHG standards for electric utilities as NSPS for new and existing fossil-fueled EGUs. The EPA entered a settlement agreement that required the issuance of proposed regulations for new and existing power plants by July 2011 and final regulations no later than May 2012. As discussed below, the EPA did not meet these deadlines and final regulations are pending.

New EGUs - In April 2012, the EPA published proposed NSPS for GHG, including CO2 emissions from new fossil-fueled EGUs larger than 25 MW (not including simple-cycle combustion turbines), with an output-based emissions rate limitation of 1,000 pounds of CO2 per MWh. This emissions rate limitation is expected to be effective upon the EPA’s issuance of the final rule in the second quarter of 2013. The proposed NSPS for new EGUs is expected to apply to IPL’s proposed construction of an approximate 600 MW natural gas-fired combined-cycle electric generating facility in Marshalltown, Iowa, which will be designed to achieve compliance with the proposed CO2 emissions rate limitation.



Existing EGUs - The EPA’s issuance of proposed regulations for existing EGUs remains delayed but is anticipated by the end of 2013. 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. Accordingly, the implications of the EPA’s NSPS rule for GHG emissions from existing EGUs are highly uncertain, including the nature of required emission controls and compliance schedule for mandating reductions of GHGs. Alliant Energy is currently unable to predict with certainty the final outcome of this proposed standard, but expects that expenditures to comply with any regulations to reduce GHG emissions could be significant.

EPA Mandatory GHG Reporting Rule - In 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. The primary GHG emitted from Alliant Energy’s utility operations is CO2 from the combustion of fossil fuels at its larger EGUs. Emissions of GHG are reported at the facility level in carbon dioxide-equivalent (CO2e) and include those facilities that emit 25,000 metric tons or more of CO2e annually. Alliant Energy continues to maintain and update its emissions monitoring methodologies and data collection procedures to capture all the GHG emissions data required for ongoing compliance with the EPA’s mandatory GHG reporting rule. This rule is subject to a legal challenge that is pending in the D.C. Circuit Court. Alliant Energy’s annual 2011 emissions, in terms of total mass of CO2e, as reported to the EPA for electric utility and natural gas distribution operations, were as follows (in millions):

<table><tr><td></td><td>Tons</td><td>Metric Tons</td></tr><tr><td>CO2e emissions (a)</td><td>29.4</td><td>26.7</td></tr></table>

(a) CO2e emissions reported to the EPA represent all emissions from the facilities operated by IPL and WPL and do not reflect their share of co-owned facilities operated by other companies.

Refer to Note 13(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

Overview - Alliant Energy monitors various legislative developments, including those relating to energy, tax, financial and other matters. Recent key legislative developments impacting Alliant Energy include the following:

American Taxpayer Relief Act of 2012 (the ATR Act) - In January 2013, the ATR Act was enacted. The most significant provision of the ATR Act for Alliant Energy relates to the extension of bonus depreciation deductions for certain expenditures for property that are incurred through December 31, 2013. Based on capital projects projected to be placed into service in 2013 and 2014, Alliant Energy currently estimates its total bonus depreciation deductions to be claimed on its 2013 and 2014 U.S. federal income tax returns will be approximately $140 million and $290 million, respectively.

## RESULTS OF OPERATIONS

Overview - “Executive Summary” provides an overview of Alliant Energy’s 2012, 2011 and 2010 earnings and the various components of Alliant Energy’s business. Additional details of Alliant Energy’s 2012, 2011 and 2010 earnings are discussed below.

Utility Electric Margins - Electric margins are defined as electric operating revenues less electric production fuel, energy purchases and purchased electric 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 electric 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 electric capacity expenses. Electric margins and MWh sales for Alliant Energy were as follows:



<table><tr><td rowspan="2"></td><td colspan="5">Revenues and Costs (dollars in millions)</td><td colspan="5">MWhs Sold (MWhs in thousands)</td></tr><tr><td>2012</td><td>2011</td><td>(a)</td><td>2010</td><td>(b)</td><td>2012</td><td>2011</td><td>(a)</td><td>2010</td><td>(b)</td></tr><tr><td>Residential</td><td>$975.9</td><td>$985.8</td><td>(1%)</td><td>$1,001.5</td><td>(2%)</td><td>7,679</td><td>7,740</td><td>(1%)</td><td>7,836</td><td>(1%)</td></tr><tr><td>Commercial</td><td>611.4</td><td>612.1</td><td>—%</td><td>619.0</td><td>(1%)</td><td>6,352</td><td>6,253</td><td>2%</td><td>6,219</td><td>1%</td></tr><tr><td>Industrial</td><td>741.8</td><td>748.9</td><td>(1%)</td><td>762.8</td><td>(2%)</td><td>11,555</td><td>11,504</td><td>—%</td><td>11,213</td><td>3%</td></tr><tr><td>Retail subtotal</td><td>2,329.1</td><td>2,346.8</td><td>(1%)</td><td>2,383.3</td><td>(2%)</td><td>25,586</td><td>25,497</td><td>—%</td><td>25,268</td><td>1%</td></tr><tr><td>Sales for resale:</td><td></td><td></td><td></td><td></td><td></td><td></td><td></td><td></td><td></td><td></td></tr><tr><td>Wholesale</td><td>187.6</td><td>189.8</td><td>(1%)</td><td>196.8</td><td>(4%)</td><td>3,317</td><td>3,372</td><td>(2%)</td><td>3,325</td><td>1%</td></tr><tr><td>Bulk power and other</td><td>23.8</td><td>52.2</td><td>(54%)</td><td>44.1</td><td>18%</td><td>1,303</td><td>1,757</td><td>(26%)</td><td>1,378</td><td>28%</td></tr><tr><td>Other</td><td>48.8</td><td>47.0</td><td>4%</td><td>50.0</td><td>(6%)</td><td>151</td><td>151</td><td>—%</td><td>153</td><td>(1%)</td></tr><tr><td>Total revenues/sales</td><td>2,589.3</td><td>2,635.8</td><td>(2%)</td><td>2,674.2</td><td>(1%)</td><td>30,357</td><td>30,777</td><td>(1%)</td><td>30,124</td><td>2%</td></tr><tr><td>Electric production fuel expense</td><td>367.2</td><td>428.3</td><td>(14%)</td><td>387.9</td><td>10%</td><td></td><td></td><td></td><td></td><td></td></tr><tr><td>Energy purchases expense</td><td>345.1</td><td>336.2</td><td>3%</td><td>431.3</td><td>(22%)</td><td></td><td></td><td></td><td></td><td></td></tr><tr><td>Purchased electric capacity expense</td><td>271.5</td><td>257.2</td><td>6%</td><td>279.7</td><td>(8%)</td><td></td><td></td><td></td><td></td><td></td></tr><tr><td>Margins</td><td>$1,605.5</td><td>$1,614.1</td><td>(1%)</td><td>$1,575.3</td><td>2%</td><td></td><td></td><td></td><td></td><td></td></tr></table>

(a) Reflects the % change from 2011 to 2012. (b) Reflects the % change from 2010 to 2011.

2012 vs. 2011 Summary - Electric margins decreased $9 million, or 1%, primarily due to $22 million of decreased revenues due to higher credits on Iowa retail electric customers' bills resulting from the electric tax benefit rider during 2012 compared to 2011. Other decreases to electric margins included $8 million of higher purchased electric capacity expenses at WPL related to the Kewaunee PPA, $6 million of higher purchased electric capacity expenses at IPL related to the DAEC PPA, $5 million of revenues recognized in 2011 related to interim fuel rates collected in 2010 at WPL and lower weather-normalized sales volumes at WPL. The electric tax benefit rider resulted in $83 million and $61 million of credits on Iowa retail electric customers' bills during 2012 and 2011, respectively. IPL's electric tax benefit rider resulted in reductions in electric revenues that were offset by reductions in income tax expense for the years ended December 31, 2012 and 2011. These items were partially offset by $16 million of higher revenues at IPL from changes in recovery of transmission costs related to the transmission rider implemented in 2011, a $10 million increase in electric margins from changes in the recovery of electric production fuel and energy purchases expenses at WPL, an estimated $7 million increase in electric margins from changes in sales caused by weather conditions in Alliant Energy's service territories, $2 million of SO2 emission allowance charges at IPL in 2011 and an increase in weather-normalized sales volumes at IPL. The higher transmission rider revenues were offset by higher electric transmission service expenses. Estimated increases to Alliant Energy's electric margins from the impacts of weather during 2012 and 2011 were $36 million and $29 million, respectively.

2011 vs. 2010 Summary - Electric margins increased $39 million, or 2%, primarily due to the impact of base retail rate increases (excluding fuel cost recoveries and transmission rider) at IPL and WPL, which increased electric revenues by $71 million in 2011. Other increases to electric margins included $21 million of lower purchased electric capacity expenses at WPL related to the Kewaunee PPA, higher revenues at IPL related to changes in recovery of transmission costs due to the implementation of the transmission rider in 2011, an estimated $4 million increase in electric margins from changes in sales caused by weather conditions in Alliant Energy's service territories and a 3% increase in industrial sales volumes. Estimated increases to Alliant Energy's electric margins from the impacts of weather in 2011 and 2010 were $29 million and $25 million, respectively. These items were partially offset by credits on Iowa retail electric customers' bills in 2011 resulting from the implementation of the tax benefit rider, which decreased IPL's electric revenues by $61 million in 2011, the impact of a wholesale formula rate change, which increased WPL's electric revenues by $4 million in 2010, $4 million of lower energy conservation revenues at IPL, $3 million of higher purchased power electric capacity expenses at IPL related to the DAEC PPA, $2 million of SO2 emission allowance charges in 2011 and a decrease in weather-normalized residential sales volumes. Changes in energy conservation revenues are largely offset by changes in energy conservation expenses included in other operation and maintenance expenses.

Base Retail Rate Increases - Increases to Alliant Energy’s electric revenues from the impacts of base retail rate increases (excluding fuel cost recoveries and transmission rider, and net of any reserves for rate refunds) were as follows (dollars in millions):



<table><tr><td>Retail Base Rate Cases</td><td>Effective Date</td><td>2011 vs. 2010 Revenue Increases</td></tr><tr><td>WPL’s Wisconsin 2011 Test Year</td><td>January 1, 2011</td><td>$38</td></tr><tr><td>IPL’s Iowa 2009 Test Year</td><td>March 20, 2010</td><td>26</td></tr><tr><td>IPL’s Minnesota 2009 Test Year</td><td>July 6, 2010</td><td>7</td></tr><tr><td></td><td></td><td>$71</td></tr></table>

There were no material changes in base retail rates from 2011 to 2012. Refer to “Rate Matters” for additional information relating to these retail electric rate increases, a retail electric base rate freeze at WPL through December 31, 2014 and a retail electric base rate freeze at IPL through December 31, 2013.

Weather Conditions - Alliant Energy’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 wholesale 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 “Utility Gas Margins - Weather Conditions” for details regarding HDD in Alliant Energy’s service territories. CDD in Alliant Energy’s service territories were as follows:

<table><tr><td rowspan="2">CDD (a):</td><td colspan="4">Actual</td></tr><tr><td>2012</td><td>2011</td><td>2010</td><td>Normal (a)</td></tr><tr><td>Cedar Rapids, Iowa (IPL)</td><td>1,052</td><td>887</td><td>923</td><td>740</td></tr><tr><td>Madison, Wisconsin (WPL)</td><td>1,070</td><td>814</td><td>829</td><td>625</td></tr></table>

(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.

Electric Production Fuel and Energy Purchases (Fuel-related) Cost Recoveries - Alliant Energy 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. Alliant Energy also purchases electricity to meet the demand of its customers and charges these costs to energy purchases expense. Alliant Energy's electric production fuel expense decreased $61 million, or 14%, and increased $40 million, or 10%, in 2012 and 2011, respectively. The 2012 decrease was largely due to lower MISO dispatch of Alliant Energy's generating facilities. Alliant Energy's generating facilities were dispatched at a lower level during 2012 because electricity could be purchased in the MISO market at prices that were lower than the cost to generate electricity at certain of Alliant Energy's generating facilities. The 2011 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 2011 and higher delivered coal prices. Alliant Energy's energy purchases expense increased $9 million, or 3%, and decreased $95 million, or 22%, in 2012 and 2011, respectively. The 2012 increase was largely due to increased electricity purchases in the MISO market. The 2011 decrease was primarily due to lower energy prices. The impact of the changes in energy volumes purchased were largely offset by the impact of changes in electricity volumes generated from Alliant Energy's generating facilities and changes in bulk power sales volumes discussed below.

Due to IPL’s rate recovery mechanisms for fuel-related costs, changes in fuel-related costs resulted in comparable changes in electric revenues and, therefore, did not have a significant impact on Alliant Energy’s electric margins. WPL’s rate recovery mechanism for wholesale fuel-related costs also provides for adjustments to its wholesale electric rates for changes in commodity costs, thereby mitigating impacts of changes to commodity costs on Alliant Energy’s electric margins.

WPL’s retail fuel-related costs incurred in 2012 were lower than the forecasted fuel-related costs used to set retail rates during such period. Alliant Energy estimates the lower than forecasted retail fuel-related costs increased electric margins by approximately $6 million in 2012. WPL’s retail fuel-related costs incurred in 2011 and 2010 were higher than the forecasted fuel-related costs used to set retail rates during such periods. Alliant Energy estimates the higher than forecasted retail fuel-related costs decreased electric margins by approximately $4 million and $3 million in 2011 and 2010, 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 Alliant Energy’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.



Purchased Electric Capacity Expense - Alliant Energy enters into PPAs to help meet the electricity demand of IPL’s and WPL’s customers. Certain of these PPAs include minimum payments for IPL’s and WPL’s rights to electric generating capacity. Details of purchased electric capacity expense included in the utility electric margins table above were as follows (in millions):

<table><tr><td></td><td>2012</td><td>2011</td><td>2010</td></tr><tr><td>DAEC PPA (IPL)</td><td>152</td><td>146</td><td>143</td></tr><tr><td>Riverside PPA (WPL)</td><td>59</td><td>59</td><td>58</td></tr><tr><td>Kewaunee PPA (WPL)</td><td>59</td><td>51</td><td>72</td></tr><tr><td>Other</td><td>2</td><td>1</td><td>7</td></tr><tr><td></td><td>272</td><td>257</td><td>280</td></tr></table>

At December 31, 2012, the future estimated purchased electric capacity expense related to the DAEC (expires in February 2014) and Kewaunee (expires in December 2013) PPAs were as follows (in millions):

<table><tr><td></td><td>2013</td><td>2014</td><td>Total</td></tr><tr><td>DAEC PPA (IPL)</td><td>154</td><td>28</td><td>182</td></tr><tr><td>Kewaunee PPA (WPL)</td><td>62</td><td>—</td><td>62</td></tr><tr><td></td><td>216</td><td>28</td><td>244</td></tr></table>

WPL had a PPA with a subsidiary of Calpine Corporation related to Riverside. In December 2012, WPL purchased Riverside and terminated the PPA.

Sales Trends - Retail sales volumes were relatively flat in 2012 and increased 1% in 2011. The 2011 increase was primarily due to higher usage per customer caused by weather conditions in Alliant Energy’s service territories and higher sales to industrial customers driven by increased production requirements. These items were largely offset by a decrease in weather-normalized residential sales volumes. Alliant Energy believes the decrease in weather-normalized residential sales volumes in 2011 was largely due to energy efficiency improvements implemented by customers and changes in customers’ usage patterns driven by economic challenges.

Wholesale sales volumes decreased 2% and increased 1% in 2012 and 2011, respectively, primarily due to changes in sales to WPL’s partial-requirement wholesale customers that have contractual options to be served by WPL, other power supply sources or the MISO market. The 2011 increase was also impacted by changes in weather conditions.

Bulk power and other revenue changes were largely due to changes in sales in the wholesale energy markets operated by MISO and PJM Interconnection, LLC. These changes are impacted by several factors including the availability of Alliant Energy’s generating facilities and electricity demand within these wholesale energy markets. Changes in bulk power and other sales revenues were largely offset by changes in fuel-related costs and therefore did not have a significant impact on electric margins.

Alliant Energy is currently expecting relatively flat weather-normalized retail electric sales in 2013 compared to 2012. This is driven largely by low customer growth and modest economic growth. Alliant Energy is currently expecting a decrease in credits on Iowa retail electric customers’ bills resulting from the electric tax benefit rider during 2013 compared to 2012.

Refer to “Rate Matters” for discussion of IPL’s electric tax benefit rider, and IPL and WPL retail rate cases, including a retail electric base rate freeze at WPL through December 31, 2014 and a retail electric base rate freeze at IPL through December 31, 2013. Refer to “Other Future Considerations” for discussion of increased recoveries under the transmission rider related to expected increases in electric transmission service expenses.

Utility 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 is generally passed through to customers, and therefore results in changes to gas operating revenues that are comparable to changes in cost of gas sold. Gas margins and dekatherm (Dth) sales for Alliant Energy were as follows:



<table><tr><td rowspan="2"></td><td colspan="5">Revenues and Costs (dollars in millions)</td><td colspan="5">Dths Sold (Dths in thousands)</td></tr><tr><td>2012</td><td>2011</td><td>(a)</td><td>2010</td><td>(b)</td><td>2012</td><td>2011</td><td>(a)</td><td>2010</td><td>(b)</td></tr><tr><td>Residential</td><td>$224.3</td><td>$269.7</td><td>(17%)</td><td>$273.7</td><td>(1%)</td><td>23,071</td><td>26,891</td><td>(14%)</td><td>27,128</td><td>(1%)</td></tr><tr><td>Commercial</td><td>124.3</td><td>155.1</td><td>(20%)</td><td>154.2</td><td>1%</td><td>17,115</td><td>19,271</td><td>(11%)</td><td>18,691</td><td>3%</td></tr><tr><td>Industrial</td><td>16.7</td><td>24.5</td><td>(32%)</td><td>27.3</td><td>(10%)</td><td>3,068</td><td>3,848</td><td>(20%)</td><td>4,158</td><td>(7%)</td></tr><tr><td>Retail subtotal</td><td>365.3</td><td>449.3</td><td>(19%)</td><td>455.2</td><td>(1%)</td><td>43,254</td><td>50,010</td><td>(14%)</td><td>49,977</td><td>—%</td></tr><tr><td>Transportation/other</td><td>31.0</td><td>27.4</td><td>13%</td><td>25.4</td><td>8%</td><td>57,532</td><td>52,210</td><td>10%</td><td>50,408</td><td>4%</td></tr><tr><td>Total revenues/sales</td><td>396.3</td><td>476.7</td><td>(17%)</td><td>480.6</td><td>(1%)</td><td>100,786</td><td>102,220</td><td>(1%)</td><td>100,385</td><td>2%</td></tr><tr><td>Cost of gas sold</td><td>217.2</td><td>295.2</td><td>(26%)</td><td>304.0</td><td>(3%)</td><td></td><td></td><td></td><td></td><td></td></tr><tr><td>Margins</td><td>$179.1</td><td>$181.5</td><td>(1%)</td><td>$176.6</td><td>3%</td><td></td><td></td><td></td><td></td><td></td></tr></table>

(a) Reflects the % change from 2011 to 2012. (b) Reflects the % change from 2010 to 2011.

2012 vs. 2011 Summary - Gas margins decreased $2 million, or 1%, in 2012 largely due to an estimated $13 million decrease in gas margins from changes in sales caused by weather conditions in Alliant Energy’s service territories. Estimated increases (decreases) to Alliant Energy’s gas margins from the impacts of weather during 2012 and 2011 were ($13) million and $0, respectively. This item was partially offset by an increase in weather-normalized sales volumes at WPL and $5 million of higher gas revenues due to the impact of an interim retail gas base rate increase effective in June 2012 at IPL. Alliant Energy believes the increase in weather-normalized sales volumes is partially due to relatively low natural gas prices.

2011 vs. 2010 Summary - Gas margins increased $5 million, or 3%, in 2011 primarily due to $4 million of higher energy conservation revenues at IPL. Changes in energy conservation revenues are largely offset by changes in energy conservation expenses in 2011.

Natural Gas Cost Recoveries - In 2012 and 2011, Alliant Energy’s cost of gas sold decreased $78 million, or 26%, and $9 million, or 3%, respectively. The 2012 and 2011 decreases were primarily due to a decrease in natural gas prices. The 2012 decrease was also due to lower retail gas volumes caused by weather discussed below. Due to Alliant Energy’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.

Weather Conditions - Alliant Energy’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 Alliant Energy’s service territories were as follows:

<table><tr><td rowspan="2">HDD (a):</td><td colspan="4">Actual</td></tr><tr><td>2012</td><td>2011</td><td>2010</td><td>Normal (a)</td></tr><tr><td>Cedar Rapids, Iowa (IPL)</td><td>5,901</td><td>6,745</td><td>6,868</td><td>6,794</td></tr><tr><td>Madison, Wisconsin (WPL)</td><td>5,964</td><td>6,992</td><td>6,798</td><td>7,089</td></tr></table>

(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.

Refer to “Rate Matters” for discussion of retail rate cases, including an interim retail gas base rate increase effective June 4, 2012 and final retail gas base rate increase effective January 10, 2013 for IPL’s Iowa customers, a retail gas base rate decrease for WPL’s customers effective January 1, 2013 and IPL’s gas tax benefit rider.

## Non-regulated Revenues -

2012 vs. 2011 Summary - Alliant Energy’s non-regulated revenues increased $5 million in 2012 primarily due to increased Transportation revenues resulting from increased demand for freight services provided by Alliant Energy’s short-line railway company and increased demand for barge terminal and hauling services.

## Electric Transmission Service Expenses -

2012 vs. 2011 Summary - Alliant Energy’s electric transmission service expense for the utilities increased $18 million in 2012 primarily due to changes in transmission costs at IPL related to transmission services from ITC. The increase was primarily due to $10 million of higher electric transmission service costs billed by ITC to IPL during 2012 compared to 2011 due to a modest increase in transmission service rates, and the impact of IPL utilizing regulatory liabilities to credit a portion



of the transmission service expenses billed to IPL by ITC during 2011. IPL is currently recovering the Iowa retail portion of these increased electric transmission service costs from its retail electric customers in Iowa through a pilot transmission cost rider approved by the IUB in January 2011 resulting in an offsetting increase in electric revenues.

2011 vs. 2010 Summary - Alliant Energy’s electric transmission service expense for the utilities increased $44 million in 2011 primarily due to higher transmission costs at IPL related to transmission services from ITC. The electric transmission service costs billed by ITC to IPL were $11 million higher in 2011 than those billed by ITC to IPL in 2010. In addition, deferrals and regulatory liability offsets approved by the IUB to reduce transmission service expenses were lower in 2011 compared to 2010 resulting in higher transmission service expense at IPL in 2011. In 2010, IPL deferred $41 million of electric transmission expenses related to the Iowa retail portion of 2008 under-recovered costs billed to IPL by ITC. IPL also utilized $4 million of regulatory liabilities to offset a portion of the Iowa retail electric transmission service expenses incurred in 2010. IPL utilized $19 million of regulatory liabilities to offset transmission service expenses related to the Iowa retail portion of 2009 under-recovered costs billed to IPL by ITC in 2011. The combined impact of the higher electric transmission service costs billed by ITC to IPL and these deferrals and regulatory liability offsets resulted in an increase in IPL’s electric transmission service costs of $37 million in 2011.

Refer to “Rate Matters” for additional discussion of the transmission rider approved by the IUB in January 2011. Refer to “Other Future Considerations” for discussion of potential changes in future electric transmission services expenses. Refer to Notes 1(b) and 1(h) of the “Notes to Consolidated Financial Statements” for additional information relating to recovery of electric transmission service expenses.

Utility Other Operation and Maintenance Expenses - Alliant Energy’s other operation and maintenance expenses for the utilities decreased $40 million and increased $13 million for 2012 and 2011, respectively, due to the following reasons (amounts represent variances between periods in millions):

<table><tr><td colspan="2">2012 vs. 2011 Summary:</td></tr><tr><td>Regulatory-related (charges) and credits from IPL&#x27;s Minnesota electric rate case order recorded in 2011 (a)</td><td>($11)</td></tr><tr><td>Lower generation operation and maintenance expenses at IPL (b)</td><td>(10)</td></tr><tr><td>Additional benefits costs for Cash Balance Plan amendment in 2011 (c)</td><td>(10)</td></tr><tr><td>Regulatory asset impairments in 2011 (d)</td><td>(9)</td></tr><tr><td>Regulatory-related credits from WPL&#x27;s 2013/2014 rate case decision recorded in 2012 (a)</td><td>(5)</td></tr><tr><td>Wind site impairment charge at WPL in 2011 (e)</td><td>(5)</td></tr><tr><td>SO2 emission allowance charge allocated to IPL&#x27;s steam business in 2011 (f)</td><td>(2)</td></tr><tr><td>Allocated cost of capital charges from Corporate Services in 2012 (g)</td><td>9</td></tr><tr><td>Contract cancellation charge at IPL in 2012 (h)</td><td>3</td></tr><tr><td></td><td>($40)</td></tr></table>

<table><tr><td>Regulatory-related charges and (credits) from IPL&#x27;s Minnesota electric rate case order recorded in 2011 (a)</td><td>$11</td></tr><tr><td>Additional benefits costs for Cash Balance Plan amendment in 2011 (c)</td><td>10</td></tr><tr><td>Regulatory asset impairments in 2011 (d)</td><td>9</td></tr><tr><td>Higher wind turbine operation and maintenance expenses at WPL (i)</td><td>7</td></tr><tr><td>Wind site impairment charge at WPL in 2011 (e)</td><td>5</td></tr><tr><td>Higher energy conservation cost recovery amortizations at WPL (j)</td><td>3</td></tr><tr><td>SO2 emission allowance charges allocated to IPL&#x27;s steam business in 2011 (f)</td><td>2</td></tr><tr><td>Regulatory-related (charges) and credits from IPL&#x27;s Iowa electric rate case order recorded in 2010 (a)</td><td>(20)</td></tr><tr><td>Lower other postretirement benefits costs (k)</td><td>(10)</td></tr><tr><td>Restructuring charges in 2010 (l)</td><td>(4)</td></tr><tr><td>Asset impairment in 2010 related to Sixth Street (m)</td><td>(4)</td></tr><tr><td>Other</td><td>4</td></tr><tr><td></td><td>$13</td></tr></table>



(a) Refer to Notes 1(b) and 1(e) of the “Notes to Consolidated Financial Statements” for details of regulatory-related charges and credits incurred in 2010, 2011 and 2012 due to the decisions by the IUB in IPL’s Iowa retail electric rate case (2009 test year) in 2010, decisions by the MPUC in IPL’s Minnesota retail electric rate case (2009 test year) in 2011 and decisions by the PSCW in WPL’s Wisconsin retail electric and gas rate case (2013/2014 test period) in 2012. Alliant Energy also recognized a $7 million impairment charge in 2010 related to the remaining net book value of Sixth Street that the IUB did not allow IPL to recover as part of the decisions in IPL’s Iowa retail electric rate case (2009 test year).

(b) Primarily resulting from the timing of maintenance projects at IPL’s electric generating facilities.

(c) Refer to Notes 6(a) and 13(c) of the “Notes to Consolidated Financial Statements” for details of the additional benefit costs incurred in 2011 resulting from an amendment to the Cash Balance Plan and details of the Cash Balance Plan lawsuit.

(d) Refer to Note 1(b) of the “Notes to Consolidated Financial Statements” for details of regulatory asset impairments incurred in 2011.

(e) Refer to Note 1(e) of the “Notes to Consolidated Financial Statements” for details of the wind site impairment charge recorded in 2011.

(f) Refer to Note 1(b) of the “Notes to Consolidated Financial Statements” for details of the SO2 emission allowance charges recorded in 2011.

(g) Cost of capital charges allocated by Corporate Services to IPL and WPL in accordance with a new service agreement effective in 2012.

(h) Due to the cancellation of a services agreement for one of IPL’s electric generating facilities in 2012.

(i) Alliant Energy started to incur operation and maintenance expenses to operate WPL’s Bent Tree - Phase I wind project in late 2010 when the wind project began generating electricity.

(j) WPL’s 2011 test year base retail electric rate case resulted in higher energy conservation cost recovery amortizations effective in January 2011.

(k) Changes in pension and other postretirement benefits costs are largely based on changes in plan assets caused by contributions and returns on plan assets, changes in discount rates used to measure benefit obligations and plan amendments. An amendment to the defined benefit postretirement health care plans in 2011 resulted in lower other postretirement benefits costs in 2011. Refer to Note 6(a) of the “Notes to Consolidated Financial Statements” for further details. These variance amounts exclude the portion of pension and other postretirement benefits costs allocated to capital projects.

(I) Resulting from the elimination of certain corporate and operations positions in 2010.

(m) Alliant Energy recognized a $4 million impairment in 2010 related to IPL’s Sixth Street electric assets as a result of a decision not to rebuild electric operations at Sixth Street.

Alliant Energy currently expects its other operation and maintenance expenses to decrease in 2013 as compared to 2012 due to decreases in regulatory amortizations at WPL related to energy conservation that were approved in WPL's 2013/2014 test period electric and gas base rate case and decreases in retirement plan costs. These items are expected to be partially offset by additional operation and maintenance expenses associated with Riverside, which WPL acquired in December 2012. Refer to “Other Future Considerations” for discussion of expected changes in retirement plan costs.

## Depreciation and Amortization Expenses -

2012 vs. 2011 Summary - Depreciation and amortization expenses increased $11 million in 2012 primarily due to higher depreciation rates at IPL effective January 1, 2012 resulting from IPL’s most recent depreciation study, and property additions at IPL and WPL. These items were partially offset by the impact of regulatory-related charges and credits to depreciation expense in 2012 compared to 2011 at WPL.

2011 vs. 2010 Summary - Depreciation and amortization expenses increased $33 million in 2011 primarily due to property additions, including $17 million of depreciation expense recognized in 2011 related to WPL’s Bent Tree - Phase I wind project, which began generating electricity in late 2010. Also contributing to the increase in 2011 was a depreciation adjustment recorded in 2010 at WPL, which is not anticipated to have a material impact on future periods.

Alliant Energy currently expects its depreciation expense to increase in 2013 as compared to 2012 primarily due to property additions, including the full year impact of depreciation from WPL’s purchase of Riverside in December 2012, depreciation from certain large projects placed in service in the fourth quarter of 2012, including WPL’s SCR project at Edgewater Unit 5 and Resources’ Franklin County wind project, and property additions in 2013.

## Interest Expense -

2012 vs. 2011 Summary - Alliant Energy’s interest expense decreased $2 million in 2012 primarily due to $3 million of higher capitalized interest recognized in 2012 for the Franklin County wind project.



2011 vs. 2010 Summary - Alliant Energy’s interest expense decreased $5 million in 2011 due to the following reasons (amounts represent variances between periods in millions):

<table><tr><td>Interest expense variances from certain issuances of long-term debt:</td><td></td></tr><tr><td>IPL’s $200 million of 3.65% senior debentures issued in August 2010</td><td>$5</td></tr><tr><td>WPL’s $150 million of 4.6% debentures issued in June 2010</td><td>3</td></tr><tr><td>IPL’s $150 million of 3.3% senior debentures issued in June 2010</td><td>2</td></tr><tr><td>Interest expense variances from certain reductions in long-term debt:</td><td></td></tr><tr><td>IPL’s $200 million of 6.75% senior debentures retired in September 2010</td><td>(10)</td></tr><tr><td>WPL’s $100 million of 7.625% debentures retired in March 2010</td><td>(1)</td></tr><tr><td>Other (includes impact of $3 million of capitalized interest in 2011 for the Franklin County wind project)</td><td>(4)</td></tr><tr><td></td><td>($5)</td></tr></table>

Alliant Energy currently expects its interest expense to increase in 2013 as compared to 2012 due to financings related to WPL’s purchase of Riverside in December 2012.

Refer to Note 9 of the “Notes to Consolidated Financial Statements” for additional details of debt.

## AFUDC -

2012 vs. 2011 Summary - AFUDC increased $10 million in 2012 primarily due to AFUDC recognized in 2012 for WPL's emission controls projects at Columbia Units 1 and 2, and Edgewater Unit 5, and IPL's emission controls projects at Ottumwa Unit 1 and George Neal Units 3 and 4.

2011 vs. 2010 Summary - AFUDC decreased $6 million in 2011 primarily due to $10 million of AFUDC recognized in 2010 for WPL's Bent Tree - Phase I wind project. This item was partially offset by $3 million of AFUDC recognized in 2011 for WPL's Edgewater Unit 5 emission controls project.

Alliant Energy currently expects AFUDC to increase in 2013 as compared to 2012 primarily due to increased construction work in progress balances related to environmental projects at Ottumwa Unit 1, George Neal Units 3 and 4, and Lansing Unit 4.

Income Taxes - The effective income tax rates for Alliant Energy’s continuing operations were 20.8%, 16.9% and 32.3% for 2012, 2011 and 2010, respectively. Details of the effective income tax rates were as follows:

<table><tr><td></td><td>2012</td><td>2011</td><td>2010</td></tr><tr><td>Statutory federal income tax rate</td><td>35.0%</td><td>35.0%</td><td>35.0%</td></tr><tr><td>State apportionment change due to announced sale of RMT</td><td>3.5</td><td>—</td><td>—</td></tr><tr><td>IPL&#x27;s electric tax benefit rider</td><td>(11.2)</td><td>(8.8)</td><td>—</td></tr><tr><td>Production tax credits</td><td>(5.8)</td><td>(6.6)</td><td>(2.4)</td></tr><tr><td>Effect of rate-making on property-related differences</td><td>(5.0)</td><td>(2.0)</td><td>(4.2)</td></tr><tr><td>Wisconsin tax legislation enacted in June 2011</td><td>—</td><td>(4.6)</td><td>—</td></tr><tr><td>Federal Health Care Legislation enacted in March 2010</td><td>—</td><td>—</td><td>1.6</td></tr><tr><td>IRS audit completed in September 2010</td><td>—</td><td>—</td><td>(1.4)</td></tr><tr><td>Other items, net</td><td>4.3</td><td>3.9</td><td>3.7</td></tr><tr><td>Overall income tax rate</td><td>20.8%</td><td>16.9%</td><td>32.3%</td></tr></table>

2012 vs. 2011 Summary - The increase in the effective income tax rate for Alliant Energy’s continuing operations was primarily due to the reversal of $19 million of valuation allowances in 2011 due to passage of Wisconsin tax legislation, which changed the ability of companies to use prior net operating losses, and a $15 million state apportionment charge due to the announced sale of RMT in 2012. These items were partially offset by the impact of $13 million of additional income tax benefits in 2012 from the effect of rate-making on property-related differences resulting from changes in accounting methodologies for IPL’s allocation of mixed services costs and recording of repair expenditures, and an additional $12 million of income tax benefits in 2012 related to IPL’s tax benefit rider that began in 2011.

2011 vs. 2010 Summary - The decrease in the effective income tax rate for Alliant Energy’s continuing operations was primarily related to the impact of $36 million of income tax benefits related to IPL’s tax benefit rider that began in 2011 and



the reversal of $19 million of valuation allowances in 2011 due to passage of Wisconsin tax legislation. In addition, Alliant Energy had $16 million of higher production tax credits in 2011 due to WPL's Bent Tree - Phase I wind project, which began generating electricity in late 2010, and increased electricity generated from IPL's Whispering Willow - East wind project primarily due to fewer transmission constraints in 2011 and $7 million of income tax expense recognized in 2010 related to the impacts of the Federal Health Care Legislation. These items were partially offset by higher state income taxes at IPL related to property-related differences for which Iowa deferred tax is not recorded in the income statement pursuant to Iowa rate-making principles, and $7 million of income tax benefits recorded in 2010 related to the impact of the IRS completing audits of Alliant Energy's U.S. federal income tax returns for calendar years 2005 through 2008.

Refer to Note 5 of the “Notes to Consolidated Financial Statements” for additional discussion of state apportionment changes, IPL’s tax benefit rider implemented in 2011, production tax credits, tax effect of rate-making on property-related differences at IPL, Wisconsin tax legislation enacted in 2011, Federal Health Care Legislation enacted in 2010, and an IRS audit completed in 2010. Refer to “Rate Matters” for discussion of IPL’s tax benefit rider. Refer to “Critical Accounting Policies and Estimates - Income Taxes” for discussion of the effect of rate-making on property differences at IPL and changes to state apportionment projections resulting from Alliant Energy’s decision in February 2012 to sell RMT. Refer to “Other Future Considerations” for discussion of possible impacts to Alliant Energy’s future income taxes resulting from potential tax accounting method changes and trends in IPL’s and WPL’s production tax credits.

Loss from Discontinued Operations, Net of Tax - RMT’s net loss in 2011 was largely driven by losses associated with certain large solar projects. Schedule delays, abandonment of work by the original subcontractor and the need to hire additional subcontractors to complete the solar projects in a timely manner resulted in significant additional costs for RMT in 2011. Refer to Note 17 of the “Notes to Consolidated Financial Statements” for additional discussion of Alliant Energy’s discontinued operations.

## Preferred Dividend Requirements of Subsidiaries -

2012 vs. 2011 Summary - Preferred dividend requirements of subsidiaries decreased $2 million in 2012 primarily due to a $2 million charge in the first quarter of 2011 related to IPL's redemption of its 7.10% cumulative preferred stock in 2011.

In February 2013, IPL announced it will redeem all 6,000,000 outstanding shares of its 8.375% cumulative preferred stock in March 2013 at par value for approximately $150 million plus accrued and unpaid dividends to the redemption date. In February 2013, WPL announced it will redeem all 1,049,225 outstanding shares of its 4.40% through 6.50% cumulative preferred stock in March 2013 for approximately $61 million plus accrued and unpaid dividends to the redemption date. As a result of these preferred stock redemptions, Alliant Energy expects to record a charge of $6 million in the first quarter of 2013 in “Preferred dividend requirements” in the Consolidated Statement of Income.

## LIQUIDITY AND CAPITAL RESOURCES

Overview - Alliant Energy expects to maintain adequate liquidity to operate its businesses and implement its strategic plan as a result of available capacity under its revolving credit facility, IPL’s sales of accounts receivable program and operating cash flows generated by its utility business, supplemented by periodic issuances of long-term debt and equity securities.

Liquidity Position - At December 31, 2012, Alliant Energy had $21 million of cash and cash equivalents, $733 million ($196 million at the parent company, $224 million at IPL and $313 million at WPL) of available capacity under their revolving credit facilities and $20 million of available capacity at IPL under its sales of accounts receivable program. Refer to “Cash Flows - Financing Activities - Short-term Debt” and Note 9(a) of the “Notes to Consolidated Financial Statements” for further discussion of the credit facilities. Refer to Note 4(a) of the “Notes to Consolidated Financial Statements” for additional information on IPL’s sales of accounts receivable program.

Capital Structure - Alliant Energy plans to maintain debt-to-total capitalization ratios that are consistent with its investment-grade credit ratings. Alliant Energy currently expects to maintain capital structures in which debt would not exceed 45% to 55% of total capital and preferred stock would not exceed 5% to 10% of total capital. These targets may be adjusted depending on subsequent developments and their impact on Alliant Energy’s weighted average cost of capital and investment-grade credit ratings. Capital structures at December 31, 2012 were as follows (dollars in millions):



<table><tr><td></td><td colspan="2">Alliant Energy (Consolidated)</td><td colspan="2">IPL</td><td colspan="2">WPL</td></tr><tr><td>Common equity</td><td>$3,134.9</td><td>47%</td><td>$1,519.2</td><td>50%</td><td>$1,583.0</td><td>52%</td></tr><tr><td>Preferred stock</td><td>205.1</td><td>3%</td><td>145.1</td><td>5%</td><td>60.0</td><td>2%</td></tr><tr><td>Noncontrolling interest</td><td>1.8</td><td>—%</td><td>—</td><td>—%</td><td>—</td><td>—%</td></tr><tr><td>Long-term debt (incl. current maturities)</td><td>3,138.1</td><td>47%</td><td>1,359.5</td><td>45%</td><td>1,331.5</td><td>43%</td></tr><tr><td>Short-term debt</td><td>217.5</td><td>3%</td><td>26.3</td><td>—%</td><td>86.6</td><td>3%</td></tr><tr><td></td><td>$6,697.4</td><td>100%</td><td>$3,050.1</td><td>100%</td><td>$3,061.1</td><td>100%</td></tr></table>

Alliant Energy intends to manage these capital structures and liquidity positions in such a way that facilitates its ability to raise the necessary funds reliably and on reasonable terms and conditions, while maintaining financial capital structures consistent with those approved by regulators and necessary to maintain appropriate credit quality. In addition to capital structures, other important financial considerations used to determine the characteristics of future financings include financial coverage ratios, flexibility in capital spending plans, regulatory orders and rate-making considerations, the levels of debt imputed by rating agencies, market conditions and the impact of tax initiatives. The most significant debt imputations relate to the sales of accounts receivable program, the DAEC and Kewaunee PPAs, and pension and other postretirement benefits obligations. The PSCW factors certain imputed debt adjustments in establishing a regulatory capital structure as part of WPL’s retail rate cases, particularly those related to PPAs. The IUB and MPUC do not make any explicit adjustments for imputed debt in establishing capital ratios used in determining customer rates, although such adjustments are considered by IPL in recommending an appropriate capital structure.

Credit and Capital Markets - Alliant Energy is aware of the potential implications that credit and capital market disruptions might have on its ability to raise the external funding required for its operations and capital expenditure plans. The strategic initiatives include a desire to maintain sufficient liquidity resources to reasonably withstand such a disruption. Alliant Energy, IPL and WPL maintain revolving credit facilities to provide backstop liquidity to their commercial paper programs, ensure a committed source of liquidity in the event the commercial paper market becomes disrupted and efficiently manage their long-term financings. In addition, Alliant Energy maintains a sales of accounts receivable program at IPL as an alternative financing source.

Primary Sources and Uses of Cash - Alliant Energy’s most significant source of cash is from electric and gas sales to its utility customers. Cash from these sales reimburses IPL and WPL for prudently-incurred expenses to provide service to their utility customers and provides IPL and WPL a return of and a return on the assets used to provide such services. Utility operating cash flows are expected to cover the majority of IPL’s and WPL’s capital expenditures required to maintain their current infrastructure and to pay dividends to Alliant Energy’s shareowners. Capital needed to retire debt and fund capital expenditures related to environmental compliance programs and other large strategic projects is expected to be met primarily through external financings.

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

<table><tr><td></td><td>2012</td><td>2011</td><td>2010</td></tr><tr><td>Cash and cash equivalents, January 1</td><td>$11.4</td><td>$159.3</td><td>$175.3</td></tr><tr><td>Cash flows from (used for):</td><td></td><td></td><td></td></tr><tr><td>Operating activities</td><td>841.1</td><td>702.7</td><td>984.9</td></tr><tr><td>Investing activities</td><td>(1,155.5)</td><td>(652.1)</td><td>(866.5)</td></tr><tr><td>Financing activities</td><td>324.2</td><td>(198.5)</td><td>(134.4)</td></tr><tr><td>Net increase (decrease)</td><td>9.8</td><td>(147.9)</td><td>(16.0)</td></tr><tr><td>Cash and cash equivalents, December 31</td><td>$21.2</td><td>$11.4</td><td>$159.3</td></tr></table>

## Operating Activities -

2012 vs. 2011 - Alliant Energy’s cash flows from operating activities increased $138 million primarily due to $166 million of higher cash flows from operations at RMT due to changes in working capital requirements associated with renewable energy projects in 2012 and 2011 and $117 million of pension plan contributions in 2011. These items were partially offset by $85 million of lower cash flows from changes in the level of IPL’s accounts receivable sold during 2012 and 2011, $22 million of higher credits on retail electric customers’ bills in Iowa during 2012 compared to 2011 resulting from IPL’s electric tax benefit rider and changes in working capital during 2012 and 2011.



2011 vs. 2010 - Alliant Energy’s cash flows from operating activities decreased $282 million primarily due to $121 million of lower cash flows from operations at RMT due to increased working capital requirements associated with additional renewable energy projects in 2011, $117 million of pension plan contributions in 2011, $105 million of lower income tax refunds and $61 million of credits on retail electric customers’ bills in Iowa in 2011 resulting from IPL’s implementation of the tax benefit rider. These items were partially offset by increased collections from IPL’s and WPL’s customers in 2011 caused by the impacts of rate increases, the timing of fuel-cost recoveries at IPL and $21 million of lower purchased electric capacity payments related to the Kewaunee PPA at WPL.

RMT’s Working Capital Requirements - Cash flows from operations at RMT increased significantly in 2012 compared to 2011 largely due to amounts collected in 2012 for customers’ large renewable energy projects completed in late 2011 and in 2012. In January 2013, Alliant Energy sold its remaining interest in RMT.

Pension Plan Contributions - Contributions to qualified and non-qualified defined benefit pension plans for 2010 through 2012 were as follows (in millions):

<table><tr><td></td><td>2012</td><td>2011</td><td>2010</td></tr><tr><td>IPL (a)</td><td>$—</td><td>$58</td><td>$—</td></tr><tr><td>WPL (a)</td><td>—</td><td>47</td><td>—</td></tr><tr><td>Other subsidiaries</td><td>16</td><td>12</td><td>8</td></tr><tr><td>Alliant Energy</td><td>$16</td><td>$117</td><td>$8</td></tr></table>

(a) Pension plan contributions for IPL and WPL include contributions to their respective qualified pension plans as well as an assigned portion of the contributions to pension plans sponsored by Corporate Services.

Alliant Energy currently does not expect to make any significant pension plan contributions in 2013 through 2015 based on the funded status and assumed return on assets for each plan as of the December 31, 2012 measurement date. Refer to Note 6(a) of the “Notes to Consolidated Financial Statements” for discussion of the current funded levels of pension plans and contributions expected in 2013.

IPL’s Sales of Accounts Receivable Program - Changes in cash flows related to IPL’s sales of accounts receivable program increased (decreased) cash flows from operations by ($10) million, $75 million and $65 million in 2012, 2011 and 2010, respectively. The decrease in 2012 was primarily due to IPL relying less on its sales of accounts receivable program in 2012 to finance its cash needs. In 2011 and 2010, proceeds from the receivables sold were primarily used by IPL to help fund working capital and construction expenditures, and to reduce short-term debt. In March 2012, IPL extended through March 2014 the purchase commitment from the third-party financial institution to which IPL sells its receivables. Refer to Note 4(a) of the “Notes to Consolidated Financial Statements” for additional details of IPL’s sales of accounts receivable program.

IPL’s Tax Benefit Riders - IPL implemented its electric tax benefit rider in early 2011 and its gas tax benefit rider in early 2013. These tax benefit riders provide credits on Iowa retail customers’ bills, which result in lower cash flows from operations for Alliant Energy. IPL’s electric tax benefit rider resulted in $83 million and $61 million of credits on Iowa retail electric customers’ bills during 2012 and 2011, respectively. Alliant Energy currently expects $56 million and $12 million of billing credits in 2013 for Iowa retail electric and gas customers, respectively. Refer to “Rate Matters,” “Results of Operations,” and Note 5 of the “Notes to Consolidated Financial Statements” for further discussion of IPL’s tax benefit riders.

Income Tax Payments and Refunds - Income tax payments (refunds) received for 2010 through 2012 were as follows (in millions):

<table><tr><td></td><td>2012</td><td>2011</td><td>2010</td></tr><tr><td>IPL</td><td>$3</td><td>$25</td><td>($126)</td></tr><tr><td>WPL</td><td>(3)</td><td>(51)</td><td>(4)</td></tr><tr><td>Other subsidiaries</td><td>(20)</td><td>15</td><td>14</td></tr><tr><td>Alliant Energy</td><td>($20)</td><td>($11)</td><td>($116)</td></tr></table>

Alliant Energy’s income tax refunds in 2012, 2011 and 2010 were primarily due to claims filed with the IRS to carryback net operating losses to prior years. Alliant Energy does not expect to make any significant federal income tax payments in 2013 and 2014, based on the federal net operating loss and credit carryforward positions as of December 31, 2012. While no significant federal income tax payments in 2013 and 2014 are expected to occur, some tax payments and refunds may occur between consolidated group members (including IPL and WPL) under the tax sharing agreement between Alliant Energy and



its subsidiaries. Refer to Note 5 of the “Notes to Consolidated Financial Statements” for discussion of the carryforward positions.

## Investing Activities -

2012 vs. 2011 - Alliant Energy’s cash flows used for investing activities increased $503 million primarily due to $485 million of higher construction and acquisition expenditures and $12 million of net proceeds from the sale of RMT’s environmental business unit in June 2011. The higher construction and acquisition expenditures resulted from expenditures during 2012 for WPL’s purchase of Riverside, Resources’ Franklin County wind project, Corporate Services’ purchase of its corporate headquarters building at the expiration of the lease term, and emission controls projects at WPL’s Columbia Units 1 and 2, IPL’s Ottumwa Unit 1 and IPL’s George Neal Units 3 and 4. These items were partially offset by progress payments by IPL during 2011 for wind turbine generators that were sold to Resources in 2011, and expenditures during 2011 for WPL’s Bent Tree - Phase I wind project and WPL’s acquisition of the remaining 25% interest in Edgewater Unit 5.

2011 vs. 2010 - Alliant Energy’s cash flows used for investing activities decreased $214 million primarily due to $194 million of lower construction and acquisition expenditures and $12 million of net proceeds from the sale of RMT’s environmental business unit in 2011. The lower construction and acquisition expenditures resulted from expenditures during 2010 for WPL’s Bent Tree - Phase I wind project, IPL’s Lansing Unit 4 emission controls project and IPL’s Whispering Willow - East wind project. These items were partially offset by expenditures during 2011 for wind turbine generators for Resources’ Franklin County wind project, WPL’s acquisition of the remaining 25% interest in Edgewater Unit 5 and WPL’s emission controls project at Edgewater Unit 5.

Construction and Acquisition Expenditures - Capital expenditures and financing plans are reviewed, approved and updated as part of Alliant Energy’s strategic and operational planning processes. Significant capital projects and investments are subject to a cross-functional review prior to approval. Changes in Alliant Energy’s anticipated construction and acquisition expenditures may result from a number of reasons including economic conditions, regulatory requirements, changing legislation, ability to obtain adequate and timely rate relief, improvements in technology, changing market conditions and new opportunities. Alliant Energy 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. Alliant Energy currently anticipates construction and acquisition expenditures for 2013 through 2016 as follows (in millions):

<table><tr><td rowspan="2">Utility business (a):</td><td colspan="4">Alliant Energy</td><td colspan="4">IPL</td><td colspan="4">WPL</td></tr><tr><td>2013</td><td>2014</td><td>2015</td><td>2016</td><td>2013</td><td>2014</td><td>2015</td><td>2016</td><td>2013</td><td>204</td><td>2015</td><td>2016</td></tr><tr><td>Generation - new IPL gas facility</td><td>$10</td><td>$100</td><td>$325</td><td>$200</td><td>$10</td><td>$100</td><td>$325</td><td>$200</td><td>$—</td><td>$—</td><td>$—</td><td>$—</td></tr><tr><td>Environmental</td><td>355</td><td>210</td><td>200</td><td>165</td><td>185</td><td>120</td><td>15</td><td>5</td><td>170</td><td>90</td><td>185</td><td>160</td></tr><tr><td>Generation performance improvements</td><td>35</td><td>75</td><td>25</td><td>45</td><td>30</td><td>60</td><td>10</td><td>20</td><td>5</td><td>15</td><td>15</td><td>25</td></tr><tr><td>Other</td><td>380</td><td>410</td><td>405</td><td>410</td><td>200</td><td>225</td><td>230</td><td>235</td><td>180</td><td>185</td><td>175</td><td>175</td></tr><tr><td>Total utility business</td><td>780</td><td>795</td><td>955</td><td>820</td><td>$425</td><td>$505</td><td>$580</td><td>$460</td><td>$355</td><td>$290</td><td>$375</td><td>$360</td></tr><tr><td>Corporate Services (b)</td><td>40</td><td>45</td><td>30</td><td>20</td><td></td><td></td><td></td><td></td><td></td><td></td><td></td><td></td></tr><tr><td>Other (b)</td><td>15</td><td>20</td><td>5</td><td>5</td><td></td><td></td><td></td><td></td><td></td><td></td><td></td><td></td></tr><tr><td></td><td>$835</td><td>$860</td><td>$990</td><td>$845</td><td></td><td></td><td></td><td></td><td></td><td></td><td></td><td></td></tr></table>

(a) Cost estimates represent Alliant Energy’s, IPL’s or WPL’s estimated portion of total escalated construction and acquisition expenditures and exclude AFUDC, if applicable. Refer to “Strategic Overview” for further discussion of the generation and environmental compliance plans.

(b) Cost estimates represent total escalated construction and acquisition expenditures and exclude capitalized interest.

Government Incentives for Wind Projects - Alliant Energy completed Resources’ 100 MW Franklin County wind project in the fourth quarter of 2012, which made the project eligible for one of the government incentives available under the American Recovery and Reinvestment Act (ARRA) enacted in 2009. Alliant Energy chose to elect the cash grant option, which is expected to result in approximately $62 million of grant proceeds in the first half of 2013. Refer to Note 4(d) of the “Notes to Consolidated Financial Statements” for further discussion of the cash grant related to the Franklin County wind project.



## Financing Activities -

2012 vs. 2011 - Alliant Energy’s cash flows from financing activities increased $523 million primarily due to the impacts of $385 million of long-term debt issued in 2012 discussed below, changes in the amount of commercial paper outstanding at Alliant Energy, IPL and WPL, and $40 million of payments to redeem IPL’s 7.10% cumulative preferred stock in April 2011.

Increases in financing cash flows due to the issuance of long-term debt for 2012 vs. 2011 were as follows (in millions):

<table><tr><td>WPL&#x27;s 2.25% debentures in November 2012</td><td>$250</td></tr><tr><td>Corporate Services&#x27; 3.45% senior notes in September 2012</td><td>75</td></tr><tr><td>Franklin County Holdings, LLC variable-rate term loan credit agreement in December 2012</td><td>60</td></tr><tr><td></td><td>$385</td></tr></table>

2011 vs. 2010 - Alliant Energy’s cash flows used for financing activities increased $64 million primarily due to the impacts of long-term debt issued and retired during 2010 discussed below and $40 million of payments to redeem IPL’s 7.10% cumulative preferred stock in 2011. These items were partially offset by changes in the amount of commercial paper outstanding at Alliant Energy, IPL and WPL.

Increases (decreases) in financing cash flows due to changes in long-term debt for 2011 vs. 2010 were as follows (in millions):

<table><tr><td colspan="2">Proceeds from issuances:</td></tr><tr><td>IPL&#x27;s 3.65% senior debentures issued in August 2010</td><td>(200)</td></tr><tr><td>IPL&#x27;s 3.3% senior debentures issued in June 2010</td><td>(150)</td></tr><tr><td>WPL&#x27;s 4.6% debentures issued in June 2010</td><td>(150)</td></tr><tr><td colspan="2">Payments to retire:</td></tr><tr><td>IPL&#x27;s 6.75% senior debentures retired in September 2010</td><td>206</td></tr><tr><td>WPL&#x27;s 7.625% debentures retired in March 2010</td><td>100</td></tr><tr><td></td><td>(194)</td></tr></table>

FERC and Public Utility Holding Company Act Financing Authorizations - Under the Public Utility Holding Company Act of 2005, FERC has authority over the issuance of utility securities, except to the extent that a public utility’s primary state regulatory commission has retained jurisdiction over such matters. FERC has authority over the issuance of securities by IPL and Corporate Services. FERC does not have authority over the issuance of securities by Alliant Energy, WPL or Resources.

In October 2011, IPL received authorization from FERC for $750 million of long-term debt securities issuances, $750 million of short-term debt securities outstanding (including borrowings from its parent, with $674 million of remaining authority as of December 31, 2012) and $200 million of preferred stock issuances through 2013.

In March 2012, Corporate Services received authorization from FERC for $150 million of long-term debt securities issuances (with $75 million of remaining authority as of December 31, 2012) and to maintain up to $200 million of short-term debt securities outstanding through March 30, 2014. As of December 31, 2012, Corporate Services has authority under the March 2012 order issued by FERC to receive an unspecified amount of capital contributions and advances from its parent or other affiliates through March 30, 2014.

State Regulatory Financing Authorizations - In November 2011, WPL received authorization from the PSCW to have up to $400 million of short-term borrowings and/or letters of credit outstanding through the earlier of the expiration date of WPL's credit facility agreement (including extensions) or December 2019. As of December 31, 2012, WPL has remaining authority to issue up to $400 million of long-term debt securities in 2013 pursuant to a February 2012 PSCW order.

In 2010, the MPUC issued an order that determined IPL does not need to obtain authorization to issue securities as long as IPL is not organized under the laws of the state of Minnesota and the securities issued do not encumber any of its property in the state of Minnesota. IPL currently does not have, and does not plan to issue, securities that encumber its property, thus IPL is not currently required to obtain approval from the MPUC for unsecured securities issuances. However, if in the future IPL were to subject its utility property in Minnesota to an encumbrance for the purpose of securing the payment of any indebtedness, IPL would be required to obtain an order from the MPUC approving such securities issuances.



Shelf Registrations - Alliant Energy, IPL and WPL have current shelf registration statements with the Securities and Exchange Commission for availability through December 2014 as follows:

<table><tr><td rowspan="2">Aggregate amount available as of December 31, 2012</td><td>Alliant Energy</td><td>IPL</td><td>WPL</td></tr><tr><td>Unspecified</td><td>$800 million</td><td>$550 million</td></tr><tr><td>Securities available to be issued</td><td>Common stock, debt and other securities</td><td>Preferred stock and debt securities</td><td>Preferred stock and debt securities</td></tr></table>

Common Stock Dividends - Payment of common stock dividends is subject to dividend declaration by Alliant Energy’s Board of Directors. In November 2012, Alliant Energy announced an increase in its targeted 2013 annual common stock dividend to $1.88 per share, which is equivalent to a quarterly rate of $0.47 per share, beginning with the February 15, 2013 dividend payment. Alliant Energy’s general long-term goal is to maintain a dividend payout ratio that is competitive with the industry average. Based on that, Alliant Energy’s goal is to maintain a dividend payout ratio of approximately 60% to 70% of consolidated earnings from continuing operations. Alliant Energy’s dividend payout ratio was 61% of its consolidated earnings from continuing operations in 2012. Refer to Note 7 of the “Notes to Consolidated Financial Statements” for discussion of IPL’s and WPL’s dividend payment restrictions based on the terms of their outstanding preferred stock and applicable regulatory limitations.

Common Stock Issuances and Capital Contributions - Alliant Energy issued $1 million, $3 million and $6 million of additional common stock from the exercise of stock options under its equity-based compensation plans for employees in 2012, 2011 and 2010, respectively. Alliant Energy currently anticipates its only common stock issuances in 2013 will be to issue new shares under its equity-based compensation plans for employees. Refer to Note 6(b) of the “Notes to Consolidated Financial Statements” for discussion of Alliant Energy’s common stock issuances in 2012 under its equity-based compensation plans for employees.

Preferred Stock Redemptions - In February 2013, IPL announced it will redeem all 6,000,000 outstanding shares of its 8.375% cumulative preferred stock in March 2013 at par value for approximately $150 million plus accrued and unpaid dividends to the redemption date. In February 2013, WPL announced it will redeem all 1,049,225 outstanding shares of its 4.40% through 6.50% cumulative preferred stock in March 2013 for approximately $61 million plus accrued and unpaid dividends to the redemption date. In 2011, IPL redeemed all 1,600,000 outstanding shares of its 7.10% cumulative preferred stock at par value for $40 million plus accrued and unpaid dividends up to the redemption date.

Short-term Debt - Alliant Energy and its subsidiaries maintain committed revolving credit facilities to provide short-term borrowing flexibility and backstop liquidity for commercial paper outstanding. At December 31, 2012, Alliant Energy's short-term borrowing arrangements included three revolving credit facilities totaling $1 billion ($300 million for Alliant Energy at the parent company level, $300 million for IPL and $400 million for WPL), which expire in December 2016. There are currently 12 lenders that participate in the three credit facilities, with aggregate respective commitments ranging from $25 million to $113 million. Each of the credit facilities has a renewal provision for two one-year extensions, subject to lender approval. Each of the credit facilities has a provision to expand the facility size up to $100 million, subject to lender approval for Alliant Energy and IPL, and subject to lender and regulatory approvals for WPL. During 2012, the Alliant Energy parent company, IPL and WPL issued commercial paper to meet short-term financing requirements and did not borrow directly under their respective credit facilities.

Alliant Energy’s, IPL’s and WPL’s credit facility agreements each contain a financial covenant, which requires the entities to maintain certain debt-to-capital ratios in order to borrow under the credit facilities. The debt component of the capital ratios includes long- and short-term debt (excluding non-recourse debt and hybrid securities to the extent the total carrying value of such hybrid securities does not exceed 15% of consolidated capital of the applicable borrower), capital lease obligations, letters of credit, guarantees of the foregoing and new synthetic leases. Unfunded vested benefits under qualified pension plans are not included in the debt-to-capital ratios. The equity component of the capital ratios excludes accumulated other comprehensive income (loss).

The credit agreements contain provisions that prohibit placing liens on any of Alliant Energy’s, IPL’s or WPL’s property or their respective subsidiaries with certain exceptions. Exceptions include among others, liens to secure obligations of up to 5% of the consolidated assets of the applicable borrower (valued at carrying value), liens imposed by government entities, materialmens’ and similar liens, judgment liens, and liens to secure non-recourse debt not to exceed $100 million outstanding at any one time, and purchase money liens.

The credit agreements contain provisions that require, during their term, any proceeds from asset sales, with certain exclusions, in excess of 20% of Alliant Energy’s, IPL’s and WPL’s respective consolidated assets be used to reduce



commitments under their respective facilities. Exclusions include, among others, certain sale and lease-back transactions and sales of non-regulated assets and accounts receivable.

The credit agreements contain customary events of default. In addition, Alliant Energy’s credit agreement contains a cross-default provision that would be triggered if Alliant Energy or any domestic, majority-owned subsidiary of Alliant Energy defaults on debt (other than non-recourse debt) totaling $50 million or more. A cross-default provision would be triggered for Alliant Energy under the IPL or WPL credit agreements if IPL or WPL, as applicable, or a majority-owned subsidiary accounting for 20% or more of IPL’s or WPL’s, as applicable, consolidated assets (valued at carrying value) defaults on debt totaling $50 million or more. A default by a minority-owned subsidiary and, in the case of the Alliant Energy credit agreement, a default by a foreign subsidiary, would not trigger a cross-default. A default by Alliant Energy, Corporate Services or Resources and its subsidiaries would not trigger a cross-default under either the IPL or WPL credit agreements, nor would a default by either of IPL or WPL constitute a cross-default event for the other. If an event of default under any of the credit agreements occurs and is continuing, then the lenders may declare any outstanding obligations under the credit agreements immediately due and payable. In addition, if any order for relief is entered under bankruptcy laws with respect to Alliant Energy, IPL or WPL, then any outstanding obligations under the respective credit agreements would be immediately due and payable. In addition, IPL’s sales of accounts receivable program agreement contains a cross-default provision that is triggered if IPL or Alliant Energy incurs an event of default on debt totaling $50 million or more. If an event of default under IPL’s sales of accounts receivable program agreement occurs, then the counterparty could terminate such agreement. Refer to Note 4(a) of the “Notes to Consolidated Financial Statements” for additional information on amounts outstanding under IPL’s sales of accounts receivable program.

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

At December 31, 2012, Alliant Energy, IPL and WPL were in compliance with all covenants and other provisions of the credit agreements.

Refer to Note 9(a) of the “Notes to Consolidated Financial Statements” for additional information on the credit facilities, commercial paper outstanding and debt-to-capital ratios.

Long-term Debt - In 2012, there were no significant retirements of long-term debt. In 2012, significant issuances of long-term debt were as follows (dollars in millions):

<table><tr><td>Company</td><td>Principal Amount</td><td>Type</td><td>Interest Rate</td><td>Maturity Date</td><td>Use of Proceeds</td></tr><tr><td>WPL</td><td>$250</td><td>Debentures</td><td>2.25%</td><td>Nov-2022</td><td>Fund a portion of the purchase price of Riverside</td></tr><tr><td>Corporate Services</td><td>75</td><td>Senior notes</td><td>3.45%</td><td>Sep-2022</td><td>Repay short-term debt primarily incurred for the purchase of the corporate headquarters building and for general working capital purposes</td></tr><tr><td>Franklin County Holdings, LLC</td><td>60</td><td>Variable-rate term loan credit agreement</td><td>1.1% at December 31, 2012</td><td>Dec-2014</td><td>Fund a portion of the costs of the Franklin County wind project</td></tr></table>

Refer to Note 9(b) of the “Notes to Consolidated Financial Statements” for further discussion of long-term debt.

Financing Forecast for 2013 - Alliant Energy currently expects to issue up to $500 million of preferred stock and/or long-term debt in 2013. This amount excludes any commercial paper outstanding that may be classified as long-term debt.

## Creditworthiness -

Ratings Triggers - The long-term debt of Alliant Energy and its subsidiaries is not subject to any repayment requirements as a result of explicit credit rating downgrades or so-called “ratings triggers.” However, Alliant Energy and its subsidiaries are parties to various agreements, including PPAs, commodity contracts and corporate guarantees that are dependent on maintaining investment-grade credit ratings. In the event of a downgrade below investment-grade level, Alliant Energy or its subsidiaries 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 Alliant Energy, IPL and WPL have sufficient liquidity to cover counterparty credit support or collateral requirements under these various agreements. In addition, a downgrade in the credit ratings of Alliant Energy, IPL or WPL could also result in them paying higher interest rates in future financings, reduce their pool of potential lenders, increase their borrowing costs under existing credit facilities or limit their access to the commercial paper market. Alliant Energy is committed to taking the necessary steps required to maintain investment-grade credit ratings. Current credit ratings and outlooks are as follows:



<table><tr><td rowspan="4">Alliant Energy:</td><td>Corporate/issuer</td><td>A-</td><td>Baa1</td></tr><tr><td>Commercial paper</td><td>A-2</td><td>P-2</td></tr><tr><td>Senior unsecured long-term debt</td><td>BBB+</td><td>Baa1</td></tr><tr><td>Outlook</td><td>Stable</td><td>Stable</td></tr><tr><td rowspan="5">IPL:</td><td>Corporate/issuer</td><td>A-</td><td>A3</td></tr><tr><td>Commercial paper</td><td>A-2</td><td>P-2</td></tr><tr><td>Senior unsecured long-term debt</td><td>A-</td><td>A3</td></tr><tr><td>Preferred stock</td><td>BBB</td><td>Baa2</td></tr><tr><td>Outlook</td><td>Stable</td><td>Stable</td></tr><tr><td rowspan="5">WPL:</td><td>Corporate/issuer</td><td>A</td><td>A2</td></tr><tr><td>Commercial paper</td><td>A-1</td><td>P-1</td></tr><tr><td>Senior unsecured long-term debt</td><td>A</td><td>A2</td></tr><tr><td>Preferred stock</td><td>BBB+</td><td>Baa1</td></tr><tr><td>Outlook</td><td>Stable</td><td>Stable</td></tr><tr><td>Resources:</td><td>Corporate/issuer</td><td>A-</td><td>Not rated</td></tr></table>

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. Alliant Energy assumes no obligation to update these credit ratings. Refer to Note 12 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 - Alliant Energy utilizes off-balance sheet synthetic operating leases related to the financing of certain utility railcars. Synthetic leases provide favorable financing rates to Alliant Energy while allowing it to maintain operating control of its leased assets. Refer to Note 3 of the “Notes to Consolidated Financial Statements” for future minimum lease payments and residual value guarantees associated with these synthetic leases.

Special Purpose Entities - IPL maintains a Receivables Purchase and Sale Agreement (Agreement) whereby it may sell its customer accounts receivables, unbilled revenues and certain other accounts receivables to a third-party financial institution through wholly-owned and consolidated special purpose entities. In 2012, 2011 and 2010, IPL evaluated the third-party financial institution that purchases IPL's receivable assets under the Agreement and believes that the third-party financial institution is a variable interest entity. However, IPL does not have a variable interest in the third-party financial institution. Refer to "Cash Flows - Operating Activities - IPL's Sales of Accounts Receivable Program" and Note 4(a) of the "Notes to Consolidated Financial Statements" for information regarding IPL's sales of accounts receivable program including an extension through March 2014 of the purchase commitment from the third-party financial institution to which IPL sells its receivables.

Guarantees, Surety Bonds and Indemnifications - Alliant Energy has guarantees, surety bonds and indemnifications outstanding at December 31, 2012 related to its prior divestiture activities, including Alliant Energy’s sale of its remaining interest in RMT in January 2013. Refer to Note 13(d) of the “Notes to Consolidated Financial Statements” for additional information.

## Certain Financial Commitments -

Contractual Obligations - Consolidated long-term contractual obligations as of December 31, 2012 were as follows (in millions):

<table><tr><td></td><td>2013</td><td>2014</td><td>2015</td><td>2016</td><td>2017</td><td>Thereafter</td><td>Total</td></tr><tr><td>Operating expense purchase obligations (Note 13(b)):</td><td></td><td></td><td></td><td></td><td></td><td></td><td></td></tr><tr><td>Purchased power and fuel commitments (a)</td><td>$574</td><td>$183</td><td>$111</td><td>$31</td><td>$14</td><td>$6</td><td>$919</td></tr><tr><td>SO2 emission allowances</td><td>—</td><td>—</td><td>12</td><td>14</td><td>8</td><td>—</td><td>34</td></tr><tr><td>Other (b)</td><td>22</td><td>4</td><td>3</td><td>—</td><td>—</td><td>—</td><td>29</td></tr><tr><td>Long-term debt maturities (Note 9(b))</td><td>51</td><td>358</td><td>183</td><td>3</td><td>4</td><td>2,551</td><td>3,150</td></tr><tr><td>Interest - long-term debt obligations</td><td>162</td><td>162</td><td>146</td><td>142</td><td>142</td><td>1,694</td><td>2,448</td></tr><tr><td>Capital purchase obligations (Note 13(a))</td><td>46</td><td>—</td><td>—</td><td>—</td><td>—</td><td>—</td><td>46</td></tr><tr><td>Operating leases (Note 3)</td><td>9</td><td>13</td><td>5</td><td>3</td><td>2</td><td>24</td><td>56</td></tr><tr><td>Capital leases</td><td>1</td><td>1</td><td>1</td><td>—</td><td>—</td><td>1</td><td>4</td></tr><tr><td></td><td>$865</td><td>$721</td><td>$461</td><td>$193</td><td>$170</td><td>$4,276</td><td>$6,686</td></tr></table>



(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.

(b) Other operating expense purchase obligations represent individual commitments incurred during the normal course of business that exceeded $1 million at December 31, 2012.

At December 31, 2012, Alliant Energy’s uncertain tax positions recorded as liabilities were not material, and are 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 construction and acquisition programs. In addition, at December 31, 2012, 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.

## OTHER MATTERS

Market Risk Sensitive Instruments and Positions - Alliant Energy’s primary market risk exposures are associated with commodity prices, investment prices and interest rates. Alliant Energy has risk management policies to monitor and assist in mitigating these market risks and uses derivative instruments to manage some of the exposures. Refer to Notes 1(i) and 12 of the “Notes to Consolidated Financial Statements” for further discussion of derivative instruments.

Commodity Price - Alliant Energy is exposed to the impact of market fluctuations in the price and transportation costs of commodities it procures and markets. Alliant Energy 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. Alliant Energy’s exposure to commodity price risks in its utility businesses is also significantly mitigated by current rate-making structures in place for recovery of its electric production fuel and purchased energy expenses (fuel-related costs) as well as its cost of natural gas purchased for resale. IPL’s electric and gas tariffs and WPL’s wholesale electric and gas tariffs provide for subsequent monthly adjustments to their tariff rates for material changes in prudently incurred commodity costs. IPL’s and WPL’s rate mechanisms, combined with commodity derivatives, significantly reduce commodity risk associated with their electric and gas margins.

WPL’s retail electric margins have the most exposure to the impact of changes in commodity prices for Alliant Energy due largely to the current retail recovery mechanism in place in Wisconsin for fuel-related costs. The cost recovery mechanism applicable for WPL’s retail electric customers is based on forecasts of fuel-related costs expected to be incurred during forward-looking test year periods and fuel monitoring ranges determined by the PSCW during each retail electric rate proceeding or in a separate fuel cost plan approval proceeding. Under this 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 under-/over-collection of fuel-related costs from retail electric customers that are outside the approved ranges. Deferral of under-collection of fuel-related costs are reduced to the extent WPL’s return on common equity during the fuel cost plan year exceeds the most recently authorized return on common equity. Retail fuel-related costs incurred by WPL in 2012 were lower than retail fuel-related costs used to determine rates for such period resulting in an over-collection of fuel-related costs for 2012 of approximately $17 million (including $11 million outside the approved range for 2012). As of December 31, 2012, Alliant Energy recorded $11 million in “Regulatory liabilities” on the Consolidated Balance Sheet for refunds expected to be used to adjust fuel-related cost changes in 2014.

In December 2012, the PSCW approved annual forecasted fuel-related costs per MWh of $23.28 based on $320 million of variable fuel-related costs for WPL’s 2013 test period. These 2013 fuel-related costs will be monitored using an annual bandwidth of plus or minus 2%. Based on the cost recovery mechanism in Wisconsin, the annual forecasted fuel-related costs approved by the PSCW in December 2012 and an annual bandwidth of plus or minus 2%, Alliant Energy currently estimates the commodity risk exposure to its electric margins in 2013 is approximately $5 million.

Refer to “Rate Matters” and Note 1(h) of the “Notes to Consolidated Financial Statements” for additional details of utility cost recovery mechanisms that significantly reduce Alliant Energy’s commodity risk.



Investment Price - Alliant Energy 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. Refer to Note 6(a) of the “Notes to Consolidated Financial Statements” for details of the debt and equity securities held by its pension and other postretirement benefits plans. Refer to “Critical Accounting Policies and Estimates - Pensions and Other Postretirement Benefits” for the impact on Alliant Energy’s retirement plan costs of changes in the rate of returns earned by its plan assets.

Interest Rate - Alliant Energy is exposed to risk resulting from changes in interest rates as a result of its issuance of variable-rate borrowings. In addition, Alliant Energy is exposed to risk resulting from changes in interest rates as a result of cash proceeds outstanding under IPL’s sales of accounts receivable program. Assuming the impact of a hypothetical 100 basis point increase in interest rates on variable-rate borrowings and cash proceeds outstanding under IPL’s sales of accounts receivable program at December 31, 2012, Alliant Energy’s annual pre-tax expense would increase by approximately $5 million.

Refer to Notes 4(a) and 9 of the “Notes to Consolidated Financial Statements” for additional information on cash proceeds outstanding under IPL’s sales of accounts receivable program, and short- and long-term variable-rate borrowings, respectively. Refer to “Critical Accounting Policies and Estimates - Pensions and Other Postretirement Benefits” for the impacts of changes in discount rates on retirement plan obligations and costs.

Critical Accounting Policies and Estimates - The preparation of consolidated financial statements in conformity with 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, Alliant Energy 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. Alliant Energy’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 accounting policies and the estimates used in the preparation of the consolidated financial statements.

Contingencies - Alliant Energy 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 estimated 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 Alliant Energy 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. Note 13 of the “Notes to Consolidated Financial Statements” provides discussion of contingencies assessed at December 31, 2012 including various pending legal proceedings that may have a material impact on Alliant Energy’s financial condition and results of operations.

Regulatory Assets and Regulatory Liabilities - Alliant Energy’s utility subsidiaries (IPL and WPL) are regulated by various federal and state regulatory agencies. As a result, they are subject to accounting guidance for regulated 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 in the rate-making process. 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. Alliant Energy recognizes regulatory assets and regulatory liabilities in accordance with the rulings of applicable federal and state regulators, and future regulatory rulings may impact the carrying value and accounting treatment of its regulatory assets and regulatory liabilities.

Alliant Energy makes assumptions and judgments each reporting period regarding whether its regulatory assets are probable of future recovery and its regulatory liabilities are probable future obligations by considering factors such as regulatory environment changes, rate orders issued by the applicable regulatory agencies and historical decisions by such regulatory agencies regarding similar regulatory assets and regulatory liabilities. The judgments used by regulatory authorities 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 judgments may result in a material impact on Alliant Energy’s results of operations and the amount of assets and liabilities in its financial statements. Note 1(b) of the “Notes to Consolidated Financial Statements” provides details of the nature and amounts of Alliant Energy’s regulatory assets and regulatory liabilities assessed at December 31, 2012 as well as material changes to its regulatory assets and regulatory liabilities during 2012.



Long-Lived Assets - Alliant Energy completes periodic assessments regarding the recoverability of certain long-lived assets when factors indicate the carrying value of such assets may be impaired or such assets are planned to be sold. These assessments require significant assumptions and judgments by management. The long-lived assets assessed for impairment generally include assets within its non-regulated operations that are proposed to be sold or are generating operating losses, and certain long-lived assets within its regulated operations that may not be fully recovered from IPL's and WPL's customers as a result of regulatory decisions in the future.

Non-regulated Operations - Factors considered in determining if an impairment review is necessary for long-lived assets within non-regulated operations 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 exceeds the expected undiscounted future cash flows, 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. Alliant Energy's and IPL's long-lived assets within their non-regulated operations assessed in 2012 included a wind site currently expected to be used to develop a future wind project. In addition, Alliant Energy's long-lived assets within its non-regulated operations assessed in 2012 also included the Franklin County wind project.

Franklin County Wind Project - Alliant Energy completed construction of its 100 MW Franklin County wind project and placed it into service in December 2012. Alliant Energy performed an evaluation of the recoverability of the carrying value of the Franklin County wind project given a significant change in the use of the asset as a result of it being placed into service, continued downturn in forward electricity prices in 2012 and no long-term off-take arrangement. The evaluation concluded the undiscounted cash flows expected from the Franklin County wind project during its estimated useful life exceeded its carrying value as of December 31, 2012, resulting in no impairment. Changes in the estimated cash flows could result in the undiscounted cash flows being less than the carrying amount and a future material impairment could be required. Primary factors that could have an effect on the future expected cash flows for the project include the price of electricity generated from the project during its useful life, the volume of electricity generated, the expected life of the project and changes in anticipated operation and maintenance expenses. An impairment of the Franklin County wind project could be triggered in the future if long-term electricity prices stay at current depressed levels or decline even further, or if the expected output or life of the project is significantly reduced. As of December 31, 2012, the capitalized expenditures for the project were $148 million. Notes 1(e) and 1(f) of the “Notes to Consolidated Financial Statements” provide additional discussion of the Franklin County wind project. Note 4(d) of the “Notes to Consolidated Financial Statements” and “Other Future Considerations” provide discussion of a cash grant related to the Franklin County wind project.

Undeveloped Wind Site - As of December 31, 2012, Alliant Energy has an undeveloped wind site with capitalized costs of $13 million related to IPL's 200 MW of wind site capacity in Franklin County, Iowa. Alliant Energy assessed the recoverability of this undeveloped wind site given the long-term period projected until the site is utilized and concluded no impairment was required as of December 31, 2012. Changes in the future use of this undeveloped wind site could result in a future material impairment. The future utilization of this undeveloped wind site is dependent on the future demand of wind energy in the region where the wind site is located. The future demand of wind energy in the region where the wind site is located is dependent on various factors including future government incentives for wind projects, energy policy and legislation including federal and state renewable energy standards and regulation of carbon emissions, electricity and fossil fuel prices, transmission constraints in the region where the wind site is located and further technological advancements for wind generation. Alliant Energy currently believes, based on a combination of the various factors, further wind development in the region where the wind site is located will occur. Alliant Energy could realize an impairment related to this wind site if one or more of these factors are no longer expected to occur, or actions by regulatory agencies with jurisdiction over IPL indicate the costs of the undeveloped wind site would not be approved to be recovered from customers.

Regulated Operations - Long-lived assets within 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 IPL or WPL is disallowed recovery of any portion of the carrying value of its regulated property, plant and equipment that has been recently completed or is probable of abandonment, an impairment charge is recognized equal to the amount of the carrying value that was disallowed. If IPL or WPL is disallowed a full or partial return on the carrying value of its regulated property, plant and equipment that has been recently completed or is probable of abandonment, an impairment charge is recognized equal to the difference between the carrying amount of the asset and the present value of the future revenues expected from its regulated property, plant and equipment. Alliant Energy’s long-lived assets within its regulated



operations that were assessed for impairment in 2012 included WPL’s Bent Tree - Phase I wind project, IPL’s Whispering Willow - East wind project, and IPL’s and WPL’s generating units subject to early retirement.

WPL § Bent Tree - Phase I Wind Project - WPL placed the remaining portion of its 200 MW Bent Tree - Phase I wind project in service in 2011. In 2009, WPL requested that MISO conduct an optional study to identify any local transmission constraints that would prevent full output of the Bent Tree wind project. Based on the results of the optional study performed by MISO, WPL requested that ITC perform a facilities study to determine the feasibility and cost of an upgrade to a local transmission line needed to enable Bent Tree to achieve full generation capacity, which ITC completed in 2010. WPL entered into a Facility Construction Agreement (FCA) with ITC and MISO in 2011 to address the local transmission system constraint. Pursuant to the FCA and ITC’s Attachment “FF” tariff, WPL advanced funds to ITC in 2011 and 2012 necessary to construct the transmission upgrades on ITC’s system. As of December 31, 2012, Alliant Energy recorded $14 million in “Deferred charges and other” on the Consolidated Balance Sheet related to the project constructed by ITC. MISO is expected to complete the definitive planning phase study for Bent Tree in the first half of 2013. If the facilities are identified as required network upgrades as a result of the MISO definitive planning phase study, the facilities will be entitled to cost reimbursement from ITC, and WPL will be reimbursed by ITC for up to 100% of the transmission upgrade costs. While Alliant Energy believes WPL’s cost of the facilities will be reimbursed fully by ITC, Alliant Energy could record an impairment of these costs if they are determined not to be a required network upgrade and thus fail to qualify for reimbursement under ITC’s current Attachment “FF” tariff mechanism or if there is a change in ITC’s current Attachment “FF” tariff mechanism, and WPL is not able to recover these costs from its electric customers. Refer to “Other Future Considerations - Electric Transmission Service Charges” for further discussion of ITC’s Attachment “FF” tariff mechanism.

IPL § Whispering Willow - East Wind Project - Refer to Note 1(e) of the “Notes to Consolidated Financial Statements” for discussion of an $8 million impairment of the Minnesota retail portion of IPL’s Whispering Willow - East wind project costs during 2011 based on the MPUC’s August 2011 order.

Generating Units Subject to Early Retirement - Due to current and proposed environmental regulations, Alliant Energy is evaluating future plans for its electric generation fleet and has announced the early retirement of certain older and less-efficient EGUs. When it becomes probable that an EGU will be retired before the end of its useful life, Alliant Energy must assess whether the EGU meets the criteria to be considered abandoned. EGUs that are considered to be abandoned generally have material remaining net book values and are expected to cease operations in the near term significantly before the end of their original estimated useful lives. If an EGU meets the criteria to be considered abandoned, Alliant Energy must assess the probability of full recovery of the remaining carrying value of such EGU. If it is probable that regulators will not allow full recovery of and a full return on the remaining carrying amount of the abandoned EGU, an impairment charge is recognized equal to the difference between the remaining carrying value and the present value of the future revenues expected from the abandoned EGU. Alliant Energy evaluated its EGUs that are subject to early retirement and determined it did not have any EGUs that met the criteria to be considered abandoned as of December 31, 2012. Changes in the conclusions of whether an EGU is considered abandoned and the probability of regulators allowing full recovery of and return on the remaining carrying amount of EGUs considered to be abandoned could result in future material impairments. Refer to “Strategic Overview” for discussion of EGUs that may be retired by Alliant Energy along with the aggregate net book values of these EGUs.

Unbilled Revenues - Unbilled revenues are primarily associated with Alliant Energy’s utility operations. Energy sales to individual customers are based on the reading of customers’ meters, which occurs on a systematic basis throughout the month. Amounts 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 judgments and assumptions and significant changes in these judgments and assumptions could have a material impact on Alliant Energy’s results of operations. As of December 31, 2012, unbilled revenues related to Alliant Energy’s utility operations were $158 million ($77 million at IPL and $81 million at WPL). Note 4(a) of the “Notes to Consolidated Financial Statements” provides discussion of IPL’s unbilled revenues as of December 31, 2012 sold to a third-party financial institution related to its sales of accounts receivable program.

Pensions and Other Postretirement Benefits - Alliant Energy sponsors various defined benefit pension and other postretirement benefits plans that provide benefits to a significant portion of its employees. Alliant Energy makes assumptions and judgments periodically to estimate the obligations and costs related to its retirement plans. There are many judgments and assumptions involved in determining an entity’s pension and other postretirement liabilities and costs each period including employee demographics (including age, life expectancies and compensation levels), discount rates, assumed rates of return and funding. Changes made to plan provisions may also impact current and future benefits costs. Judgments



and assumptions are supported by historical data and reasonable projections and are reviewed at least annually. The following table shows the impacts of changing certain key actuarial assumptions discussed above (in millions):

<table><tr><td rowspan="2">Change in Actuarial Assumption</td><td colspan="2">Defined Benefit Pension Plans</td><td colspan="2">Other Postretirement Benefits Plans</td></tr><tr><td>Impact on Projected Benefit Obligation at December 31, 2012</td><td>Impact on 2013 Net Periodic Benefit Costs</td><td>Impact on Projected Benefit Obligation at December 31, 2012</td><td>Impact of 2013 Net Periodic Benefit Costs</td></tr><tr><td>1% change in discount rate</td><td>$161</td><td>$10</td><td>$21</td><td>$2</td></tr><tr><td>1% change in expected rate of return</td><td>N/A</td><td>9</td><td>N/A</td><td>1</td></tr></table>

Note 6(a) of the “Notes to Consolidated Financial Statements” provides additional details of pension and other postretirement benefits plans. Note 13(c) of the “Notes to Consolidated Financial Statements” provides recent developments of the class-action lawsuit filed against the Cash Balance Plan in 2008.

Income Taxes - Alliant Energy is subject to income taxes in various jurisdictions. Alliant Energy makes assumptions and judgments each reporting period to estimate its income tax assets, liabilities, benefits and expenses. Judgments and assumptions are supported by historical data and reasonable projections. Significant changes in these judgments and assumptions could have a material impact on Alliant Energy’s financial condition and results of operations. Alliant Energy’s, critical assumptions and judgments for 2012 include projections of qualifying repairs expenditures and allocation of mixed service costs due to the impact of Iowa rate-making principles on such property-related differences, and projections of future taxable income used to determine its ability to utilize net operating losses and credit carryforwards prior to their expiration and the states in which such future taxable income will be apportioned.

Effect of Rate-making on Property-related Differences - Alliant Energy’s effective tax rates are normally impacted by certain property-related differences at IPL for which deferred tax is not recorded in the income statement pursuant to Iowa rate-making principles. In 2009, IPL filed a request with the IUB to create a regulatory liability account for potential tax benefits and expenses resulting from certain of these property-related differences caused by changes in accounting methodologies and tax elections available under the Internal Revenue Code. These tax benefits related to the tax treatment of repair expenditures, allocation of insurance proceeds from the floods in 2008 and allocation of mixed services costs. In 2010, IPL received approval from the IUB to record any tax benefits and expenses from these changes in accounting methodologies in a regulatory liability account until the IRS audit process related to such changes in accounting methodologies was completed. The IRS audit process was completed for allocation of mixed service costs with the income tax return for calendar year 2010 and repairs expenditures with the income tax return for calendar year 2011. As a result, IPL has recognized the tax benefits and expenses from the change in accounting method for allocation of mixed service costs through 2010 and the tax benefits and expenses from the change in accounting method for repairs expenditures through 2011 in a regulatory liability referred to as the tax benefit riders. The tax benefits and expenses from the changes in accounting method for allocation of mixed service costs subsequent to 2010 and the tax benefits and expenses from the changes in accounting method for repairs expenditures subsequent to 2011 are being recorded consistent with general Iowa rate-making principles, which impact income tax expense and benefits at Alliant Energy. Changes in assumptions regarding the amount of IPL’s qualifying repairs expenditures and allocation of mixed service costs could result in a material impact on Alliant Energy’s financial condition and results of operations. Refer to Note 5 of the “Notes to Consolidated Financial Statements” and “Rate Matters” for further discussion of the tax benefit riders and details of how the effect of rate-making on property-related differences impacted Alliant Energy’s effective income tax rates for 2012 and 2011.

Carryforward Utilization - Alliant Energy generated significant federal tax credits and federal and state net operating losses that are currently being carried forward. Based on current projections of future taxable income, Alliant Energy plans to utilize substantially all of these carryforwards prior to their expiration. Changes in assumptions regarding Alliant Energy’s future taxable income could require valuation allowances in the future resulting in a material impact on its financial condition and results of operations.

State Apportionment - Alliant Energy utilizes state apportionment projections to record its deferred tax assets and liabilities each reporting period. Deferred tax assets and liabilities for temporary differences between the tax basis of assets and liabilities and the amounts reported in the consolidated financial statements are recorded utilizing currently enacted tax rates and estimates of future state apportionment rates expected to be in effect at the time the temporary differences reverse. These state apportionment projections are most significantly impacted by the estimated amount of revenues expected in the future from each state jurisdiction for Alliant Energy’s consolidated tax group, including both its regulated operations and its non-regulated operations. Alliant Energy recorded $15 million of income tax expense in the first quarter of 2012 due to changes in state apportionment projections caused by the anticipated sale of Alliant Energy’s RMT business that was completed in



January 2013. A significant majority of the additional income tax expense recognized from changes in state apportionment projections were recorded at IPL and WPL due to their large deferred tax liability positions at December 31, 2011.

Refer to Note 1(c) of the “Notes to Consolidated Financial Statements” for further discussion of regulatory accounting for taxes. Refer to Note 5 of the “Notes to Consolidated Financial Statements” for further discussion of federal tax credit carryforwards, federal and state net operating loss carryforwards, state apportionment impacts, and details of uncertain tax positions.

Other Future Considerations - In addition to items discussed earlier in MDA and the “Notes to Consolidated Financial Statements,” the following items could impact Alliant Energy’s future financial condition or results of operations:

Electric Transmission Service Charges - IPL and WPL currently receive substantially all their transmission services from ITC and ATC, respectively. The annual transmission service rates that ITC or ATC charges their customers are calculated each calendar year using a FERC-approved cost of service formula rate template referred to as Attachment “O.” The Attachment “O” rate is based on ITC’s or ATC’s projected net revenue requirement for the upcoming calendar year (i.e., the year the rates will be billed) as well as any true-up adjustment for any over- or under-recovered amounts from previous calendar years. For ITC, the true-up adjustment is applied two years subsequent to the collected year. For ATC, an over-collection is refunded to its customers in the subsequent year and an under-collection is recovered two years subsequent to the collected year. Because Attachment “O” is a FERC-approved formula rate, ITC and ATC can implement new rates each calendar year without filing a request with FERC. However, new rates are subject to challenge by FERC if the rates proposed by ITC or ATC are determined by FERC to be unjust or unreasonable or another mechanism is determined by FERC to be just and reasonable. FERC is currently performing an investigation into Attachment “O” protocols focusing on the areas of participation, transparency and challenge procedures. IPL filed comments related to ITC’s Attachment “O” protocols. Alliant Energy is currently unable to determine what impacts this investigation will have on future electric transmission service charges.

## 2013 Electric Transmission Service Expenses

2013 Rates Charged by ITC to IPL - In September 2012, ITC filed with MISO the Attachment “O” rate it proposes to charge its customers in 2013 for electric transmission services. The proposed rate was based on ITC’s net revenue requirement for 2013 as well as a true-up adjustment credit related to amounts that ITC over-recovered from its customers in 2011. The 2013 Attachment “O” rate filed with MISO is approximately 15% higher than the rate ITC charged its customers in 2012.

2013 Rates Charged by ATC to WPL - In September 2012, ATC shared with its customers the Attachment “O” rate it proposes to charge them in 2013 for electric transmission services. The proposed rate was based on ATC’s net revenue requirement for 2013 as well as a true-up adjustment credit related to amounts that ATC over-recovered from its customers in 2011. The 2013 Attachment “O” rate is approximately 5% higher than the rate ATC charged its customers in 2012.

MISO Transmission Charges Billed to IPL and WPL - MISO tariffs billed to IPL and WPL include costs related to various shared transmission projects including Multi-Value Projects (MVPs). MVPs include new large scale transmission projects that enable the reliable and economic delivery of energy in support of documented energy policy mandates or provide economic value across multiple pricing zones within MISO. MVP costs are socialized across the entire MISO footprint based on energy usage of each MISO participant. MISO tariffs billed to IPL and WPL also include costs related to other shared transmission projects, including projects designed to reduce market congestion, to provide interconnection to the transmission grid for new generation, and to ensure compliance with applicable standards. The costs of these projects are allocated to MISO participants in a way that is commensurate with the benefit to the participants' pricing zone. The MISO transmission charges billed to IPL and WPL are expected to increase in the future due to the increased number of shared transmission projects occurring in the MISO region.

The increase in ITC’s and ATC’s Attachment “O” rates and MISO transmission charges for shared transmission projects are expected to contribute to material increases in future electric transmission service charges for IPL and WPL. Alliant Energy, IPL and WPL currently estimate their electric transmission service expenses in 2013 will be higher than the comparable expenses charged in 2012 by approximately $70 million, $60 million and $10 million, respectively. A significant portion of the increase in IPL’s electric transmission service expenses is expected to be offset with increases in electric revenues resulting from the automatic transmission cost recovery rider approved by the IUB and implemented in 2011. A significant portion of the increase in WPL’s electric transmission service expenses was utilized to set electric revenues approved by the PSCW in WPL’s latest retail electric base rate case.



ITC’s Attachment “FF” Tariff - In September 2012, IPL filed a formal complaint with FERC alleging that ITC’s Attachment “FF” tariff is unjust, unreasonable and unduly discriminatory to IPL and its customers. In the complaint, IPL alleges that its customers have made payments of $32 million in incremental costs for the period 2008 through 2011 as compared to costs that would have been charged under the version of Attachment “FF” tariff applicable in the majority of the MISO pricing zones without obtaining equal benefits. The complaint filed with FERC also includes estimates that IPL’s customers could make aggregate payments of $138 million in incremental costs for the period 2012 through 2016. IPL requested in its formal complaint that FERC investigate ITC’s Attachment “FF” tariff, establish a refund date of September 14, 2012 with respect to the complaint, and establish hearing procedures. IPL also requested that if FERC determines that ITC’s Attachment “FF” tariff is unjust and unreasonable then it should require ITC to file revisions to conform its Attachment “FF” tariff to the MISO Attachment “FF” tariff, which is applicable in the majority of the other pricing zones. In October 2012, ITC filed a response to IPL’s formal complaint. Alliant Energy is currently unable to predict what action FERC may take regarding IPL’s formal complaint or a time-line under which FERC may act, but believes the outcome could be material to the future amount of transmission service costs billed by ITC to IPL. Alliant Energy expects any changes in the amount of electric transmission services expenses resulting from IPL’s formal complaint will have a comparable offsetting impact in electric revenues due to the automatic transmission cost recovery rider approved by the IUB and implemented in 2011.

FERC Order 1000 - In 2011, FERC issued Order 1000, which reforms its electric transmission planning and cost allocation requirements for public utility transmission providers. One substantial change from the order is the requirement for projects with regional cost allocation to have the federal right of first refusal (ROFR) removed. Incumbent public utility transmission providers no longer have a federal ROFR to build, own and operate large-scale transmission projects located within their service territory that have regional cost sharing. In the MISO footprint, the removal of ROFR is expected to create a competitive bidding process for projects subject to the ROFR removal and could lead to a potential decrease in the expected costs of impacted future transmission projects. Alliant Energy is currently unable to determine what impacts this order may have on its future electric transmission service charges.

FERC Audit of ITC - FERC audit staff conducted an audit of ITC’s compliance with certain of FERC’s regulations and conditions established in FERC’s approval of ITC’s acquisition of IPL’s electric transmission assets. In September 2011, FERC audit staff issued an audit report that identified certain findings and recommendations related to specific aspects of the accounting treatment for the acquisition. In January 2013, FERC approved the issuance of a $3 million refund to IPL through a true-up adjustment in 2014 under its formula rates from ITC. IPL currently expects to pass on the Iowa retail portion of this refund to its electric customers in Iowa in 2014 through the transmission cost rider.

Government Incentives for Wind Projects - Alliant Energy’s generation plans have included building wind projects to produce electricity to meet customer demand and renewable portfolio standards. In addition to producing electricity, these wind projects also generate material incentives depending on when they are placed in service. The ARRA enacted in 2009 provided incentives to owners of wind projects placed into service between January 1, 2009 and December 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 wind projects that began construction in 2009 and 2010. In 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 began construction in 2009, 2010 and 2011 and are placed into service by December 31, 2012.

Alliant Energy has four wind projects that currently qualify for one of the government incentives: (1) WPL’s Cedar Ridge wind project (68 MW capacity) that began generating electricity in late 2008; (2) IPL’s Whispering Willow - East wind project (200 MW capacity) that began generating electricity in late 2009; (3) WPL’s Bent Tree - Phase I wind project (200 MW capacity) that began generating electricity in late 2010; and (4) Resources’ Franklin County wind project (100 MW capacity) that began generating electricity in late 2012. Based on an evaluation of the most beneficial alternative for customers, Alliant Energy chose to recognize production tax credits for the three IPL and WPL wind projects. Alliant Energy chose to elect the government cash grant equal to 30% of the qualified cost basis of its Franklin County wind project. Refer to Note 4(d) of the “Notes to Consolidated Financial Statements” for discussion of possible federal spending cuts, or sequestration, which may cause Alliant Energy to reevaluate its options on government incentive elections for the Franklin County wind project.



Production Tax Credits - The amount of production tax credits earned 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 IPL's and WPL's wind projects are expected to be utilized in determining customers' rates. Production tax credits earned for these wind projects in 2010, 2011 and 2012, along with estimates of production tax credits currently expected to be earned in 2013, are as follows (in millions):

<table><tr><td></td><td>2010</td><td>2011</td><td>2012</td><td>Estimated 2013</td></tr><tr><td>Whispering Willow - East (IPL)</td><td>$8</td><td>$12</td><td>$13</td><td>$13 - $14</td></tr><tr><td>Bent Tree - Phase I (WPL)</td><td>1</td><td>9</td><td>9</td><td>13 - 14</td></tr><tr><td>Cedar Ridge (WPL)</td><td>3</td><td>5</td><td>4</td><td>3 - 4</td></tr><tr><td></td><td>$12</td><td>$26</td><td>$26</td><td>$29 - $32</td></tr></table>

Potential Tax Accounting Method Changes - Alliant Energy is currently assessing accounting method changes as a result of tangible property regulations released in 2011. In addition, Alliant Energy anticipates the IRS will publish guidance clarifying the tax treatment of costs incurred to retire and remove depreciable assets. The outcomes of the assessment and additional guidance could result in Alliant Energy filing additional tax accounting method changes with the IRS. If approved by the IRS, these tax accounting method changes could materially impact Alliant Energy’s future income tax benefits and expenses due to Iowa rate-making principles, which do not recognize deferred income tax benefits and expenses for certain property-related differences at IPL including costs incurred to retire and remove depreciable assets.

Retirement Plan Costs - Alliant Energy’s net periodic benefit costs related to its defined benefit pension and other postretirement benefits plans are currently expected to be lower in 2013 compared to 2012 by approximately $13 million, primarily due to higher than expected returns on plan assets resulting in increases in retirement plan assets during 2012 and settlement losses in 2012 related to payments made to retired executives of Alliant Energy. Approximately 30% to 40% of net periodic benefit costs are allocated to capital projects each year. As a result, the decrease in net periodic benefit costs is not expected to result in a comparable decrease in other operation and maintenance expenses. Refer to Note 6(a) of the “Notes to Consolidated Financial Statements” for additional details of Alliant Energy’s defined benefit pension and other postretirement benefits plans.

Performance-based Compensation Plans - Alliant Energy’s total compensation package includes a performance-based compensation program, which provides substantially all of Alliant Energy’s non-bargaining employees an opportunity to receive annual cash payments based on the achievement of specific short-term annual operational and financial performance measures. The operational performance measures for 2013 relate to diversity, safety, customer satisfaction, service reliability and the availability of certain generating facilities. The financial performance measures for 2013 relate to earnings per share from continuing operations and cash flows from operations generated by IPL, WPL and Corporate Services, as adjusted pursuant to the terms of the Omnibus Incentive Plan. In addition, the total compensation program for certain key employees includes long-term awards issued under equity-based compensation plans. Refer to Note 6(b) of the “Notes to Consolidated Financial Statements” for details of the equity-based compensation plans. Alliant Energy is currently unable to determine what impacts these performance-based compensation plans will have on its future financial condition or results of operations.



## MANAGEMENT'S ANNUAL REPORT ON INTERNAL CONTROL OVER FINANCIAL REPORTING

The management of Alliant Energy Corporation and subsidiaries (Alliant Energy) 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. Alliant Energy’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 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.

Alliant Energy’s management assessed the effectiveness of Alliant Energy’s internal control over financial reporting as of December 31, 2012 using the criteria set forth in Internal Control - Integrated Framework issued by the Committee of Sponsoring Organizations of the Treadway Commission. Based on this assessment, Alliant Energy’s management concluded that, as of December 31, 2012, Alliant Energy’s internal control over financial reporting was effective.

Deloitte & Touche LLP, Alliant Energy’s independent registered public accounting firm, has audited Alliant Energy’s internal control over financial reporting. That report is set forth immediately prior to the report of Deloitte & Touche LLP on the financial statements included herein.



Patricia L. Kampling
Chairman, President and Chief Executive Officer



Thomas L. Hanson
Senior Vice President and Chief Financial Officer



Robert J. Durian
Controller and Chief Accounting Officer

February 26, 2013



# REPORT OF INDEPENDENT REGISTERED PUBLIC ACCOUNTING FIRM

To the Board of Directors and Shareowners of Alliant Energy Corporation Madison, Wisconsin

We have audited the internal control over financial reporting of Alliant Energy Corporation and subsidiaries (the “Company”) as of December 31, 2012, based on the criteria established in Internal Control — Integrated Framework issued by the Committee of Sponsoring Organizations of the Treadway Commission. The Company’s management is responsible for maintaining effective internal control over financial reporting and for its assessment of the effectiveness of internal control over financial reporting, included in the accompanying Management’s Annual Report on Internal Control over Financial Reporting. Our responsibility is to express an opinion on the Company’s internal control over financial reporting based on our audit.

We conducted our audit 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 effective internal control over financial reporting was maintained in all material respects. Our audit included obtaining an understanding of internal control over financial reporting, assessing the risk that a material weakness exists, testing and evaluating the design and operating effectiveness of internal control based on the assessed risk, and performing such other procedures as we considered necessary in the circumstances. We believe that our audit provides a reasonable basis for our opinion.

A company’s internal control over financial reporting is a process designed by, or under the supervision of, the company’s principal executive and principal financial officers, or persons performing similar functions, and effected by the company’s board of directors, management, and other personnel to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles. A company’s internal control over financial reporting includes those policies and procedures that (1) pertain to the maintenance of records that, in reasonable detail, accurately and fairly reflect the transactions and dispositions of the assets of the company; (2) provide reasonable assurance that transactions are recorded as necessary to permit preparation of financial statements in accordance with generally accepted accounting principles, and that receipts and expenditures of the company are being made only in accordance with authorizations of management and directors of the company; and (3) provide reasonable assurance regarding prevention or timely detection of unauthorized acquisition, use, or disposition of the company’s assets that could have a material effect on the financial statements.

Because of the inherent limitations of internal control over financial reporting, including the possibility of collusion or improper management override of controls, material misstatements due to error or fraud 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.

In our opinion, the Company maintained, in all material respects, effective internal control over financial reporting as of December 31, 2012, based on the criteria established in Internal Control — Integrated Framework issued by the Committee of Sponsoring Organizations of the Treadway Commission.

We have also audited, in accordance with the standards of the Public Company Accounting Oversight Board (United States), the consolidated financial statements as of and for the year ended December 31, 2012 of the Company and our report dated February 26, 2013, expressed an unqualified opinion on those financial statements.



Milwaukee, Wisconsin
February 26, 2013



# REPORT OF INDEPENDENT REGISTERED PUBLIC ACCOUNTING FIRM

To the Board of Directors and Shareowners of Alliant Energy Corporation Madison, Wisconsin

We have audited the accompanying consolidated balance sheets of Alliant Energy Corporation and subsidiaries (the “Company”) as of December 31, 2012 and 2011, and the related consolidated statements of income, common equity, and cash flows for each of the three years in the period ended December 31, 2012. These financial statements are the responsibility of the Company’s management. Our responsibility is to express an opinion on these financial statements based on our audits.

We conducted our audits in accordance with 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. An audit includes examining, on a test basis, evidence supporting the amounts and disclosures in the financial statements. An audit also includes 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, 2012 and 2011, and the results of its operations and its cash flows for each of the three years in the period ended December 31, 2012, in conformity with accounting principles generally accepted in the United States of America.

We have also audited, in accordance with the standards of the Public Company Accounting Oversight Board (United States), the Company’s internal control over financial reporting as of December 31, 2012, based on the criteria established in Internal Control - Integrated Framework issued by the Committee of Sponsoring Organizations of the Treadway Commission and our report dated February 26, 2013 expressed an unqualified opinion on the Company’s internal control over financial reporting.

Deloitte & Touche LLP

Milwaukee, Wisconsin
February 26, 2013



## CONSOLIDATED FINANCIAL STATEMENTS
CONSOLIDATED STATEMENTS OF INCOME

<table><tr><td rowspan="3"></td><td colspan="3">Year Ended December 31,</td></tr><tr><td>2012</td><td>2011</td><td>2010</td></tr><tr><td colspan="3">(dollars in millions, except per share amounts)</td></tr><tr><td>Operating revenues:</td><td></td><td></td><td></td></tr><tr><td>Utility:</td><td></td><td></td><td></td></tr><tr><td>Electric</td><td>$2,589.3</td><td>$2,635.8</td><td>$2,674.2</td></tr><tr><td>Gas</td><td>396.3</td><td>476.7</td><td>480.6</td></tr><tr><td>Other</td><td>56.7</td><td>62.0</td><td>64.6</td></tr><tr><td>Non-regulated</td><td>52.2</td><td>46.9</td><td>42.7</td></tr><tr><td>Total operating revenues</td><td>3,094.5</td><td>3,221.4</td><td>3,262.1</td></tr><tr><td>Operating expenses:</td><td></td><td></td><td></td></tr><tr><td>Utility:</td><td></td><td></td><td></td></tr><tr><td>Electric production fuel and energy purchases</td><td>712.3</td><td>764.5</td><td>819.2</td></tr><tr><td>Purchased electric capacity</td><td>271.5</td><td>257.2</td><td>279.7</td></tr><tr><td>Electric transmission service</td><td>341.3</td><td>323.8</td><td>279.5</td></tr><tr><td>Cost of gas sold</td><td>217.2</td><td>295.2</td><td>304.0</td></tr><tr><td>Other operation and maintenance</td><td>590.0</td><td>630.2</td><td>617.2</td></tr><tr><td>Non-regulated operation and maintenance</td><td>11.9</td><td>18.0</td><td>19.4</td></tr><tr><td>Depreciation and amortization</td><td>332.4</td><td>321.0</td><td>287.3</td></tr><tr><td>Taxes other than income taxes</td><td>98.2</td><td>98.2</td><td>95.8</td></tr><tr><td>Total operating expenses</td><td>2,574.8</td><td>2,708.1</td><td>2,702.1</td></tr><tr><td>Operating income</td><td>519.7</td><td>513.3</td><td>560.0</td></tr><tr><td>Interest expense and other:</td><td></td><td></td><td></td></tr><tr><td>Interest expense</td><td>156.7</td><td>158.3</td><td>162.8</td></tr><tr><td>Equity income from unconsolidated investments, net</td><td>(41.3)</td><td>(39.3)</td><td>(38.1)</td></tr><tr><td>Allowance for funds used during construction</td><td>(21.9)</td><td>(12.0)</td><td>(18.0)</td></tr><tr><td>Interest income and other</td><td>(4.0)</td><td>(4.3)</td><td>(4.6)</td></tr><tr><td>Total interest expense and other</td><td>89.5</td><td>102.7</td><td>102.1</td></tr><tr><td>Income from continuing operations before income taxes</td><td>430.2</td><td>410.6</td><td>457.9</td></tr><tr><td>Income taxes</td><td>89.4</td><td>69.2</td><td>147.7</td></tr><tr><td>Income from continuing operations, net of tax</td><td>340.8</td><td>341.4</td><td>310.2</td></tr><tr><td>Loss from discontinued operations, net of tax</td><td>(5.1)</td><td>(19.5)</td><td>(3.9)</td></tr><tr><td>Net income</td><td>335.7</td><td>321.9</td><td>306.3</td></tr><tr><td>Preferred dividend requirements of subsidiaries</td><td>15.9</td><td>18.3</td><td>18.7</td></tr><tr><td>Net income attributable to Alliant Energy common shareowners</td><td>$319.8</td><td>$303.6</td><td>$287.6</td></tr><tr><td>Weighted average number of common shares outstanding (basic) (000s)</td><td>110,753</td><td>110,626</td><td>110,442</td></tr><tr><td>Weighted average number of common shares outstanding (diluted) (000s)</td><td>110,768</td><td>110,678</td><td>110,521</td></tr><tr><td>Earnings per weighted average common share attributable to Alliant Energy common shareowners (basic and diluted):</td><td></td><td></td><td></td></tr><tr><td>Income from continuing operations, net of tax</td><td>$2.93</td><td>$2.92</td><td>$2.64</td></tr><tr><td>Loss from discontinued operations, net of tax</td><td>(0.04)</td><td>(0.18)</td><td>(0.04)</td></tr><tr><td>Net income</td><td>$2.89</td><td>$2.74</td><td>$2.60</td></tr><tr><td>Amounts attributable to Alliant Energy common shareowners:</td><td></td><td></td><td></td></tr><tr><td>Income from continuing operations, net of tax</td><td>$324.9</td><td>$323.1</td><td>$291.5</td></tr><tr><td>Loss from discontinued operations, net of tax</td><td>(5.1)</td><td>(19.5)</td><td>(3.9)</td></tr><tr><td>Net income attributable to Alliant Energy common shareowners</td><td>$319.8</td><td>$303.6</td><td>$287.6</td></tr><tr><td>Dividends declared per common share</td><td>$1.80</td><td>$1.70</td><td>$1.58</td></tr></table>

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



## CONSOLIDATED BALANCE SHEETS

<table><tr><td rowspan="2"></td><td colspan="2">December 31,</td></tr><tr><td>2012</td><td>2011</td></tr><tr><td></td><td colspan="2">(in millions)</td></tr><tr><td>ASSETS</td><td></td><td></td></tr><tr><td>Property, plant and equipment:</td><td></td><td></td></tr><tr><td>Utility:</td><td></td><td></td></tr><tr><td>Electric plant in service</td><td>$9,070.7</td><td>$8,165.4</td></tr><tr><td>Gas plant in service</td><td>878.4</td><td>852.9</td></tr><tr><td>Other plant in service</td><td>506.2</td><td>510.1</td></tr><tr><td>Accumulated depreciation (accum. depr.)</td><td>(3,513.0)</td><td>(3,206.0)</td></tr><tr><td>Net plant</td><td>6,942.3</td><td>6,322.4</td></tr><tr><td>Construction work in progress:</td><td></td><td></td></tr><tr><td>Columbia Energy Center Units 1 and 2 emission controls (WPL)</td><td>130.4</td><td>9.0</td></tr><tr><td>Ottumwa Generating Station Unit 1 emission controls (IPL)</td><td>73.7</td><td>7.7</td></tr><tr><td>George Neal Generating Station Units 3 and 4 emission controls (IPL)</td><td>66.9</td><td>8.3</td></tr><tr><td>Other</td><td>147.8</td><td>232.2</td></tr><tr><td>Other, less accum. depr. of $5.6 and $5.3</td><td>21.2</td><td>34.9</td></tr><tr><td>Total utility</td><td>7,382.3</td><td>6,614.5</td></tr><tr><td>Non-regulated and other:</td><td></td><td></td></tr><tr><td>Non-regulated Generation, less accum. depr. of $31.0 and $26.4</td><td>258.6</td><td>270.6</td></tr><tr><td>Alliant Energy Corporate Services, Inc. and other, less accum. depr. of $200.2 and $177.4</td><td>197.1</td><td>148.2</td></tr><tr><td>Total non-regulated and other</td><td>455.7</td><td>418.8</td></tr><tr><td>Total property, plant and equipment</td><td>7,838.0</td><td>7,033.3</td></tr><tr><td>Current assets:</td><td></td><td></td></tr><tr><td>Cash and cash equivalents</td><td>21.2</td><td>11.4</td></tr><tr><td>Accounts receivable, less allowance for doubtful accounts:</td><td></td><td></td></tr><tr><td>Customer</td><td>94.9</td><td>88.1</td></tr><tr><td>Unbilled utility revenues</td><td>81.4</td><td>75.1</td></tr><tr><td>Other</td><td>209.4</td><td>114.9</td></tr><tr><td>Income tax refunds receivable</td><td>18.2</td><td>39.1</td></tr><tr><td>Production fuel, at weighted average cost</td><td>103.1</td><td>101.9</td></tr><tr><td>Materials and supplies, at weighted average cost</td><td>63.1</td><td>58.5</td></tr><tr><td>Gas stored underground, at weighted average cost</td><td>37.7</td><td>57.7</td></tr><tr><td>Regulatory assets</td><td>83.5</td><td>103.6</td></tr><tr><td>Prepaid gross receipts tax</td><td>40.4</td><td>40.2</td></tr><tr><td>Deferred income tax assets</td><td>170.2</td><td>22.8</td></tr><tr><td>Assets held for sale</td><td>27.9</td><td>119.6</td></tr><tr><td>Prepayments and other</td><td>43.3</td><td>37.7</td></tr><tr><td>Total current assets</td><td>994.3</td><td>870.6</td></tr><tr><td>Investments:</td><td></td><td></td></tr><tr><td>Investment in American Transmission Company LLC</td><td>257.0</td><td>238.8</td></tr><tr><td>Other</td><td>62.0</td><td>61.9</td></tr><tr><td>Total investments</td><td>319.0</td><td>300.7</td></tr><tr><td>Other assets:</td><td></td><td></td></tr><tr><td>Regulatory assets</td><td>1,528.9</td><td>1,391.4</td></tr><tr><td>Deferred charges and other</td><td>105.3</td><td>91.9</td></tr><tr><td>Total other assets</td><td>1,634.2</td><td>1,483.3</td></tr><tr><td>Total assets</td><td>$10,785.5</td><td>$9,687.9</td></tr></table>

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



## CONSOLIDATED BALANCE SHEETS (Continued)

<table><tr><td rowspan="3"></td><td colspan="2">December 31,</td></tr><tr><td>2012</td><td>2011</td></tr><tr><td colspan="2">(in millions, except per share and share amounts)</td></tr><tr><td colspan="3">CAPITALIZATION AND LIABILITIES</td></tr><tr><td colspan="3">Capitalization:</td></tr><tr><td colspan="3">Alliant Energy Corporation common equity:</td></tr><tr><td>Common stock - $0.01 par value - 240,000,000 shares authorized; 110,987,400 and 111,018,821 shares outstanding</td><td>$1.1</td><td>$1.1</td></tr><tr><td>Additional paid-in capital</td><td>1,511.2</td><td>1,510.8</td></tr><tr><td>Retained earnings</td><td>1,630.7</td><td>1,510.2</td></tr><tr><td>Accumulated other comprehensive loss</td><td>(0.8)</td><td>(0.8)</td></tr><tr><td>Shares in deferred compensation trust - 216,030 and 262,735 shares at a weighted average cost of $33.61 and $31.68 per share</td><td>(7.3)</td><td>(8.3)</td></tr><tr><td>Total Alliant Energy Corporation common equity</td><td>3,134.9</td><td>3,013.0</td></tr><tr><td>Cumulative preferred stock of Interstate Power and Light Company</td><td>145.1</td><td>145.1</td></tr><tr><td>Noncontrolling interest</td><td>1.8</td><td>1.8</td></tr><tr><td>Total equity</td><td>3,281.8</td><td>3,159.9</td></tr><tr><td>Cumulative preferred stock of Wisconsin Power and Light Company</td><td>60.0</td><td>60.0</td></tr><tr><td>Long-term debt, net (excluding current portion)</td><td>3,136.6</td><td>2,703.1</td></tr><tr><td>Total capitalization</td><td>6,478.4</td><td>5,923.0</td></tr><tr><td colspan="3">Current liabilities:</td></tr><tr><td>Current maturities of long-term debt</td><td>1.5</td><td>1.4</td></tr><tr><td>Commercial paper</td><td>217.5</td><td>102.8</td></tr><tr><td>Accounts payable</td><td>339.3</td><td>267.8</td></tr><tr><td>Regulatory liabilities</td><td>189.7</td><td>164.7</td></tr><tr><td>Accrued taxes</td><td>48.0</td><td>46.9</td></tr><tr><td>Accrued interest</td><td>48.0</td><td>46.6</td></tr><tr><td>Derivative liabilities</td><td>31.1</td><td>55.9</td></tr><tr><td>Liabilities held for sale</td><td>31.4</td><td>62.1</td></tr><tr><td>Other</td><td>113.5</td><td>107.0</td></tr><tr><td>Total current liabilities</td><td>1,020.0</td><td>855.2</td></tr><tr><td colspan="3">Other long-term liabilities and deferred credits:</td></tr><tr><td>Deferred income tax liabilities</td><td>1,934.2</td><td>1,592.2</td></tr><tr><td>Regulatory liabilities</td><td>726.4</td><td>745.4</td></tr><tr><td>Pension and other benefit obligations</td><td>364.0</td><td>312.7</td></tr><tr><td>Other</td><td>262.5</td><td>259.4</td></tr><tr><td>Total long-term liabilities and deferred credits</td><td>3,287.1</td><td>2,909.7</td></tr><tr><td colspan="3">Commitments and contingencies (Note 13)</td></tr><tr><td>Total capitalization and liabilities</td><td>$10,785.5</td><td>$9,687.9</td></tr></table>

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



## CONSOLIDATED STATEMENTS OF CASH FLOWS

<table><tr><td rowspan="3"></td><td colspan="3">Year Ended December 31,</td></tr><tr><td>2012</td><td>2011</td><td>2010</td></tr><tr><td colspan="3">(in millions)</td></tr><tr><td>Cash flows from operating activities:</td><td></td><td></td><td></td></tr><tr><td>Net income</td><td>$335.7</td><td>$321.9</td><td>$306.3</td></tr><tr><td>Adjustments to reconcile net income to net cash flows from operating activities:</td><td></td><td></td><td></td></tr><tr><td>Depreciation and amortization</td><td>332.9</td><td>323.8</td><td>292.3</td></tr><tr><td>Other amortizations</td><td>55.0</td><td>56.3</td><td>51.8</td></tr><tr><td>Deferred tax expense and investment tax credits</td><td>143.3</td><td>10.2</td><td>216.6</td></tr><tr><td>Equity income from unconsolidated investments, net</td><td>(41.3)</td><td>(39.3)</td><td>(38.1)</td></tr><tr><td>Distributions from equity method investments</td><td>34.2</td><td>32.3</td><td>32.2</td></tr><tr><td>Equity component of allowance for funds used during construction</td><td>(14.1)</td><td>(7.6)</td><td>(11.2)</td></tr><tr><td>Non-cash valuation and regulatory-related charges</td><td>3.3</td><td>25.5</td><td>38.0</td></tr><tr><td>Other</td><td>(2.6)</td><td>(5.2)</td><td>(4.7)</td></tr><tr><td>Other changes in assets and liabilities:</td><td></td><td></td><td></td></tr><tr><td>Accounts receivable</td><td>61.3</td><td>(54.3)</td><td>16.3</td></tr><tr><td>Sales of accounts receivable</td><td>(10.0)</td><td>75.0</td><td>65.0</td></tr><tr><td>Income tax refunds receivable</td><td>20.9</td><td>0.3</td><td>130.4</td></tr><tr><td>Regulatory assets</td><td>(178.1)</td><td>(413.1)</td><td>(20.8)</td></tr><tr><td>Regulatory liabilities</td><td>16.4</td><td>168.3</td><td>8.4</td></tr><tr><td>Derivative liabilities</td><td>(37.6)</td><td>10.7</td><td>(52.0)</td></tr><tr><td>Deferred income tax liabilities</td><td>87.6</td><td>148.5</td><td>28.9</td></tr><tr><td>Non-current taxes payable</td><td>(2.9)</td><td>(5.1)</td><td>(66.6)</td></tr><tr><td>Pension and other benefit obligations</td><td>51.3</td><td>8.9</td><td>(20.1)</td></tr><tr><td>Other</td><td>(14.2)</td><td>45.6</td><td>12.2</td></tr><tr><td>Net cash flows from operating activities</td><td>841.1</td><td>702.7</td><td>984.9</td></tr><tr><td>Cash flows used for investing activities:</td><td></td><td></td><td></td></tr><tr><td>Construction and acquisition expenditures:</td><td></td><td></td><td></td></tr><tr><td>Utility business - Riverside Energy Center</td><td>(403.5)</td><td>—</td><td>—</td></tr><tr><td>Utility business - other</td><td>(622.0)</td><td>(608.1)</td><td>(833.3)</td></tr><tr><td>Alliant Energy Corporate Services, Inc. and non-regulated businesses</td><td>(132.6)</td><td>(65.3)</td><td>(33.6)</td></tr><tr><td>Advances for customer energy efficiency projects</td><td>(0.4)</td><td>(5.1)</td><td>(17.1)</td></tr><tr><td>Collections of advances for customer energy efficiency projects</td><td>22.9</td><td>31.0</td><td>34.2</td></tr><tr><td>Other</td><td>(19.9)</td><td>(4.6)</td><td>(16.7)</td></tr><tr><td>Net cash flows used for investing activities</td><td>(1,155.5)</td><td>(652.1)</td><td>(866.5)</td></tr><tr><td>Cash flows from (used for) financing activities:</td><td></td><td></td><td></td></tr><tr><td>Common stock dividends</td><td>(199.3)</td><td>(188.1)</td><td>(174.6)</td></tr><tr><td>Preferred dividends paid by subsidiaries</td><td>(15.9)</td><td>(16.8)</td><td>(18.7)</td></tr><tr><td>Payments to redeem cumulative preferred stock of IPL</td><td>—</td><td>(40.0)</td><td>—</td></tr><tr><td>Proceeds from issuance of long-term debt</td><td>385.0</td><td>0.4</td><td>500.0</td></tr><tr><td>Payments to retire long-term debt</td><td>(1.4)</td><td>(1.3)</td><td>(307.8)</td></tr><tr><td>Net change in commercial paper</td><td>164.7</td><td>55.4</td><td>(142.6)</td></tr><tr><td>Other</td><td>(8.9)</td><td>(8.1)</td><td>9.3</td></tr><tr><td>Net cash flows from (used for) financing activities</td><td>324.2</td><td>(198.5)</td><td>(134.4)</td></tr><tr><td>Net increase (decrease) in cash and cash equivalents</td><td>9.8</td><td>(147.9)</td><td>(16.0)</td></tr><tr><td>Cash and cash equivalents at beginning of period</td><td>11.4</td><td>159.3</td><td>175.3</td></tr><tr><td>Cash and cash equivalents at end of period</td><td>$21.2</td><td>$11.4</td><td>$159.3</td></tr><tr><td>Supplemental cash flows information:</td><td></td><td></td><td></td></tr><tr><td>Cash paid (refunded) during the period for:</td><td></td><td></td><td></td></tr><tr><td>Interest, net of capitalized interest</td><td>$155.2</td><td>$157.6</td><td>$165.5</td></tr><tr><td>Income taxes, net of refunds</td><td>($20.3)</td><td>($10.8)</td><td>($116.2)</td></tr><tr><td>Significant non-cash investing and financing activities:</td><td></td><td></td><td></td></tr><tr><td>Accrued capital expenditures</td><td>$105.3</td><td>$49.7</td><td>$75.0</td></tr></table>

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



## CONSOLIDATED STATEMENTS OF COMMON EQUITY

<table><tr><td></td><td>Common Stock</td><td>Additional Paid-In Capital</td><td>Retained Earnings</td><td>Accumulated Other Comprehensive Income (Loss)</td><td>Shares in Deferred Compensation Trust</td><td>Total Alliant Energy Common Equity</td></tr><tr><td></td><td></td><td></td><td></td><td>(in millions)</td><td></td><td></td></tr><tr><td>2010:</td><td></td><td></td><td></td><td></td><td></td><td></td></tr><tr><td>Beginning balance</td><td>$1.1</td><td>$1,499.1</td><td>$1,281.7</td><td>($1.4)</td><td>($7.9)</td><td>$2,772.6</td></tr><tr><td>Net income attributable to Alliant Energy common shareowners</td><td></td><td></td><td>287.6</td><td></td><td></td><td>287.6</td></tr><tr><td>Common stock dividends ($1.58 per share)</td><td></td><td></td><td>(174.6)</td><td></td><td></td><td>(174.6)</td></tr><tr><td>Common stock issued, repurchased and other, net</td><td></td><td>7.7</td><td></td><td></td><td>0.3</td><td>8.0</td></tr><tr><td>Ending balance</td><td>1.1</td><td>1,506.8</td><td>1,394.7</td><td>(1.4)</td><td>(7.6)</td><td>2,893.6</td></tr><tr><td>2011:</td><td></td><td></td><td></td><td></td><td></td><td></td></tr><tr><td>Net income attributable to Alliant Energy common shareowners</td><td></td><td></td><td>303.6</td><td></td><td></td><td>303.6</td></tr><tr><td>Common stock dividends ($1.70 per share)</td><td></td><td></td><td>(188.1)</td><td></td><td></td><td>(188.1)</td></tr><tr><td>Common stock issued, repurchased and other, net</td><td></td><td>4.0</td><td></td><td></td><td>(0.7)</td><td>3.3</td></tr><tr><td>Other comprehensive income, net of tax</td><td></td><td></td><td></td><td>0.6</td><td></td><td>0.6</td></tr><tr><td>Ending balance</td><td>1.1</td><td>1,510.8</td><td>1,510.2</td><td>(0.8)</td><td>(8.3)</td><td>3,013.0</td></tr><tr><td>2012:</td><td></td><td></td><td></td><td></td><td></td><td></td></tr><tr><td>Net income attributable to Alliant Energy common shareowners</td><td></td><td></td><td>319.8</td><td></td><td></td><td>319.8</td></tr><tr><td>Common stock dividends ($1.80 per share)</td><td></td><td></td><td>(199.3)</td><td></td><td></td><td>(199.3)</td></tr><tr><td>Common stock issued, repurchased and other, net</td><td></td><td>0.4</td><td></td><td></td><td>1.0</td><td>1.4</td></tr><tr><td>Ending balance</td><td>$1.1</td><td>$1,511.2</td><td>$1,630.7</td><td>($0.8)</td><td>($7.3)</td><td>$3,134.9</td></tr></table>

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 - Alliant Energy Corporation’s (Alliant Energy’s) consolidated financial statements include the accounts of Alliant Energy and its consolidated subsidiaries. Alliant Energy is an investor-owned public utility holding company, whose primary subsidiaries are Interstate Power and Light Company (IPL), Wisconsin Power and Light Company (WPL), Alliant Energy Resources, LLC (Resources) and Alliant Energy Corporate Services, Inc. (Corporate Services).

IPL is a direct subsidiary of Alliant Energy and is engaged principally in the generation and distribution of electricity and the distribution and transportation of natural gas. IPL is also engaged in the generation and distribution of steam for two customers in Cedar Rapids, Iowa. IPL’s service territories are located in Iowa and southern Minnesota.

WPL is a direct subsidiary of Alliant Energy and is engaged principally in the generation and distribution of electricity and the distribution and transportation of natural gas. WPL’s service territories are located in southern and central Wisconsin.

Resources is comprised of Transportation, Non-regulated Generation and other non-regulated investments. Transportation includes a short-line railway that provides freight service between Cedar Rapids, Iowa and Iowa City, Iowa; barge terminal and hauling services on the Mississippi River; and other transfer and storage services. Non-regulated Generation owns the 300 megawatt (MW), simple-cycle, natural gas-fired Sheboygan Falls Energy Facility near Sheboygan Falls, Wisconsin, which is leased to WPL for an initial period of 20 years ending in 2025. In addition, Non-regulated Generation owns the non-regulated 100 MW Franklin County wind project located in Franklin County, Iowa, which was placed in service in the fourth quarter of 2012. Refer to Note 17 for discussion of the Industrial Energy Applications, Inc. (IEA) business and RMT, Inc.'s (RMT's) environmental consulting and engineering services business unit, which were both sold in 2011, and the remaining portion of Alliant Energy's RMT business, which was sold in January 2013.

Corporate Services is the subsidiary formed to provide administrative services to Alliant Energy and its subsidiaries.

Basis of Presentation - The consolidated financial statements reflect investments in controlled subsidiaries on a consolidated basis and Alliant Energy’s proportionate shares of jointly owned utility facilities. Unconsolidated investments, which Alliant Energy does not control, but does have the ability to exercise significant influence over operating and financial policies, 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. Alliant Energy did not reflect any variable interest entities (VIEs) on a consolidated basis in the consolidated financial statements. Refer to Notes 1(q) and 10(a) for further discussion of VIEs and equity method investments, respectively.

All intercompany balances and transactions, other than certain transactions affecting the rate-making process at IPL and WPL, have been eliminated from the consolidated financial statements. Such transactions not eliminated include costs that are recoverable from customers through rate-making processes. 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. Certain prior period amounts in the Consolidated Financial Statements and Notes to Consolidated Financial Statements have been reclassified to conform to the current period presentation for comparative purposes. Unless otherwise noted, the notes herein have been revised to exclude discontinued operations and assets and liabilities held for sale for all periods presented.

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 Regulatory Liabilities - Alliant Energy, IPL and WPL are subject to regulation by FERC and various state regulatory commissions. As a result, Alliant Energy, IPL and WPL are subject to GAAP provisions for regulated operations, which provide that rate-regulated public utilities record certain costs and credits allowed in the rate-making process in different periods than for non-regulated entities. 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. Amounts deferred as regulatory assets or accrued as regulatory liabilities are generally recognized in the Consolidated Statements of Income at the time they are reflected in rates.



Regulatory Assets - At December 31, regulatory assets were comprised of the following items (in millions):

<table><tr><td rowspan="2"></td><td colspan="2">Alliant Energy</td><td colspan="2">IPL</td><td colspan="2">WPL</td></tr><tr><td>2012</td><td>2011</td><td>2012</td><td>2011</td><td>2012</td><td>2011</td></tr><tr><td>Tax-related</td><td>$770.7</td><td>$634.7</td><td>$746.2</td><td>$614.6</td><td>$24.5</td><td>$20.1</td></tr><tr><td>Pension and other postretirement benefits costs</td><td>549.2</td><td>514.1</td><td>279.3</td><td>264.9</td><td>269.9</td><td>249.2</td></tr><tr><td>Asset retirement obligations (AROs)</td><td>62.4</td><td>65.9</td><td>38.6</td><td>48.7</td><td>23.8</td><td>17.2</td></tr><tr><td>Derivatives</td><td>40.2</td><td>77.7</td><td>16.3</td><td>33.5</td><td>23.9</td><td>44.2</td></tr><tr><td>Environmental-related costs</td><td>34.9</td><td>38.9</td><td>30.3</td><td>32.2</td><td>4.6</td><td>6.7</td></tr><tr><td>Emission allowances</td><td>30.0</td><td>30.0</td><td>30.0</td><td>30.0</td><td>—</td><td>—</td></tr><tr><td>Debt redemption costs</td><td>19.8</td><td>21.8</td><td>13.6</td><td>15.1</td><td>6.2</td><td>6.7</td></tr><tr><td>Proposed clean air compliance projects costs</td><td>16.7</td><td>14.9</td><td>7.8</td><td>6.9</td><td>8.9</td><td>8.0</td></tr><tr><td>IPL’s electric transmission service costs</td><td>16.6</td><td>24.9</td><td>16.6</td><td>24.9</td><td>—</td><td>—</td></tr><tr><td>Proposed coal-fired base-load projects costs</td><td>14.2</td><td>21.5</td><td>10.1</td><td>15.3</td><td>4.1</td><td>6.2</td></tr><tr><td>Other</td><td>57.7</td><td>50.6</td><td>29.1</td><td>31.2</td><td>28.6</td><td>19.4</td></tr><tr><td></td><td>$1,612.4</td><td>$1,495.0</td><td>$1,217.9</td><td>$1,117.3</td><td>$394.5</td><td>$377.7</td></tr></table>

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 respective carrying costs of these assets are not expected to be recovered from customers in future rates. At December 31, 2012, IPL and WPL had $68 million and $13 million, respectively, of regulatory assets representing past expenditures that were not earning a return. IPL’s regulatory assets that were not earning a return consisted primarily of electric transmission service costs, costs for proposed coal-fired base-load and clean air compliance projects, and debt redemption costs. WPL’s regulatory assets that were not earning a return consisted primarily of amounts related to wholesale customer rate recovery. The 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.

Tax-related - IPL and WPL record regulatory assets for certain temporary differences (primarily related to utility property, plant and equipment at IPL) that result in a decrease in current rates charged to customers and an increase in future rates charged to customers based on the timing of income tax expense that is used to determine such rates. These temporary differences include the impact of Iowa accelerated tax depreciation, which contributes to lower current income tax expense during the first part of an asset’s useful life and higher current tax expense during the last part of an asset’s useful life. These regulatory assets will be recovered from customers in the future when these temporary differences reverse resulting in additional current income tax expense used to determine customers’ rates. During 2012, Alliant Energy’s and IPL’s “Tax-related” regulatory assets in the above table increased primarily due to changes in the estimated amount of qualifying repair expenditures and allocation of mixed service costs at IPL.

Pension and other postretirement benefits costs - The Iowa Utilities Board (IUB) and the Public Service Commission of Wisconsin (PSCW) have authorized IPL and WPL to record the retail portion of their respective previously unrecognized net actuarial gains and losses, and prior service costs and credits, as regulatory assets in lieu of accumulated other comprehensive loss (AOCL) on the Consolidated Balance Sheets, as these amounts are expected to be recovered in future rates. IPL and WPL also recognize the wholesale portion of their previously unrecognized net actuarial gains and losses, and prior service costs and credits, 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. 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.

Pension and other postretirement benefits costs are included within the recoverable cost of service component of rates charged to IPL’s and 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 IPL and WPL operate. The methods for IPL’s and WPL’s primary regulatory jurisdictions are described below. The IUB authorized IPL in its most recent Iowa retail electric rate case order to recover from its retail electric customers in Iowa an allocated portion of annual costs equal to a two-year simple average of actual costs incurred during its test year (2009) and an estimate of costs for its forward-looking post-test year (2010). The PSCW authorized WPL to recover from its electric and gas retail customers in base rates an estimated allocated portion of annual costs equal to the costs expected to be incurred during the 2013 and 2014 rate freeze period. 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 pension and other postretirement benefits costs.

AROs - Alliant Energy 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. The decrease in IPL's regulatory assets related to AROs is primarily due to revisions in estimated cash flows based on revised remediation timing and cost information for asbestos remediation at Sixth Street. The increase in WPL's regulatory assets related to AROs is primarily due to revisions in estimated cash flows based on revised remediation timing and cost information for remediation of the coal yard and ash pond at Rock River. Refer to Note 18 for additional details of AROs.

Derivatives - In accordance with IPL's and WPL's fuel and natural gas recovery mechanisms, prudently incurred costs from derivative instruments are recovered from customers in the future after any losses are realized and gains from derivative instruments are refunded to customers in the future after any gains are realized. Based on these recovery mechanisms, the changes in the fair value of derivative liabilities/assets resulted in comparable changes to regulatory assets/liabilities on the Consolidated Balance Sheets. Refer to Note 12 for additional details of derivative assets and derivative liabilities.

Environmental-related costs - The IUB has permitted IPL to recover prudently incurred costs by allowing a representative level of manufactured gas plant (MGP) costs in the recoverable cost of service component of rates, as determined in its most recent retail gas rate case. Under the current rate-making treatment approved by the PSCW, the MGP expenditures of WPL are deferred and collected from retail gas customers over a five-year period after new rates are implemented. The Minnesota Public Utilities Commission (MPUC) allows the deferral of MGP-related costs applicable to IPL's Minnesota sites and IPL has received approval to recover such costs in retail gas rates in Minnesota in its most recent retail gas rate case. Regulatory assets recorded by IPL and WPL reflect the probable future rate recovery of MGP expenditures. Refer to Note 13(e) for additional details of environmental-related MGP costs.

Emission allowances - IPL entered into forward contracts in 2007 to purchase sulfur dioxide (SO \( _{2} \) ) emission allowances with vintage years of 2014 through 2017 from various counterparties for 34 million to meet future Clean Air Interstate Rule (CAIR) emission reduction standards. Any SO \( _{2} \)  emission allowances acquired under these forward contracts may be used to meet requirements under the existing Acid Rain program regulations or the more stringent CAIR emission reduction standards but are not eligible to be used for compliance requirements under the Cross-State Air Pollution Rule (CSAPR). In 2011, the U.S. Environmental Protection Agency (EPA) issued CSAPR to replace CAIR with an anticipated effective date in 2012. As a result of the issuance of CSAPR, Alliant Energy and IPL concluded in 2011 that the allowances to be acquired under these forward contracts would not be needed by IPL to comply with expected environmental regulations in the future. The value of these allowances was nominal, which was significantly below the 34 million contract price for these allowances. As a result, Alliant Energy recognized charges of 34 million for these forward contracts in 2011 with an offsetting obligation recorded in other long-term liabilities and deferred credits. Alliant Energy concluded that 30 million of the charges are probable of recovery from IPL's customers and therefore were recorded to regulatory assets in 2011. The remaining 4 million of charges were determined not to be probable of recovery from IPL's customers resulting in 2 million of charges related to electric customers recorded to "Electric production fuel and energy purchases" and 2 million of charges related to steam customers recorded to "Utility - Other operation and maintenance" in the Consolidated Statement of Income in 2011. In August 2012, the U.S. Court of Appeals for the D.C. Circuit (D.C. Circuit Court) vacated and remanded CSAPR for further revision to the EPA. The D.C. Circuit Court order also requires the EPA to continue administering CAIR pending the promulgation of a valid replacement for CSAPR. Despite CSAPR being vacated, the current value of these allowances continues to be nominal and significantly below the 34 million contract price for these allowances. Alliant Energy currently believes that CAIR will be replaced in the future, either by a modified CSAPR or another rule that addresses the interstate transport of air pollutants.

Debt redemption costs - For debt retired early with no subsequent re-issuance, IPL and WPL defer 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 by IPL and WPL are deferred as regulatory assets and amortized over the life of the new debt issued.

Proposed clean air compliance plan (CACP) projects costs - CACP projects require material expenditures for activities related to determining the feasibility of environmental compliance projects under consideration. These expenditures are



commonly referred to as preliminary survey and investigation charges. The wholesale portion of these amounts is recorded as regulatory assets on the Consolidated Balance Sheets in accordance with FERC regulations. In Iowa, no specific retail authorization is required before charging these costs to regulatory asset accounts. 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 CACP projects, WPL requested and received deferral accounting approval to record the retail portion of these costs as regulatory assets on the Consolidated Balance Sheets.

For IPL, 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). Upon management’s decision to proceed with a project, including receipt of certain regulatory approvals, all such amounts included as preliminary survey and investigation charges are transferred to construction work in progress (CWIP) and begin to accrue AFUDC.

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 construction 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 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.

Alliant Energy anticipates the remaining costs for proposed CACP projects are probable of recovery from future rates charged to customers. The recovery period for these remaining costs will generally be determined by regulators in future rate proceedings.

IPL’s electric transmission service costs - In 2010, IPL incurred electric transmission service costs billed by ITC Midwest LLC (ITC) under the Attachment “O” rate for ITC’s under-recovered 2008 costs. In 2010, the IUB issued an order authorizing IPL to defer the Iowa retail portion of these under-recovered costs and amortize the deferred costs over a 5-year period ending December 2014. In accordance with this order, IPL is amortizing $8 million of this regulatory asset annually, with an equal and offsetting amount of amortization of IPL’s regulatory liability related to its electric transmission assets sale. The IUB determined that IPL should not include the unamortized balance of these deferred costs in electric rate base during the 5-year recovery period. The IUB also authorized IPL to use up to $46 million of regulatory liabilities from its 2007 electric transmission assets sale to offset these deferred costs as they are amortized. In 2010, $41 million (portion allocated to Iowa retail customers) of the Attachment “O” costs were deferred by IPL and recognized as a regulatory asset.

## Proposed coal-fired base-load projects costs -

IPL’s coal-fired base-load project - In 2009, IPL announced a decision to cancel the construction of the proposed 630 MW coal-fired electric generating facility in Marshalltown, Iowa referred to as Sutherland #4. In 2010, IPL received approval from the IUB to recover $26 million of the costs incurred for Sutherland #4 from its retail customers in Iowa by amortizing the costs over a 5-year period ending August 2014. In accordance with this approval, IPL is amortizing $5 million of this regulatory asset annually, with an equal and offsetting amount of amortization of IPL’s regulatory liability resulting from the sale of the Duane Arnold Energy Center (DAEC). The IUB determined that IPL should not include the unamortized balance of these Sutherland #4 costs in electric rate base during the 5-year recovery period.

In accordance with the MPUC’s November 2011 order related to IPL’s 2009 test year Minnesota retail electric rate case, IPL was authorized to recover $2 million of previously incurred plant cancellation costs for Sutherland #4 over a 25-year period ending in 2037. As a result, Alliant Energy recorded a $2 million increase to regulatory assets, and a $2 million credit to “Utility - Other operation and maintenance” in the Consolidated Statement of Income in 2011.

WPL’s coal-fired base-load project - In 2008, the PSCW issued an order denying WPL’s application to construct a 300 MW coal-fired electric generating facility in Cassville, Wisconsin referred to as Nelson Dewey #3. In 2009, WPL received approval from the PSCW to recover $11 million of project costs from its retail customers over a 5-year period ending December 2014. In accordance with this approval, WPL is amortizing $2 million of this regulatory asset annually.

Other - Alliant Energy assesses whether IPL’s and WPL’s regulatory assets are probable of future recovery by considering factors such as applicable regulations, recent orders by the applicable regulatory agencies, historical treatment of similar costs by the applicable regulatory agencies and regulatory environment changes. Based on these assessments, Alliant Energy believes the regulatory assets recognized as of December 31, 2012 in the above table are probable of future recovery.



However, no assurance can be made that IPL and 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. Based on assessments completed in 2011, Alliant Energy recognized impairment charges of $9 million for regulatory assets that were no longer probable of future recovery. The regulatory asset impairment charges were recorded as reductions in regulatory assets, and charges to “Utility - Other operation and maintenance” in the Consolidated Statement of Income in 2011.

Based on the PSCW’s July 2012 order related to WPL’s 2013/2014 test period Wisconsin retail electric and gas rate case, WPL was authorized to recover previously incurred costs associated with the acquisition of a 25% ownership interest in Edgewater Unit 5 and proposed CACP projects. As a result, Alliant Energy recorded a $5 million increase to “Regulatory assets” on the Consolidated Balance Sheet and a $5 million credit to “Utility - Other operation and maintenance” in the Consolidated Statement of Income in 2012.

Based on the IUB’s February 2011 order related to IPL’s 2009 test year Iowa retail electric rate case, IPL was authorized to recover from its retail electric customers in Iowa operation and maintenance expenses incurred in 2009 for restoration activities from severe flooding in IPL’s service territory. As a result, Alliant Energy recorded a $7 million regulatory asset in 2010 with an offsetting pre-tax regulatory-related credit of $7 million in “Utility - Other operation and maintenance” in the Consolidated Statement of Income in 2010. In addition, the IUB’s February 2011 order also authorized IPL to recover from its retail electric customers in Iowa a portion of the remaining net book value of Sixth Street and previously impaired CWIP assets related to Sixth Street, which was shut down as a result of the flooding. As a result, Alliant Energy recorded a $16 million regulatory asset in 2010 with an offsetting increase of $14 million in utility accumulated depreciation and a credit of $2 million in “Utility - Other operation and maintenance” in the Consolidated Statement of Income in 2010.

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

<table><tr><td rowspan="2"></td><td colspan="2">Alliant Energy</td><td colspan="2">IPL</td><td colspan="2">WPL</td></tr><tr><td>2012</td><td>2011</td><td>2012</td><td>2011</td><td>2012</td><td>2011</td></tr><tr><td>Cost of removal obligations</td><td>$408.7</td><td>$404.9</td><td>$268.0</td><td>$261.9</td><td>$140.7</td><td>$143.0</td></tr><tr><td>IPL’s tax benefit riders</td><td>355.8</td><td>349.6</td><td>355.8</td><td>349.6</td><td>—</td><td>—</td></tr><tr><td>Energy conservation cost recovery</td><td>55.1</td><td>29.6</td><td>10.0</td><td>4.7</td><td>45.1</td><td>24.9</td></tr><tr><td>IPL’s electric transmission assets sale</td><td>32.5</td><td>45.1</td><td>32.5</td><td>45.1</td><td>—</td><td>—</td></tr><tr><td>Commodity cost recovery</td><td>17.7</td><td>23.8</td><td>5.2</td><td>23.2</td><td>12.5</td><td>0.6</td></tr><tr><td>IPL’s DAEC sale</td><td>9.5</td><td>14.6</td><td>9.5</td><td>14.6</td><td>—</td><td>—</td></tr><tr><td>Other</td><td>36.8</td><td>42.5</td><td>20.4</td><td>22.2</td><td>16.4</td><td>20.3</td></tr><tr><td></td><td>$916.1</td><td>$910.1</td><td>$701.4</td><td>$721.3</td><td>$214.7</td><td>$188.8</td></tr></table>

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 IPL’s and WPL’s respective rate proceedings.

Cost of removal obligations - Alliant Energy collects in rates future removal costs for many assets that do not have associated legal AROs. Alliant Energy records a regulatory liability for the estimated amounts it has collected in rates for these future removal costs less amounts spent on removal activities.

IPL’s tax benefit riders - Alliant Energy’s and IPL’s “IPL’s tax benefit riders” regulatory liabilities in the above table increased primarily due to changes in the estimated amounts of qualifying repair expenditures and allocation of mixed service costs at IPL. These items were offset by regulatory liabilities used to credit IPL’s Iowa retail electric customers’ bills in 2012. In January 2011, the IUB approved IPL’s proposed electric tax benefit rider, which utilizes tax-related regulatory liabilities related to projected tax benefits from tax accounting methodologies and tax elections available under the Internal Revenue Code to credit IPL’s retail electric customer bills in Iowa during 2011, 2012 and 2013. Alliant Energy recognizes an offsetting reduction to income tax expense for the after-tax amounts credited to IPL’s retail electric customers’ bills in Iowa, resulting in no impact to Alliant Energy’s net income from the electric tax benefit rider. In 2012 and 2011, Alliant Energy and IPL utilized $83 million and $61 million, respectively, of electric tax benefit rider-related regulatory liabilities accumulated in prior years to credit IPL’s Iowa retail electric customers’ bills. In 2012 and 2011, the $83 million and $61 million reductions to “Electric operating revenues” resulted in $35 million and $25 million of credits to “Income taxes” as a result of the decrease in taxable income in the Consolidated Statements of Income in 2012 and 2011, respectively. In 2012 and 2011, additional reductions to “Income taxes” of $48 million and $36 million, respectively, were also recognized in the Consolidated Statements of Income representing the tax benefits realized related to the electric tax benefit rider.



In December 2012, the IUB issued an order authorizing $56 million of regulatory liabilities from tax benefits to be credited to IPL’s retail electric customers’ bills in Iowa during 2013 through the electric tax benefit rider. In November 2012, the IUB issued an order authorizing $12 million of regulatory liabilities from tax benefits to be credited to IPL’s retail gas customers’ bills in Iowa during 2013 through a gas tax benefit rider. In February 2013, the IUB issued an order authorizing IPL to utilize $24 million of regulatory liabilities during 2013 from tax benefits for the electric tax benefit rider to recognize the revenue requirement impact of the changes in tax accounting methods. Refer to Note 2 for discussion of the gas tax benefit rider for IPL’s Iowa retail gas customers and Note 5 for additional details regarding the tax benefit rider for IPL’s Iowa retail electric customers.

Energy conservation cost recovery - WPL collects revenues from its customers to offset certain expenditures incurred by WPL for conservation programs, including state mandated programs and WPL’s Shared Savings program. Differences between forecasted costs used to set rates and actual costs for these programs are deferred as a regulatory asset or regulatory liability. In 2012, WPL’s forecasted costs used to set current rates exceeded actual costs for these programs, resulting in the increase to Alliant Energy’s and WPL’s “Energy conservation cost recovery” regulatory liability.

IPL electric transmission assets sale - In 2007, IPL completed the sale of its electric transmission assets to ITC and recognized a gain based on the terms of the agreement. Upon closing of the sale, IPL established a regulatory liability of $89 million pursuant to conditions established by the IUB when it allowed the transaction to proceed. The regulatory liability represented the present value of IPL’s obligation to refund to its customers payments beginning in the year IPL’s customers experience an increase in rates related to the transmission charges assessed by ITC. The regulatory liability accrues interest at the monthly average U.S. Treasury rate for three-year maturities.

Iowa retail portion - In 2009, the IUB issued an order authorizing IPL to use a portion of this regulatory liability to reduce Iowa retail electric customers' rates by $12 million for the period from July 2009 through February 2010 with billing credits included in the monthly energy adjustment clause. In 2010, the IUB issued an order authorizing IPL to use up to $46 million of this regulatory liability to offset electric transmission service costs expected to be billed to IPL by ITC in 2010 related to ITC's 2008 transmission revenue adjustment. IPL expects to utilize $41 million of this regulatory liability over a 5-year period ending December 2014 to offset the Iowa retail portion of transmission costs billed to IPL by ITC in 2010 related to ITC's 2008 transmission revenue adjustment. As a result, IPL is amortizing $8 million of this regulatory liability annually, with an equal and offsetting amount of amortization for IPL's regulatory asset related to electric transmission service costs.

In accordance with the IUB’s 2011 order related to IPL’s 2009 test year Iowa retail electric rate case, IPL was authorized to utilize regulatory liabilities in 2011 to offset transmission service expenses related to the Iowa retail portion of 2009 under-recovered costs billed to IPL. As a result, Alliant Energy recorded a reduction of $19 million in “Electric transmission service” in the Consolidated Statement of Income in 2011. The IUB also authorized IPL to utilize $3 million of this regulatory liability in 2011 to reduce IPL’s Iowa retail electric rate base associated with the Whispering Willow - East wind project.

Minnesota retail portion - In 2010, the MPUC issued an interim rate order authorizing IPL to use a portion of this regulatory liability to implement an alternative transaction adjustment through its energy adjustment clause resulting in annual credits to its Minnesota retail electric customers beginning in July 2010 to coincide with the effective date of the interim rate increase for Minnesota retail customers. The amounts of the annual credits are dependent upon the level of kilowatt-hours sold to IPL’s Minnesota retail customers. In accordance with the MPUC’s November 2011 order related to IPL’s 2009 test year Minnesota retail electric rate case, IPL was authorized to refund a higher amount of the gain realized from the sale of its electric transmission assets in 2007 to its Minnesota retail electric customers than previously estimated. As a result, Alliant Energy recorded a $5 million increase to regulatory liabilities, and a $5 million charge to “Utility - Other operation and maintenance” in the Consolidated Statement of Income in 2011 for the additional amount to be refunded.

Refunds related to any remaining balance of IPL’s electric transmission assets sale regulatory liability are expected to be determined in future rate proceedings.

Commodity cost recovery - Refer to Note 1(h) for additional details of IPL’s and WPL’s cost recovery mechanisms. Refer to Note 2 for discussion of certain rate refund reserves recorded as regulatory liabilities on the Consolidated Balance Sheets.

IPL’s DAEC sale - In 2006, IPL completed the sale of its 70% ownership interest in DAEC and recognized a regulatory liability of approximately $59 million from the transaction based on the terms of the sale agreement. Pursuant to the IUB order approving the DAEC sale, the gain resulting from the sale was used to establish a regulatory liability. In 2009, IPL



received $12 million as part of a settlement of a claim filed against the U.S. Department of Energy (DOE) in 2004 for recovery of damages due to the DOE’s delay in accepting spent nuclear fuel produced at DAEC. IPL recognized the $12 million received from the settlement as an increase to the regulatory liability established with the sale of DAEC. The regulatory liability accrues interest at the monthly average U.S. Treasury rate for three-year maturities.

In 2009, the IUB authorized IPL to utilize $29 million of this regulatory liability to reduce electric plant in service in 2009 related to the cumulative AFUDC recognized for the Whispering Willow - East wind project. In 2010, IPL received approval from the IUB to utilize $26 million of this regulatory liability to offset the amortization of costs incurred for the Sutherland #4 project over a 5-year period ending August 2014. As a result, IPL is amortizing $5 million of this regulatory liability annually, with an equal and offsetting amount of amortization for IPL's regulatory asset related to the Sutherland #4 project. In 2011, the IUB authorized IPL to utilize $23 million of this regulatory liability to reduce IPL's Iowa retail electric rate base in 2011 for the Whispering Willow - East wind project.

Refunds related to any remaining balance of IPL’s DAEC sale regulatory liability are expected to be determined in future rate proceedings.

(c) Income Taxes - Alliant Energy 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 and estimates of state apportionment rates. Changes in deferred income tax assets and liabilities associated with certain property-related differences at IPL are accounted for differently than other subsidiaries of Alliant Energy due to rate-making practices in Iowa. Rate-making practices in Iowa do not include the impact of certain deferred tax expenses (benefits) in the determination of retail rates. Based on these rate-making practices, deferred tax expense (benefit) related to these property-related differences at IPL is not recorded in the income statement but instead charged to regulatory assets or regulatory liabilities until these temporary differences are reversed. Refer to Note 1(b) for further discussion of regulatory assets and regulatory liabilities associated with property-related differences at IPL. In Wisconsin, the PSCW has allowed rate recovery of deferred taxes on all temporary differences since 1991.

Alliant Energy recognizes 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 position, or some portion thereof, will not be sustained, the related tax benefits are not recognized in the consolidated financial statements. 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 Alliant Energy recognizes current taxes payable related to uncertain tax positions in “Accrued taxes” and non-current taxes payable related to uncertain tax positions in “Other long-term liabilities and deferred credits” on the Consolidated Balance Sheets. However, if the uncertain tax position would be settled through the reduction of 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 uncertain tax positions.

Alliant Energy defers investment tax credits and amortizes the credits to income over the average lives of the related property. Other tax credits for Alliant Energy reduce income tax expense in the year claimed.

Alliant Energy has elected the alternative transition method to calculate its beginning pool of excess tax benefits available to absorb any tax deficiencies associated with recognition of share-based payment awards.

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 return including Alliant Energy and all of its subsidiaries is filed in Wisconsin. Alliant Energy subsidiaries with a presence in Iowa file as part of a consolidated return in Iowa. Under the terms of a tax sharing agreement between Alliant Energy and its subsidiaries, the subsidiaries calculate state income tax using consolidated apportionment rates applied to separate company taxable income.

(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 - Utility plant in service (other than acquisition adjustments) 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 utility plant in service and salvage value are netted and charged to accumulated depreciation upon removal from utility plant in service accounts and no gain or loss is recognized consistent with rate-making policies. Removal costs incurred reduce the regulatory liability.

Electric Plant In Service - Electric plant in service by functional category at December 31 was as follows (in millions):

<table><tr><td rowspan="2"></td><td colspan="2">Alliant Energy</td><td colspan="2">IPL</td><td colspan="2">WPL</td></tr><tr><td>2012</td><td>2011</td><td>2012</td><td>2011</td><td>2012</td><td>2011</td></tr><tr><td>Generation</td><td>$4,798.9</td><td>$4,100.6</td><td>$2,393.0</td><td>$2,392.3</td><td>$2,405.9</td><td>$1,708.3</td></tr><tr><td>Distribution</td><td>3,981.5</td><td>3,782.1</td><td>2,205.9</td><td>2,074.8</td><td>1,775.6</td><td>1,707.3</td></tr><tr><td>Other</td><td>290.3</td><td>282.7</td><td>216.3</td><td>216.9</td><td>74.0</td><td>65.8</td></tr><tr><td></td><td>$9,070.7</td><td>$8,165.4</td><td>$4,815.2</td><td>$4,684.0</td><td>$4,255.5</td><td>$3,481.4</td></tr></table>

The increase in Alliant Energy’s and WPL’s generation portion of electric plant in service was primarily due to WPL’s purchase of the Riverside Energy Center (Riverside) and installation of emission controls at Edgewater Unit 5 in the fourth quarter of 2012.

## Wind Generation Projects -

Wind Site in Franklin County, Iowa - In 2007, IPL acquired approximately 500 MW of wind site capacity in Franklin County, Iowa. The initial 200 MW of the wind site was utilized for IPL's Whispering Willow - East wind project, which began generating electricity in 2009. In 2011, IPL sold 100 MW of wind site capacity to Resources for construction of a non-regulated wind project referred to as the Franklin County wind project. Future development of the balance of the wind site by IPL will depend on numerous factors such as renewable portfolio standards, environmental legislation, fossil fuel prices, technology advancements and transmission capabilities. As of December 31, 2012, Alliant Energy's capitalized costs related to the remaining approximately 200 MW of wind site capacity in Franklin County, Iowa were $13 million and were recorded in "Other property, plant and equipment" on the Consolidated Balance Sheet.

IPL’s Whispering Willow - East Wind Project - In 2008, IPL received approval from the IUB to construct the 200 MW Whispering Willow - East wind project. The advanced rate-making principles for this project, as approved by the IUB in 2008, included a predetermined level, or “cost cap,” of $417 million for construction costs. Final construction costs for the project exceeded this cost cap. In January 2011, IPL received an order from the IUB allowing IPL to recover all of its Whispering Willow - East wind project construction costs. However, the IUB did not allow IPL to recover a return on a portion of costs above the cost cap. As a result, Alliant Energy recognized a $21 million impairment related to the disallowance, which was recorded as a charge to “Utility - Other operation and maintenance” in the Consolidated Statement of Income in 2010.

In 2011, IPL received an order from the MPUC approving a temporary recovery rate for the Minnesota retail portion of its Whispering Willow - East wind project construction costs. In its order, the MPUC did not conclude on the prudence of these project costs. The prudence of these project costs and the final recovery rate for these costs will be addressed in a separate proceeding that is expected to be completed in 2013. The initial recovery rate approved by the MPUC is below the amount required by IPL to recover the Minnesota retail portion of its total project costs. Based on its interpretation of the order, Alliant Energy currently believes that it is probable IPL will not be allowed to recover the entire Minnesota retail portion of its project costs. Alliant Energy currently believes the most likely outcome of the final rate proceeding will result in the MPUC effectively disallowing recovery of approximately $8 million of project costs out of a total of approximately $30 million of project costs allocated to the Minnesota retail jurisdiction. As a result, Alliant Energy recognized an $8 million impairment related to this probable disallowance, which was recorded as a reduction to electric plant in service and a charge to “Utility - Other operation and maintenance” in the Consolidated Statement of Income in 2011. This amount is subject to change until the MPUC determines the final recovery rate for these project costs.

Franklin County Wind Project - 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 and WPL’s Bent Tree - Phase I wind projects. In 2011, Alliant Energy decided to utilize the remaining 100 MW of wind turbine generator sets and related equipment at Resources to build the Franklin County wind project. In 2011, IPL sold the assets for this wind project to Resources for $115.3 million, which represented IPL’s book value for progress payments to date for the 100 MW of wind turbine generator sets and related equipment and land rights in Franklin County, Iowa. In addition,



Resources assumed the remaining progress payments to Vestas for the 100 MW of wind turbine generator sets and related equipment. Refer to Note 1(f) for further discussion of the Franklin County wind project.

Wind Site in Green Lake and Fond du Lac Counties in Wisconsin - In 2009, WPL purchased development rights to an approximate 100 MW wind site in Green Lake and Fond du Lac Counties in Wisconsin. Due to events in 2011 resulting in uncertainty regarding wind siting requirements in Wisconsin and increased risks with permitting this wind site, WPL determined it would be difficult to sell or effectively use the site for wind development. As a result, WPL recognized a $5 million impairment in 2011 for the amount of capitalized costs incurred for this site. Alliant Energy recorded the impairment as a reduction in other utility property, plant and equipment, and a charge to “Utility - Other operation and maintenance” in the Consolidated Statement of Income in 2011.

## Environmental Compliance Plans Projects -

IPL’s George Neal Units 3 and 4 Emission Controls Project - MidAmerican Energy Company is currently installing scrubbers and baghouses at George Neal Units 3 and 4 to reduce SO \( _{2} \)  and mercury emissions at the generating facility. IPL owns a 28.0% and 25.695% interest in George Neal Units 3 and 4, respectively. Construction began in the fourth quarter of 2011 and is expected to be completed in 2013 and 2014. The scrubbers and baghouses are expected to help meet requirements under CAIR or some alternative to this rule that may be implemented and the Utility Maximum Achievable Control Technology (MACT) Rule. As of December 31, 2012, Alliant Energy recorded capitalized expenditures of 66 million and AFUDC of 1 million for IPL’s allocated portion of the scrubbers and baghouses in “Construction work in progress - George Neal Generating Station Units 3 and 4 emission controls” on the Consolidated Balance Sheet.

IPL’s Ottumwa Unit 1 Emission Controls Project - IPL is currently installing a scrubber and baghouse at Ottumwa Unit 1 to reduce SO \( _{2} \)  and mercury emissions at the generating facility. IPL owns a 48% interest in Ottumwa Unit 1. Construction began in the second quarter of 2012 and is expected to be completed in 2014. The scrubber and baghouse are expected to help meet requirements under CAIR or some alternative to this rule that may be implemented and the Utility MACT Rule. As of December 31, 2012, Alliant Energy recorded capitalized expenditures of 72 million and AFUDC of 2 million for IPL’s allocated portion of the scrubber and baghouse in “Construction work in progress - Ottumwa Generating Station Unit 1 emission controls” on the Consolidated Balance Sheet.

WPL’s Edgewater Unit 5 Emission Controls Project - In 2010, WPL began installing a selective catalytic reduction (SCR) system at Edgewater Unit 5 to reduce nitrogen oxide (NOx) emissions at the generating facility. The SCR is expected to help meet requirements under the Wisconsin Reasonably Available Control Technology (RACT) Rule, which require additional NOx emission reductions at Edgewater by May 2013. Construction was completed in the fourth quarter of 2012, which resulted in a transfer of the capitalized project costs from “Construction work in progress - Other” to “Electric plant in service” on the Consolidated Balance Sheet in 2012. At December 31, 2012, the capitalized project costs consisted of capitalized expenditures of 132 million and AFUDC of 11 million for the SCR system.

WPL’s Columbia Units 1 and 2 Emission Controls Project - WPL is currently installing scrubbers and baghouses at Columbia Units 1 and 2 to reduce SO \( _{2} \)  and mercury emissions at the generating facility. WPL owns a 46.2% interest in Columbia Units 1 and 2. Construction began in the first quarter of 2012 and is expected to be completed in 2014. The scrubbers and baghouses are expected to help meet requirements under CAIR or some alternative to this rule that may be implemented, the Utility MACT Rule and the Wisconsin State Mercury Rule. As of December 31, 2012, Alliant Energy recorded capitalized expenditures of 126 million and AFUDC of 4 million for WPL’s allocated portion of the scrubbers and baghouses in “Construction work in progress - Columbia Energy Center Units 1 and 2 emission controls” on the Consolidated Balance Sheet.

## Natural Gas-Fired Electric Generation Project -

WPL’s Purchase of Riverside - On December 31, 2012, WPL purchased Riverside, a 600 MW natural gas-fired electric generating facility in Beloit, Wisconsin, from a subsidiary of Calpine Corporation. The purchase price, including certain transaction-related costs, was $403.5 million. Riverside was originally placed into service in 2004. WPL’s purchase of Riverside replaced the 490 MW of electricity output previously obtained from the Riverside purchased power agreement (PPA) to meet the long-term energy needs of its customers. Refer to Note 3 for further discussion of the Riverside PPA terminated with the purchase. As of the closing date, the carrying values of the assets purchased were as follows (in millions):



<table><tr><td>Electric plant in service</td><td>$512.7</td></tr><tr><td>Accumulated depreciation</td><td>(121.4)</td></tr><tr><td>Current assets</td><td>4.2</td></tr><tr><td>Other assets</td><td>8.0</td></tr><tr><td></td><td>$403.5</td></tr></table>

Alliant Energy recorded intangible assets of $8.0 million for contract rights related to a PPA with a third-party for a portion of Riverside’s capacity that were assumed with the acquisition of Riverside. This PPA expires in May 2014. As of December 31, 2012, these intangible assets were included in “Deferred charges and other” on the Consolidated Balance Sheet. At December 31, 2012, Alliant Energy’s estimated amortization expense related to these contract rights for 2013 and 2014 was $5.4 million and $2.6 million, respectively.

Depreciation - IPL and WPL use a combination of remaining life and straight-line depreciation methods as approved by their respective regulatory commissions. 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, estimated cost of removal and group depreciation rates. These depreciation studies are subject to review and approval by IPL’s and WPL’s respective regulatory commissions. 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 other properties, consistent with current rate-making practices, were as follows:

<table><tr><td rowspan="2"></td><td colspan="3">IPL</td><td colspan="3">WPL</td></tr><tr><td>2012</td><td>2011</td><td>2010</td><td>2012</td><td>2011</td><td>2010</td></tr><tr><td>Electric - generation</td><td>3.7%</td><td>3.5%</td><td>3.7%</td><td>3.2%</td><td>3.3%</td><td>2.9%</td></tr><tr><td>Electric - distribution</td><td>2.5%</td><td>2.4%</td><td>2.7%</td><td>2.9%</td><td>2.9%</td><td>2.6%</td></tr><tr><td>Gas</td><td>3.4%</td><td>3.5%</td><td>3.3%</td><td>2.6%</td><td>2.6%</td><td>2.2%</td></tr><tr><td>Other</td><td>4.5%</td><td>4.8%</td><td>4.9%</td><td>5.3%</td><td>5.2%</td><td>6.5%</td></tr></table>

In May 2012, the PSCW issued an order approving the implementation of updated depreciation rates for WPL effective January 1, 2013 as a result of a recently completed depreciation study. In February 2013, the PSCW issued an order approving WPL’s request to revise depreciation rates for Riverside, effective January 1, 2013. WPL estimates the new average rates of depreciation for its electric generation, electric distribution and gas properties will be approximately 3.4%, 2.7% and 2.5%, respectively, during 2013.

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):

<table><tr><td rowspan="2"></td><td colspan="3">Alliant Energy</td><td colspan="3">IPL</td><td colspan="3">WPL</td></tr><tr><td>2012</td><td>2011</td><td>2010</td><td>2012</td><td>2011</td><td>2010</td><td>2012</td><td>2011</td><td>20</td></tr><tr><td>Equity</td><td>$14.1</td><td>$7.6</td><td>$11.2</td><td>$5.2</td><td>$3.5</td><td>$3.0</td><td>$8.9</td><td>$4.1</td><td>$8.2</td></tr><tr><td>Debt</td><td>7.8</td><td>4.4</td><td>6.8</td><td>3.2</td><td>2.3</td><td>2.5</td><td>4.6</td><td>2.1</td><td>4.3</td></tr><tr><td></td><td>$21.9</td><td>$12.0</td><td>$18.0</td><td>$8.4</td><td>$5.8</td><td>$5.5</td><td>$13.5</td><td>$6.2</td><td>$12.5</td></tr></table>

WPL recognized $11 million and $3 million of AFUDC in 2012 and 2011, respectively, for its Edgewater Unit 5 and Columbia Units 1 and 2 emission controls projects. WPL recognized $1 million and $10 million of AFUDC in 2011 and 2010, respectively, for its Bent Tree - Phase I wind project, a portion of which was placed in service in 2010 and 2011.

AFUDC for IPL’s construction projects is calculated in accordance with FERC guidelines. 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:

<table><tr><td></td><td>2012</td><td>2011</td><td>2010</td></tr><tr><td>IPL (FERC formula)</td><td>8.2%</td><td>8.5%</td><td>4.8%</td></tr><tr><td>WPL (PSCW formula - retail jurisdiction) (a)</td><td>8.8%</td><td>8.8%</td><td>8.8%</td></tr><tr><td>WPL (FERC formula - wholesale jurisdiction)</td><td>7.9%</td><td>6.2%</td><td>7.2%</td></tr></table>



(a) Consistent with the PSCW’s retail rate case order issued in 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. Consistent with the PSCW’s retail order issued in 2009, WPL accrued AFUDC on 100% of CWIP related to the Edgewater Unit 5 emission controls project and the Columbia Units 1 and 2 emission controls project in 2012, 2011 and 2010. Consistent with the PSCW’s retail rate case order issued in 2012, WPL will earn a return on 50% of the estimated CWIP related to its Columbia Units 1 and 2 emission controls project for 2013 and will accrue AFUDC on the remaining 50% in 2013.

## (f) Non-regulated and Other Property, Plant and Equipment -

General - Non-regulated and 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. Upon retirement or sale of non-regulated and 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.

The Franklin County wind project and the Sheboygan Falls Energy Facility within Alliant Energy’s Non-regulated Generation business represent a large portion of the non-regulated and other property, plant and equipment. The Franklin County wind project was placed in service in the fourth quarter of 2012 and is being depreciated using the straight-line method over a 30-year period. As of December 31, 2012, Alliant Energy recorded $148 million (capitalized expenditures of $130 million, capitalized interest of $9 million, and AROs of $9 million) in “Non-regulated Generation property, plant and equipment” on the Consolidated Balance Sheet related to the wind project. Refer to Note 4(d) for discussion of a cash grant expected to be received related to the Franklin County wind project, which reduced the cost of the project. The Sheboygan Falls Energy Facility was placed into service in 2005 and is being depreciated using the straight-line method over a 35-year period. As of December 31, 2012, Alliant Energy recorded $111 million in “Non-regulated Generation property, plant and equipment” on the Consolidated Balance Sheet related to the Sheboygan Falls Energy Facility. The property, plant and equipment related to Corporate Services, Transportation and other non-regulated investments is recorded in “Alliant Energy Corporate Services, Inc. and other property, plant and equipment” on the Consolidated Balance Sheets and is depreciated using the straight-line method over periods ranging from 5 to 30 years.

The increase in “Alliant Energy Corporate Services, Inc. and other property, plant and equipment” on the Consolidated Balance Sheets during 2012 was primarily due to Alliant Energy exercising its option under the corporate headquarters lease to purchase the building at the expiration of the lease term for $48 million.

Refer to Note 1(e) for further discussion of the Franklin County wind project and Note 18 for discussion of the Franklin County wind project AROs.

## (g) Operating Revenues -

Utility - Revenues from Alliant Energy’s utility business are primarily from electricity and natural gas sales and are recognized on an accrual basis as services are rendered or commodities are delivered to customers. Energy sales to individual customers are based on the reading of customers’ meters, which occurs on a systematic basis throughout each reporting period. Amounts 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.

IPL and WPL accrue revenues from their 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. IPL’s estimated recovery amount is recorded in the current period of service and is reflected in customer bills within two years under the provisions of approved formula rates. WPL’s estimated recovery amount is recorded in the 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.

IPL and WPL participate in bid/offer-based wholesale energy and ancillary services markets operated by the Midwest Independent Transmission System Operator (MISO). IPL’s and WPL’s customers and generating resources are located in the MISO region. MISO requires that all load serving entities and generation owners, including IPL and WPL, submit hourly



day-ahead and/or real-time bids and offers for energy and ancillary services. The MISO 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 utility operating revenues” and the net purchase from MISO is recorded in “Electric production fuel and energy purchases” in the Consolidated Statements of Income. IPL and WPL also engage in transactions in PJM Interconnection, LLC’s bid/offer-based wholesale energy market, which are accounted for similar to the MISO transactions.

Non-regulated - Revenues from Alliant Energy’s non-regulated businesses are primarily from its Transportation business and are recognized on an accrual basis as services are rendered or goods are delivered to customers.

Taxes Collected from Customers - Certain of Alliant Energy’s subsidiaries serve as collection agents for sales or various other taxes and record revenues on a net basis. Operating revenues do not include the collection of the aforementioned taxes.

## (h) Utility Cost Recovery Mechanisms -

Electric Production Fuel and Energy Purchases (Fuel-related Costs) - Alliant Energy, IPL and WPL incur fuel-related costs each period to generate and purchase electricity to meet the demand of their electric customers. These fuel-related costs include the cost of fossil fuels (primarily coal and natural gas) used during each period to produce electricity at their generating facilities, electricity purchased each period from wholesale energy markets (primarily MISO) and under PPAs, costs for allowances acquired to allow certain emissions (primarily SO \( _{2} \)  and NO \( _{x} \) ) from their generating facilities and costs for chemicals utilized to control emissions from their generating facilities. Alliant Energy records these fuel-related costs in “Electric production fuel and energy purchases” in the Consolidated Statements of Income.

IPL Retail - The cost recovery mechanisms applicable for IPL’s retail electric customers provide for subsequent adjustments to their electric rates for changes in electric production fuel and purchased energy costs. Fuel adjustment clause rules applicable to IPL’s Iowa retail jurisdiction also currently allow IPL to recover prudently incurred costs for emission allowances required to comply with EPA regulations including the Acid Rain program and CAIR through the fuel adjustment clause. Changes in the under-/over-collection of these costs each period are 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 fuel adjustment clause rules applicable to IPL’s Iowa retail jurisdiction currently do not contain a provision for recovery of emission control chemical costs to flow through the fuel adjustment clause. The fuel adjustment clause rules applicable to IPL’s Minnesota retail jurisdiction currently do not contain a provision for recovery of emission allowance costs or emission control chemical costs through the fuel adjustment clause.

WPL Retail - The cost recovery mechanism applicable for WPL’s retail electric customers was changed effective January 2011. For periods prior to 2011, WPL’s retail electric rates approved by the PSCW were based on forecasts of forward-looking test periods and included estimates of future electric production fuel and purchased energy costs anticipated during the test period. During each electric retail rate proceeding, the PSCW set fuel monitoring ranges based on the forecasted electric production fuel and purchased energy costs used to determine retail base rates. If WPL’s actual electric production fuel and purchased energy costs fell outside these fuel monitoring ranges during the test period, WPL and/or other parties could request, and the PSCW could authorize, an adjustment to future retail electric rates based on changes in electric production fuel and purchased energy costs only. The PSCW could also authorize an interim retail rate increase. However, if the final retail rate increase was less than the monitoring range threshold required to be met in order to request interim rate relief, all interim rates collected would be subject to refund to WPL’s retail customers with interest at the current authorized return on common equity rate. In 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 2010, the cost recovery mechanism applicable for WPL’s retail electric customers continues to be based on forecasts of certain fuel-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 post-2010 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 under-/over-collection of fuel costs that are outside the approved ranges. Deferral of under-collections are reduced to the extent actual return on common equity earned by WPL during the fuel cost plan year exceeds the most recently authorized return on common equity. Such deferred amounts are recognized in “Electric production fuel and energy purchases” in the Consolidated Statements of Income each period. The cumulative effects of these deferred amounts are recorded in current “Regulatory assets” or current “Regulatory liabilities” on the Consolidated Balance Sheets until they are reflected in future billings to customers. Effective January



2012, WPL’s retail fuel-related costs include costs for emission allowances and emission control chemicals. Prior to 2012, WPL’s retail fuel-related costs excluded costs for emission allowances and emission control chemicals.

IPL and WPL Wholesale - The cost recovery mechanisms applicable for IPL’s and WPL’s wholesale electric customers provide for subsequent adjustments to their electric rates for changes in electric production fuel and purchased energy costs. Changes in the under-/over-collection of these costs are recognized in “Electric production fuel and energy purchases” in the Consolidated Statements of Income each period. 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. IPL’s and WPL’s costs for emission allowances and emission control chemicals are recovered through the capacity charge component of their respective wholesale formula rates.

Purchased Electric Capacity - Alliant Energy, IPL and WPL enter into PPAs to help meet the electricity demand of their customers. Certain of these PPAs include minimum payments for IPL's and 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 IPL's and WPL's retail electric customers through changes in base rates determined during periodic rate proceedings. Purchased electric capacity expenses are recovered from IPL's and WPL's wholesale electric customers through annual changes in base rates determined by a formula rate structure.

Electric Transmission Service - Alliant Energy, IPL and WPL incur costs for the transmission of electricity to their customers and charge 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 IPL’s and WPL’s wholesale electric customers through annual changes in base rates determined by a formula rate structure.

Prior to 2011, electric transmission service expenses were recovered from IPL’s retail electric customers through changes in base rates determined during periodic rate proceedings. In January 2011, the IUB approved IPL’s proposal to implement a transmission cost rider for recovery of electric transmission service expenses with certain conditions. The IUB stipulated that the rider would be implemented on a pilot basis conditional upon IPL’s agreement to not file an electric base rate case for three years from the date of the order and meet additional reporting requirements. In January 2011, IPL accepted the transmission cost rider with the IUB’s conditions. Effective February 2011, electric transmission service expenses were removed from base rates and billed to IPL’s Iowa electric retail customers through the transmission cost rider. This new cost recovery mechanism provides for subsequent adjustments to electric rates charged to Iowa electric retail customers for changes in electric transmission service expenses. Changes in the under-/over-collection of these costs each period are recognized in “Electric transmission service” 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.

Cost of Gas Sold - Alliant Energy, IPL and WPL incur costs for the purchase, transportation and storage of natural gas to serve their gas customers and charge 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 IPL’s and WPL’s retail gas customers provide for subsequent adjustments to their rates for changes in the cost of gas sold. Changes in the under-/over-collection of these costs are also recognized in “Cost of gas sold” 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.

Energy Efficiency Costs - Alliant Energy, IPL and WPL incur costs to fund energy efficiency programs and initiatives that help customers reduce their energy usage and charge these costs incurred each period to “Utility - Other operation and maintenance” in the Consolidated Statements of Income. Energy efficiency costs incurred by IPL are recovered from its retail electric and gas customers in Iowa through an additional tariff called an energy efficiency cost recovery (EECR) factor. EECR factors are revised annually and include a reconciliation to eliminate any under-/over-collection of energy efficiency costs from prior periods. Energy efficiency costs incurred by WPL are recovered from retail electric and gas customers through changes in base rates determined during periodic rate proceedings. Reconciliation of any under-/over-collection of energy efficiency costs from prior periods are also addressed in periodic rate proceedings. Changes in the under-/over-collection of energy efficiency costs each period are recognized in “Utility - 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 Notes 1(b) and 2 for additional information regarding these utility cost recovery mechanisms.

(i) Financial Instruments - Alliant Energy, IPL and WPL periodically use financial instruments for risk management purposes to mitigate exposures to fluctuations in certain commodity prices and transmission congestion costs. The fair value of those financial instruments that are determined to be derivatives are recorded as assets or liabilities on the Consolidated Balance Sheets. Derivative instruments representing unrealized gain positions are reported as derivative assets, and derivative instruments representing unrealized loss positions are reported as derivative liabilities at the end of each reporting period. Alliant Energy, IPL and WPL also have certain 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. Alliant Energy, IPL and WPL do 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 gains on IPL's and WPL's derivative instruments. Refer to Notes 12 and 13(f) for further discussion of derivatives and related credit risk, respectively.

(j) Pension and Other Postretirement Benefits Plans - Corporate Services sponsors various pension and other postretirement benefits plans. The costs related to Corporate Services’ plans are allocated to IPL, WPL, Resources and the parent company based on labor costs of plan participants.

## (k) Asset Impairments -

Property, Plant and Equipment of Regulated Operations - Property, 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 IPL or WPL are disallowed recovery of any portion of the carrying value of their regulated property, plant and equipment that has been recently completed or is probable of abandonment, an impairment charge is recognized equal to the amount of the carrying value that was disallowed. If IPL or WPL are disallowed a full or partial return on the carrying value of their regulated property, plant and equipment that has been recently completed or is probable of abandonment, an impairment charge is recognized equal to the difference between the carrying value and the present value of the future revenues expected from their regulated property, plant and equipment. Refer to Note 1(e) for discussion of impairments recorded in 2011 and 2010 related to IPL's Whispering Willow - East wind project.

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(e) for discussion of an impairment recorded in 2011 related to WPL’s Green Lake and Fond du Lac Counties wind site.

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 10(a) for additional discussion of investments accounted for under the equity method of accounting.

(I) Operating Leases - Historically, WPL had certain PPAs that provided it exclusive rights to all or a substantial portion of the output from the specific generating facility over the contract term and that had pricing factors that required accounting for the PPAs as operating leases. Costs associated with these PPAs were included in “Electric production fuel and 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 was higher during the peak demand period from May 1 through September 30 and lower in all other periods during each calendar year. These seasonal differences in capacity charges were consistent with expected market pricing trends and the expected usage of energy from the facility. In December 2012, WPL purchased Riverside, which terminated the Riverside PPA. The Riverside PPA was accounted for as an operating lease.

(m) Emission Allowances - Emission allowances are granted by the EPA at zero cost and permit the holder of the allowances to emit certain gaseous by-products of 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 used. Emission allowances



allocated to or acquired by Alliant Energy, IPL or 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. In 2012, 2011 and 2010, amortization expense of $0, $13.4 million and $16.5 million was recorded in “Electric production fuel and energy purchases” in the Consolidated Statements of Income. No amortization expense for emission allowances held at December 31, 2012 is currently expected to be recorded during 2013 through 2017.

Cash inflows and outflows related to sales and purchases of emission allowances are recorded as investing activities in the Consolidated Statements of Cash Flows. Refer to Note 1(b) for information regarding regulatory assets related to emission allowances.

(n) AROs - The fair value of any retirement costs associated with an asset for which Alliant Energy, IPL and WPL have a legal obligation is recorded as a liability with an equivalent amount added to the asset cost when an asset is placed in 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. Accretion and depreciation expenses related to AROs for IPL's and WPL's regulated operations are recorded to regulatory assets on the Consolidated Balance Sheets. Upon regulatory approval to recover IPL's AROs expenditures, its regulatory assets are amortized to depreciation and amortization expense in the Consolidated Statements of Income over the same time period that IPL's customer rates are increased to recover the ARO expenditures. Effective January 1, 2013, WPL's regulatory assets related to AROs are being recovered as a component of depreciation rates included in the most recent depreciation study approved by the PSCW in its May 2012 order. Accretion and depreciation expenses related to AROs for Alliant Energy's non-regulated operations are recorded to depreciation and amortization expense in the Consolidated Statements of Income.

Upon settlement of the ARO liability, an entity settles the obligation for its recorded amount or incurs a gain or loss. Any gains or losses related to AROs for IPL's and WPL's regulated operations are recorded to regulatory liabilities or regulatory assets on the Consolidated Balance Sheets. Any gains or losses related to AROs for Alliant Energy's non-regulated operations are recorded to non-regulated operating revenue or non-regulated operation and maintenance expense in the Consolidated Statements of Income.

Refer to Note 18 for additional discussion of AROs.

(o) Debt Issuance and Retirement Costs - Alliant Energy, IPL and WPL defer and amortize debt issuance costs and debt premiums or discounts over the expected lives of respective debt issues, considering maturity dates and, if applicable, redemption rights held by others. Alliant Energy’s non-regulated businesses and Corporate Services expense in the period of retirement any unamortized debt issuance costs and debt premiums or discounts on debt retired early. Refer to Note 1(b) for information on regulatory assets related to IPL’s and WPL’s debt retired early or refinanced.

(p) Allowance for Doubtful Accounts - Alliant Energy, IPL and WPL maintain allowances for doubtful accounts for estimated losses resulting from the inability of their customers to make required payments. Alliant Energy, IPL and WPL estimate the allowance for doubtful accounts based on historical write-offs, customer arrears and other economic factors within their service territories. Allowance for doubtful accounts at December 31 was as follows (in millions):

<table><tr><td rowspan="2"></td><td colspan="2">Alliant Energy</td><td colspan="2">IPL</td><td colspan="2">WPL</td></tr><tr><td>2012</td><td>2011</td><td>2012</td><td>2011</td><td>2012</td><td>2011</td></tr><tr><td>Customer (a)</td><td>$1.3</td><td>$1.6</td><td>$—</td><td>$—</td><td>$1.3</td><td>$1.6</td></tr><tr><td>Other</td><td>2.7</td><td>2.6</td><td>0.7</td><td>0.9</td><td>0.5</td><td>0.3</td></tr><tr><td></td><td>$4.0</td><td>$4.2</td><td>$0.7</td><td>$0.9</td><td>$1.8</td><td>$1.9</td></tr></table>

(a) Refer to Note 4(a) for discussion of IPL’s sales of accounts receivable program.

(q) Variable Interest Entities (VIEs) - An entity is considered a VIE 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 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 VIE. If Alliant Energy, IPL or WPL have a variable interest in a VIE, a determination as to who the primary beneficiary is must be assessed.



Historically, after making exhaustive efforts, Alliant Energy and WPL concluded they were unable to obtain the information necessary from the counterparty (a subsidiary of Calpine Corporation) for the Riverside PPA for Alliant Energy and WPL to determine whether the counterparty was a VIE and if WPL was the primary beneficiary. In December 2012, WPL purchased Riverside, thereby terminating the Riverside PPA. Refer to Note 1(e) for details of WPL's purchase of Riverside.

(r) Cash Flows Presentation - Alliant Energy reports cash flows from continuing operations together with cash flows from discontinued operations in the Consolidated Statements of Cash Flows.

(s) Comprehensive Income - In 2012, 2011 and 2010, Alliant Energy’s other comprehensive income was $0, $0.6 million and $0, respectively; therefore, its comprehensive income was substantially equal to its net income and its comprehensive income attributable to Alliant Energy common shareowners was substantially equal to its net income attributable to Alliant Energy common shareowners for such periods.

## (2) UTILITY RATE CASES

WPL’s Wisconsin Retail Electric and Gas Rate Case (2013/2014 Test Period) - In May 2012, WPL filed a retail base rate filing based on a forward-looking test period that included 2013 and 2014. The filing requested approval for WPL to implement a decrease in annual base rates for WPL’s retail gas customers of $13 million effective January 1, 2013 followed by a freeze of such gas base rates through the end of 2014. The filing also requested authority to maintain customer base rates for WPL’s retail electric customers at their current levels through the end of 2014. Recovery of the costs for the acquisition of Riverside, the SCR project at Edgewater Unit 5 and the scrubber and baggage projects at Columbia Units 1 and 2 were included in the request. The recovery of the costs for these capital projects are offset by decreases in rate base resulting from increased net deferred tax liabilities, the impact of changes in the amortizations of regulatory assets and regulatory liabilities, and the reduction of capacity payments. In July 2012, WPL received an order from the PSCW authorizing WPL to implement its retail base rate filing as requested. Refer to Note 1(b) for details of increases to “Regulatory assets” on the Consolidated Balance Sheet and regulatory-related credits to “Utility - Other operation and maintenance” in the Consolidated Statement of Income in 2012 as a result of the PSCW’s order authorizing WPL to recover previously incurred costs associated with the acquisition of a 25% interest in Edgewater Unit 5 and proposed CACP projects.

WPL’s Wisconsin Retail 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. The request was based on a forward-looking test period that included 2011. The key drivers for the filing included recovery of investments in WPL’s Bent Tree - Phase I wind project and expiring deferral credits, partially offset by lower variable fuel expenses. In December 2010, WPL received an order from the PSCW authorizing an annual retail electric rate increase of $8 million, or approximately 1%, effective January 1, 2011. This $8 million increase in annual rates effective January 1, 2011, combined with the termination of the $9 million interim fuel-related rate increase after December 2010, resulted in a net $1 million decrease in annual retail electric rates charged to customers effective January 2011. Refer to “WPL’s Retail Fuel-related Rate Case (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 retail electric customers related to interim fuel cost collections in 2010.

IPL’s Iowa Retail Gas Rate Case (2011 Test Year) - In May 2012, IPL filed a request with the IUB to increase annual rates for its Iowa retail gas customers based on a 2011 historical test year as adjusted for certain known and measurable changes occurring up to 12 months after the commencement of the proceeding. The key drivers for the filing included recovery of capital investments since IPL’s last Iowa retail gas rate case filed in 2005. IPL’s request included a proposal to utilize regulatory liabilities to credit bills of Iowa retail gas customers to help mitigate the impact of the proposed final rate increase on such customers. IPL proposed to reduce customer bills utilizing a gas tax benefit rider over a three-year period by approximately $36 million in aggregate. In conjunction with the filing, IPL implemented an interim retail gas rate increase of $9 million, or approximately 3%, on an annual basis, effective June 4, 2012, without regulatory review and subject to refund pending determination of final rates from the request. In 2012, Alliant Energy recorded $5 million in gas revenues from IPL’s Iowa retail gas customers related to the interim retail gas rate increase. In August 2012, IPL, the Iowa Office of Consumer Advocate and the Iowa Consumers Coalition filed a unanimous settlement proposal with the IUB addressing all issues among these parties related to this rate case. In November 2012, the IUB approved the settlement agreement between the parties. The parties agreed to, and the IUB approved, an increase in annual rates for IPL’s Iowa retail gas customers of $11 million, or approximately 4%, effective January 10, 2013. The parties and the IUB also agreed to IPL’s proposed gas tax benefit rider.

IPL’s Iowa Retail Electric Rate Case (2009 Test Year) - In March 2010, IPL filed a request with the IUB to increase annual rates for its Iowa retail electric customers based on a 2009 historical test year as adjusted for certain known and measurable changes occurring up to 12 months after the commencement of the proceeding. The key drivers for the filing included recovery of investments in the Whispering Willow - East wind project and emission controls projects at Lansing Unit 4, and



recovery of increased electric transmission service costs. In conjunction with the filing, IPL implemented an interim retail electric rate increase of $119 million, on an annual basis, effective March 20, 2010. In February 2011, IPL received an order from the IUB authorizing a final annual retail electric rate increase of $114 million, or approximately 10%. In 2011, IPL refunded $5 million, including interest, to its retail electric customers in Iowa. Refer to Note 1(b) for discussion of the impacts of the IUB's decision in this rate case on regulatory assets and regulatory liabilities. Refer to Note 1(e) for discussion of the IUB's decision in this rate case, which disallowed IPL a return on a portion of its Whispering Willow - East wind project costs.

IPL’s Minnesota Retail Electric Rate Case (2009 Test Year) - In May 2010, IPL filed a request with the MPUC to increase annual rates for its Minnesota retail electric customers based on a 2009 historical test year as adjusted for certain known and measurable items at the time of the filing. The key drivers for the filing included recovery of investments in the Whispering Willow - East wind project and emission controls projects at Lansing Unit 4, and recovery of increased electric transmission service costs. In conjunction with the filing, IPL implemented an interim retail rate increase of $14 million, on an annual basis, effective July 6, 2010. In November 2011, IPL received an order from the MPUC authorizing a final annual retail electric rate increase equivalent to $11 million. The final annual retail electric rate increase of $11 million includes $8 million of higher base rates, $2 million from the temporary renewable energy rider and $1 million from the utilization of regulatory liabilities to offset higher electric transmission service costs. Refer to Note 1(b) for discussion of changes to regulatory assets and regulatory liabilities in 2011 based on the MPUC’s decisions in this rate case. Refer to Note 1(e) for discussion of an impairment recognized in 2011 based on the MPUC’s decision regarding the recovery of IPL’s Whispering Willow - East wind project costs.

WPL’s Retail Fuel-related Rate Case (2013 Test Year) - In June 2012, WPL filed a request with the PSCW to decrease annual rates for WPL’s retail electric customers to reflect anticipated decreases in retail fuel-related costs in 2013 compared to the fuel-related cost estimates used to determine rates for 2012. In December 2012, WPL received an order from the PSCW authorizing an annual retail electric rate decrease of $29 million, or approximately 3%, effective January 1, 2013. WPL’s 2013 fuel-related costs will be monitored using an annual bandwidth of plus or minus 2%.

WPL’s Retail Fuel-related Rate Case (2012 Test Year) - In May 2011, WPL filed a request with the PSCW to increase annual retail electric rates to recover anticipated increases in retail fuel-related costs in 2012 due to higher purchased power energy costs and emission compliance costs. In December 2011, WPL received an order from the PSCW authorizing an annual retail electric rate increase of $4 million, effective January 1, 2012, related to expected changes in retail fuel-related costs for 2012. The 2012 fuel-related costs were subject to an annual bandwidth of plus or minus 2%. Retail fuel-related costs incurred by WPL for 2012 were lower than the approved fuel monitoring level by more than the 2% bandwidth resulting in future refunds anticipated to be used to offset fuel-related cost changes in 2014. As of December 31, 2012, Alliant Energy recorded $11 million in “Regulatory liabilities” on the Consolidated Balance Sheet for refunds anticipated to be used to adjust fuel-related cost changes in 2014.

WPL’s Retail Fuel-related Rate Case (2010 Test Year) - In April 2010, WPL filed a request with the PSCW to increase annual retail electric rates to recover anticipated increased fuel-related costs in 2010. WPL received approval from the PSCW to implement an interim rate increase of $9 million, on an annual basis, effective in 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.

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

Operating Leases - Alliant Energy has entered into various agreements related to property, plant and equipment rights that are accounted for as operating leases. Historically, Alliant Energy’s most significant operating lease related to the Riverside PPA, which contained fixed rental payments related to capacity and contingent rental payments related to the energy portion (actual MWhs) of the PPA. In December 2012, WPL purchased Riverside, thereby terminating the Riverside PPA. Rental expenses associated with operating leases were as follows (in millions):



<table><tr><td></td><td>2012</td><td>2011</td><td>2010</td></tr><tr><td>Operating lease rental expenses (excluding contingent rentals)</td><td>$69</td><td>$70</td><td>$70</td></tr><tr><td>Contingent rentals (primarily related to certain PPAs)</td><td>6</td><td>5</td><td>5</td></tr><tr><td></td><td>$75</td><td>$75</td><td>$75</td></tr></table>

At December 31, 2012, future minimum operating lease payments, excluding contingent rentals, were as follows (in millions):

<table><tr><td></td><td>2013</td><td>2014</td><td>2015</td><td>2016</td><td>2017</td><td>Thereafter</td><td>Total</td></tr><tr><td>Alliant Energy</td><td>$9</td><td>$13</td><td>$5</td><td>$3</td><td>$2</td><td>$24</td><td>$56</td></tr></table>

Alliant Energy’s future minimum operating lease payments in the above table include synthetic leases related to the financing of certain utility railcars. The entities that lease these assets to Alliant Energy do not meet consolidation requirements and are not included on the Consolidated Balance Sheets. Alliant Energy 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 three years. Residual value guarantee amounts have been included in the future minimum operating lease payments.

## (4) RECEIVABLES

(a) Sales of Accounts Receivable - IPL maintains a Receivables Purchase and Sale Agreement (Agreement) whereby it may sell its customer accounts receivables, unbilled revenues and certain other accounts receivables to a third-party financial institution through wholly-owned and consolidated special purpose entities. In March 2012, IPL extended through March 2014 the purchase commitment from the third-party financial institution to which it sells its receivables. IPL accounts for sales of receivables under the Agreement as transfers of financial assets. In exchange for the receivables sold, IPL receives cash proceeds from the third-party financial institution (based on seasonal limits up to $180 million including $150 million as of December 31, 2012), and deferred proceeds recorded in “Accounts receivable” on the Consolidated Balance Sheets. IPL makes monthly payments to the third-party financial institution of an amount that varies based on interest rates, the length of time the cash proceeds remain outstanding and the total amount under commitment by the third-party financial institution. IPL has historically used proceeds from the sales of receivables to maintain flexibility in its capital structure, take advantage of favorable short-term rates and finance a portion of its cash needs.

Deferred proceeds are payable by the third-party financial institution solely from the collections of the receivables, but only after paying any required expenses to the third-party financial institution and the collection agent. Corporate Services acts as collection agent for the third-party financial institution and receives a fee for collection services. Alliant Energy believes that the allowance for doubtful accounts related to IPL's sales of receivables is a reasonable approximation of any credit risk of the customers that generated the receivables. Therefore, the carrying amount of deferred proceeds, after being reduced by the allowance for doubtful accounts, approximates the fair value of the deferred proceeds due to the short-term nature of the collection period. The carrying amount of deferred proceeds represents IPL's maximum exposure to loss related to the receivables sold.

As of December 31, 2012 and 2011, IPL sold $198.4 million and $195.3 million aggregate amounts of receivables, respectively. IPL's maximum and average outstanding cash proceeds, and costs incurred related to the sales of accounts receivable program were as follows (in millions):

<table><tr><td></td><td>2012</td><td>2011</td><td>2010</td></tr><tr><td>Maximum outstanding aggregate cash proceeds (based on daily outstanding balances)</td><td>$160.0</td><td>$160.0</td><td>$160.0</td></tr><tr><td>Average outstanding aggregate cash proceeds (based on daily outstanding balances)</td><td>119.8</td><td>118.1</td><td>78.1</td></tr><tr><td>Costs incurred</td><td>1.4</td><td>1.5</td><td>1.4</td></tr></table>



As of December 31, the attributes of IPL’s receivables sold under the Agreement were as follows (in millions):

<table><tr><td></td><td>2012</td><td>2011</td></tr><tr><td>Customer accounts receivable</td><td>$118.2</td><td>$122.4</td></tr><tr><td>Unbilled utility revenues</td><td>77.4</td><td>65.4</td></tr><tr><td>Other receivables</td><td>2.8</td><td>7.5</td></tr><tr><td>Receivables sold</td><td>198.4</td><td>195.3</td></tr><tr><td>Less: cash proceeds (a)</td><td>130.0</td><td>140.0</td></tr><tr><td>Deferred proceeds</td><td>68.4</td><td>55.3</td></tr><tr><td>Less: allowance for doubtful accounts</td><td>1.6</td><td>1.6</td></tr><tr><td>Fair value of deferred proceeds</td><td>$66.8</td><td>$53.7</td></tr><tr><td>Outstanding receivables past due</td><td>$16.1</td><td>$15.9</td></tr></table>

(a) Changes in cash proceeds are recorded in “Sales of accounts receivable” in operating activities in the Consolidated Statements of Cash Flows.

Additional attributes of IPL’s receivables sold under the Agreement were as follows (in millions):

<table><tr><td></td><td>2012</td><td>2011</td><td>2010</td></tr><tr><td>Collections reinvested in receivables</td><td>$1,771.6</td><td>$1,795.7</td><td>$1,354.2</td></tr><tr><td>Credit losses, net of recoveries</td><td>10.0</td><td>10.9</td><td>7.9</td></tr></table>

(b) Whiting Petroleum Corporation (Whiting) Tax Sharing Agreement - Prior to an initial public offering (IPO) of Whiting in 2003, Alliant Energy and Whiting entered into a tax separation and indemnification agreement pursuant to which Alliant Energy and Whiting made tax elections. These tax elections had the effect of increasing the tax basis of the assets of Whiting’s consolidated tax group based on the sales price of Whiting’s shares in the IPO. The increase in the tax basis of the assets was included in income in Alliant Energy’s U.S. federal income tax return for the calendar year 2003. Pursuant to the tax separation and indemnification agreement, Whiting will be obligated to pay Resources 90% of any tax benefits realized annually due to the additional tax deductions from the increase in tax basis for years ending on or prior to December 31, 2013. Such tax benefits will generally be calculated by comparing Whiting’s actual taxes to the taxes that would have been owed by Whiting had the increase in basis not occurred. In 2014, Whiting will be obligated to pay Resources the present value of the remaining tax benefits assuming all such tax benefits will be realized in future years. At the IPO closing date, Alliant Energy recorded a receivable from Whiting based on the estimated present value of the payments expected from Whiting. At December 31, 2012 and 2011, the carrying value of this receivable was $27 million and $27 million, respectively. The current and non-current portions of this receivable are recorded in “Prepayments and other” and “Deferred charges and other,” respectively, on the Consolidated Balance Sheets.

(c) Advances for Customer Energy Efficiency Projects - WPL and IPL offer energy efficiency programs to certain of their customers in Wisconsin and Minnesota, respectively. The energy efficiency programs provide low-cost financing to help customers identify, purchase and install energy efficiency improvement projects. The customers repay WPL and IPL with monthly payments over a term up to 5 years. The advances for and collections of customer energy efficiency projects are recorded as investing activities in the Consolidated Statements of Cash Flows. The current portion and non-current portion of outstanding advances for customer energy efficiency projects are recorded in “Accounts receivable - other” and “Deferred charges and other,” respectively, on the Consolidated Balance Sheets. At December 31, outstanding advances for customer energy efficiency projects were as follows (in millions):

<table><tr><td rowspan="2"></td><td colspan="2">Alliant Energy</td><td colspan="2">IPL</td><td colspan="2">WPL</td></tr><tr><td>2012</td><td>2011</td><td>2012</td><td>2011</td><td>2012</td><td>2011</td></tr><tr><td>Current portion</td><td>$14.9</td><td>$22.2</td><td>$0.8</td><td>$1.7</td><td>$14.1</td><td>$20.5</td></tr><tr><td>Non-current portion</td><td>13.0</td><td>28.2</td><td>0.6</td><td>1.7</td><td>12.4</td><td>26.5</td></tr><tr><td></td><td>$27.9</td><td>$50.4</td><td>$1.4</td><td>$3.4</td><td>$26.5</td><td>$47.0</td></tr></table>

(d) Franklin County Wind Project Cash Grant - The American Recovery and Reinvestment Act of 2009 (ARRA) provides incentives for wind projects placed into service between January 1, 2009 and December 31, 2012. In accordance with the ARRA, Alliant Energy filed an application with the U.S. Department of the Treasury in February 2013 requesting a cash grant for 30% of qualifying project expenditures of the Franklin County wind project that was placed into service in December 2012. Since the requirements to receive the cash grant were met in 2012, Alliant Energy recorded $62 million in “Accounts receivable - other” on the Consolidated Balance Sheet as of December 31, 2012 for the proceeds expected to be received in 2013 from the cash grant. Alliant Energy elected to record the anticipated cash grant as a reduction of the carrying value of the Franklin County wind project which resulted in a decrease of $62 million in “Non-regulated Generation



property, plant and equipment” on the Consolidated Balance Sheet as of December 31, 2012. In addition, 50% of the expected grant proceeds will generate a timing difference between the book and tax basis of the wind project and the other 50% of the expected grant will generate a permanent decrease in the tax basis of the wind project. Alliant Energy elected to account for the permanent decrease in the tax basis of the wind project as a reduction to the wind project’s carrying value. As a result, Alliant Energy recorded $20 million in long-term deferred income tax assets, with an offsetting decrease in “Non-regulated Generation property, plant and equipment” on the Consolidated Balance Sheet as of December 31, 2012 for the impact of the permanent decrease in the tax basis of the wind project.

The Budget Control Act of 2011 is currently scheduled to introduce automatic federal spending cuts, or sequestration, if a budget reduction plan does not occur by March 1, 2013. A portion of government grant funding may be subject to sequestration for any government grant that is not received by March 1, 2013. In the event of sequestration, Alliant Energy may reevaluate its options on electing the cash grant for the Franklin County wind project.

## (5) INCOME TAXES

Income Taxes - The components of “Income taxes” in the Consolidated Statements of Income were as follows (in millions):

<table><tr><td></td><td>2012</td><td>2011</td><td>2010</td></tr><tr><td>Current tax expense (benefit):</td><td></td><td></td><td></td></tr><tr><td>Federal</td><td>($29.3)</td><td>$58.6</td><td>$7.1</td></tr><tr><td>State</td><td>11.6</td><td>15.7</td><td>10.6</td></tr><tr><td>IPL&#x27;s electric tax benefit rider</td><td>(48.3)</td><td>(35.9)</td><td>—</td></tr><tr><td>Deferred tax expense (benefit):</td><td></td><td></td><td></td></tr><tr><td>Federal</td><td>157.8</td><td>99.0</td><td>165.5</td></tr><tr><td>State</td><td>23.9</td><td>(16.8)</td><td>4.9</td></tr><tr><td>Production tax credits</td><td>(24.8)</td><td>(27.1)</td><td>(11.2)</td></tr><tr><td>Investment tax credits</td><td>(1.7)</td><td>(1.8)</td><td>(1.8)</td></tr><tr><td>Provision recorded as a change in uncertain tax positions:</td><td></td><td></td><td></td></tr><tr><td>Current</td><td>8.0</td><td>16.3</td><td>(84.0)</td></tr><tr><td>Deferred</td><td>(7.6)</td><td>(38.3)</td><td>59.6</td></tr><tr><td>Provision recorded as a change in accrued interest</td><td>(0.2)</td><td>(0.5)</td><td>(3.0)</td></tr><tr><td></td><td>$89.4</td><td>$69.2</td><td>$147.7</td></tr></table>

Income Tax Rates - The overall income tax rates shown in the following table were computed by dividing income taxes by income from continuing operations before income taxes.

<table><tr><td></td><td>2012</td><td>2011</td><td>2010</td></tr><tr><td>Statutory federal income tax rate</td><td>35.0%</td><td>35.0%</td><td>35.0%</td></tr><tr><td>State income taxes, net of federal benefits</td><td>5.7</td><td>4.6</td><td>4.8</td></tr><tr><td>State apportionment change due to announced sale of RMT</td><td>3.5</td><td>—</td><td>—</td></tr><tr><td>IPL&#x27;s electric tax benefit rider</td><td>(11.2)</td><td>(8.8)</td><td>—</td></tr><tr><td>Production tax credits</td><td>(5.8)</td><td>(6.6)</td><td>(2.4)</td></tr><tr><td>Effect of rate-making on property-related differences</td><td>(5.0)</td><td>(2.0)</td><td>(4.2)</td></tr><tr><td>Adjustment of prior period taxes</td><td>—</td><td>0.2</td><td>0.3</td></tr><tr><td>Wisconsin tax legislation</td><td>—</td><td>(4.6)</td><td>—</td></tr><tr><td>Federal Health Care Legislation</td><td>—</td><td>—</td><td>1.6</td></tr><tr><td>Other items, net</td><td>(1.4)</td><td>(0.9)</td><td>(2.8)</td></tr><tr><td>Overall income tax rate</td><td>20.8%</td><td>16.9%</td><td>32.3%</td></tr></table>

State apportionment change due to announced sale of RMT - Alliant Energy utilizes state apportionment projections to record its deferred tax assets and liabilities each reporting period. Deferred tax assets and liabilities for temporary differences between the tax basis of assets and liabilities and the amounts reported in the consolidated financial statements are recorded utilizing currently enacted tax rates and estimates of future state apportionment rates expected to be in effect at the time the temporary differences reverse. These state apportionment projections are most significantly impacted by the estimated amount of revenues expected in the future from each state jurisdiction for Alliant Energy’s consolidated tax group, including both its regulated operations and its non-regulated operations. In the first quarter of 2012, Alliant Energy recorded $15 million of deferred income tax expense due to changes in state apportionment projections caused by the planned sale of Alliant Energy’s RMT business.



IPL’s electric tax benefit rider - In January 2011, the IUB approved an electric tax benefit rider proposed by IPL, which utilizes tax-related regulatory liabilities to credit bills of Iowa retail electric customers beginning in February 2011 to help offset the impact of recent rate increases on such customers. These regulatory liabilities are related to tax benefits from tax accounting method changes for repairs expenditures, allocation of mixed service costs and allocation of insurance proceeds from the floods in 2008. Alliant Energy’s effective income tax rates in 2012 and 2011 include the impact of reducing income tax expense with offsetting reductions to regulatory liabilities as a result of implementing the electric tax benefit rider. Refer to Note 1(b) for additional details on IPL’s electric tax benefit rider.

Production tax credits - Alliant Energy earns production tax credits from the wind projects it owns and operates. Production tax credits are based on the electricity generated by each wind project during the first 10 years of operation. Alliant Energy has three wind projects that are currently generating production tax credits: WPL's 68 MW Cedar Ridge wind project, which began generating electricity in late 2008; IPL's 200 MW Whispering Willow - East wind project, which began generating electricity in late 2009; and WPL's 200 MW Bent Tree - Phase I wind project, which began generating electricity in late 2010. Production tax credits (net of state tax impacts) resulting from these wind projects were as follows (in millions):

<table><tr><td></td><td>2012</td><td>2011</td><td>2010</td></tr><tr><td>Whispering Willow - East (IPL)</td><td>$12.5</td><td>$12.3</td><td>$7.7</td></tr><tr><td>Bent Tree - Phase I (WPL) (a)</td><td>9.3</td><td>9.3</td><td>1.2</td></tr><tr><td>Cedar Ridge (WPL)</td><td>4.0</td><td>4.5</td><td>3.3</td></tr><tr><td></td><td>25.8</td><td>26.1</td><td>12.2</td></tr><tr><td>Deferral (a)</td><td>(1.0)</td><td>1.0</td><td>(1.0)</td></tr><tr><td></td><td>$24.8</td><td>$27.1</td><td>$11.2</td></tr></table>

(a) In 2010 and 2012, WPL deferred the retail portion of the production tax credits generated in 2010 from its Bent Tree - Phase I wind project pursuant to orders issued by the PSCW in December 2009 and July 2012, respectively. As a result of a regulatory assessment completed in 2011, the retail portion of the production tax credit deferral recorded in 2010 was reversed.

Effect of rate-making on property-related differences - Alliant Energy’s income tax expense and benefits are impacted by certain property-related differences at IPL for which deferred tax is not recognized in the income statement pursuant to Iowa rate-making principles. In 2012, the primary factor contributing to the increase in tax benefits recorded for the effect of rate-making on property-related differences is related to repair expenditures and the allocation of mixed service costs at IPL. The Internal Revenue Service (IRS) audit process was completed for allocation of mixed service costs with the income tax return for calendar year 2010 and repairs expenditures with the income tax return for calendar year 2011. The tax benefits and expenses from the change in accounting method for allocation of mixed service costs subsequent to 2010 and the tax benefits and expenses from the change in accounting method for repairs expenditures subsequent to 2011 are being recorded consistent with general Iowa rate-making principles, which resulted in an increase in tax benefits for Alliant Energy in 2012 of approximately $13 million. In 2011, a primary factor contributing to the decrease in tax benefits recorded for the effect of rate-making on property-related differences is related to a decrease in tax depreciation for IPL’s Whispering Willow - East wind project, which was placed into service in late 2009. The net income tax benefits related to tax depreciation for IPL’s Whispering Willow - East wind project were $3 million, $6 million and $12 million in 2012, 2011 and 2010, respectively.

Adjustment of prior period taxes - In 2010, the IRS completed the audits of Alliant Energy’s U.S. federal income tax returns for calendar years 2005 through 2008. The net impact of the completion of these audits and reversal of reserves for uncertain tax positions related to those audits resulted in Alliant Energy recognizing net income tax benefits in 2010 of $7 million. These income tax benefits decreased Alliant Energy’s effective tax rate by 1.5% and are included, along with other adjustments, in “Adjustment of prior period taxes” in the 2010 column of the above table.

Wisconsin tax legislation - In 2011, the 2011 Wisconsin Act 32 (Act 32) was enacted. The most significant provision of Act 32 for Alliant Energy authorizes combined groups to share net operating loss carryforwards that were incurred by group members prior to January 1, 2009 and utilize these shared net operating losses over 20 years beginning after December 31, 2011. Based on this provision of Act 32, Alliant Energy anticipated its Wisconsin combined group would be able to fully utilize $368 million of Wisconsin net operating losses incurred by Alliant Energy and Resources prior to January 1, 2009 to offset future taxable income and therefore reversed previously recorded deferred tax asset valuation allowances related to state net operating loss carryforwards of $19 million in 2011.



Federal health care legislation - In 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 Alliant Energy 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 December 31, 2009 required Alliant Energy to record deferred income tax expense of $7 million in 2010.

Deferred Tax Assets and Liabilities - The deferred income tax (assets) and liabilities included on the Consolidated Balance Sheets at December 31 arise from the following temporary differences (in millions):

<table><tr><td rowspan="2"></td><td colspan="3">2012</td><td colspan="3">2011</td></tr><tr><td>Deferred Tax Assets</td><td>Deferred Tax Liabilities</td><td>Net</td><td>Deferred Tax Assets</td><td>Deferred Tax Liabilities</td><td>Net</td></tr><tr><td>Property</td><td>$—</td><td>$2,143.8</td><td>$2,143.8</td><td>$—</td><td>$1,926.4</td><td>$1,926.4</td></tr><tr><td>Investment in American Transmission Company (ATC)</td><td>—</td><td>104.3</td><td>104.3</td><td>—</td><td>93.8</td><td>93.8</td></tr><tr><td>Deferred portion of tax gain on IPL&#x27;s electric transmission assets sale</td><td>—</td><td>50.7</td><td>50.7</td><td>—</td><td>75.5</td><td>75.5</td></tr><tr><td>Net operating losses carryforward - state</td><td>(46.8)</td><td>—</td><td>(46.8)</td><td>(39.9)</td><td>—</td><td>(39.9)</td></tr><tr><td>Federal credit carryforward</td><td>(133.8)</td><td>—</td><td>(133.8)</td><td>(107.4)</td><td>—</td><td>(107.4)</td></tr><tr><td>Regulatory liability - IPL&#x27;s tax benefit rider</td><td>(144.6)</td><td>—</td><td>(144.6)</td><td>(140.6)</td><td>—</td><td>(140.6)</td></tr><tr><td>Net operating losses carryforward - federal</td><td>(306.0)</td><td>—</td><td>(306.0)</td><td>(336.1)</td><td>—</td><td>(336.1)</td></tr><tr><td>Other</td><td>(113.7)</td><td>208.2</td><td>94.5</td><td>(128.2)</td><td>224.7</td><td>96.5</td></tr><tr><td>Subtotal</td><td>(744.9)</td><td>2,507.0</td><td>1,762.1</td><td>(752.2)</td><td>2,320.4</td><td>1,568.2</td></tr><tr><td>Valuation allowances</td><td>1.9</td><td>—</td><td>1.9</td><td>1.2</td><td>—</td><td>1.2</td></tr><tr><td></td><td>($743.0)</td><td>$2,507.0</td><td>$1,764.0</td><td>($751.0)</td><td>$2,320.4</td><td>$1,569.4</td></tr></table>

<table><tr><td>Other current assets</td><td>2012</td><td>2011</td></tr><tr><td>Deferred income taxes</td><td>($170.2)</td><td>($22.8)</td></tr><tr><td>Total deferred tax liabilities</td><td>1,934.2</td><td>1,592.2</td></tr><tr><td></td><td>$1,764.0</td><td>$1,569.4</td></tr></table>

## Property -

Bonus depreciation deductions - In 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 provisions of the SBJA and the Act for Alliant Energy are related to the extension of bonus depreciation deductions for certain expenditures for property that are placed in service through December 31, 2012. Based on capital projects expected to be placed into service in 2012, Alliant Energy currently estimates its total bonus depreciation deductions to be claimed in its 2012 federal income tax return will be approximately $284 million ($67 million for IPL, $117 million for WPL and $100 million for Resources).

Deferred portion of tax gain on IPL’s electric transmission asset sale - Alliant Energy recognized a $527 million taxable gain upon the sale of IPL’s electric transmission assets in 2007. Under the provisions of the 2005 Energy Tax Act, Alliant Energy deferred its income tax obligation associated with the taxable gain over an eight-year period, with one-eighth of the income tax obligation recognized in each of the years of 2007 through 2014.

Carryforwards - At December 31, 2012, Alliant Energy’s tax carryforwards and associated deferred tax assets and expiration dates were estimated as follows (in millions):

<table><tr><td></td><td>Tax Carryforwards</td><td>Deferred Tax Assets</td><td>Earliest Expiration Date</td></tr><tr><td>Federal net operating losses</td><td>$892</td><td>$306</td><td>2029</td></tr><tr><td>State net operating losses</td><td>871</td><td>47</td><td>2014</td></tr><tr><td>Federal tax credits</td><td>136</td><td>134</td><td>2022</td></tr><tr><td></td><td></td><td>$487</td><td></td></tr></table>

At December 31, 2012, Alliant Energy’s state net operating losses carryforwards had expiration dates ranging from 2014 to 2032 with 99% expiring after 2020.



Uncertain Tax Positions - A reconciliation of the beginning and ending amounts of uncertain tax positions, excluding interest, is as follows (in millions):

<table><tr><td></td><td>2012</td><td>2011</td><td>2010</td></tr><tr><td>Balance, January 1</td><td>$23.5</td><td>$66.7</td><td>$101.7</td></tr><tr><td>Additions based on tax positions related to the current year</td><td>0.7</td><td>0.7</td><td>3.8</td></tr><tr><td>Additions for tax positions of prior years (a)</td><td>—</td><td>—</td><td>9.1</td></tr><tr><td>Reductions for tax positions of prior years (b)</td><td>(23.5)</td><td>(43.9)</td><td>(31.8)</td></tr><tr><td>Settlements with taxing authorities</td><td>—</td><td>—</td><td>(16.1)</td></tr><tr><td>Balance, December 31 (c)</td><td>$0.7</td><td>$23.5</td><td>$66.7</td></tr></table>

(a) The additions for tax positions of prior years were related to positions taken by Alliant Energy on its federal and state tax returns related to the capitalization and dispositions of property.

(b) In 2012, the reductions for tax positions of prior years were due to the finalization of Alliant Energy’s federal income tax return audits for calendar years 2005 through 2009. In 2011, the reductions for tax positions of prior years were related to guidance published by the IRS clarifying the treatment of repair expenditures for electric distribution property. In 2010, the reductions of tax positions of prior years were primarily related to deductions taken by Alliant Energy on its federal and state tax returns that were settled under audit for amounts less than the reductions of tax positions recorded.

(c) At December 31, 2012 and 2011, $0 and $10 million, respectively, of uncertain tax positions balances included amounts recorded in regulatory liability accounts.

At December 31, 2012, 2011 and 2010, there were no penalties accrued related to uncertain tax positions. Additional information regarding uncertain tax positions at December 31 is as follows (in millions):

<table><tr><td></td><td>2012</td><td>2011</td><td>2010</td></tr><tr><td>Tax positions favorably impacting future effective tax rates for continuing operations</td><td>$0.7</td><td>$—</td><td>$—</td></tr><tr><td>Interest accrued</td><td>—</td><td>0.4</td><td>0.7</td></tr></table>

Open tax years - Tax years that remain subject to the statute of limitations in the major jurisdictions are as follows:

<table><tr><td>Consolidated federal income tax returns (a)</td><td>2005 - 2011</td></tr><tr><td>Consolidated Iowa income tax returns (b)</td><td>2005 - 2011</td></tr><tr><td>Wisconsin income tax returns</td><td>2005 - 2008</td></tr><tr><td>Wisconsin combined tax returns</td><td>2009 - 2011</td></tr></table>

(a) 2005 through 2010 are effectively settled. The statute of limitations for 2005 through 2008 has been extended to June 30, 2013. The statute of limitations for 2009 through 2011 expires three years from the extended due date of the federal tax return.

(b) 2005 through 2008 are open for federal audit adjustments only.

Reasonably possible changes to uncertain tax positions in 2013 - In 2013, statutes of limitations will expire for Alliant Energy’s tax returns in multiple state jurisdictions. The expiration of the statutes of limitations will not have any impact on Alliant Energy’s uncertain tax positions in 2013. It is reasonably possible that Alliant Energy could have material changes to its unrecognized tax benefits during the next 12 months as a result of the expected issuance in 2013 of revenue procedures clarifying the treatment of repair expenditures for electric generation and gas distribution property. An estimate of the expected changes during the next 12 months cannot be determined at this time.

## (6) BENEFIT PLANS

(a) Pension and Other Postretirement Benefits Plans - Alliant Energy provides retirement benefits to substantially all of its employees through various qualified and non-qualified non-contributory defined benefit pension plans, and/or through defined contribution plans (including 401(k) savings plans). Alliant Energy’s qualified and non-qualified 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 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. Alliant Energy also provides certain defined benefit postretirement health care and life benefits to eligible retirees. In general, the retiree health care plans consist of fixed benefit subsidy structures and the retiree life insurance plans are non-contributory.



Assumptions - The assumptions for defined benefit pension and other postretirement benefits plans at the measurement date of December 31 were as follows (Not Applicable (N/A)):

<table><tr><td rowspan="2"></td><td colspan="3">Defined Benefit Pension Plans</td><td colspan="3">Other Postretirement Benefits Plans</td></tr><tr><td>2012</td><td>2011</td><td>2010</td><td>2012</td><td>2011</td><td>2010</td></tr><tr><td>Discount rate for benefit obligations</td><td>4.11%</td><td>4.86%</td><td>5.56%</td><td>3.82%</td><td>4.60%</td><td>5.25%</td></tr><tr><td>Discount rate for net periodic cost</td><td>4.86%</td><td>5.56%</td><td>5.80%</td><td>4.60%</td><td>5.25%</td><td>5.55%</td></tr><tr><td>Expected rate of return on plan assets</td><td>7.90%</td><td>7.90%</td><td>8.00%</td><td>7.50%</td><td>7.00%</td><td>6.90%</td></tr><tr><td>Rate of compensation increase</td><td>3.50% - 4.50%</td><td>3.50% - 4.50%</td><td>3.50% -4.50%</td><td>3.50%</td><td>3.50%</td><td>3.50%</td></tr><tr><td>Medical cost trend on covered charges:</td><td></td><td></td><td></td><td></td><td></td><td></td></tr><tr><td>Initial trend rate (end of year)</td><td>N/A</td><td>N/A</td><td>N/A</td><td>7.50%</td><td>8.00%</td><td>7.00%</td></tr><tr><td>Ultimate trend rate</td><td>N/A</td><td>N/A</td><td>N/A</td><td>5.00%</td><td>5.00%</td><td>5.00%</td></tr></table>

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. Alliant Energy uses a forward-looking building blocks approach and also review historical returns, survey information and capital market information to support the expected rate of return on plan assets assumption. Refer to “Investment Policy and Strategy for Plan Assets” below for additional information related to Alliant Energy’s investment policy and strategy and mix of assets 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 2012, holding all other assumptions constant, would have the following effects (in millions):

<table><tr><td></td><td>1% Increase</td><td>1% Decrease</td></tr><tr><td>Effect on total of service and interest cost components</td><td>$0.4</td><td>($0.4)</td></tr><tr><td>Effect on postretirement benefit obligation</td><td>2.6</td><td>(2.4)</td></tr></table>

Net Periodic Benefit Costs - The components of net periodic benefit costs for Alliant Energy’s sponsored defined benefit pension and other postretirement benefits plans were as follows (in millions):

<table><tr><td rowspan="2"></td><td colspan="3">Defined Benefit Pension Plans</td><td colspan="3">Other Postretirement Benefits Plans (a)</td></tr><tr><td>2012</td><td>2011</td><td>2010</td><td>2012</td><td>2011</td><td>2010</td></tr><tr><td>Service cost</td><td>$13.5</td><td>$11.4</td><td>$11.9</td><td>$6.9</td><td>$7.0</td><td>$9.3</td></tr><tr><td>Interest cost</td><td>51.6</td><td>52.0</td><td>52.3</td><td>10.2</td><td>12.3</td><td>14.9</td></tr><tr><td>Expected return on plan assets (b)</td><td>(68.8)</td><td>(63.8)</td><td>(62.1)</td><td>(7.5)</td><td>(7.9)</td><td>(7.7)</td></tr><tr><td>Amortization of (c):</td><td></td><td></td><td></td><td></td><td></td><td></td></tr><tr><td>Transition obligation</td><td>—</td><td>—</td><td>—</td><td>—</td><td>—</td><td>0.1</td></tr><tr><td>Prior service cost (credit)</td><td>0.3</td><td>0.7</td><td>0.9</td><td>(12.0)</td><td>(10.0)</td><td>(2.4)</td></tr><tr><td>Actuarial loss</td><td>33.3</td><td>21.1</td><td>23.8</td><td>6.3</td><td>5.3</td><td>7.4</td></tr><tr><td>Additional benefit costs (d)</td><td>0.1</td><td>10.2</td><td>—</td><td>—</td><td>—</td><td>—</td></tr><tr><td>Settlement losses (e)</td><td>5.4</td><td>1.1</td><td>1.4</td><td>—</td><td>—</td><td>—</td></tr><tr><td></td><td>$35.4</td><td>$32.7</td><td>$28.2</td><td>$3.9</td><td>$6.7</td><td>$21.6</td></tr></table>

(a) In 2011, Alliant Energy amended its defined benefit postretirement health care plans resulting in a revision to the method and level of coverage provided for participants more than 65 years of age. This amendment was determined to be a significant event, which required Alliant Energy to remeasure its defined benefit postretirement health care plans in 2011. The amendment resulted in a decrease in Alliant Energy’s postretirement benefit obligations of $55 million in 2011 with the impact of the remeasurement on net periodic benefit costs being recognized prospectively from the remeasurement date. The impact of the remeasurement decreased Alliant Energy’s net periodic benefit costs by $11.3 million in 2011. The discount rate used for the remeasurement was 5.20%. All other assumptions used for the remeasurement were consistent with the measurement assumptions used at December 31, 2010.

(b) 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.



(c) Unrecognized net actuarial gains or losses in excess of 10% of the greater of the plans' benefit obligations or assets are amortized over the average future service lives of plan participants, except for the Alliant Energy Cash Balance Pension Plan (Cash Balance Plan) where gains or losses outside the 10% threshold are amortized over the time period the participants are expected to receive benefits. Unrecognized prior service costs (credits) for the postretirement benefits plans are amortized over the average future service period to full eligibility of the participants of each plan.

(d) Alliant Energy reached an agreement with the IRS, which resulted in a favorable determination letter for the Cash Balance Plan in 2011. The agreement with the IRS required Alliant Energy to amend the Cash Balance Plan, which was completed in 2011 resulting in aggregate additional benefits of $10.2 million paid by Alliant Energy to certain former participants in the Cash Balance Plan in 2011. Alliant Energy recognized $10.2 million of additional benefits costs in 2011 related to these benefits. Refer to Note 13(c) for additional information regarding the Cash Balance Plan.

(e) Settlement losses related to payments made to retired executives of Alliant Energy.

The estimated amortization from “Regulatory assets,” “Regulatory liabilities” and AOCL on the Consolidated Balance Sheet into net periodic benefit cost in 2013 is as follows (in millions):

<table><tr><td></td><td>Defined Benefit Pension Plans</td><td>Other Postretirement Benefits Plans</td></tr><tr><td>Actuarial loss</td><td>$36.2</td><td>$4.9</td></tr><tr><td>Prior service cost (credit)</td><td>0.2</td><td>(11.9)</td></tr><tr><td></td><td>$36.4</td><td>($7.0)</td></tr></table>

Alliant Energy’s net periodic benefit costs are primarily included in “Utility - Other operation and maintenance” in the Consolidated Statements of Income.

Benefit Plan Assets and Obligations - A reconciliation of the funded status of Alliant Energy’s qualified and non-qualified defined benefit pension and other postretirement benefits plans to the amounts recognized on the Consolidated Balance Sheets at December 31 was as follows (in millions):

<table><tr><td rowspan="2"></td><td colspan="2">Defined Benefit Pension Plans</td><td colspan="2">Other Postretirement Benefits Plans</td></tr><tr><td>2012</td><td>2011</td><td>2012</td><td>2011</td></tr><tr><td>Change in projected benefit obligation:</td><td></td><td></td><td></td><td></td></tr><tr><td>Net projected benefit obligation at January 1</td><td>$1,081.4</td><td>$953.0</td><td>$224.2</td><td>$274.9</td></tr><tr><td>Service cost</td><td>13.5</td><td>11.4</td><td>6.9</td><td>7.0</td></tr><tr><td>Interest cost</td><td>51.6</td><td>52.0</td><td>10.2</td><td>12.3</td></tr><tr><td>Plan participants&#x27; contributions</td><td>—</td><td>—</td><td>2.7</td><td>6.4</td></tr><tr><td>Plan amendments (a)</td><td>—</td><td>10.2</td><td>—</td><td>(56.6)</td></tr><tr><td>Additional benefit costs</td><td>0.1</td><td>—</td><td>—</td><td>—</td></tr><tr><td>Actuarial (gain) loss</td><td>135.4</td><td>126.2</td><td>(1.6)</td><td>(0.8)</td></tr><tr><td>Early Retiree Reinsurance Program proceeds</td><td>—</td><td>—</td><td>—</td><td>0.6</td></tr><tr><td>Gross benefits paid</td><td>(74.5)</td><td>(71.4)</td><td>(19.2)</td><td>(20.8)</td></tr><tr><td>Federal subsidy on other postretirement benefits paid</td><td>—</td><td>—</td><td>—</td><td>1.2</td></tr><tr><td>Net projected benefit obligation at December 31</td><td>1,207.5</td><td>1,081.4</td><td>223.2</td><td>224.2</td></tr><tr><td>Change in plan assets:</td><td></td><td></td><td></td><td></td></tr><tr><td>Fair value of plan assets at January 1</td><td>897.4</td><td>823.0</td><td>120.4</td><td>122.7</td></tr><tr><td>Actual return on plan assets</td><td>126.9</td><td>28.9</td><td>14.3</td><td>2.6</td></tr><tr><td>Employer contributions</td><td>15.8</td><td>116.9</td><td>4.9</td><td>9.5</td></tr><tr><td>Plan participants&#x27; contributions</td><td>—</td><td>—</td><td>2.7</td><td>6.4</td></tr><tr><td>Gross benefits paid</td><td>(74.5)</td><td>(71.4)</td><td>(19.2)</td><td>(20.8)</td></tr><tr><td>Fair value of plan assets at December 31</td><td>965.6</td><td>897.4</td><td>123.1</td><td>120.4</td></tr><tr><td>Under funded status at December 31</td><td>($241.9)</td><td>($184.0)</td><td>($100.1)</td><td>($103.8)</td></tr></table>



<table><tr><td rowspan="2"></td><td colspan="2">Defined Benefit Pension Plans</td><td colspan="2">Other Postretirement Benefits Plans</td></tr><tr><td>2012</td><td>2011</td><td>2012</td><td>2011</td></tr><tr><td>Amounts recognized on the Consolidated Balance Sheets consist of:</td><td></td><td></td><td></td><td></td></tr><tr><td>Non-current assets</td><td>$—</td><td>$—</td><td>$3.5</td><td>$1.3</td></tr><tr><td>Other current liabilities</td><td>(2.4)</td><td>(4.6)</td><td>(2.8)</td><td>—</td></tr><tr><td>Pension and other benefit obligations</td><td>(239.5)</td><td>(179.4)</td><td>(100.8)</td><td>(105.1)</td></tr><tr><td>Net amount recognized at December 31</td><td>($241.9)</td><td>($184.0)</td><td>($100.1)</td><td>($103.8)</td></tr><tr><td>Amounts recognized in Regulatory Assets, Regulatory Liabilities and AOCL consist of (b):</td><td></td><td></td><td></td><td></td></tr><tr><td>Net actuarial loss</td><td>$533.4</td><td>$494.8</td><td>$62.1</td><td>$76.7</td></tr><tr><td>Prior service credit</td><td>(7.2)</td><td>(6.9)</td><td>(40.5)</td><td>(52.5)</td></tr><tr><td></td><td>$526.2</td><td>$487.9</td><td>$21.6</td><td>$24.2</td></tr></table>

(a) Refer to “Net Periodic Benefit Costs” above for additional information regarding plan amendments to the defined benefit pension and other postretirement benefits plans in 2011.

(b) Refer to Note 1(b) and the Consolidated Statements of Common Equity for amounts recognized in “Regulatory assets” and “AOCL,” respectively, on the Consolidated Balance Sheets. At December 31, 2012 and 2011, $2.7 million and $3.3 million, respectively, of regulatory liabilities were recognized related to Alliant Energy’s other postretirement benefits plans.

Included in the following table are accumulated benefit obligations, aggregate amounts applicable to defined benefit pension and other postretirement benefits plans with accumulated benefit obligations in excess of plan assets, as well as defined benefit pension plans with projected benefit obligations in excess of plan assets as of the December 31 measurement date (Not Applicable (N/A); in millions):

<table><tr><td rowspan="2"></td><td colspan="2">Defined Benefit Pension Plans</td><td colspan="2">Other Postretirement Benefits Plans</td></tr><tr><td>2012</td><td>2011</td><td>2012</td><td>2011</td></tr><tr><td>Accumulated benefit obligations</td><td>$1,155.5</td><td>$1,029.4</td><td>$223.2</td><td>$224.2</td></tr><tr><td>Plans with accumulated benefit obligations in excess of plan assets:</td><td></td><td></td><td></td><td></td></tr><tr><td>Accumulated benefit obligations</td><td>1,155.5</td><td>1,029.4</td><td>223.2</td><td>224.2</td></tr><tr><td>Fair value of plan assets</td><td>965.6</td><td>897.4</td><td>123.1</td><td>120.4</td></tr><tr><td>Plans with projected benefit obligations in excess of plan assets:</td><td></td><td></td><td></td><td></td></tr><tr><td>Projected benefit obligations</td><td>1,207.5</td><td>1,081.4</td><td>N/A</td><td>N/A</td></tr><tr><td>Fair value of plan assets</td><td>965.6</td><td>897.4</td><td>N/A</td><td>N/A</td></tr></table>

Estimated Future Employer Contributions and Benefit Payments - Alliant Energy estimates that funding for the qualified defined benefit pension, non-qualified defined benefit pension and other postretirement benefits plans during 2013 will be $0, $2.4 million and $3.0 million, respectively. Expected benefit payments, and the directly assigned qualified and non-qualified defined benefit pension benefits amounts, which reflect expected future service, as appropriate, are as follows (in millions):

<table><tr><td></td><td>2013</td><td>2014</td><td>2015</td><td>2016</td><td>2017</td><td>2018 - 2022</td></tr><tr><td>Qualified and non-qualified defined benefit pension benefits</td><td>$61.9</td><td>$64.7</td><td>$68.5</td><td>$66.6</td><td>$69.2</td><td>$374.1</td></tr><tr><td>Other postretirement benefits</td><td>16.6</td><td>16.2</td><td>16.3</td><td>16.4</td><td>16.6</td><td>84.2</td></tr><tr><td></td><td>$78.5</td><td>$80.9</td><td>$84.8</td><td>$83.0</td><td>$85.8</td><td>$458.3</td></tr></table>

Investment Policy and Strategy for Plan Assets - Alliant Energy’s investment policies and its strategies employed with respect to assets of defined benefit pension and other postretirement benefits plans are to combine both preservation of principal and prudent and reasonable risk-taking to protect the integrity of plan assets, in order to meet the obligations to plan participants while minimizing benefit costs over the long term. It is recognized that risk and volatility are present with all types of investments. However, risk is mitigated at the total fund level through diversification by asset class including both U.S. and international equity exposure, the number of individual investments, and sector and industry limits.

Defined Benefit Pension Plans Assets - For assets of defined benefit pension plans, the mix among asset classes is controlled by long-term asset allocation targets. 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 of meeting obligations to plan participants and minimizing benefit costs over the long-term, the defined benefit



pension plans have a long-term investment posture more heavily weighted towards equity holdings. The asset allocation is monitored regularly and appropriate steps are taken as needed to rebalance the assets within the prescribed ranges. Alliant Energy also uses an overlay management service to help maintain target allocations and liquidity needs. The overlay manager is authorized to use derivative financial instruments to facilitate this service. Prohibited investment vehicles include, but may not be limited to, direct ownership of real estate, margin trading, oil and gas limited partnerships and securities of the managers' firms or affiliate firms. If the investment vehicle is a commingled account or mutual fund, it is not possible to place restrictions on any aspect of fund management. At December 31, 2012, the current target ranges and actual allocations for Alliant Energy's defined benefit pension plan assets were as follows:

<table><tr><td></td><td>Target Range Allocation</td><td>Actual Allocation</td></tr><tr><td>Cash and equivalents</td><td>—% - 5%</td><td>4%</td></tr><tr><td>Equity securities:</td><td></td><td></td></tr><tr><td>U.S. large cap core</td><td>10% - 20%</td><td>13%</td></tr><tr><td>U.S. large cap value</td><td>6% - 16%</td><td>11%</td></tr><tr><td>U.S. large cap growth</td><td>6% - 16%</td><td>11%</td></tr><tr><td>U.S. small cap value</td><td>—% - 6%</td><td>3%</td></tr><tr><td>U.S. small cap growth</td><td>—% - 6%</td><td>3%</td></tr><tr><td>International - developed markets</td><td>11% - 23%</td><td>16%</td></tr><tr><td>International - emerging markets</td><td>—% - 8%</td><td>4%</td></tr><tr><td>Global asset allocation securities</td><td>5% - 15%</td><td>10%</td></tr><tr><td>Fixed income securities</td><td>15% - 35%</td><td>25%</td></tr></table>

Other Postretirement Benefits Plans Assets - 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. For VEBA trusts with assets greater than $5 million, the mix among asset classes is controlled by long-term allocation targets. The asset allocation is monitored regularly and appropriate steps are taken as needed to rebalance the assets within the prescribed ranges. Prohibited investment vehicles include, but may not be limited to, direct ownership of real estate, margin trading, oil and gas limited partnerships and securities of the managers' firms or affiliate firms. If the investment vehicle is a commingled account or mutual fund, it is not possible to place restrictions on any aspect of fund management. At December 31, 2012, the current target ranges and actual allocations for Alliant Energy's VEBA trusts with assets greater than $5 million were as follows:

<table><tr><td></td><td>Target Range Allocation</td><td>Actual Allocation</td></tr><tr><td>Cash and equivalents</td><td>—% - 5%</td><td>2%</td></tr><tr><td>Equity securities:</td><td></td><td></td></tr><tr><td>Domestic</td><td>25% - 45%</td><td>34%</td></tr><tr><td>International</td><td>10% - 20%</td><td>15%</td></tr><tr><td>Global asset allocation securities</td><td>20% - 40%</td><td>29%</td></tr><tr><td>Fixed income securities</td><td>10% - 30%</td><td>20%</td></tr></table>

Securities Lending Program - Alliant Energy has a securities lending program with a third-party agent that allows the agent to lend certain securities from its defined benefit pension and other postretirement benefits plans to selected entities against receipt of collateral (in the form of cash, government and agency securities or letters of credit) as provided for and determined in accordance with its securities lending agency agreement. Initial collateral levels are no less than 100% of the market value of loans to non-affiliated borrowers of U.S. government securities; 102% of the market value of loans to affiliated borrowers of U.S. government securities; 102% of the market value of loans on U.S. corporate bonds and U.S. equity securities; 105% of the market value of loans on non-U.S. securities; and 102% of the market value of loans on all other securities. Refer to “Fair Value Measurements” below for details of 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 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. Alliant Energy’s investments in equity and fixed income securities held in registered investment companies and directly held equity securities are valued at the closing price reported in the active market in which the securities are traded.

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. Alliant Energy’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. Alliant Energy’s investments in equity and fixed income securities 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 within its 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. Alliant Energy’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 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 indicative of net realizable value or reflective of future fair values. Furthermore, while Alliant Energy believes its valuation methods are appropriate and consistent with other market participants, the use of different methodologies or assumptions to determine the fair value of certain financial instruments could result in a different fair value measurement at the reporting date.

At December 31, the fair values of qualified and non-qualified defined benefit pension plans assets by asset category and fair value hierarchy level were as follows (in millions):

<table><tr><td rowspan="2"></td><td colspan="4">2012</td><td colspan="4">2011</td></tr><tr><td>Fair Value</td><td>Level 1</td><td>Level 2</td><td>Level 3</td><td>Fair Value</td><td>Level 1</td><td>Level 2</td><td>Level 3</td></tr><tr><td>Cash and equivalents</td><td>$43.9</td><td>$—</td><td>$43.9</td><td>$—</td><td>$117.5</td><td>$117.5</td><td>$—</td><td>$—</td></tr><tr><td>Equity securities:</td><td></td><td></td><td></td><td></td><td></td><td></td><td></td><td></td></tr><tr><td>U.S. large cap core</td><td>129.0</td><td>129.0</td><td>—</td><td>—</td><td>110.7</td><td>110.7</td><td>—</td><td>—</td></tr><tr><td>U.S. large cap value</td><td>107.9</td><td>—</td><td>107.9</td><td>—</td><td>91.6</td><td>—</td><td>91.6</td><td>—</td></tr><tr><td>U.S. large cap growth</td><td>105.8</td><td>—</td><td>105.8</td><td>—</td><td>91.5</td><td>—</td><td>91.5</td><td>—</td></tr><tr><td>U.S. small cap value</td><td>30.4</td><td>—</td><td>30.4</td><td>—</td><td>25.7</td><td>—</td><td>25.7</td><td>—</td></tr><tr><td>U.S. small cap growth</td><td>25.0</td><td>25.0</td><td>—</td><td>—</td><td>21.7</td><td>21.7</td><td>—</td><td>—</td></tr><tr><td>International - developed markets</td><td>153.7</td><td>80.3</td><td>73.4</td><td>—</td><td>126.4</td><td>65.4</td><td>61.0</td><td>—</td></tr><tr><td>International - emerging markets</td><td>38.5</td><td>38.5</td><td>—</td><td>—</td><td>30.4</td><td>30.4</td><td>—</td><td>—</td></tr><tr><td>Global asset allocation securities</td><td>94.5</td><td>56.3</td><td>38.2</td><td>—</td><td>—</td><td>—</td><td>—</td><td>—</td></tr><tr><td>Fixed income securities:</td><td></td><td></td><td></td><td></td><td></td><td></td><td></td><td></td></tr><tr><td>Corporate bonds</td><td>30.7</td><td>—</td><td>30.7</td><td>—</td><td>57.1</td><td>—</td><td>57.1</td><td>—</td></tr><tr><td>Government and agency obligations</td><td>49.2</td><td>—</td><td>49.2</td><td>—</td><td>87.8</td><td>—</td><td>87.8</td><td>—</td></tr><tr><td>Fixed income funds</td><td>162.6</td><td>0.2</td><td>162.4</td><td>—</td><td>146.7</td><td>0.2</td><td>146.5</td><td>—</td></tr><tr><td>Securities lending invested collateral</td><td>4.4</td><td>—</td><td>2.9</td><td>1.5</td><td>9.3</td><td>4.7</td><td>2.8</td><td>1.8</td></tr><tr><td></td><td>975.6</td><td>$329.3</td><td>$644.8</td><td>$1.5</td><td>916.4</td><td>$350.6</td><td>$564.0</td><td>$1.8</td></tr><tr><td>Accrued investment income</td><td>0.6</td><td></td><td></td><td></td><td>1.0</td><td></td><td></td><td></td></tr><tr><td>Due to brokers, net (pending trades with brokers)</td><td>(1.5)</td><td></td><td></td><td></td><td>(4.7)</td><td></td><td></td><td></td></tr><tr><td>Due to borrowers for securities lending program</td><td>(9.1)</td><td></td><td></td><td></td><td>(15.3)</td><td></td><td></td><td></td></tr><tr><td>Total pension plan assets</td><td>$965.6</td><td></td><td></td><td></td><td>$897.4</td><td></td><td></td><td></td></tr></table>



At December 31, the fair values of other postretirement benefits plans assets by asset category and fair value hierarchy level were as follows (in millions):

<table><tr><td rowspan="2"></td><td colspan="4">2012</td><td colspan="4">2011</td></tr><tr><td>Fair Value</td><td>Level 1</td><td>Level 2</td><td>Level 3</td><td>Fair Value</td><td>Level 1</td><td>Level 2</td><td>Level 3</td></tr><tr><td>Cash and equivalents</td><td>$8.4</td><td>$—</td><td>$8.4</td><td>$—</td><td>$14.0</td><td>$14.0</td><td>$—</td><td>$—</td></tr><tr><td>Equity securities:</td><td></td><td></td><td></td><td></td><td></td><td></td><td></td><td></td></tr><tr><td>U.S. blend</td><td>32.9</td><td>32.9</td><td>—</td><td>—</td><td>—</td><td>—</td><td>—</td><td>—</td></tr><tr><td>U.S. large cap core</td><td>2.8</td><td>2.8</td><td>—</td><td>—</td><td>37.1</td><td>37.1</td><td>—</td><td>—</td></tr><tr><td>U.S. large cap value</td><td>2.4</td><td>—</td><td>2.4</td><td>—</td><td>2.4</td><td>—</td><td>2,4</td><td>—</td></tr><tr><td>U.S. large cap growth</td><td>2.3</td><td>—</td><td>2.3</td><td>—</td><td>2.4</td><td>—</td><td>2.4</td><td>—</td></tr><tr><td>U.S. mid cap core</td><td>—</td><td>—</td><td>—</td><td>—</td><td>17.8</td><td>17.8</td><td>—</td><td>—</td></tr><tr><td>U.S. small cap core</td><td>—</td><td>—</td><td>—</td><td>—</td><td>4.7</td><td>4.7</td><td>—</td><td>—</td></tr><tr><td>U.S. small cap value</td><td>0.7</td><td>—</td><td>0.7</td><td>—</td><td>0.6</td><td>—</td><td>0.6</td><td>—</td></tr><tr><td>U.S. small cap growth</td><td>0.6</td><td>0.6</td><td>—</td><td>—</td><td>0.5</td><td>0.5</td><td>—</td><td>—</td></tr><tr><td>International - blend</td><td>14.3</td><td>14.3</td><td>—</td><td>—</td><td>—</td><td>—</td><td>—</td><td>—</td></tr><tr><td>International - developed markets</td><td>3.4</td><td>1.8</td><td>1.6</td><td>—</td><td>3.3</td><td>1.7</td><td>1.6</td><td>—</td></tr><tr><td>International - emerging markets</td><td>0.8</td><td>0.8</td><td>—</td><td>—</td><td>0.8</td><td>0.8</td><td>—</td><td>—</td></tr><tr><td>Global asset allocation securities</td><td>30.4</td><td>29.6</td><td>0.8</td><td>—</td><td>—</td><td>—</td><td>—</td><td>—</td></tr><tr><td>Fixed income securities:</td><td></td><td></td><td></td><td></td><td></td><td></td><td></td><td></td></tr><tr><td>Corporate bonds</td><td>0.7</td><td>—</td><td>0.7</td><td>—</td><td>6.1</td><td>—</td><td>6.1</td><td>—</td></tr><tr><td>Government and agency obligations</td><td>1.1</td><td>—</td><td>1.1</td><td>—</td><td>5.6</td><td>—</td><td>5.6</td><td>—</td></tr><tr><td>Fixed income funds</td><td>22.4</td><td>18.3</td><td>3.6</td><td>—</td><td>25.4</td><td>21.6</td><td>3.8</td><td>—</td></tr><tr><td>Securities lending invested collateral</td><td>0.1</td><td>—</td><td>0.1</td><td>—</td><td>0.4</td><td>0.2</td><td>0.1</td><td>0.1</td></tr><tr><td></td><td>123.3</td><td>$101.6</td><td>$21.7</td><td>$—</td><td>121.1</td><td>$98.4</td><td>$22.6</td><td>$0.1</td></tr><tr><td>Accrued investment income</td><td>—</td><td></td><td></td><td></td><td>0.1</td><td></td><td></td><td></td></tr><tr><td>Due to brokers, net (pending trades with brokers)</td><td>—</td><td></td><td></td><td></td><td>(0.2)</td><td></td><td></td><td></td></tr><tr><td>Due to borrowers for securities lending program</td><td>(0.2)</td><td></td><td></td><td></td><td>(0.6)</td><td></td><td></td><td></td></tr><tr><td>Total other postretirement benefits plan assets</td><td>$123.1</td><td></td><td></td><td></td><td>$120.4</td><td></td><td></td><td></td></tr></table>

For the various defined benefit pension and other postretirement benefits plans, Alliant Energy common stock represented less than 1% of total plan assets at December 31, 2012 and 2011.

Cash Balance Plan - Alliant Energy’s defined benefit pension plans include the Cash Balance Plan that provides benefits for certain non-bargaining unit employees. The Cash Balance Plan has been closed to new hires since 2005. Effective 2008, Alliant Energy amended the Cash Balance Plan by discontinuing additional contributions into employees’ Cash Balance Plan accounts and increased its level of contributions to its 401(k) Savings Plan. In 2009, Alliant Energy amended the Cash Balance Plan by changing participants’ future interest credit formula to use the annual change in the consumer price index. This amendment provides participants an interest crediting rate that is 3% more than the annual change in the consumer price index. Refer to Note 13(c) for discussion of a class-action lawsuit filed against the Cash Balance Plan in 2008 and an agreement Alliant Energy reached with the IRS, which resulted in a favorable determination letter for the Cash Balance Plan in 2011.

401(k) Savings Plans - A significant number of Alliant Energy employees participate in defined contribution retirement plans (401(k) savings plans). Alliant Energy common stock represented 12.5% and 14.6% of total assets held in 401(k) savings plans at December 31, 2012 and 2011, respectively. In 2012, 2011 and 2010, Alliant Energy’s costs related to the 401(k) savings plans, which are partially based on the participants’ level of contribution, were $18.5 million, $18.4 million and $18.5 million, respectively.

(b) Equity-based Compensation Plans - In 2010, Alliant Energy’s shareowners approved the Alliant Energy 2010 Omnibus Incentive Plan (OIP), which permits the grant of stock options, restricted stock, restricted stock units, performance shares, performance units, and other stock-based awards and performance-based cash awards to key employees. At December 31, 2012, performance shares and restricted stock were outstanding and 4.2 million shares of Alliant Energy’s common stock remained available for grants 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 December 31, 2012, non-qualified stock options, restricted stock and performance shares were outstanding under the EIP and another predecessor plan under which new awards can no longer be granted. Alliant Energy satisfies payouts related to



equity awards under the OIP and EIP through the issuance of new shares of its common stock. Alliant Energy also has the Alliant Energy Director Long Term Incentive Plan (DLIP), which permits the grant of long-term performance-based awards, including performance units and restricted cash awards to certain key employees. At December 31, 2012, performance units and performance contingent cash awards were outstanding under the DLIP. There is no limit to the number of grants that can be made under the DLIP and Alliant Energy satisfies all payouts under the DLIP through cash.

A summary of compensation expense and the related income tax benefits recognized for share-based compensation awards was as follows (in millions):

<table><tr><td></td><td>2012</td><td>2011</td><td>2010</td></tr><tr><td>Compensation expense</td><td>$6.9</td><td>$10.1</td><td>$7.5</td></tr><tr><td>Income tax benefits</td><td>2.8</td><td>4.0</td><td>3.0</td></tr></table>

As of December 31, 2012, total unrecognized compensation cost related to share-based compensation awards was $6.1 million, which is expected to be recognized over a weighted average period of between 1 and 2 years. Share-based compensation expense is recognized on a straight-line basis over the requisite service periods and is primarily recorded in “Utility - Other operation and maintenance” in the Consolidated Statements of Income.

Performance Shares and Units - Payouts of performance shares and units to key employees are contingent upon achievement over 3-year periods of specified performance criteria, which currently include metrics of total shareowner return relative to investor-owned utility peer groups. Payouts of nonvested performance shares and units issued in 2012 are prorated at retirement, death or disability based on time worked during the first year of the performance period and achievement of the performance criteria. Upon achievement of the performance criteria, payouts of these performance shares and units to participants who terminate employment after the first year of the performance period due to retirement, death or disability are not prorated. Payouts of nonvested performance shares and units issued prior to 2012 are prorated at retirement, death, disability or involuntary termination without cause based on time worked during the full or entire performance period and achievement of the performance criteria. Participants’ nonvested performance shares and units are forfeited if the participant voluntarily leaves Alliant Energy or is terminated for cause. Nonvested performance shares and units do not have non-forfeitable rights to dividends when dividends are paid to common shareowners. Alliant Energy assumes it will make future payouts of its performance shares and units in cash; therefore, performance shares and units are accounted for as liability awards.

Performance Shares - Performance shares can be paid out in shares of Alliant Energy’s common stock, cash or a combination of cash and stock and are adjusted by a performance multiplier, which ranges from zero to 200% based on the performance criteria. A summary of the performance shares activity was as follows:

<table><tr><td rowspan="2"></td><td>2012</td><td>2011</td><td>2010</td></tr><tr><td>Shares (a)</td><td>Shares (a)</td><td>Shares (a)</td></tr><tr><td>Nonvested shares, January 1</td><td>236,979</td><td>234,518</td><td>256,579</td></tr><tr><td>Granted</td><td>45,612</td><td>64,217</td><td>72,487</td></tr><tr><td>Vested (b)</td><td>(111,980)</td><td>(57,838)</td><td>—</td></tr><tr><td>Forfeited (c)</td><td>(25,334)</td><td>(3,918)</td><td>(94,548)</td></tr><tr><td>Nonvested shares, December 31</td><td>145,277</td><td>236,979</td><td>234,518</td></tr></table>

(a) Share amounts represent the target number of performance shares. Each performance share’s value is based on the price of one share of Alliant Energy’s common stock at the end of the performance period. The actual number of shares that will be paid out upon vesting is dependent upon actual performance and may range from zero to 200% of the target number of shares.

(b) In 2012, 111,980 performance shares granted in 2009 vested at 162.5% of the target, resulting in payouts valued at $8.0 million, which consisted of a combination of cash and common stock (6,399 shares). In 2011, 57,838 performance shares granted in 2008 vested at 75% of the target, resulting in payouts valued at $1.6 million, which consisted of a combination of cash and common stock (1,387 shares).

(c) In 2010, 57,100 performance shares granted in 2007 were forfeited without payout because the specified performance criteria for such shares were not met. The remaining forfeitures during 2012, 2011 and 2010 were primarily caused by retirements and voluntary terminations of participants.



Performance Units - Performance units must be paid out in cash and are adjusted by a performance multiplier, which ranges from zero to 200% based on the performance criteria. A summary of the performance unit activity was as follows:

<table><tr><td rowspan="2"></td><td>2012</td><td>2011</td><td>2010</td></tr><tr><td>Units (a)</td><td>Units (a)</td><td>Units (a)</td></tr><tr><td>Nonvested units, January 1</td><td>42,996</td><td>23,128</td><td>—</td></tr><tr><td>Granted</td><td>24,686</td><td>23,975</td><td>23,795</td></tr><tr><td>Forfeited</td><td>(2,713)</td><td>(4,107)</td><td>(667)</td></tr><tr><td>Nonvested units, December 31</td><td>64,969</td><td>42,996</td><td>23,128</td></tr></table>

(a) Unit amounts represent the target number of performance units. Each performance unit’s value is based on the average price of one share of Alliant Energy’s common stock on the grant date of the award. The actual payout for performance units is dependent upon actual performance and may range from zero to 200% of the target number of units.

Fair Value of Awards - Information related to fair values of nonvested performance shares and units at December 31, 2012, by year of grant, were as follows:

<table><tr><td rowspan="2"></td><td colspan="3">Performance Shares</td><td colspan="3">Performance Units</td></tr><tr><td>2012 Grant</td><td>2011 Grant</td><td>2010 Grant</td><td>2012 Grant</td><td>2011 Grant</td><td>2010 Grant</td></tr><tr><td>Nonvested awards</td><td>45,612</td><td>45,235</td><td>54,430</td><td>23,969</td><td>21,095</td><td>19,905</td></tr><tr><td>Alliant Energy common stock closing price on December 31, 2012</td><td>$43.91</td><td>$43.91</td><td>$43.91</td><td></td><td></td><td></td></tr><tr><td>Alliant Energy common stock average price on grant date</td><td></td><td></td><td></td><td>$43.05</td><td>$38.75</td><td>$32.56</td></tr><tr><td>Estimated payout percentage based on performance criteria</td><td>89%</td><td>107%</td><td>198%</td><td>89%</td><td>107%</td><td>198%</td></tr><tr><td>Fair values of each nonvested award</td><td>$39.08</td><td>$46.98</td><td>$86.72</td><td>$38.31</td><td>$41.46</td><td>$64.30</td></tr></table>

At December 31, 2012, fair values of nonvested performance shares and units were calculated using a Monte Carlo simulation to determine the anticipated total shareowner returns of Alliant Energy and its investor-owned utility peer groups. Expected volatility was based on historical volatilities using daily stock prices over the past three years. Expected dividend yields were calculated based on the most recent quarterly dividend rates announced prior to the measurement date and stock prices at the measurement date. The risk-free interest rate was based on the three-year U.S. Treasury rate in effect as of the measurement date.

Restricted Stock - Restricted stock consists of time-based and performance-contingent restricted stock.

Time-based Restricted Stock - The current restriction period for outstanding time-based restricted stock is up to three years. Nonvested shares of time-based restricted stock generally become vested upon retirement. Compensation costs related to awards granted to retirement-eligible employees are generally expensed on the date of grant. Participants' nonvested time-based restricted stock issued prior to 2012 is forfeited if the participant voluntarily leaves Alliant Energy or is terminated for cause. Participants' nonvested time-based restricted stock issued prior to 2012 is fully vested in the event of retirement, death, disability or involuntary termination without cause. The fair value of time-based restricted stock is based on the average market price at the grant date. A summary of the time-based restricted stock activity was as follows:

<table><tr><td rowspan="2"></td><td colspan="3">2012</td><td colspan="3">2011</td><td colspan="3">2010</td></tr><tr><td>Shares</td><td>Weighted Average Fair Value</td><td>Shares</td><td>Weighted Average Fair Value</td><td>Shares</td><td>Weighted Average Fair Value</td><td></td><td></td><td></td></tr><tr><td>Nonvested shares, January 1</td><td>35,800</td><td>$30.87</td><td>70,033</td><td>$32.27</td><td>125,349</td><td>$32.47</td><td></td><td></td><td></td></tr><tr><td>Granted</td><td>—</td><td>—</td><td>5,000</td><td>39.86</td><td>—</td><td>—</td><td></td><td></td><td></td></tr><tr><td>Vested</td><td>(32,466)</td><td>29.95</td><td>(38,633)</td><td>34.60</td><td>(54,016)</td><td>32.72</td><td></td><td></td><td></td></tr><tr><td>Forfeited</td><td>—</td><td>—</td><td>(600)</td><td>29.41</td><td>(1,300)</td><td>32.78</td><td></td><td></td><td></td></tr><tr><td>Nonvested shares, December 31</td><td>3,334</td><td>39.86</td><td>35,800</td><td>30.87</td><td>70,033</td><td>32.27</td><td></td><td></td><td></td></tr></table>

Performance-contingent Restricted Stock - Vesting of performance-contingent restricted stock grants are based on the achievement of certain performance targets (currently specified earnings growth). The performance metric for the 2012, 2011 and 2010 grants is consolidated net income growth. If performance targets are not met within the performance period, which currently ranges from two to four years, these restricted stock grants are forfeited. Payouts of nonvested performance-contingent restricted stock issued in 2012 are prorated at retirement, death or disability based on time worked during the first



year of the performance period and achievement of the performance criteria. Upon achievement of the performance criteria, payouts of this performance-contingent restricted stock to participants who terminate employment after the first year of the performance period due to retirement, death or disability are not prorated. Nonvested shares of performance-contingent restricted stock issued prior to 2012 are prorated at retirement based on time worked during the full or entire performance period and vest only if and when the performance criteria are met. Participants' nonvested performance-contingent restricted stock is forfeited if the participant voluntarily leaves Alliant Energy or is terminated for cause. The fair value of performance-contingent restricted stock is based on the average market price at the grant date. A summary of the performance-contingent restricted stock activity was as follows:

<table><tr><td rowspan="2"></td><td colspan="2">2012</td><td colspan="2">2011</td><td colspan="2">2010</td></tr><tr><td>Shares</td><td>Weighted Average Fair Value</td><td>Shares</td><td>Weighted Average Fair Value</td><td>Shares</td><td>Weighted Average Fair Value</td></tr><tr><td>Nonvested shares, January 1</td><td>301,738</td><td>$32.60</td><td>296,190</td><td>$32.32</td><td>226,007</td><td>$32.25</td></tr><tr><td>Granted</td><td>45,612</td><td>43.05</td><td>64,217</td><td>38.75</td><td>72,487</td><td>32.56</td></tr><tr><td>Vested (a)</td><td>(65,172)</td><td>32.56</td><td>(53,274)</td><td>37.93</td><td>—</td><td>—</td></tr><tr><td>Forfeited (b)</td><td>(70,527)</td><td>39.93</td><td>(5,395)</td><td>38.00</td><td>(2,304)</td><td>32.56</td></tr><tr><td>Nonvested shares, December 31</td><td>211,651</td><td>32.42</td><td>301,738</td><td>32.60</td><td>296,190</td><td>32.32</td></tr></table>

(a) In 2012 and 2011, 65,172 and 53,274 performance-contingent restricted shares granted in 2010 and 2007, respectively, vested because the specified performance criteria for such shares were met.

(b) In 2012, 65,516 performance-contingent restricted shares granted in 2008 were forfeited because the specified performance criteria for such shares were not met. The remaining forfeitures during 2012, 2011 and 2010 were primarily caused by retirements and terminations of participants.

Non-qualified Stock Options - Options were granted at the market price of the shares on the date of grant, vested over three years and expire no later than 10 years after the grant date. Alliant Energy has not granted any options since 2004. A summary of the stock option activity was as follows:

<table><tr><td rowspan="2"></td><td colspan="2">2012</td><td colspan="2">2011</td><td colspan="2">2010</td></tr><tr><td>Shares</td><td>Weighted Average Exercise Price</td><td>Shares</td><td>Weighted Average Exercise Price</td><td>Shares</td><td>Weighted Average Exercise Price</td></tr><tr><td>Outstanding, January 1</td><td>63,889</td><td>$24.21</td><td>163,680</td><td>$24.51</td><td>384,331</td><td>$27.02</td></tr><tr><td>Exercised</td><td>(38,711)</td><td>24.41</td><td>(99,791)</td><td>24.71</td><td>(191,433)</td><td>28.93</td></tr><tr><td>Expired</td><td>—</td><td>—</td><td>—</td><td>—</td><td>(29,218)</td><td>28.59</td></tr><tr><td>Outstanding and exercisable, December 31</td><td>25,178</td><td>23.89</td><td>63,889</td><td>24.21</td><td>163,680</td><td>24.51</td></tr></table>

The weighted average remaining contractual term for options outstanding and exercisable at December 31, 2012 was 1 year. The aggregate intrinsic value of options outstanding and exercisable at December 31, 2012 was $0.5 million. Other information related to stock option activity was as follows (in millions):

<table><tr><td></td><td>2012</td><td>2011</td><td>2010</td></tr><tr><td>Cash received from stock options exercised</td><td>$0.9</td><td>$2.5</td><td>$5.5</td></tr><tr><td>Aggregate intrinsic value of stock options exercised</td><td>0.8</td><td>1.6</td><td>1.1</td></tr><tr><td>Income tax benefit from the exercise of stock options</td><td>0.3</td><td>0.7</td><td>0.4</td></tr></table>

Performance Contingent Cash Awards - Performance contingent cash award payouts to key employees are based on the achievement of certain performance targets (currently specified consolidated net income growth). If performance targets are not met within the performance period, which currently ranges from two to four years, there are no payouts for these awards. Payouts of nonvested awards issued in 2012 are prorated at retirement, death or disability based on time worked during the first year of the performance period and achievement of the performance criteria. Upon achievement of the performance criteria, payouts of these 2012 awards to participants who terminate employment after the first year of the performance period due to retirement, death or disability are not prorated. Nonvested awards issued prior to 2012 are prorated at retirement based on time worked during the full or entire performance period and achievement of the performance criteria. Participants' nonvested awards are forfeited if the participant voluntarily leaves Alliant Energy or is terminated for cause. Each performance contingent cash award's value is based on the price of one share of Alliant Energy's common stock at the end of the performance period. Alliant Energy accounts for performance contingent cash awards as liability awards because payouts will be made in the form of cash. A summary of the performance contingent cash awards activity was as follows:



<table><tr><td rowspan="2"></td><td>2012</td><td>2011</td><td>2010</td></tr><tr><td>Awards</td><td>Awards</td><td>Awards</td></tr><tr><td>Nonvested awards, January 1</td><td>46,676</td><td>23,428</td><td>—</td></tr><tr><td>Granted</td><td>36,936</td><td>23,975</td><td>23,795</td></tr><tr><td>Vested (a)</td><td>(21,605)</td><td>—</td><td>—</td></tr><tr><td>Forfeited</td><td>(2,368)</td><td>(727)</td><td>(367)</td></tr><tr><td>Nonvested awards, December 31</td><td>59,639</td><td>46,676</td><td>23,428</td></tr></table>

(a) In 2012, 21,605 performance contingent cash awards granted in 2010 vested, resulting in cash payouts valued at $0.9 million.

(c) Deferred Compensation Plan (DCP) - Alliant Energy maintains a DCP under which key employees may defer up to 100% of base salary and performance-based compensation and directors may elect to defer all or part of their retainer and committee fees. Key employees who have made the maximum allowed contribution to the Alliant Energy 401(k) Savings Plan may receive an additional credit to the DCP. Key employees and directors may elect to have their deferrals credited to a company stock account, an interest account or equity accounts based on certain benchmark funds.

Company Stock Accounts - The DCP does not permit diversification of deferrals credited to the company stock account and all distributions from participants' company stock accounts are made in the form of shares of Alliant Energy common stock. The deferred compensation obligations for participants' company stock accounts are recorded in "Additional paid-in capital" and the shares of Alliant Energy common stock held in a rabbi trust to satisfy this obligation are recorded in "Shares in deferred compensation trust" on the Consolidated Balance Sheets. At December 31, the carrying value of the deferred compensation obligation for the company stock accounts and the shares in the deferred compensation trust based on the historical value of the shares of Alliant Energy common stock contributed to the rabbi trust, and the fair market value of the shares held in the rabbi trust were as follows (in millions):

<table><tr><td></td><td>2012</td><td>2011</td></tr><tr><td>Carrying value</td><td>$7.3</td><td>$8.3</td></tr><tr><td>Fair market value</td><td>9.5</td><td>11.6</td></tr></table>

Interest and Equity Accounts - Distributions from participants’ interest and equity accounts are in the form of cash payments. The deferred compensation obligations for participants’ interest and equity accounts are recorded in “Pension and other benefit obligations” on the Consolidated Balance Sheets. At December 31, 2012 and 2011, the carrying value of Alliant Energy’s deferred compensation obligations for participants’ interest and equity accounts was $16.3 million and $20.5 million, respectively.

## (7) COMMON EQUITY

Common Share Activity - A summary of Alliant Energy’s common stock activity was as follows:

<table><tr><td></td><td>2012</td><td>2011</td><td>2010</td></tr><tr><td>Shares outstanding, January 1</td><td>111,018,821</td><td>110,893,901</td><td>110,656,498</td></tr><tr><td>Equity-based compensation plans (Note 6(b))</td><td>20,195</td><td>164,400</td><td>260,316</td></tr><tr><td>Other (a)</td><td>(51,616)</td><td>(39,480)</td><td>(22,913)</td></tr><tr><td>Shares outstanding, December 31</td><td>110,987,400</td><td>111,018,821</td><td>110,893,901</td></tr></table>

(a) Includes shares transferred from employees to Alliant Energy to satisfy tax withholding requirements in connection with the vesting of certain restricted stock under the equity-based compensation plans.

At December 31, 2012, Alliant Energy had a total of 8.4 million shares available for issuance in the aggregate, pursuant to its OIP, Shareowner Direct Plan and 401(k) Savings Plan.

Shareowner Rights Agreement - Alliant Energy has established an amended and restated Shareowner Rights Agreement. The rights under this agreement will only become exercisable if a person or group has acquired, or announced an intention to acquire, 15% or more of Alliant Energy’s outstanding common stock. Each right will initially entitle registered shareowners to purchase from Alliant Energy one-half of one share of Alliant Energy’s common stock. The rights will be exercisable at an initial price of $110.00 per full share, subject to adjustment. If any shareowner acquires 15% or more of the outstanding common stock of Alliant Energy, each right (subject to limitations) will entitle its holder to purchase, at the right’s then current exercise price, a number of common shares of Alliant Energy or of the acquirer having a market value at the time of



twice the right’s per full share exercise price. Alliant Energy’s Board of Directors is authorized to reduce the 15% ownership threshold to not less than 10%. The amended and restated Shareowner Rights Agreement expires in December 2018.

Dividend Restrictions - Alliant Energy does not have any significant common stock dividend restrictions. IPL and WPL each have common stock dividend restrictions based on the terms of their outstanding preferred stock and applicable regulatory limitations. At December 31, 2012, IPL and WPL were in compliance with all such dividend restrictions.

IPL and WPL are restricted from paying common stock dividends to their parent company, Alliant Energy, if for any past or current dividend period, dividends on their respective preferred stock have not been paid, or declared and set apart for payment. IPL and WPL have paid all dividends on their respective preferred stock through 2012.

IPL’s most significant regulatory limitation on distributions to its parent company requires IPL to obtain IUB approval for a reasonable utility capital structure if its actual 13-month average common equity ratio (calculated on a financial basis consistent with IPL’s rate cases) falls below 42% of total capitalization. As of December 31, 2012, IPL’s amount of retained earnings that were free of dividend restrictions was $387 million.

Currently, WPL’s most significant regulatory limitation on distributions to its parent company is included in an order issued by the PSCW in 2012 that prohibits WPL from paying annual common stock dividends in excess of $119 million in 2013 if WPL’s actual 13-month average common equity ratio (calculated on a financial basis consistent with WPL’s rate cases) falls below 51.03%. WPL’s dividends are also restricted to the extent that such dividend would reduce WPL’s common stock equity ratio to less than 25%. As of December 31, 2012, WPL’s amount of retained earnings that were free of dividend restrictions was $119 million for 2013.

Restricted Net Assets of Subsidiaries - IPL and WPL do not have regulatory authority to lend or advance any amounts to their parent company. As of December 31, the amount of net assets of IPL and WPL that were not available to be transferred to their parent company in the form of cash dividends without the consent of IPL’s and WPL’s regulatory authorities was as follows (in billions):

<table><tr><td></td><td>2012</td><td>2011</td></tr><tr><td>IPL</td><td>$1.1</td><td>$1.0</td></tr><tr><td>WPL</td><td>1.5</td><td>1.3</td></tr></table>

## (8) REDEEMABLE PREFERRED STOCK

Information related to the carrying value of cumulative preferred stock of subsidiaries, net at December 31 was as follows (dollars in millions):

<table><tr><td>Liquidation Preference/Stated Value</td><td>Authorized Shares</td><td>Shares Outstanding</td><td>Series</td><td>Redemption (none are mandatorily redeemable)</td><td>2012</td><td>2011</td></tr><tr><td>IPL:</td><td></td><td></td><td></td><td></td><td></td><td></td></tr><tr><td>$25</td><td>16,000,000</td><td>6,000,000</td><td>8.375%</td><td>On or after March 15, 2013</td><td>$150.0 (4.9)</td><td>$150.0 (4.9)</td></tr><tr><td>Less: discount</td><td></td><td></td><td></td><td></td><td>145.1</td><td>145.1</td></tr><tr><td>WPL:</td><td></td><td></td><td></td><td></td><td></td><td></td></tr><tr><td>$100</td><td>(a)</td><td>99,970</td><td>4.50%</td><td>Any time</td><td>10.0</td><td>10.0</td></tr><tr><td>$100</td><td>(a)</td><td>74,912</td><td>4.80%</td><td>Any time</td><td>7.5</td><td>7.5</td></tr><tr><td>$100</td><td>(a)</td><td>64,979</td><td>4.96%</td><td>Any time</td><td>6.5</td><td>6.5</td></tr><tr><td>$100</td><td>(a)</td><td>29,957</td><td>4.40%</td><td>Any time</td><td>3.0</td><td>3.0</td></tr><tr><td>$100</td><td>(a)</td><td>29,947</td><td>4.76%</td><td>Any time</td><td>3.0</td><td>3.0</td></tr><tr><td>$100</td><td>(a)</td><td>150,000</td><td>6.20%</td><td>Any time</td><td>15.0</td><td>15.0</td></tr><tr><td>$25</td><td>(a)</td><td>599,460</td><td>6.50%</td><td>Any time</td><td>60.0</td><td>60.0</td></tr><tr><td>Alliant Energy</td><td></td><td></td><td></td><td></td><td>$205.1</td><td>$205.1</td></tr></table>

(a) WPL has 3,750,000 authorized shares in total.

IPL - The articles of incorporation of IPL contain a provision that grants the holders of its preferred stock voting rights to elect two members of IPL's Board of Directors if preferred dividends equal to the annual dividend requirements are in arrears. Such voting rights would not provide the holders of IPL's preferred stock control of the decision on redemption of IPL's



preferred stock and could not force IPL to exercise its call option. Therefore, IPL’s preferred stock is presented in total equity on the Consolidated Balance Sheets in a manner consistent with noncontrolling interests.

In February 2013, IPL announced it will redeem all 6,000,000 outstanding shares of its 8.375% cumulative preferred stock in March 2013 at par value for approximately $150 million plus accrued and unpaid dividends to the redemption date. Alliant Energy expects to record a $5 million charge in the first quarter of 2013 related to this transaction in “Preferred dividend requirements” in the Consolidated Statement of Income.

WPL - The articles of organization 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 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.

In February 2013, WPL announced it will redeem all 1,049,225 outstanding shares of its 4.40% through 6.50% cumulative preferred stock in March 2013 for approximately $61 million plus accrued and unpaid dividends to the redemption date. Alliant Energy expects to record a $1 million charge in the first quarter of 2013 related to this transaction in “Preferred dividend requirements” in the Consolidated Statement of Income.

Refer to Note 11 for information on the fair value of cumulative preferred stock of subsidiaries.

## (9) DEBT

(a) Short-term Debt - Alliant Energy and its subsidiaries maintain committed bank lines of credit to provide short-term borrowing flexibility and backstop liquidity for commercial paper outstanding. At December 31, 2012, Alliant Energy's short-term borrowing arrangements included three revolving credit facilities totaling $1 billion ($300 million for Alliant Energy at the parent company level, $300 million for IPL and $400 million for WPL), which expire in December 2016. Information regarding commercial paper classified as short-term debt and backstopped by the credit facilities was as follows (dollars in millions):

<table><tr><td rowspan="2"></td><td colspan="2">Alliant Energy</td><td colspan="2">IPL</td><td colspan="2">WPL</td></tr><tr><td>2012</td><td>2011</td><td>2012</td><td>2011</td><td>2012</td><td>2011</td></tr><tr><td>December 31</td><td></td><td></td><td></td><td></td><td></td><td></td></tr><tr><td>Commercial paper:</td><td></td><td></td><td></td><td></td><td></td><td></td></tr><tr><td>Amount outstanding</td><td>$217.5</td><td>$102.8</td><td>$26.3</td><td>$7.1</td><td>$86.6</td><td>$25.7</td></tr><tr><td>Weighted average interest rates</td><td>0.4%</td><td>0.3%</td><td>0.4%</td><td>0.4%</td><td>0.3%</td><td>0.3%</td></tr><tr><td>Weighted average remaining maturity</td><td>11 days</td><td>3 days</td><td>2 days</td><td>3 days</td><td>19 days</td><td>3 days</td></tr><tr><td>Available credit facility capacity (a)</td><td>$732.5</td><td>$897.2</td><td>$223.7</td><td>$292.9</td><td>$313.4</td><td>$374.3</td></tr><tr><td rowspan="2"></td><td colspan="2">Alliant Energy</td><td colspan="2">IPL</td><td colspan="2">WPL</td></tr><tr><td>2012</td><td>2011</td><td>2012</td><td>2011</td><td>2012</td><td>2011</td></tr><tr><td>For the year ended</td><td></td><td></td><td></td><td></td><td></td><td></td></tr><tr><td>Maximum amount outstanding (based on daily outstanding balances)</td><td>$217.5</td><td>$124.4</td><td>$35.4</td><td>$54.4</td><td>$86.6</td><td>$96.5</td></tr><tr><td>Average amount outstanding (based on daily outstanding balances)</td><td>$99.8</td><td>$27.7</td><td>$5.9</td><td>$6.0</td><td>$11.7</td><td>$17.6</td></tr><tr><td>Weighted average interest rates</td><td>0.4%</td><td>0.3%</td><td>0.4%</td><td>0.3%</td><td>0.3%</td><td>0.3%</td></tr></table>

(a) Alliant Energy’s and IPL’s available credit facility capacities reflect outstanding commercial paper classified as both short- and long-term debt at December 31, 2012. Refer to Note 9(b) for further discussion of $50.0 million of commercial paper outstanding at December 31, 2012 classified as long-term debt on the Consolidated Balance Sheet.

Alliant Energy’s, IPL’s and WPL’s credit facility agreements each contain a financial covenant, which requires the entities to maintain certain debt-to-capital ratios in order to borrow under the credit facilities. The required debt-to-capital ratios compared to the actual debt-to-capital ratios at December 31, 2012 were as follows:

<table><tr><td></td><td>Alliant Energy</td><td>IPL</td><td>WPL</td></tr><tr><td>Requirement</td><td>Less than 65%</td><td>Less than 58%</td><td>Less than 58%</td></tr><tr><td>Actual</td><td>50%</td><td>45%</td><td>48%</td></tr></table>



The debt component of the capital ratios includes long- and short-term debt (excluding non-recourse debt and hybrid securities to the extent the total carrying value of such hybrid securities does not exceed 15% of consolidated capital of the applicable borrower), capital lease obligations, letters of credit, guarantees of the foregoing and new synthetic leases. Unfunded vested benefits under qualified pension plans are not included in the debt-to-capital ratios. The equity component of the capital ratios excludes accumulated other comprehensive income (loss).

(b) Long-Term Debt - Long-term debt, net as of December 31 was as follows (dollars in millions):

<table><tr><td rowspan="2"></td><td colspan="3">2012</td><td colspan="3">2011</td></tr><tr><td>Alliant Energy</td><td>IPL</td><td>WPL</td><td>Alliant Energy</td><td>IPL</td><td>WPL</td></tr><tr><td>Senior Debentures:</td><td></td><td></td><td></td><td></td><td></td><td></td></tr><tr><td>3.3%, due 2015</td><td>$150.0</td><td>$150.0</td><td>$—</td><td>$150.0</td><td>$150.0</td><td>$—</td></tr><tr><td>5.875%, due 2018</td><td>100.0</td><td>100.0</td><td>—</td><td>100.0</td><td>100.0</td><td>—</td></tr><tr><td>7.25%, due 2018</td><td>250.0</td><td>250.0</td><td>—</td><td>250.0</td><td>250.0</td><td>—</td></tr><tr><td>3.65%, due 2020</td><td>200.0</td><td>200.0</td><td>—</td><td>200.0</td><td>200.0</td><td>—</td></tr><tr><td>5.5%, due 2025</td><td>50.0</td><td>50.0</td><td>—</td><td>50.0</td><td>50.0</td><td>—</td></tr><tr><td>6.45%, due 2033</td><td>100.0</td><td>100.0</td><td>—</td><td>100.0</td><td>100.0</td><td>—</td></tr><tr><td>6.3%, due 2034</td><td>125.0</td><td>125.0</td><td>—</td><td>125.0</td><td>125.0</td><td>—</td></tr><tr><td>6.25%, due 2039</td><td>300.0</td><td>300.0</td><td>—</td><td>300.0</td><td>300.0</td><td>—</td></tr><tr><td></td><td>1,275.0</td><td>1,275.0</td><td>—</td><td>1,275.0</td><td>1,275.0</td><td>—</td></tr><tr><td>Debentures:</td><td></td><td></td><td></td><td></td><td></td><td></td></tr><tr><td>5%, due 2019</td><td>250.0</td><td>—</td><td>250.0</td><td>250.0</td><td>—</td><td>250.0</td></tr><tr><td>4.6%, due 2020</td><td>150.0</td><td>—</td><td>150.0</td><td>150.0</td><td>—</td><td>150.0</td></tr><tr><td>2.25%, due 2022 (a)</td><td>250.0</td><td>—</td><td>250.0</td><td>—</td><td>—</td><td>—</td></tr><tr><td>6.25%, due 2034</td><td>100.0</td><td>—</td><td>100.0</td><td>100.0</td><td>—</td><td>100.0</td></tr><tr><td>6.375%, due 2037</td><td>300.0</td><td>—</td><td>300.0</td><td>300.0</td><td>—</td><td>300.0</td></tr><tr><td>7.6%, due 2038</td><td>250.0</td><td>—</td><td>250.0</td><td>250.0</td><td>—</td><td>250.0</td></tr><tr><td></td><td>1,300.0</td><td>—</td><td>1,300.0</td><td>1,050.0</td><td>—</td><td>1,050.0</td></tr><tr><td>Pollution Control Revenue Bonds:</td><td></td><td></td><td></td><td></td><td></td><td></td></tr><tr><td>5%, due 2014</td><td>38.4</td><td>38.4</td><td>—</td><td>38.4</td><td>38.4</td><td>—</td></tr><tr><td>5%, due 2014 and 2015</td><td>24.5</td><td>—</td><td>24.5</td><td>24.5</td><td>—</td><td>24.5</td></tr><tr><td>5.375%, due 2015</td><td>14.6</td><td>—</td><td>14.6</td><td>14.6</td><td>—</td><td>14.6</td></tr><tr><td></td><td>77.5</td><td>38.4</td><td>39.1</td><td>77.5</td><td>38.4</td><td>39.1</td></tr><tr><td>Other:</td><td></td><td></td><td></td><td></td><td></td><td></td></tr><tr><td>Commercial paper, 0.4% at December 31, 2012 (b)</td><td>50.0</td><td>50.0</td><td>—</td><td>—</td><td>—</td><td>—</td></tr><tr><td>4% senior notes, due 2014</td><td>250.0</td><td>—</td><td>—</td><td>250.0</td><td>—</td><td>—</td></tr><tr><td>Term loan credit agreement through 2014, 1.1% at December 31, 2012 (c)</td><td>60.0</td><td>—</td><td>—</td><td>—</td><td>—</td><td>—</td></tr><tr><td>3.45% senior notes, due 2022 (d)</td><td>75.0</td><td>—</td><td>—</td><td>—</td><td>—</td><td>—</td></tr><tr><td>5.06% senior secured notes, due 2013 to 2024</td><td>61.9</td><td>—</td><td>—</td><td>63.3</td><td>—</td><td>—</td></tr><tr><td>Other, 1% at December 31, 2012, due 2013 to 2025</td><td>0.5</td><td>—</td><td>—</td><td>0.5</td><td>—</td><td>—</td></tr><tr><td></td><td>497.4</td><td>50.0</td><td>—</td><td>313.8</td><td>—</td><td>—</td></tr><tr><td>Subtotal</td><td>3,149.9</td><td>1,363.4</td><td>1,339.1</td><td>2,716.3</td><td>1,313.4</td><td>1,089.1</td></tr><tr><td>Current maturities</td><td>(1.5)</td><td>—</td><td>—</td><td>(1.4)</td><td>—</td><td>—</td></tr><tr><td>Unamortized debt (discount) and premium, net</td><td>(11.8)</td><td>(3.9)</td><td>(7.6)</td><td>(11.8)</td><td>(4.4)</td><td>(6.9)</td></tr><tr><td>Long-term debt, net</td><td>$3,136.6</td><td>$1,359.5</td><td>$1,331.5</td><td>$2,703.1</td><td>$1,309.0</td><td>$1,082.2</td></tr></table>

(a) In 2012, WPL issued $250.0 million of 2.25% debentures due 2022. The proceeds from the issuance were used by WPL to fund a portion of the purchase price of Riverside.

(b) As of December 31, 2012, $50.0 million of commercial paper was recorded in “Long-term debt, net” on the Consolidated Balance Sheet due to the existence of long-term credit facilities that back-stop this commercial paper balance, along with Alliant Energy’s intent and ability to refinance these balances on a long-term basis. As of December 31, 2012, this commercial paper balance had a remaining maturity of 8 days.

(c) In 2012, Franklin County Holdings LLC, Resources’ wholly-owned subsidiary, entered into a $60.0 million variable-rate term loan credit agreement that exists through 2014 to fund a portion of the costs of its Franklin County wind project, which was placed into service in the fourth quarter of 2012.

(d) In 2012, Corporate Services issued $75 million of 3.45% senior notes due 2022. The proceeds from the issuance were used by Corporate Services to repay short-term debt primarily incurred for the purchase of the corporate headquarters building and for general working capital purposes.



Five-Year Schedule of Debt Maturities - At December 31, 2012, debt maturities for 2013 to 2017 were as follows (in millions):

<table><tr><td></td><td>2013</td><td>2014</td><td>2015</td><td>2016</td><td>2017</td></tr><tr><td>IPL (a)</td><td>$50</td><td>$38</td><td>$150</td><td>$—</td><td>$—</td></tr><tr><td>WPL</td><td>—</td><td>8</td><td>31</td><td>—</td><td>—</td></tr><tr><td>Resources</td><td>1</td><td>62</td><td>2</td><td>3</td><td>4</td></tr><tr><td>Alliant Energy parent company</td><td>—</td><td>250</td><td>—</td><td>—</td><td>—</td></tr><tr><td>Alliant Energy</td><td>$51</td><td>$358</td><td>$183</td><td>$3</td><td>$4</td></tr></table>

(a) IPL’s amount for 2013 includes $50.0 million of commercial paper that was recorded in “Long-term debt, net” on the Consolidated Balance Sheet as described above.

At December 31, 2012, there were no significant sinking fund requirements related to the long-term debt on the Consolidated Balance Sheet.

Indentures - Alliant Energy maintains an indenture related to its 4% senior notes due 2014. IPL maintains an indenture related to its senior debentures due 2015 through 2039. WPL maintains an indenture related to its debentures due 2019 through 2038. Sheboygan Power, LLC, Resources' wholly-owned subsidiary, maintains an indenture related to the issuance of its 5.06% senior secured notes due 2013 to 2024.

Optional Redemption Provisions - Alliant Energy and its subsidiaries have certain issuances of long-term debt that contain optional redemption provisions which, if elected by the issuer at its sole discretion, could require material redemption premium payments by 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 December 31, 2012, the debt issuances that contained these optional redemption provisions included Alliant Energy’s senior notes due 2014, Corporate Services’ senior notes due 2022, IPL’s senior debentures due 2015 through 2039, WPL’s debentures due 2019 through 2038 and Sheboygan Power, LLC’s senior secured notes due 2013 to 2024.

Security Provisions - Sheboygan Power, LLC’s 5.06% senior secured notes due 2013 to 2024 are secured by the Sheboygan Falls Energy Facility and related assets.

Unamortized Debt Issuance Costs - Alliant Energy’s unamortized debt issuance costs recorded in “Deferred charges and other” on the Consolidated Balance Sheets at December 31, 2012 and 2011 were $19.5 million and $19.1 million, respectively.

Carrying Amount and Fair Value of Long-term Debt - Refer to Note 11 for information on the carrying amount and fair value of long-term debt outstanding at December 31, 2012 and 2011.

## (10) INVESTMENTS

(a) Unconsolidated Equity Investments - Alliant Energy’s unconsolidated investments accounted for under the equity method of accounting are as follows (in millions):

<table><tr><td rowspan="2"></td><td rowspan="2">Ownership Interest at December 31, 2012</td><td colspan="2">Carrying Value at December 31,</td><td colspan="3">Equity (Income) / Loss</td></tr><tr><td>2012</td><td>2011</td><td>2012</td><td>2011</td><td>2010</td></tr><tr><td>ATC (a)</td><td>16%</td><td>$257.0</td><td>$238.8</td><td>($41.3)</td><td>($37.8)</td><td>($36.9)</td></tr><tr><td>Wisconsin River Power Company</td><td>50%</td><td>7.3</td><td>7.7</td><td>(0.8)</td><td>(0.9)</td><td>(0.9)</td></tr><tr><td>Other</td><td>Various</td><td>2.3</td><td>3.1</td><td>0.8</td><td>(0.6)</td><td>(0.3)</td></tr><tr><td></td><td></td><td>$266.6</td><td>$249.6</td><td>($41.3)</td><td>($39.3)</td><td>($38.1)</td></tr></table>

(a) Alliant Energy 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 aggregate financial information from the financial statements of these investments is as follows (in millions):

<table><tr><td></td><td>2012</td><td>2011</td><td>2010</td></tr><tr><td>Operating revenues</td><td>$611</td><td>$575</td><td>$564</td></tr><tr><td>Operating income</td><td>326</td><td>307</td><td>307</td></tr><tr><td>Net income</td><td>234</td><td>218</td><td>226</td></tr><tr><td>As of December 31:</td><td></td><td></td><td></td></tr><tr><td>Current assets</td><td>67</td><td>62</td><td></td></tr><tr><td>Non-current assets</td><td>3,321</td><td>3,100</td><td></td></tr><tr><td>Current liabilities</td><td>252</td><td>299</td><td></td></tr><tr><td>Non-current liabilities</td><td>1,652</td><td>1,490</td><td></td></tr></table>

(b) Cash Surrender Value of Life Insurance Policies - Alliant Energy, IPL and WPL have various life insurance policies that cover certain current and former employees and directors. At December 31, 2012 and 2011, the cash surrender value of these investments was $50.5 million and $49.2 million, respectively.

## (11) FAIR VALUE MEASUREMENTS

Fair Value of Financial Instruments - The carrying amounts of Alliant Energy’s current assets and current liabilities approximate fair value because of the short maturity of such financial instruments. Carrying amounts and the related estimated fair values of other financial instruments at December 31 were as follows (in millions):

<table><tr><td></td><td>Carrying Amount</td><td>Fair Value</td></tr><tr><td>2012</td><td></td><td></td></tr><tr><td>Assets:</td><td></td><td></td></tr><tr><td>Derivative assets (Note 12)</td><td>$26.2</td><td>$26.2</td></tr><tr><td>Deferred proceeds (sales of receivables) (Note 4(a))</td><td>66.8</td><td>66.8</td></tr><tr><td>Capitalization and liabilities:</td><td></td><td></td></tr><tr><td>Long-term debt (including current maturities) (Note 9(b))</td><td>3,138.1</td><td>3,860.5</td></tr><tr><td>Cumulative preferred stock of subsidiaries (Note 8)</td><td>205.1</td><td>212.6</td></tr><tr><td>Derivative liabilities (Note 12)</td><td>40.4</td><td>40.4</td></tr><tr><td>2011</td><td></td><td></td></tr><tr><td>Assets:</td><td></td><td></td></tr><tr><td>Derivative assets (Note 12)</td><td>15.7</td><td>15.7</td></tr><tr><td>Deferred proceeds (sales of receivables) (Note 4(a))</td><td>53.7</td><td>53.7</td></tr><tr><td>Capitalization and liabilities:</td><td></td><td></td></tr><tr><td>Long-term debt (including current maturities) (Note 9(b))</td><td>2,704.5</td><td>3,325.3</td></tr><tr><td>Cumulative preferred stock of subsidiaries (Note 8)</td><td>205.1</td><td>222.5</td></tr><tr><td>Derivative liabilities (Note 12)</td><td>78.0</td><td>78.0</td></tr></table>

Valuation Hierarchy - Fair value measurement accounting 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. As of December 31, 2012, Level 1 items included IPL's 8.375% cumulative preferred stock and WPL's 4.50% cumulative preferred stock.

Level 2 - Pricing inputs are quoted prices for similar assets 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. As of December 31, 2012 and 2011, Level 2 items included certain of IPL's and WPL's non-exchange traded commodity contracts. Level 2 items as of December 31, 2012 also included the remainder of WPL's cumulative preferred stock and substantially all of the long-term debt instruments.

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. As of December 31, 2012 and 2011, Level 3 items included IPL's deferred proceeds, and IPL's and WPL's financial transmission rights (FTRs) and certain non-exchange traded commodity contracts.



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.

## Valuation Techniques -

Derivative assets and derivative liabilities - Alliant Energy, IPL and WPL periodically use derivative instruments for risk management purposes to mitigate exposures to fluctuations in certain commodity prices and transmission congestion costs, and maintain risk policies that govern the use of such derivative instruments. As of December 31, 2012 and 2011, Alliant Energy’s derivative instruments were not designated as hedging instruments and included the following:

<table><tr><td>Risk management purpose</td><td>Type of instrument</td></tr><tr><td>Mitigate pricing volatility for:</td><td></td></tr><tr><td>Electricity purchased to supply customers</td><td>Electric swap and physical purchase contracts (IPL and WPL)</td></tr><tr><td>Fuel used to supply natural gas-fired electric generating facilities</td><td>Natural gas swap and physical purchase contracts (IPL and WPL)</td></tr><tr><td></td><td>Natural gas options (WPL)</td></tr><tr><td>Natural gas supplied to retail customers</td><td>Natural gas options and physical purchase contracts (IPL and WPL)</td></tr><tr><td></td><td>Natural gas swap contracts (IPL)</td></tr><tr><td>Fuel used at coal-fired generating facilities</td><td>Coal physical purchase contract with volumetric optionality (WPL)</td></tr><tr><td>Optimize the value of natural gas pipeline capacity</td><td>Natural gas physical purchase and sale contracts (IPL and WPL)</td></tr><tr><td></td><td>Natural gas swap contracts (IPL)</td></tr><tr><td>Manage transmission congestion costs</td><td>FTRs (IPL and WPL)</td></tr></table>

IPL’s and WPL’s swap, option and physical forward commodity contracts were non-exchange-based derivative instruments and were valued using indicative price quotations available through a pricing vendor that provides daily exchange forward price settlements, from broker or dealer quotations, from market publications 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. IPL and WPL corroborated a portion of these indicative price quotations using quoted prices for similar assets or liabilities in active markets and categorized derivative instruments based on such indicative price quotations as Level 2. IPL’s and WPL’s commodity contracts that were valued using indicative price quotations based on significant assumptions such as seasonal or monthly shaping and indicative price quotations that could not be readily corroborated were categorized as Level 3. IPL’s and WPL’s swap, option and physical forward commodity contracts were predominately at liquid trading points. IPL’s and WPL’s FTRs were valued using monthly or annual auction shadow prices from relevant auctions and were categorized as Level 3. Refer to Note 12 for additional details of derivative assets and derivative liabilities.

The significant unobservable inputs (Level 3 inputs) used in the fair value measurement of IPL’s and WPL’s commodity contracts are forecasted electricity, natural gas and coal prices, and the expected volatility of such prices. Significant changes in any of those inputs would result in a significantly lower or higher fair value measurement. These commodity contracts were valued using a market approach technique that utilizes significant observable inputs to estimate forward commodity prices. Forward electric and coal prices are estimated using market information obtained from counterparties and brokers, including bids, offers, historical transactions (including historical price differences between locations with both observable and unobservable prices) and executed trades. Forward natural gas prices are estimated using the most recent quoted observable inputs applied to future months (including historical price differences between locations with both observable and unobservable prices). Observable inputs are obtained from third-party pricing data sources and include bids, offers, historical transactions and executed trades. Forward electric price commodity curves that extend beyond currently available observable inputs utilize market prices for the most recent period for which observable inputs are available. Observable inputs include bids, offers, historical transactions and executed trades.

Deferred proceeds (sales of receivables) - The fair value of IPL’s deferred proceeds related to its sales of receivables program was calculated each reporting date using the cost approach valuation technique. The fair value represents the carrying amount of receivables sold less the allowance for doubtful accounts associated with the receivables sold and cash proceeds received from the receivables sold due to the short-term nature of the collection period. These inputs were considered unobservable and deferred proceeds were categorized as Level 3. Deferred proceeds represent IPL’s maximum exposure to loss related to the receivables sold. Refer to Note 4(a) for additional information regarding deferred proceeds.



Long-term debt (including current maturities) - For long-term debt instruments that are actively traded, the fair value was based upon quoted market prices for similar liabilities on each reporting date. For long-term debt instruments that are not actively traded, the fair value was based on a discounted cash flow methodology and utilizes assumptions of current market pricing curves at each reporting date. Refer to Note 9(b) for additional information regarding long-term debt.

Cumulative preferred stock of subsidiaries - The fair value of IPL's 8.375% cumulative preferred stock was based on its closing market price quoted by the New York Stock Exchange on each reporting date. The fair value of WPL's 4.50% cumulative preferred stock was based on the closing market price quoted by the NYSE Amex LLC on each reporting date. The fair value of WPL's remaining preferred stock was calculated based on the market yield of similar securities on each reporting date. Refer to Note 8 for additional information regarding cumulative preferred stock of subsidiaries.

Items subject to fair value measurement disclosure requirements for Alliant Energy were as follows (Not Applicable (N/A); in millions):

<table><tr><td rowspan="2"></td><td colspan="4">2012</td><td colspan="4">2011</td></tr><tr><td>Fair Value</td><td>Level 1</td><td>Level 2</td><td>Level 3</td><td>Fair Value</td><td>Level 1</td><td>Level 2</td><td>Level 3</td></tr><tr><td>Assets:</td><td></td><td></td><td></td><td></td><td></td><td></td><td></td><td></td></tr><tr><td>Derivatives - commodity contracts</td><td>$26.2</td><td>$—</td><td>$4.8</td><td>$21.4</td><td>$15.7</td><td>$—</td><td>$3.4</td><td>$12.3</td></tr><tr><td>Deferred proceeds</td><td>66.8</td><td>—</td><td>—</td><td>66.8</td><td>53.7</td><td>—</td><td>—</td><td>53.7</td></tr><tr><td>Capitalization and liabilities:</td><td></td><td></td><td></td><td></td><td></td><td></td><td></td><td></td></tr><tr><td>Long-term debt (including current maturities)</td><td>3,860.5</td><td>—</td><td>3,860.0</td><td>0.5</td><td>N/A</td><td>N/A</td><td>N/A</td><td>N/A</td></tr><tr><td>Cumulative preferred stock of subsidiaries</td><td>212.6</td><td>162.3</td><td>50.3</td><td>—</td><td>N/A</td><td>N/A</td><td>N/A</td><td>N/A</td></tr><tr><td>Derivatives - commodity contracts</td><td>40.4</td><td>—</td><td>30.9</td><td>9.5</td><td>78.0</td><td>—</td><td>64.8</td><td>13.2</td></tr></table>

Alliant Energy generally records gains and losses from IPL’s and WPL’s derivative instruments with offsets to regulatory assets or regulatory liabilities, based on their fuel and natural gas cost recovery mechanisms, as well as other specific regulatory authorizations. Based on these recovery mechanisms, the changes in the fair value of derivative liabilities resulted in comparable changes to regulatory assets, and the changes in the fair value of derivative assets resulted in comparable changes to regulatory liabilities on the Consolidated Balance Sheets.

Information for fair value measurements using significant unobservable inputs (Level 3 inputs) for Alliant Energy was as follows (in millions):

<table><tr><td rowspan="3"></td><td colspan="4">Commodity Contract</td></tr><tr><td colspan="2">Derivative Assets and (Liabilities), net</td><td colspan="2">Deferred Proceeds</td></tr><tr><td>2012</td><td>2011</td><td>2012</td><td>2011</td></tr><tr><td>Beginning balance, January 1</td><td>($0.9)</td><td>$2.8</td><td>$53.7</td><td>$152.9</td></tr><tr><td>Total net losses (realized/unrealized) included in changes in net assets (a)</td><td>(7.6)</td><td>(7.3)</td><td>—</td><td>—</td></tr><tr><td>Transfers into Level 3 (b)</td><td>(1.1)</td><td>0.2</td><td>—</td><td>—</td></tr><tr><td>Transfers out of Level 3 (c)</td><td>8.3</td><td>—</td><td>—</td><td>—</td></tr><tr><td>Purchases</td><td>35.8</td><td>21.8</td><td>—</td><td>—</td></tr><tr><td>Settlements (d)</td><td>(22.6)</td><td>(18.4)</td><td>13.1</td><td>(99.2)</td></tr><tr><td>Ending balance, December 31</td><td>$11.9</td><td>($0.9)</td><td>$66.8</td><td>$53.7</td></tr><tr><td>The amount of total net losses for the period included in changes in net assets attributable to the change in unrealized losses relating to assets and liabilities held at December 31 (a)</td><td>($2.6)</td><td>($7.3)</td><td>$—</td><td>$—</td></tr></table>

(a) Gains and losses related to derivative assets and derivative liabilities are generally recorded in “Regulatory assets” and “Regulatory liabilities” on the Consolidated Balance Sheets.

(b) Markets for similar assets and liabilities became inactive and observable market inputs became unavailable for transfers into Level 3. The transfers were valued as of the beginning of the period.

(c) Observable market inputs became available for certain commodity contracts previously classified as Level 3 for transfers out of Level 3. The transfers were valued as of the beginning of the period.



(d) Settlements related to deferred proceeds are due to the change in the carrying amount of receivables sold less the allowance for doubtful accounts associated with the receivables sold and cash proceeds received from the receivables sold.

Commodity Contracts - As of December 31, 2012, the fair values of Alliant Energy’s electric, natural gas and coal commodity contracts categorized as Level 3, excluding FTRs, were recognized as net derivative liabilities of $3.2 million. As of December 31, 2012, Alliant Energy’s FTRs categorized as Level 3 were recognized as net derivative assets of $15.1 million.

## (12) DERIVATIVE INSTRUMENTS

## Commodity and Foreign Exchange Derivatives -

Purpose - Alliant Energy, IPL and WPL periodically use derivative instruments for risk management purposes to mitigate exposures to fluctuations in certain commodity prices and transmission congestion costs. Refer to Note 11 for detailed discussion of derivative instruments as of December 31, 2012 and 2011.

Notional Amounts - As of December 31, 2012, notional amounts by delivery year related to outstanding swap contracts, option contracts, physical forward contracts, FTRs and coal contracts that were accounted for as commodity derivative instruments were as follows (units in thousands):

<table><tr><td></td><td>2013</td><td>2014</td><td>2015</td><td>Total</td></tr><tr><td>Electricity (MWhs)</td><td>4,130</td><td>2,670</td><td>876</td><td>7,676</td></tr><tr><td>FTRs (MWs)</td><td>28</td><td>—</td><td>—</td><td>28</td></tr><tr><td>Natural gas (dekathems (Dths))</td><td>72,105</td><td>7,747</td><td>450</td><td>80,302</td></tr><tr><td>Coal (tons)</td><td>896</td><td>981</td><td>562</td><td>2,439</td></tr></table>

The notional amounts in the above table were computed by aggregating the absolute value of purchase and sale positions within commodities for each delivery year.

Financial Statement Presentation - Alliant Energy records derivative instruments at fair value each reporting date on the balance sheet as assets or liabilities. At December 31, the fair values of current derivative assets were included in “Prepayments and other,” 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):

<table><tr><td>Commodity contracts</td><td>2012</td><td>2011</td></tr><tr><td>Current derivative assets</td><td>$23.5</td><td>$12.7</td></tr><tr><td>Non-current derivative assets</td><td>2.7</td><td>3.0</td></tr><tr><td>Current derivative liabilities</td><td>31.1</td><td>55.9</td></tr><tr><td>Non-current derivative liabilities</td><td>9.3</td><td>22.1</td></tr></table>

Changes in unrealized gains (losses) from derivative instruments not designated as hedging instruments were recorded with offsets to regulatory assets or regulatory liabilities on the Consolidated Balance Sheets as follows (in millions):

<table><tr><td></td><td>2012</td><td>2011</td><td>2010</td></tr><tr><td>Commodity contracts</td><td>Regulatory assets</td><td>($37.9)</td><td>($79.6)</td></tr><tr><td>Commodity contracts</td><td>Regulatory liabilities</td><td>20.3</td><td>9.3</td></tr><tr><td>Foreign exchange contracts</td><td>Regulatory liabilities</td><td>—</td><td>—</td></tr></table>

Net unrealized losses from commodity contracts during 2012, 2011 and 2010 were primarily due to impacts of decreases in electricity and natural gas prices during such periods.

Credit Risk-related Contingent Features - Alliant Energy and its subsidiaries have entered into various agreements that contain credit risk-related contingent features including requirements for them to maintain certain credit ratings from each of the major credit rating agencies and/or limitations on their liability positions under the various agreements based upon their credit ratings. In the event of a downgrade in their credit ratings or if their liability positions exceed certain contractual limits, Alliant Energy and its subsidiaries may need to provide credit support in the form of letters of credit or cash collateral up to the amount of their 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. The aggregate fair value of all derivatives with credit risk-related contingent features that were in a net liability position on December 31, 2012 was $40.4 million for Alliant Energy. At December 31, 2012, Alliant Energy and its subsidiaries all had investment-grade credit ratings. However, IPL exceeded its liability position with one counterparty requiring it to post $0.5 million of cash collateral. If the most restrictive credit risk-related contingent features for derivative agreements in a net liability position were triggered on December 31, 2012, Alliant Energy would be required to post an additional $39.9 million of credit support to its counterparties.

## (13) COMMITMENTS AND CONTINGENCIES

(a) Capital Purchase Obligations - Alliant Energy has entered into capital purchase obligations that contain minimum future commitments related to capital expenditures for certain of its emission control projects. At December 31, 2012, Alliant Energy’s minimum future commitments related to capital expenditures for the installation of scrubbers and baghouses at WPL’s Columbia Units 1 and 2 to reduce SO \( _{2} \)  and mercury emissions at the generating facility were 46 million.

(b) Operating Expense Purchase Obligations - Alliant Energy has entered into various commodity supply, transportation and storage contracts to meet its obligations to deliver electricity and natural gas to IPL's and WPL's utility customers. Alliant Energy also enters into other operating expense purchase obligations with various vendors for other goods and services. At December 31, 2012, minimum future commitments related to these operating expense purchase obligations were as follows (in millions):

<table><tr><td></td><td>2013</td><td>2014</td><td>2015</td><td>2016</td><td>2017</td><td>Thereafter</td><td>Total</td></tr><tr><td>Purchased power (a):</td><td></td><td></td><td></td><td></td><td></td><td></td><td></td></tr><tr><td>DAEC (IPL) (b)</td><td>$200</td><td>$34</td><td>$—</td><td>$—</td><td>$—</td><td>$—</td><td>$234</td></tr><tr><td>Kewaunee Nuclear Power Plant (WPL)</td><td>77</td><td>—</td><td>—</td><td>—</td><td>—</td><td>—</td><td>77</td></tr><tr><td>Other</td><td>8</td><td>14</td><td>30</td><td>—</td><td>—</td><td>—</td><td>52</td></tr><tr><td></td><td>285</td><td>48</td><td>30</td><td>—</td><td>—</td><td>—</td><td>363</td></tr><tr><td>Natural gas</td><td>163</td><td>55</td><td>37</td><td>21</td><td>10</td><td>6</td><td>292</td></tr><tr><td>Coal</td><td>126</td><td>80</td><td>44</td><td>10</td><td>4</td><td>—</td><td>264</td></tr><tr><td>SO2 emission allowances (c)</td><td>—</td><td>—</td><td>12</td><td>14</td><td>8</td><td>—</td><td>34</td></tr><tr><td>Other (d)</td><td>22</td><td>4</td><td>3</td><td>—</td><td>—</td><td>—</td><td>29</td></tr><tr><td></td><td>$596</td><td>$187</td><td>$126</td><td>$45</td><td>$22</td><td>$6</td><td>$982</td></tr></table>

(a) Includes payments required by PPAs for capacity rights and minimum quantities of MWhs required to be purchased. Refer to Note 19 for additional information on purchased power transactions.

(b) IPL is obligated to pay for capacity and energy delivered under the DAEC PPA. If energy delivered under the DAEC PPA is less than the targeted energy amount, an adjustment payment is made to IPL, which is reflected in IPL's energy adjustment clause. In January 2013, the IUB issued an order approving a proposed DAEC PPA, with rights to purchase 431 MWs of capacity and the resulting energy from DAEC for a term from the expiration of the existing PPA in February 2014 through December 31, 2025. As of December 31, 2012, there was no minimum future commitment for the proposed DAEC PPA.

(c) Refer to Note 1(b) for discussion of $34 million of charges recognized in 2011 for forward contracts to purchase SO \( _{2} \)  emission allowances.

(d) Includes individual commitments incurred during the normal course of business that exceeded $1 million at December 31, 2012.

Alliant Energy enters into certain contracts that are considered leases and are therefore not included here, but are included in Note 3.

## (c) Legal Proceedings -

Air Permitting Violation Claims - In 2009, the EPA sent a Notice of Violation (NOV) to WPL as an owner and the operator of the Edgewater Generating Station (Edgewater), the Nelson Dewey Generating Station (Nelson Dewey) and the Columbia Energy Center (Columbia). The NOV alleges that the owners of Edgewater, Nelson Dewey and Columbia failed to comply with appropriate pre-construction review and permitting requirements and as a result violated the Prevention of Significant Deterioration (PSD) program requirements, Title V Operating Permit requirements of the Clean Air Act (CAA) and the Wisconsin state implementation plan (SIP).



In September 2010, Sierra Club filed in the U.S. District Court for the Western District of Wisconsin a complaint against WPL, as owner and operator of Nelson Dewey and Columbia, based on allegations that modifications were made at the facilities without complying with the PSD program requirements, Title V Operating Permit requirements of the CAA and state regulatory counterparts contained within the Wisconsin SIP 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 responded to the motions. In May 2012, the parties filed a Stipulation of Dismissal without Prejudice, and the court closed the case, although the Sierra Club is permitted to file a future lawsuit against WPL.

In September 2010, Sierra Club filed in the U.S. District Court for the Eastern District of Wisconsin a complaint against WPL, as owner and operator of Edgewater, which contained similar allegations regarding air permitting violations at Edgewater. In the Edgewater complaint, additional allegations were made regarding violations of emission limits for visible emissions. 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.

Alliant Energy is defending against the allegations in the NOV and both lawsuits because it believes the projects at Edgewater, Nelson Dewey and Columbia were routine or not projected to increase emissions and therefore did not violate the requirements of the CAA. Simultaneously, WPL, the other owners of Edgewater and Columbia, the EPA and Sierra Club (collectively “the parties”) are exploring settlement options. Alliant Energy believes that the parties have reached agreement on general terms to settle these air permitting violation claims and is currently negotiating a consent decree based upon those general terms. Those terms are subject to change during the negotiations. Based on a review of existing EPA consent decrees, Alliant Energy anticipates that the final consent decree could include the installation of emission controls technology, changed operating conditions (including use of fuels other than coal and retirement of units), limitations on emissions, beneficial environmental mitigation projects and a civil penalty.

Once the parties agree to the final terms, the Court must approve the consent decree. Alliant Energy cannot predict the outcome of these claims, but believes the outcome could be significant if the parties are unable to reach final agreement, or reach final agreement on different terms than currently anticipated, or if the Court does not approve the final consent decree.

Alliant Energy currently expects to recover any material costs that could be incurred by WPL related to the terms of the final consent decree from WPL’s electric customers. Alliant Energy does not currently believe any material losses from these air permitting violation claims are both probable and reasonably estimated and therefore has not recognized any material loss contingency amounts related to these claims as of December 31, 2012.

Alliant Energy Cash Balance Pension Plan (Plan) - In February 2008, a class-action lawsuit was filed against the Plan in the U.S. District Court for the Western District of Wisconsin (Court). The complaint alleged that certain Plan participants who received distributions 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 (ERISA) because the Plan applied an improper interest crediting rate to project the cash balance account to their normal retirement age. These Plan participants were limited to individuals who, prior to normal retirement age, received a lump-sum distribution or an annuity payment. The Court originally certified two subclasses of plaintiffs that in aggregate include all persons vested or partially vested in the Plan who received these distributions from January 1, 1998 to August 17, 2006 including: (1) persons who received distributions from January 1, 1998 through February 28, 2002; and (2) persons who received distributions from March 1, 2002 to August 17, 2006.

In June 2010, the Court issued an opinion and order that granted the plaintiffs' motion for summary judgment on liability. 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 accounts of the plaintiffs during the class period should have been 8.2% and that a pre-retirement mortality discount would not be applied to the damages calculation. In May 2011, the Plan was amended and the Plan subsequently made approximately $10 million in additional payments in 2011 to certain former participants in the Plan. This amendment was required based on an agreement Alliant Energy reached with the IRS, which resulted in a favorable determination letter for the Plan in 2011. In November 2011, plaintiffs filed a motion for leave to file a supplemental complaint to assert that the 2011 amendment to the Plan was itself an ERISA violation. In March 2012, the Plan and the plaintiffs each filed motions for summary judgment related to the supplemental complaint, and the plaintiffs filed a motion for class certification, seeking to amend the class definition and for appointment of class representatives and class counsel.



In July 2012, the Court issued an opinion and order granting plaintiffs' motion for class certification, but only as to the interest crediting rate and the pre-retirement mortality discount claims of lump-sum recipients. As a result of the opinion and order, two new subclasses were certified in lieu of the prior subclass certification. Subclass A involves persons who received a lump-sum distribution between January 1, 1998 and August 17, 2006 and who received an interest crediting rate of less than 8.2% under the Plan as amended in May 2011. Subclass B involves persons who received a lump-sum distribution between January 1, 1998 and August 17, 2006 and who would have received a larger benefit under the Plan as amended in May 2011 if a pre-retirement mortality discount had not been applied. In the opinion and order the Court then granted plaintiffs' motion for summary judgment as to the two subclasses, and denied as moot the parties' motions for summary judgment with respect to issues beyond the two subclasses. In August 2012, as amended in September 2012, the Court entered a final judgment for the two subclasses in the total amount of $18.7 million. The judgment amount includes pre-judgment interest through July 2012 and takes into account the approximate $10 million of additional benefits paid by the Plan following the Plan amendment in 2011. In September 2012, the Plan appealed the judgment, and the interlocutory orders that led to the judgment, to the Seventh Circuit Court of Appeals. In November 2012, the Plan filed its opening brief in which it seeks to reverse all or part of the judgment. The judgment discussed above did not address any award for plaintiffs' attorney's fees or costs. In September 2012, the plaintiffs filed a motion with the Court for payment of plaintiffs' attorney's fees and costs in the amount of $9.6 million, of which $4.3 million was requested to be paid out of the common fund awarded to the two subclasses in the September 2012 judgment. In February 2013, the Court awarded plaintiffs' attorney's fees and costs in the amount of $6.4 million. The Court ordered that all of the fees and costs be paid from the $18.7 million judgment previously awarded and not be in addition to that judgment. Alliant Energy has not recognized any material loss contingency amounts for the final judgment of damages as of December 31, 2012. A material loss contingency for the judgment will not be recognized unless a final unappealable ruling is received, or a settlement is reached, which results in an amendment to the Plan and payment of additional benefits to Plan participants. Alliant Energy is currently unable to predict the final outcome of the class-action lawsuit or the ultimate impact on its financial condition or results of operations but believes an adverse outcome could have a material effect on its retirement plan funding and expense.

RMT Contract Disputes - In September 2011, RMT filed a lawsuit in the U.S. District Court for the Western District of Wisconsin, which alleged, among other things, breach of contract against Cable System Installation (CSI), a subcontractor to RMT on several solar projects in New Jersey. The lawsuit sought to recover all costs incurred by RMT as a result of the breaches of contract by CSI. CSI filed an answer and counterclaims against RMT asserting that RMT owed CSI additional amounts for work performed under the contract that have not been paid to date. CSI filed liens against the projects based on claims that they have not been paid for work performed under the contract with RMT and filed lawsuits in New Jersey to foreclose upon the liens that it has filed in that jurisdiction. Vendors of CSI also filed lawsuits against RMT and liens against the projects based on claims that they have not been paid as required under their agreements with CSI. In January 2013, RMT entered into a confidential settlement agreement, which includes the release of all claims by all parties to this matter and the discharge of all liens related to this matter. The terms of the settlement did not have a material impact on Alliant Energy’s financial condition or results of operations.

Other - Alliant Energy 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, Alliant Energy believes that appropriate reserves have been established and final disposition of these actions will not have a material effect on its financial condition or results of operations.

## (d) Guarantees and Indemnifications -

RMT - In January 2013, Alliant Energy sold its remaining interest in RMT. RMT provides renewable energy services including construction and high voltage connection services for wind and solar projects. Alliant Energy provided indemnifications to the buyer of RMT for losses resulting from potential breach of the representations and warranties made by Alliant Energy as of the sale date and for the potential breach of its obligations under the sale agreement. These indemnifications are limited to $3 million and expire in July 2014. The dollar limit on these indemnifications is subject to increase, based on the amount, if any, of contingent consideration Alliant Energy is entitled to receive under the terms of the sale. Although unable to predict the outcome of these matters, Alliant Energy believes the likelihood of having to make any material cash payments under these indemnifications is remote.

Alliant Energy also continues to guarantee RMT’s performance obligations related to certain of RMT’s projects that were commenced prior to Alliant Energy’s sale of RMT. As of December 31, 2012, Alliant Energy had $615 million of performance guarantees outstanding with $270 million, $294 million and $51 million expiring in 2013, 2014 and 2015, respectively. RMT has also provided surety bonds in support of the payment and performance obligations of certain of these projects, and Alliant Energy has guaranteed RMT’s indemnity obligations to the holders of such bonds. As of December 31, 2012, RMT provided $18 million in surety bonds guaranteed by Alliant Energy, which expire in 2013. Alliant Energy



currently believes that no material cash payments will be made and has not recognized any material liabilities related to these obligations as of December 31, 2012. Refer to Note 17 for further discussion of RMT.

Whiting - In 2004, Alliant Energy sold its remaining interest in Whiting. Whiting is an independent oil and gas company. Alliant Energy continues to guarantee the abandonment obligations of certain offshore platforms in California and related onshore plant and equipment that were owned by Whiting prior to Alliant Energy’s sale of Whiting. The guarantee does not include a maximum limit. As of December 31, 2012, the present value of the abandonment obligations is estimated at $30 million. Alliant Energy believes that no payments will be made under this guarantee. Alliant Energy has not recognized any material liabilities related to this guarantee as of December 31, 2012.

Refer to Note 3 for discussion of Alliant Energy’s residual value guarantees of its synthetic leases.

(e) Environmental Matters - Alliant Energy, IPL and WPL are subject to environmental regulations as a result of their 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 December 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):

<table><tr><td></td><td>2012</td><td>2011</td></tr><tr><td>Current environmental liabilities</td><td>$3.7</td><td>$4.8</td></tr><tr><td>Non-current environmental liabilities</td><td>25.3</td><td>28.8</td></tr><tr><td></td><td>$29.0</td><td>$33.6</td></tr></table>

MGP Sites - IPL and WPL have current or previous ownership interests in 40 and 14 sites, respectively, previously associated with the production of gas for which they may be liable for investigation, remediation and monitoring costs. IPL and WPL have received letters from state environmental agencies requiring no further action at 13 and 9 of these sites, respectively. Additionally, IPL has met state environmental agency expectations at 3 additional sites requiring no further action for soil remediation. IPL and WPL are 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.

Alliant Energy records environmental liabilities related to these MGP sites based upon periodic 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. Management currently estimates the range of remaining costs to be incurred for the investigation, remediation and monitoring of these sites to be $18 million ($16 million for IPL and $2 million for WPL) to $42 million ($38 million for IPL and $4 million for WPL). At December 31, 2012, Alliant Energy recorded $29 million in current and non-current environmental liabilities for its remaining costs to be incurred for these MGP sites.

Refer to Note 1(b) for discussion of regulatory assets recorded by IPL and WPL, which reflect the probable future rate recovery of MGP expenditures. Considering the current rate treatment, and assuming no material change therein, Alliant Energy believes that the clean-up costs incurred for these MGP sites will not have a material effect on its financial condition or results of operations. Settlement has been reached with all of IPL's and WPL's insurance carriers regarding reimbursement for their 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, Alliant Energy is also monitoring various environmental regulations that may have a significant impact on its future operations. Given uncertainties regarding the outcome, timing and compliance plans for these environmental matters, Alliant Energy 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 potential environmental matters that may require significant future expenditures are included below along with a brief description of these environmental regulations.

## Air Quality -

CAIR/CSAPR - CAIR is an emissions trading program that requires SO2 and NOx emissions reductions at IPL's and WPL's fossil-fueled electric generating units (EGUs) with greater than 25 MW capacity located in Iowa and Wisconsin through installation of emission controls and/or purchases of allowances. The requirements for SO2 and NOx reductions started in 2010 and 2009, respectively. CSAPR was expected to replace CAIR starting in 2012, however, it was subsequently vacated and remanded to the EPA for further revision by the D.C. Circuit Court. In January 2013, the D.C. Circuit Court denied the EPA's request for rehearing of the decision that vacated and remanded CSAPR for further revision. Petitioners may seek the Supreme Court's review of this decision and, during the interim, CAIR remains effective.

Clean Air Visibility Rule (CAVR) addresses regional haze at national parks and wilderness areas and is expected to require reductions in visibility-imparing emissions, including SO2, NOx and particulate matter, from certain EGUs by installing emission controls including those determined to be Best Available Retrofit Technology (BART). In 2012, the EPA published a final rule that would allow BART obligations for SO2 and NOx emissions to be fulfilled by compliance with CSAPR. In 2012, the EPA also approved the Iowa, Minnesota and Wisconsin CAVR plans, which would require compliance with CSAPR to fulfill BART requirements for SO2 and NOx emission reductions. In 2012, CSAPR requirements were vacated by the D.C. Circuit Court and the related rule that allowed for CAVR BART obligations to be met by CSAPR was challenged in the D.C. Circuit Court. It is unknown whether the EPA will allow BART to be fulfilled by CAIR, a modified CSAPR or another rule. This outcome remains uncertain pending the ongoing D.C. Circuit Court's review of these regulations and the EPA's responses to resolve the court orders on these rules.

Utility MACT Rule requires compliance with numerical emission limitations and work practice standards for the control of mercury and other federal hazardous air pollutants for coal-fueled EGUs with greater than 25 MW capacity. Compliance is currently expected to be required by April 2015. In 2012, the EPA issued a proposed reconsideration to limited aspects to the Utility MACT rule including revisions to the startup and shutdown provisions for existing EGUs. The EPA plans to issue a final reconsideration rule by March 2013.

Wisconsin State Mercury Rule requires WPL’s existing coal-fueled EGUs to reduce 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 RACT Rule requires NOx emissions reductions at Edgewater to support achieving compliance with 2013 requirements since it is located in Sheboygan County, which is currently designated as a non-attainment area for Ozone National Ambient Air Quality Standards (NAAQS). WPL installed NOx emission controls technologies at Edgewater, which met the 2009 to 2012 compliance requirements under this rule. In 2012, WPL completed the installation of an SCR at Edgewater to support achieving compliance with the 2013 requirements.

Industrial Boiler and Process Heater MACT Rule requires reductions of emissions of hazardous air pollutants at certain EGUs, and auxiliary boilers and process heaters located at EGUs. In December 2012, the EPA issued a final reconsidered rule with a compliance deadline of early 2016 for major sources. The final rule remains subject to legal challenges in the D.C. Circuit Court.

Ozone NAAQS Rule reduced the primary standard to a level of 0.075 parts per million. In 2012, the EPA issued a final rule that classifies Sheboygan County in Wisconsin as marginal non-attainment, which requires this area to achieve the eight-hour ozone NAAQS by December 2015. WPL operates Edgewater and the Sheboygan Falls Energy Facility in Sheboygan County, Wisconsin.

Fine Particle NAAQS Rule - In 2012, the EPA issued a final rule revising the fine particle primary NAAQS (PM2.5 NAAQS), which strengthens the annual standard from 15 micrograms per cubic meter ( \( \mu \) g/m \( ^{3} \) ) to 12  \( \mu \) g/m \( ^{3} \) . The EPA is expected to designate non-attainment areas for the revised annual PM2.5 NAAQS by December 2015. Compliance with the final rule is expected to be required by 2020 for non-attainment areas designated in 2015.

Nitrogen Dioxide (NO2) NAAQS Rule requires a new 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 of 53 ppb. The EPA is expected to re-evaluate non-attainment areas for the NO2 NAAQS in 2016 based on expanded monitoring data. The schedule for compliance has not yet been established.



SO2 NAAQS Rule requires a new one-hour NAAQS for SO2 at a level of 75 ppb. The EPA plans to finalize non-attainment designations for the SO2 NAAQS for certain parts of Iowa and Wisconsin in June 2013. The compliance deadline for SO2 NAAQS is currently expected to be required by 2017 for non-attainment areas finalized in 2013.

## Water Quality -

Section 316(b) of the Federal Clean Water Act proposal is expected to require modifications to 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 schedule for compliance has not yet been finalized; however, compliance will likely be required within eight years of the effective date of the final rule. A final rule is expected to be issued by the EPA in 2013.

Wisconsin and Iowa State Thermal Rules may require modifications to certain of WPL's and IPL's EGUs to limit the amount of heat those facilities can discharge into Wisconsin and Iowa waters, respectively. Compliance with the thermal rules will be evaluated on a case-by-case basis as discharge permits for WPL's and IPL's EGUs are renewed.

Hydroelectric Fish Passage Device - FERC issued an order requiring an agency-approved fish passage to be installed at WPL's Prairie du Sac hydro plant by December 2012. In 2012, FERC extended the installation deadline to July 1, 2015. In January 2013, WPL requested the U.S. Fish and Wildlife Service (FWS) delay or withdraw the fish passage requirement due to recent concerns regarding Asian carp and other invasive species. The FWS agreed to prepare an environmental impact study, during which time WPL is expected to request a further extension of the project deadlines.

## 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 coal ash surface impoundments (ash ponds) and/or landfills. The EPA issued a proposed regulation for public comment in 2010, and a final rule is expected in 2013. The schedule for compliance with the CCR Rule has not yet been established.

Polychlorinated Biphenyls (PCB) - The EPA is re-evaluating the existing authorized uses of PCB-containing equipment and other applications. The EPA is expected to issue proposed PCB rules for public comment in 2014 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 Gases (GHG) Emissions -

EPA New Source Performance Standards (NSPS) for GHG Emissions from Electric Utilities is expected to require performance standards for GHG emissions from new and existing fossil-fueled EGUs. In 2012, the EPA published proposed NSPS for GHG, including carbon dioxide (CO \( _{2} \) ) emissions from new fossil-fueled EGUs larger than 25 MW (not including simple-cycle combustion turbines), with an output-based emissions rate limitation of 1,000 pounds of CO \( _{2} \)  per MWh. This emissions rate limitation is expected to be effective upon the EPA's issuance of the final rule in the second quarter of 2013. The issuance of proposed regulations for existing EGUs remains delayed and it is anticipated the EPA will issue proposed regulations by the end of 2013. The schedule for compliance with the NSPS has not yet been established.

(f) Credit Risk - Alliant Energy, IPL and WPL are 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.

IPL and WPL provide regulated electricity and natural gas services to residential, commercial, industrial and wholesale customers in the Midwest region of the U.S. The geographic concentration of their customers did not contribute significantly to their overall exposure to credit risk. In addition, as a result of their diverse customer base, IPL and WPL did not have any significant concentration of credit risk for receivables arising from the sale of electricity and natural gas services.

IPL and WPL are typically net buyers of commodities (primarily electricity, coal and natural gas) required to provide regulated electricity and natural gas services to their customers. As a result, IPL and WPL are also subject to credit risk related to their counterparties' failures to deliver commodities at the contracted price.

Alliant Energy, IPL and WPL maintain credit policies to minimize their 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 a single counterparty. Based on these credit policies, it is unlikely that a material effect on Alliant Energy’s financial condition or results of operations would occur as a result of counterparty non-performance. However, there is no assurance that such policies will protect Alliant Energy against all losses from non-performance by counterparties.

Refer to Notes 1(p) and 12 for details of allowances for doubtful accounts and credit risk-related contingent features, respectively.

(g) Collective Bargaining Agreements - At December 31, 2012, employees covered by collective bargaining agreements represented 55%, 67% and 80% of total employees of Alliant Energy, IPL and WPL, respectively. In August 2013, IPL's collective bargaining agreement with International Brotherhood of Electrical Workers Local 204 (Cedar Rapids) expires, representing 18% and 44% of total employees of Alliant Energy and IPL, respectively.

## (14) JOINTLY-OWNED ELECTRIC UTILITY PLANT

Under joint ownership agreements with other utilities, IPL and WPL have undivided ownership interests in jointly-owned coal-fired 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. IPL's and WPL's shares of expenses from jointly-owned coal-fired electric generating facilities are included in the corresponding operating expenses (e.g., electric production fuel, other operation and maintenance, etc.) in their Consolidated Statements of Income. Refer to Note 1(b) for further discussion of cost of removal obligations. Information relative to IPL's and WPL's ownership interest in these jointly-owned coal-fired electric generating facilities at December 31, 2012 was as follows (dollars in millions):

<table><tr><td></td><td>In-service Dates</td><td>Ownership Interest %</td><td>Plant in Service</td><td>Accumulated Provision for Depreciation</td><td>Construction Work in Progress</td><td>Cost of Removal Obligations Included in Regulatory Liabilities</td></tr><tr><td>IPL</td><td></td><td></td><td></td><td></td><td></td><td></td></tr><tr><td>Ottumwa Unit 1</td><td>1981</td><td>48.0%</td><td>$239.2</td><td>$118.8</td><td>$84.0</td><td>$12.0</td></tr><tr><td>George Neal Unit 4</td><td>1979</td><td>25.7%</td><td>97.1</td><td>67.8</td><td>44.5</td><td>11.5</td></tr><tr><td>George Neal Unit 3</td><td>1975</td><td>28.0%</td><td>59.1</td><td>39.1</td><td>27.2</td><td>5.6</td></tr><tr><td>Louisa Unit 1</td><td>1983</td><td>4.0%</td><td>35.0</td><td>19.2</td><td>0.2</td><td>3.0</td></tr><tr><td></td><td></td><td></td><td>430.4</td><td>244.9</td><td>155.9</td><td>32.1</td></tr><tr><td>WPL</td><td></td><td></td><td></td><td></td><td></td><td></td></tr><tr><td>Columbia Units 1-2</td><td>1975-1978</td><td>46.2%</td><td>247.0</td><td>157.9</td><td>133.5</td><td>10.2</td></tr><tr><td>Edgewater Unit 4</td><td>1969</td><td>68.2%</td><td>91.8</td><td>49.2</td><td>0.4</td><td>2.2</td></tr><tr><td></td><td></td><td></td><td>338.8</td><td>207.1</td><td>133.9</td><td>12.4</td></tr><tr><td>Alliant Energy</td><td></td><td></td><td>$769.2</td><td>$452.0</td><td>$289.8</td><td>$44.5</td></tr></table>

## (15) SEGMENTS OF BUSINESS

Alliant Energy’s principal businesses as of December 31, 2012 are:
- Utility - includes the operations of IPL and WPL, which serve customers in Iowa, Wisconsin and Minnesota. The utility business has three reportable segments: a) utility electric operations; b) utility gas operations; and c) utility other, which includes steam operations, 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 Utility.”

- Non-regulated, Parent and Other - includes the operations of Resources and its subsidiaries, Corporate Services, the Alliant Energy parent company, and any Alliant Energy parent company consolidating adjustments. Resources' businesses include Transportation, Non-regulated Generation and other non-regulated investments described in Note 1(a).

Alliant Energy’s administrative support services are directly charged to the applicable segment where practicable. In all other cases, administrative support services are allocated to the applicable segment based on services agreements. Intersegment revenues were not material to Alliant Energy’s operations and there was no single customer whose revenues were 10% or more of Alliant Energy’s consolidated revenues. Certain financial information relating to Alliant Energy’s business segments, products and services and geographic information was as follows (in millions):



<table><tr><td rowspan="2">2012</td><td colspan="4">Utility</td><td rowspan="2">Non-Regulated, Parent and Other</td><td rowspan="2">Alliant Energy Consolidated</td></tr><tr><td>Electric</td><td>Gas</td><td>Other</td><td>Total</td></tr><tr><td>Operating revenues</td><td>$2,589.3</td><td>$396.3</td><td>$56.7</td><td>$3,042.3</td><td>$52.2</td><td>$3,094.5</td></tr><tr><td>Depreciation and amortization</td><td>299.3</td><td>29.1</td><td>1.4</td><td>329.8</td><td>2.6</td><td>332.4</td></tr><tr><td>Operating income</td><td>426.2</td><td>51.5</td><td>7.4</td><td>485.1</td><td>34.6</td><td>519.7</td></tr><tr><td>Interest expense, net of AFUDC</td><td></td><td></td><td></td><td>136.8</td><td>(2.0)</td><td>134.8</td></tr><tr><td>Equity (income) loss from unconsolidated investments, net</td><td>(42.1)</td><td>—</td><td>—</td><td>(42.1)</td><td>0.8</td><td>(41.3)</td></tr><tr><td>Interest income and other</td><td></td><td></td><td></td><td>(0.3)</td><td>(3.7)</td><td>(4.0)</td></tr><tr><td>Income taxes</td><td></td><td></td><td></td><td>74.8</td><td>14.6</td><td>89.4</td></tr><tr><td>Income from continuing operations, net of tax</td><td></td><td></td><td></td><td>315.9</td><td>24.9</td><td>340.8</td></tr><tr><td>Loss from discontinued operations, net of tax</td><td></td><td></td><td></td><td>—</td><td>(5.1)</td><td>(5.1)</td></tr><tr><td>Net income</td><td></td><td></td><td></td><td>315.9</td><td>19.8</td><td>335.7</td></tr><tr><td>Preferred dividends</td><td></td><td></td><td></td><td>15.9</td><td>—</td><td>15.9</td></tr><tr><td>Net income attributable to Alliant Energy common shareowners</td><td></td><td></td><td></td><td>300.0</td><td>19.8</td><td>319.8</td></tr><tr><td>Total assets</td><td>8,438.8</td><td>814.8</td><td>966.0</td><td>10,219.6</td><td>565.9</td><td>10,785.5</td></tr><tr><td>Investments in equity method subsidiaries</td><td>264.3</td><td>—</td><td>—</td><td>264.3</td><td>2.3</td><td>266.6</td></tr><tr><td>Construction and acquisition expenditures</td><td>994.0</td><td>31.4</td><td>0.1</td><td>1,025.5</td><td>132.6</td><td>1,158.1</td></tr></table>

<table><tr><td rowspan="2">2011</td><td colspan="4">Utility</td><td rowspan="2">Non-Regulated, Parent and Other</td><td rowspan="2">Alliant Energy Consolidated</td></tr><tr><td>Electric</td><td>Gas</td><td>Other</td><td>Total</td></tr><tr><td>Operating revenues</td><td>$2,635.8</td><td>$476.7</td><td>$62.0</td><td>$3,174.5</td><td>$46.9</td><td>$3,221.4</td></tr><tr><td>Depreciation and amortization</td><td>289.0</td><td>28.4</td><td>1.8</td><td>319.2</td><td>1.8</td><td>321.0</td></tr><tr><td>Operating income (loss)</td><td>444.2</td><td>47.8</td><td>(3.2)</td><td>488.8</td><td>24.5</td><td>513.3</td></tr><tr><td>Interest expense, net of AFUDC</td><td></td><td></td><td></td><td>146.6</td><td>(0.3)</td><td>146.3</td></tr><tr><td>Equity income from unconsolidated investments, net</td><td>(38.7)</td><td>—</td><td>—</td><td>(38.7)</td><td>(0.6)</td><td>(39.3)</td></tr><tr><td>Interest income and other</td><td></td><td></td><td></td><td>(0.2)</td><td>(4.1)</td><td>(4.3)</td></tr><tr><td>Income tax expense (benefit)</td><td></td><td></td><td></td><td>78.3</td><td>(9.1)</td><td>69.2</td></tr><tr><td>Income from continuing operations, net of tax</td><td></td><td></td><td></td><td>302.8</td><td>38.6</td><td>341.4</td></tr><tr><td>Loss from discontinued operations, net of tax</td><td></td><td></td><td></td><td>—</td><td>(19.5)</td><td>(19.5)</td></tr><tr><td>Net income</td><td></td><td></td><td></td><td>302.8</td><td>19.1</td><td>321.9</td></tr><tr><td>Preferred dividends</td><td></td><td></td><td></td><td>18.3</td><td>—</td><td>18.3</td></tr><tr><td>Net income attributable to Alliant Energy common shareowners</td><td></td><td></td><td></td><td>284.5</td><td>19.1</td><td>303.6</td></tr><tr><td>Total assets</td><td>7,524.5</td><td>831.9</td><td>781.1</td><td>9,137.5</td><td>550.4</td><td>9,687.9</td></tr><tr><td>Investments in equity method subsidiaries</td><td>246.5</td><td>—</td><td>—</td><td>246.5</td><td>3.1</td><td>249.6</td></tr><tr><td>Construction and acquisition expenditures</td><td>542.7</td><td>38.0</td><td>27.4</td><td>608.1</td><td>65.3</td><td>673.4</td></tr></table>



<table><tr><td rowspan="2">2010</td><td colspan="3">Utility</td><td rowspan="2">Non-Regulated, Parent and Other</td><td rowspan="2">Alliant Energy Consolidated</td></tr><tr><td>Electric</td><td>Gas</td><td>Other</td></tr><tr><td>Operating revenues</td><td>$2,674.2</td><td>$480.6</td><td>$64.6</td><td>$3,219.4</td><td>$42.7</td></tr><tr><td>Depreciation and amortization</td><td>255.1</td><td>25.2</td><td>5.3</td><td>285.6</td><td>1.7</td></tr><tr><td>Operating income (loss)</td><td>489.8</td><td>53.4</td><td>(2.5)</td><td>540.7</td><td>19.3</td></tr><tr><td>Interest expense, net of AFUDC</td><td></td><td></td><td></td><td>142.8</td><td>2.0</td></tr><tr><td>Equity income from unconsolidated investments, net</td><td>(37.8)</td><td>—</td><td>—</td><td>(37.8)</td><td>(0.3)</td></tr><tr><td>Interest income and other</td><td></td><td></td><td></td><td>(0.6)</td><td>(4.0)</td></tr><tr><td>Income taxes</td><td></td><td></td><td></td><td>140.6</td><td>7.1</td></tr><tr><td>Income from continuing operations, net of tax</td><td></td><td></td><td></td><td>295.7</td><td>14.5</td></tr><tr><td>Loss from discontinued operations, net of tax</td><td></td><td></td><td></td><td>—</td><td>(3.9)</td></tr><tr><td>Net income</td><td></td><td></td><td></td><td>295.7</td><td>10.6</td></tr><tr><td>Preferred dividends</td><td></td><td></td><td></td><td>18.7</td><td>—</td></tr><tr><td>Net income attributable to Alliant Energy common shareowners</td><td></td><td></td><td></td><td>277.0</td><td>10.6</td></tr><tr><td>Total assets</td><td>7,227.2</td><td>817.6</td><td>782.4</td><td>8,827.2</td><td>455.7</td></tr><tr><td>Investments in equity method subsidiaries</td><td>236.0</td><td>—</td><td>—</td><td>236.0</td><td>2.5</td></tr><tr><td>Construction and acquisition expenditures</td><td>729.1</td><td>39.9</td><td>64.3</td><td>833.3</td><td>33.6</td></tr></table>

Products and Services - Alliant Energy’s consolidated operating revenues by segment were as follows:

<table><tr><td></td><td>2012</td><td>2011</td><td>2010</td></tr><tr><td>Utility electric operations</td><td>84%</td><td>82%</td><td>82%</td></tr><tr><td>Utility gas operations</td><td>13%</td><td>15%</td><td>15%</td></tr><tr><td>Utility other</td><td>2%</td><td>2%</td><td>2%</td></tr><tr><td>Other</td><td>1%</td><td>1%</td><td>1%</td></tr><tr><td></td><td>100%</td><td>100%</td><td>100%</td></tr></table>

Geographic Information - At December 31, 2012, 2011 and 2010, Alliant Energy did not have any long-lived assets to be held and used in foreign countries.

## (16) SELECTED CONSOLIDATED QUARTERLY FINANCIAL DATA (UNAUDITED)

All “per share” references refer to earnings per diluted share. Summation of the individual quarters may not equal annual totals due to rounding. Refer to Note 17 for additional information on discontinued operations.

<table><tr><td rowspan="3"></td><td colspan="5">2012</td><td colspan="5">2011</td></tr><tr><td>March 31</td><td>June 30</td><td>Sep. 30</td><td>Dec. 31</td><td>March 31</td><td>June 30</td><td>Sep. 30</td><td>Dec.31</td><td></td><td></td></tr><tr><td colspan="10">(in millions, except per share data)</td></tr><tr><td>Operating revenues</td><td>$765.7</td><td>$690.3</td><td>$887.6</td><td>$750.9</td><td>$877.2</td><td>$712.5</td><td>$870.9</td><td>$760.8</td><td></td><td></td></tr><tr><td>Operating income</td><td>95.6</td><td>108.8</td><td>213.7</td><td>101.6</td><td>127.3</td><td>70.6</td><td>209.4</td><td>106.0</td><td></td><td></td></tr><tr><td>Amounts attributable to Alliant Energy common shareowners:</td><td></td><td></td><td></td><td></td><td></td><td></td><td></td><td></td><td></td><td></td></tr><tr><td>Income from continuing operations, net of tax</td><td>39.3</td><td>65.5</td><td>149.0</td><td>71.1</td><td>72.0</td><td>50.3</td><td>136.9</td><td>63.9</td><td></td><td></td></tr><tr><td>Income (loss) from discontinued operations, net of tax</td><td>(4.4)</td><td>0.4</td><td>1.7</td><td>(2.8)</td><td>1.5</td><td>0.8</td><td>(14.9)</td><td>(6.9)</td><td></td><td></td></tr><tr><td>Net income</td><td>34.9</td><td>65.9</td><td>150.7</td><td>68.3</td><td>73.5</td><td>51.1</td><td>122.0</td><td>57.0</td><td></td><td></td></tr><tr><td>Earnings per weighted average common share attributable to Alliant Energy common shareowners:</td><td></td><td></td><td></td><td></td><td></td><td></td><td></td><td></td><td></td><td></td></tr><tr><td>Income from continuing operations, net of tax</td><td>0.36</td><td>0.60</td><td>1.34</td><td>0.64</td><td>0.65</td><td>0.45</td><td>1.23</td><td>0.58</td><td></td><td></td></tr><tr><td>Income (loss) from discontinued operations, net of tax</td><td>(0.04)</td><td>—</td><td>0.02</td><td>(0.02)</td><td>0.01</td><td>0.01</td><td>(0.13)</td><td>(0.07)</td><td></td><td></td></tr><tr><td>Net income</td><td>0.32</td><td>0.60</td><td>1.36</td><td>0.62</td><td>0.66</td><td>0.46</td><td>1.10</td><td>0.51</td><td></td><td></td></tr></table>



## (17) DISCONTINUED OPERATIONS AND ASSETS AND LIABILITIES HELD FOR SALE

In 2011, Alliant Energy sold its IEA business to narrow its strategic focus and risk profile and received net proceeds of $5 million. In 2011, RMT sold its environmental business unit and received net proceeds of $12 million. In January 2013, Alliant Energy sold the remainder of its RMT business in order to narrow its strategic focus and risk profile. The final gain or loss from the sale of RMT is subject to a working capital adjustment and potential contingent consideration. Alliant Energy does not currently believe the final gain or loss related to the sale of RMT will be material. The RMT business qualified as assets and liabilities held for sale as of December 31, 2012.

The operating results of RMT and IEA have been separately classified and reported as discontinued operations in the Consolidated Statements of Income. A summary of the components of discontinued operations in the Consolidated Statements of Income was as follows (in millions):

<table><tr><td></td><td>2012</td><td>2011</td><td>2010</td></tr><tr><td>Operating revenues</td><td>$289.2</td><td>$445.0</td><td>$160.3</td></tr><tr><td>Operating expenses</td><td>297.0</td><td>476.9</td><td>166.8</td></tr><tr><td>Interest expense and other</td><td>0.7</td><td>—</td><td>1.0</td></tr><tr><td>Loss before income taxes</td><td>(8.5)</td><td>(31.9)</td><td>(7.5)</td></tr><tr><td>Income tax benefit</td><td>(3.4)</td><td>(12.4)</td><td>(3.6)</td></tr><tr><td>Loss from discontinued operations, net of tax</td><td>($5.1)</td><td>($19.5)</td><td>($3.9)</td></tr></table>

A summary of the assets and liabilities held for sale on the Consolidated Balance Sheets as of December 31 was as follows (in millions):

<table><tr><td></td><td>2012</td><td>2011</td></tr><tr><td>Assets held for sale:</td><td></td><td></td></tr><tr><td>Property, plant and equipment, net</td><td>$—</td><td>$3.8</td></tr><tr><td>Current assets</td><td>27.9</td><td>115.5</td></tr><tr><td>Other assets</td><td>—</td><td>0.3</td></tr><tr><td>Total assets held for sale</td><td>27.9</td><td>119.6</td></tr><tr><td>Liabilities held for sale:</td><td></td><td></td></tr><tr><td>Current liabilities</td><td>31.4</td><td>62.0</td></tr><tr><td>Other long-term liabilities and deferred credits</td><td>—</td><td>0.1</td></tr><tr><td>Total liabilities held for sale</td><td>31.4</td><td>62.1</td></tr><tr><td>Net assets (liabilities) held for sale</td><td>($3.5)</td><td>$57.5</td></tr></table>

Based on the terms of the January 2013 sale of RMT, the fair value of the business, less costs to sell, was not less than the carrying amount.

## (18) ASSET RETIREMENT OBLIGATIONS (AROs)

AROs recognized by Alliant Energy relate to legal obligations for the removal, closure or dismantlement of several assets including, but not limited to, wind projects, certain ash ponds, certain coal yards, active ash landfills and above ground storage tanks. Alliant Energy’s recognized AROs also include legal obligations for the management and final disposition of asbestos and PCB. 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):

<table><tr><td></td><td>2012</td><td>2011</td></tr><tr><td>Balance, January 1</td><td>$91.1</td><td>$75.9</td></tr><tr><td>Revisions in estimated cash flows (a)</td><td>(6.4)</td><td>7.8</td></tr><tr><td>Liabilities settled</td><td>(3.4)</td><td>(0.9)</td></tr><tr><td>Liabilities incurred (b)</td><td>16.8</td><td>4.0</td></tr><tr><td>Accretion expense</td><td>3.4</td><td>4.3</td></tr><tr><td>Balance, December 31</td><td>$101.5</td><td>$91.1</td></tr></table>



(a) In 2012 and 2011, IPL recorded revisions in estimated cash flows of ($8.2) million and $7.0 million, respectively, based on revised remediation timing and cost information for asbestos remediation at Sixth Street.

(b) In 2012, Resources recorded AROs of $9.1 million related to its Franklin County wind project and WPL recorded AROs of $7.6 million related to Nelson Dewey.

In addition, certain of Alliant Energy’s AROs related to electric generating facility assets have not been recognized. Due to an indeterminate remediation date, the fair values of the AROs for these assets cannot be currently estimated. A liability for these AROs will be recorded when fair value is determinable. Removal costs of these facilities are being recovered in rates and are recorded in regulatory liabilities.

## (19) RELATED PARTIES

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. As of December 31, 2012 and 2011, WPL owed ATC net amounts of $6 million and $6 million, respectively. The related amounts billed between the parties were as follows (in millions):

<table><tr><td></td><td>2012</td><td>2011</td><td>2010</td></tr><tr><td>ATC billings to WPL</td><td>$90</td><td>$90</td><td>$92</td></tr><tr><td>WPL billings to ATC</td><td>11</td><td>12</td><td>11</td></tr></table>

## (20) EARNINGS PER SHARE

A reconciliation of the weighted average common shares outstanding used in the basic and diluted earnings per weighted average common share (EPS) calculation was as follows (in thousands):

<table><tr><td></td><td>2012</td><td>2011</td><td>2010</td></tr><tr><td>Weighted average common shares outstanding:</td><td></td><td></td><td></td></tr><tr><td>Basic EPS calculation</td><td>110,753</td><td>110,626</td><td>110,442</td></tr><tr><td>Effect of dilutive share-based awards</td><td>15</td><td>52</td><td>79</td></tr><tr><td>Diluted EPS calculation</td><td>110,768</td><td>110,678</td><td>110,521</td></tr></table>

For 2012, 2011 and 2010, there were no potentially dilutive securities excluded from the calculation of diluted EPS.



## SELECTED FINANCIAL AND OPERATING STATISTICS

<table><tr><td>Financial Information</td><td>2012 (a)</td><td>2011 (a)</td><td>2010 (a)</td><td>2009 (b)</td><td>2008</td></tr><tr><td colspan="6">(dollars in millions, except per share data)</td></tr><tr><td>Income Statement Data:</td><td></td><td></td><td></td><td></td><td></td></tr><tr><td>Operating revenues</td><td>$3,094.5</td><td>$3,221.4</td><td>$3,262.1</td><td>$3,133.2</td><td>$3,272.3</td></tr><tr><td>Income from continuing operations, net of tax</td><td>340.8</td><td>341.4</td><td>310.2</td><td>130.3</td><td>284.5</td></tr><tr><td>Income (loss) from discontinued operations, net of tax</td><td>(5.1)</td><td>(19.5)</td><td>(3.9)</td><td>(0.6)</td><td>22.2</td></tr><tr><td>Net income</td><td>335.7</td><td>321.9</td><td>306.3</td><td>129.7</td><td>306.7</td></tr><tr><td>Amounts attributable to Alliant Energy common shareowners:</td><td></td><td></td><td></td><td></td><td></td></tr><tr><td>Income from continuing operations, net of tax</td><td>324.9</td><td>323.1</td><td>291.5</td><td>111.6</td><td>265.8</td></tr><tr><td>Income (loss) from discontinued operations, net of tax</td><td>(5.1)</td><td>(19.5)</td><td>(3.9)</td><td>(0.6)</td><td>22.2</td></tr><tr><td>Net income</td><td>319.8</td><td>303.6</td><td>287.6</td><td>111.0</td><td>288.0</td></tr><tr><td>Common Stock Data:</td><td></td><td></td><td></td><td></td><td></td></tr><tr><td>Earnings per weighted average common share attributable to Alliant Energy common shareowners (basic and diluted):</td><td></td><td></td><td></td><td></td><td></td></tr><tr><td>Income from continuing operations, net of tax</td><td>$2.93</td><td>$2.92</td><td>$2.64</td><td>$1.01</td><td>$2.41</td></tr><tr><td>Income (loss) from discontinued operations, net of tax</td><td>($0.04)</td><td>($0.18)</td><td>($0.04)</td><td>$—</td><td>$0.20</td></tr><tr><td>Net income</td><td>$2.89</td><td>$2.74</td><td>$2.60</td><td>$1.01</td><td>$2.61</td></tr><tr><td>Common shares outstanding at year-end (000s)</td><td>110,987</td><td>111,019</td><td>110,894</td><td>110,656</td><td>110,449</td></tr><tr><td>Dividends declared per common share</td><td>$1.80</td><td>$1.70</td><td>$1.58</td><td>$1.50</td><td>$1.40</td></tr><tr><td>Market value per share at year-end</td><td>$43.91</td><td>$44.11</td><td>$36.77</td><td>$30.26</td><td>$29.18</td></tr><tr><td>Book value per share at year-end</td><td>$28.25</td><td>$27.14</td><td>$26.09</td><td>$25.06</td><td>$25.56</td></tr><tr><td>Market capitalization at year-end</td><td>$4,873.4</td><td>$4,897.0</td><td>$4,077.6</td><td>$3,348.5</td><td>$3,222.9</td></tr><tr><td>Other Selected Financial Data:</td><td></td><td></td><td></td><td></td><td></td></tr><tr><td>Cash flows from operating activities</td><td>$841.1</td><td>$702.7</td><td>$984.9</td><td>$657.1</td><td>$338.2</td></tr><tr><td>Construction and acquisition expenditures</td><td>$1,158.1</td><td>$673.4</td><td>$866.9</td><td>$1,202.6</td><td>$879.0</td></tr><tr><td>Total assets at year-end</td><td>$10,785.5</td><td>$9,687.9</td><td>$9,282.9</td><td>$9,036.0</td><td>$8,201.5</td></tr><tr><td>Long-term obligations, net</td><td>$3,141.5</td><td>$2,708.0</td><td>$2,710.3</td><td>$2,512.2</td><td>$1,887.1</td></tr><tr><td>Times interest earned before income taxes (c)</td><td>3.75X</td><td>3.59X</td><td>3.81X</td><td>1.80X</td><td>4.30X</td></tr><tr><td>Capitalization ratios:</td><td></td><td></td><td></td><td></td><td></td></tr><tr><td>Common equity</td><td>47%</td><td>50%</td><td>49%</td><td>49%</td><td>56%</td></tr><tr><td>Preferred stock of subsidiaries</td><td>3%</td><td>3%</td><td>4%</td><td>4%</td><td>5%</td></tr><tr><td>Long- and short-term debt</td><td>50%</td><td>47%</td><td>47%</td><td>47%</td><td>39%</td></tr><tr><td>Total</td><td>100%</td><td>100%</td><td>100%</td><td>100%</td><td>100%</td></tr></table>

(a) Refer to “Results of Operations” in MDA for discussion of the 2012, 2011 and 2010 results of operations.

(b) In 2009, Alliant Energy incurred $203 million of pre-tax losses related to the repurchase of its 2.5% Exchangeable Senior Notes due 2030.

(c) Represents the sum of income from continuing operations before income taxes plus interest expense, divided by interest expense. The calculation does not consider the “Loss on early extinguishment of debt” that Alliant Energy has incurred as part of interest expense.



<table><tr><td>Electric Operating Information</td><td>2012</td><td>2011</td><td>2010</td><td>2009</td><td>2008</td></tr><tr><td>Operating Revenues (in millions):</td><td></td><td></td><td></td><td></td><td></td></tr><tr><td>Residential</td><td>$975.9</td><td>$985.8</td><td>$1,001.5</td><td>$868.6</td><td>$844.7</td></tr><tr><td>Commercial</td><td>611.4</td><td>612.1</td><td>619.0</td><td>556.8</td><td>537.5</td></tr><tr><td>Industrial</td><td>741.8</td><td>748.9</td><td>762.8</td><td>710.7</td><td>734.7</td></tr><tr><td>Retail subtotal</td><td>2,329.1</td><td>2,346.8</td><td>2,383.3</td><td>2,136.1</td><td>2,116.9</td></tr><tr><td>Sales for resale:</td><td></td><td></td><td></td><td></td><td></td></tr><tr><td>Wholesale</td><td>187.6</td><td>189.8</td><td>196.8</td><td>190.1</td><td>201.9</td></tr><tr><td>Bulk power and other</td><td>23.8</td><td>52.2</td><td>44.1</td><td>98.3</td><td>31.1</td></tr><tr><td>Other</td><td>48.8</td><td>47.0</td><td>50.0</td><td>51.4</td><td>61.4</td></tr><tr><td>Total</td><td>$2,589.3</td><td>$2,635.8</td><td>$2,674.2</td><td>$2,475.9</td><td>$2,411.3</td></tr><tr><td>Electric Sales (000s MWh):</td><td></td><td></td><td></td><td></td><td></td></tr><tr><td>Residential</td><td>7,679</td><td>7,740</td><td>7,836</td><td>7,532</td><td>7,664</td></tr><tr><td>Commercial</td><td>6,352</td><td>6,253</td><td>6,219</td><td>6,108</td><td>6,181</td></tr><tr><td>Industrial</td><td>11,555</td><td>11,504</td><td>11,213</td><td>10,948</td><td>12,490</td></tr><tr><td>Retail subtotal</td><td>25,586</td><td>25,497</td><td>25,268</td><td>24,588</td><td>26,335</td></tr><tr><td>Sales for resale:</td><td></td><td></td><td></td><td></td><td></td></tr><tr><td>Wholesale</td><td>3,317</td><td>3,372</td><td>3,325</td><td>3,251</td><td>3,813</td></tr><tr><td>Bulk power and other</td><td>1,303</td><td>1,757</td><td>1,378</td><td>2,583</td><td>983</td></tr><tr><td>Other</td><td>151</td><td>151</td><td>153</td><td>155</td><td>164</td></tr><tr><td>Total</td><td>30,357</td><td>30,777</td><td>30,124</td><td>30,577</td><td>31,295</td></tr><tr><td>Customers (End of Period):</td><td></td><td></td><td></td><td></td><td></td></tr><tr><td>Residential</td><td>844,388</td><td>842,780</td><td>841,726</td><td>840,927</td><td>840,644</td></tr><tr><td>Commercial</td><td>137,791</td><td>136,732</td><td>135,832</td><td>135,099</td><td>134,536</td></tr><tr><td>Industrial</td><td>2,842</td><td>2,895</td><td>2,875</td><td>2,881</td><td>2,934</td></tr><tr><td>Other</td><td>3,647</td><td>3,638</td><td>3,632</td><td>3,555</td><td>3,534</td></tr><tr><td>Total</td><td>988,668</td><td>986,045</td><td>984,065</td><td>982,462</td><td>981,648</td></tr><tr><td>Other Selected Electric Data:</td><td></td><td></td><td></td><td></td><td></td></tr><tr><td>Maximum peak hour demand (MW)</td><td>5,886</td><td>5,734</td><td>5,425</td><td>5,491</td><td>5,491</td></tr><tr><td>Cooling degree days (a):</td><td></td><td></td><td></td><td></td><td></td></tr><tr><td>Cedar Rapids, Iowa (IPL) (normal - 740)</td><td>1,052</td><td>887</td><td>923</td><td>406</td><td>583</td></tr><tr><td>Madison, Wisconsin (WPL) (normal - 625)</td><td>1,070</td><td>814</td><td>829</td><td>368</td><td>538</td></tr><tr><td>Sources of electric energy (000s MWh):</td><td></td><td></td><td></td><td></td><td></td></tr><tr><td>Coal</td><td>14,680</td><td>16,440</td><td>16,366</td><td>15,321</td><td>17,495</td></tr><tr><td>Purchased power:</td><td></td><td></td><td></td><td></td><td></td></tr><tr><td>Nuclear</td><td>5,483</td><td>5,483</td><td>5,667</td><td>5,428</td><td>5,465</td></tr><tr><td>Other (b)</td><td>8,241</td><td>7,529</td><td>7,514</td><td>9,542</td><td>7,866</td></tr><tr><td>Gas</td><td>1,285</td><td>588</td><td>633</td><td>661</td><td>1,037</td></tr><tr><td>Other (b)</td><td>1,381</td><td>1,413</td><td>820</td><td>402</td><td>245</td></tr><tr><td>Total</td><td>31,070</td><td>31,453</td><td>31,000</td><td>31,354</td><td>32,108</td></tr><tr><td>Revenue per kilowatt-hour (KWh) sold to retail customers (cents)</td><td>9.10</td><td>9.20</td><td>9.43</td><td>8.69</td><td>8.04</td></tr></table>

(a) Cooling degree days 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 cooling degree days.

(b) All or some of the renewable energy attributes associated with generation from these sources may be used in future years to comply with renewable energy standards or other regulatory requirements, or sold to third-parties in the form of renewable energy credits or other environmental commodities.



<table><tr><td>Gas Operating Information</td><td>2012</td><td>2011</td><td>2010</td><td>2009</td><td>2008</td></tr><tr><td>Operating Revenues (in millions):</td><td></td><td></td><td></td><td></td><td></td></tr><tr><td>Residential</td><td>$224.3</td><td>$269.7</td><td>$273.7</td><td>$290.8</td><td>$385.0</td></tr><tr><td>Commercial</td><td>124.3</td><td>155.1</td><td>154.2</td><td>174.7</td><td>240.5</td></tr><tr><td>Industrial</td><td>16.7</td><td>24.5</td><td>27.3</td><td>30.7</td><td>51.1</td></tr><tr><td>Retail subtotal</td><td>365.3</td><td>449.3</td><td>455.2</td><td>496.2</td><td>676.6</td></tr><tr><td>Transportation/other</td><td>31.0</td><td>27.4</td><td>25.4</td><td>29.1</td><td>33.8</td></tr><tr><td>Total</td><td>$396.3</td><td>$476.7</td><td>$480.6</td><td>$525.3</td><td>$710.4</td></tr><tr><td>Gas Sales (000s Dths):</td><td></td><td></td><td></td><td></td><td></td></tr><tr><td>Residential</td><td>23,071</td><td>26,891</td><td>27,128</td><td>27,711</td><td>30,630</td></tr><tr><td>Commercial</td><td>17,115</td><td>19,271</td><td>18,691</td><td>20,725</td><td>22,461</td></tr><tr><td>Industrial</td><td>3,068</td><td>3,848</td><td>4,158</td><td>4,558</td><td>5,558</td></tr><tr><td>Retail subtotal</td><td>43,254</td><td>50,010</td><td>49,977</td><td>52,994</td><td>58,649</td></tr><tr><td>Transportation/other</td><td>57,532</td><td>52,210</td><td>50,408</td><td>54,518</td><td>60,626</td></tr><tr><td>Total</td><td>100,786</td><td>102,220</td><td>100,385</td><td>107,512</td><td>119,275</td></tr><tr><td>Retail Customers at End of Period:</td><td></td><td></td><td></td><td></td><td></td></tr><tr><td>Residential</td><td>368,708</td><td>367,497</td><td>366,261</td><td>365,597</td><td>365,193</td></tr><tr><td>Commercial</td><td>45,684</td><td>45,667</td><td>45,552</td><td>45,641</td><td>45,413</td></tr><tr><td>Industrial</td><td>456</td><td>496</td><td>549</td><td>571</td><td>584</td></tr><tr><td>Total</td><td>414,848</td><td>413,660</td><td>412,362</td><td>411,809</td><td>411,190</td></tr><tr><td>Other Selected Gas Data:</td><td></td><td></td><td></td><td></td><td></td></tr><tr><td>Heating degree days (a):</td><td></td><td></td><td></td><td></td><td></td></tr><tr><td>Cedar Rapids, Iowa (IPL) (normal - 6,794)</td><td>5,901</td><td>6,745</td><td>6,868</td><td>7,074</td><td>7,636</td></tr><tr><td>Madison, Wisconsin (WPL) (normal - 7,089)</td><td>5,964</td><td>6,992</td><td>6,798</td><td>7,356</td><td>7,714</td></tr><tr><td>Revenue per Dth sold to retail customers</td><td>$8.45</td><td>$8.98</td><td>$9.11</td><td>$9.36</td><td>$11.54</td></tr><tr><td>Purchased gas costs per Dth sold to retail customers</td><td>$4.94</td><td>$5.88</td><td>$6.05</td><td>$6.47</td><td>$8.73</td></tr></table>

(a) Heating degree days 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 heating degree days.



<table><tr><td>Stock Exchange Listings</td><td>Trading Exchange</td><td>Trading Symbol</td><td>Newspaper Abbreviation</td></tr><tr><td>Alliant Energy — Common</td><td>New York Stock Exchange</td><td>LNT</td><td>AlliantEngy</td></tr><tr><td>Interstate Power and Light Company — 5.1% Preferred</td><td>New York Stock Exchange</td><td>IPL Pr D</td><td></td></tr></table>

<table><tr><td colspan="2">2013 Record and Dividend Payment Dates</td></tr><tr><td colspan="2">Anticipated record and payment dates are as follows:</td></tr></table>

<table><tr><td colspan="2">Common Stock</td></tr><tr><td>Record dates</td><td>Payment dates</td></tr><tr><td>Jan. 31</td><td>Feb. 15</td></tr><tr><td>Apr. 30</td><td>May 15</td></tr><tr><td>July 31</td><td>Aug. 15</td></tr><tr><td>Oct. 31</td><td>Nov. 15</td></tr></table>

<table><tr><td colspan="7">Common Stock Quarterly Price Ranges and Dividends</td></tr><tr><td></td><td colspan="3">2012</td><td colspan="3">2011</td></tr><tr><td>Quarter</td><td>High</td><td>Low</td><td>Dividend</td><td>High</td><td>Low</td><td>Dividend</td></tr><tr><td>First</td><td>$ 44.57</td><td>$ 41.86</td><td>$ 45</td><td>$ 40.68</td><td>$ 36.78</td><td>$ 42.5</td></tr><tr><td>Second</td><td>46.00</td><td>42.00</td><td>45</td><td>42.14</td><td>37.84</td><td>42.5</td></tr><tr><td>Third</td><td>47.65</td><td>42.95</td><td>45</td><td>42.09</td><td>33.91</td><td>42.5</td></tr><tr><td>Fourth</td><td>45.66</td><td>42.21</td><td>45</td><td>44.49</td><td>36.82</td><td>42.5</td></tr><tr><td>Year</td><td>47.65</td><td>41.86</td><td>1.80</td><td>44.49</td><td>33.91</td><td>1.70</td></tr></table>

Alliant Energy Corporation had 32,374 shareowners of record as of December 31, 2012. Shareowner records were maintained by Wells Fargo Shareowner Services in St. Paul, Minn.

Alliant Energy Corporation 2012 year-end common stock closing price: $43.91.

## Annual Meeting

The 2013 Annual Meeting of Shareowners will be held at the Cedar Rapids Marriott, 1200 Collins Road NE, Cedar Rapids, Iowa, on Thursday, May 9, 2013, at 10:30 a.m., Central Daylight Time (CDT).

## Form 10-K Information

Upon request, the Company will provide, without charge, copies of the Annual Report on Form 10-K for the year ended December 31, 2012, as filed with the Securities and Exchange Commission (SEC). All reports filed with the SEC are also available through our website at alliantenergy.com/investors.

## Analyst Inquiries

Inquiries from the financial community may be directed to:
Susan Trapp Gille
Manager-Investor Relations
4902 N. Biltmore Lane
Suite 1000
Madison, WI 53718-2148
Phone: 608-458-3956
Fax: 608-458-0132
E-mail:
susangille@alliantenergy.com

## Shareowner Direct Plan

The Shareowner Direct Plan is available to all shareowners of record and first-time investors. Through the plan, shareowners may buy common stock directly through the company without paying any brokerage commissions. Full details are in the prospectus, which can be obtained through our website or by calling Wells Fargo Shareowner Services. Contact information is listed on this page.

## Electronic Access to Alliant Energy’s Annual Report, Proxy Statement and Form 10-K

Alliant Energy offers shareowners access to its Annual Report, Proxy Statement and Form 10-K online at alliantenergy.com/investors as a convenient and cost-effective alternative to mailing the printed materials.

Shareowners who have access to the Internet are encouraged to enroll in the electronic access program at the website: shareowneronline.com.

## Direct Deposit

Shareowners who are not reinvesting their dividends through the Shareowner Direct Plan may choose to have their quarterly dividend electronically deposited into their checking or savings account. Electronic deposit may be initiated or changed through the website at shareowneronline.com or by calling Wells Fargo Shareowner Services. Contact information is listed on this page.

## Duplicate Mailings

Shares owned by one person but held in different forms of the same name result in duplicate mailing of shareowner information at added expense to the Company. Such duplication can be eliminated only at the direction of the shareowner. Please notify Wells Fargo Shareowner Services in order to eliminate duplication. Contact information is listed on this page.

## Stock Transfer Agent, Registrar and Dividend Payments

Wells Fargo Shareowner Services
1110 Centre Pointe Curve,
Suite 101
MAC N9173-010
Mendota Heights, MN 55120
PO. Box 64854
St. Paul, MN 55164-0854
Phone: 1-800-356-5343
7 a.m. to 7 p.m. CDT,
Monday through Friday.
shareowneronline.com
Fax: 651-450-4085

## Historical Research/Other Company Information

For assistance with account history for calculating your cost basis or requests for copies of our Annual Report, Proxy Statement and Form 10-K, please contact Alliant Energy Shareowner Services in Madison, Wis. using the contact information below.

## Additional Corporate Inquiries/Information

Alliant Energy
Shareowner Services
4902 North Biltmore Lane
PO Box 14720
Madison, WI 53708-0720
1-800-353-1089
Email: shareownerservices@alliantenergy.com



## Mission statement

We deliver the energy and exceptional service that our customers and communities count on – safely, efficiently and responsibly.

## Focusing our business – preparing for the future

There are three themes in our Strategic Plan:

Competitive costs: We will manage costs aggressively to maintain or improve our relative rate position when compared to our neighbors, regions or the U.S. average.

Reliable service: We will enhance the customer experience using proven advancements to improve system reliability and service.

Balanced generation: We will manage our generating fleet to reduce our reliance on market purchases, manage costs, and remain flexible to adapt to change.

Our filters to guide investments:

There are three key questions that we will ask ourselves on behalf of our customers and our regulators before we move forward with an investment, project or initiative:

Does it improve reliability?

Does it reduce costs, or would the majority of our customers be willing to pay for it?

Is it needed to comply with laws, regulations or safety rules?

## Alliant Energy
Corporate Headquarters

4902 North Biltmore Lane
Suite 1000

Madison, WI 53718-2148

General information: 1-800-ALLIANT

Individual shareowner questions
Alliant Energy Shareowner Services:
1-800-353-1089

Stock Transfer Agent and Registrar
Wells Fargo Shareowner Services:
1-800-356-5343

alliantenergy.com