UNITED STATES

SECURITIES AND EXCHANGE COMMISSION

WASHINGTON, D.C. 20549

FORM 10-Q



x	QUARTERLY REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934

For the quarterly period ended ~~June~~September 30, 2015



¨	TRANSITION REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934

For the transition period from to



Commission File Number	Name of Registrant, State of Incorporation, Address of Principal Executive Offices and Telephone Number	IRS Employer Identification Number
1-9894	ALLIANT ENERGY CORPORATION	39-1380265
	(a Wisconsin corporation)
	4902 N. Biltmore Lane
	Madison, Wisconsin 53718
	Telephone (608) 458-3311

1-4117	INTERSTATE POWER AND LIGHT COMPANY	42-0331370
	(an Iowa corporation)
	Alliant Energy Tower
	Cedar Rapids, Iowa 52401
	Telephone (319) 786-4411

0-337	WISCONSIN POWER AND LIGHT COMPANY	39-0714890
	(a Wisconsin corporation)
	4902 N. Biltmore Lane
	Madison, Wisconsin 53718
	Telephone (608) 458-3311

This combined Form 10-Q is separately filed by Alliant Energy Corporation, Interstate Power and Light Company and Wisconsin Power and Light Company. Information contained in the Form 10-Q relating to Interstate Power and Light Company and Wisconsin Power and Light Company is filed by each such registrant on its own behalf. Each of Interstate Power and Light Company and Wisconsin Power and Light Company makes no representation as to information relating to registrants other than itself.

Indicate by check mark whether the registrants (1) have filed all reports required to be filed by Section 13 or 15(d) of the Securities Exchange Act of 1934 during the preceding 12 months (or for such shorter period that the registrants were required to file such reports), and (2) have been subject to such filing requirements for the past 90 days. Yes x No ¨

Indicate by check mark whether the registrants have submitted electronically and posted on their corporate Web site, if any, every Interactive Data File required to be submitted and posted pursuant to Rule 405 of Regulation S-T (§232.405 of this chapter) during the preceding 12 months (or for such shorter period that the registrants were required to submit and post such files). Yes x No ¨

Indicate by check mark whether the registrants are large accelerated filers, accelerated filers, non-accelerated filers, or smaller reporting companies. See the definitions of “large accelerated filer,” “accelerated filer” and “smaller reporting company” in Rule 12b-2 of the Exchange Act.



	Large Accelerated Filer	Accelerated Filer	Non-accelerated Filer	Smaller Reporting Company Filer
Alliant Energy Corporation	x
Interstate Power and Light Company			x
Wisconsin Power and Light Company			x

Indicate by check mark whether the registrants are shell companies (as defined in Rule 12b-2 of the Exchange Act). Yes ¨ No x

Number of shares outstanding of each class of common stock as of ~~June~~September 30, 2015:



Alliant Energy Corporation	Common stock, $0.01 par value, ~~113,263,624~~113,360,425 shares outstanding

Interstate Power and Light Company	Common stock, $2.50 par value, 13,370,788 shares outstanding (all of which are owned beneficially and of record by Alliant Energy Corporation)

Wisconsin Power and Light Company	Common stock, $5 par value, 13,236,601 shares outstanding (all of which are owned beneficially and of record by Alliant Energy Corporation)

Table of Contents

TABLE OF CONTENTS



	Page
Definitions	1
Forward-looking Statements	2
Part I. Financial Information	4
Item 1. Condensed Consolidated Financial Statements (Unaudited)	4
Alliant Energy Corporation:
Condensed Consolidated Statements of Income for the Three and ~~Six~~Nine Months Ended ~~June~~September 30, 2015 and 2014	4
Condensed Consolidated Balance Sheets as of ~~June~~September 30, 2015 and December 31, 2014	5
Condensed Consolidated Statements of Cash Flows for the ~~Six~~Nine Months Ended ~~June~~September 30, 2015 and 2014	6
Interstate Power and Light Company:
Condensed Consolidated Statements of Income for the Three and ~~Six~~Nine Months Ended ~~June~~September 30, 2015 and 2014	7
Condensed Consolidated Balance Sheets as of ~~June~~September 30, 2015 and December 31, 2014	8
Condensed Consolidated Statements of Cash Flows for the ~~Six~~Nine Months Ended ~~June~~September 30, 2015 and 2014	9
Wisconsin Power and Light Company:
Condensed Consolidated Statements of Income for the Three and ~~Six~~Nine Months Ended ~~June~~September 30, 2015 and 2014	10
Condensed Consolidated Balance Sheets as of ~~June~~September 30, 2015 and December 31, 2014	11
Condensed Consolidated Statements of Cash Flows for the ~~Six~~Nine Months Ended ~~June~~September 30, 2015 and 2014	12
Combined Notes to Condensed Consolidated Financial Statements	13
1. Summary of Significant Accounting Policies	13
2. Regulatory Matters	13
3. Property, Plant and Equipment	15
4. Receivables	1516
5. Investments	17
6. Common Equity	17
7. Debt	18
8. Income Taxes	18
9. Benefit Plans	2019
10. Asset Retirement Obligations	2322
11. Fair Value Measurements	23
12. Derivative Instruments	2827
13. Commitments and Contingencies	2928
14. Segments of Business	33
15. Related Parties	35
16. Discontinued Operations and Assets and Liabilities Held for Sale	3635
Item 2. Management’s Discussion and Analysis of Financial Condition and Results of Operations	3736
Executive Summary	3736
Strategic Overview	4039
Rate Matters	41
Environmental Matters	41
Legislative Matters	4142
Results of Operations	4142
Liquidity and Capital Resources	5052
Other Matters	5255
Market Risk Sensitive Instruments and Positions	5255
New Accounting Pronouncements	5255
Critical Accounting Policies and Estimates	5255
Other Future Considerations	5255
Item 3. Quantitative and Qualitative Disclosures About Market Risk	5357
Item 4. Controls and Procedures	5357
Part II. Other Information	5357
Item 1. Legal Proceedings	5357
Item 1A. Risk Factors	5357
Item 2. Unregistered Sales of Equity Securities and Use of Proceeds	5458
Item 5. Other Information	58
Item 6. Exhibits	5458
Signatures	5459

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DEFINITIONS

The following abbreviations or acronyms used in this Form 10-Q are defined below:



Abbreviation or Acronym		Definition
2014 Form 10-K		Combined Annual Report on Form 10-K filed by Alliant Energy, IPL and WPL for the year ended Dec. 31, 2014
AFUDC		Allowance for funds used during construction
Alliant Energy		Alliant Energy Corporation
AROs		Asset retirement obligations
ATC		American Transmission Company LLC
CAA		Clean Air Act
CCR		Coal Combustion Residuals
CDD		Cooling degree days
CEO		Chief Executive Officer
CFO		Chief Financial Officer
Columbia		Columbia Energy Center
Corporate Services		Alliant Energy Corporate Services, Inc.
CRANDIC		Cedar Rapids and Iowa City Railway Company
DAEC		Duane Arnold Energy Center
Dth		Dekatherm
Edgewater		Edgewater Generating Station
EGU		Electric generating unit
EPA		U.S. Environmental Protection Agency
EPS		Earnings per weighted average common share
FERC		Federal Energy Regulatory Commission
Financial Statements		Condensed Consolidated Financial Statements
FTR		Financial transmission right
Fuel-related		Electric production fuel and energy purchases
GAAP		U.S. generally accepted accounting principles
HDD		Heating degree days
IPL		Interstate Power and Light Company
ITC		ITC Midwest LLC
IUB		Iowa Utilities Board
Marshalltown		Marshalltown Generating Station
MDA		Management’s Discussion and Analysis of Financial Condition and Results of Operations
MGP		Manufactured gas plant
MISO		Midcontinent Independent System Operator, Inc.
~~MPUC~~		~~Minnesota Public Utilities Commission~~
MW		Megawatt
MWh		Megawatt-hour
N/A		Not applicable
NAAQS		National Ambient Air Quality Standards
Nelson Dewey		Nelson Dewey Generating Station
Note(s)		Combined Notes to Condensed Consolidated Financial Statements
NOx		Nitrogen oxide
OPEB		Other postretirement benefits
PJM		PJM Interconnection, LLC
PPA		Purchased power agreement
PSCW		Public Service Commission of Wisconsin
Receivables Agreement		Receivables Purchase and Sale Agreement
Resources		Alliant Energy Resources, LLC
Riverside		Riverside Energy Center
RMT		RMT, Inc.
SCR		Selective catalytic reduction
SO2		Sulfur dioxide
U.S.		United States of America
Whiting Petroleum		Whiting Petroleum Corporation
WPL		Wisconsin Power and Light Company

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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 “may,” “believe,” “expect,” “anticipate,” “plan,” “project,” “will,” “projections,” “estimate,” 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, IPL and WPL 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 regulatory agency orders;

IPL’s and WPL’s ability to obtain adequate and timely rate relief to allow for, among other things, the recovery of fuel costs, operating costs, transmission costs, deferred expenditures, capital expenditures, and remaining costs related to EGUs that may be permanently closed, earning their authorized rates of return, and the payments to their parent of expected levels of dividends;

the ability to continue cost controls and operational efficiencies;

the impact of IPL’s retail electric base rate freeze in Iowa during 2015 and 2016;

the impact of WPL’s retail electric and gas base rate freeze in Wisconsin during 2015 and 2016;

weather effects on results of utility operations, including impacts of temperature changes in IPL’s and WPL’s service territories on customers’ demand for electricity and gas;

the impact of the economy in IPL’s and WPL’s service territories and the resulting impacts on sales volumes, margins and the ability to collect unpaid bills;

the impact of customer- and third party-owned generation, including alternative electric suppliers, in IPL’s and WPL’s service territories on system reliability, operating expenses and customers’ demand for electricity;

the impact of energy efficiency, franchise retention, customer- and third party-owned generation and customer disconnects on sales volumes and margins;

the impact that price changes may have on IPL’s and WPL’s customers’ demand for electric, gas and steam services and their ability to pay their bills;

developments that adversely impact the ability to implement the strategic plan, including unanticipated issues with new emission controls equipment for various coal-fired EGUs of IPL and WPL, IPL’s construction of Marshalltown, WPL’s proposed Riverside expansion, various replacements, modernization and expansion of IPL’s and WPL’s ~~natural~~electric and gas distribution systems, Resources’ electricity output and selling price of such output from its Franklin County wind ~~project,~~farm, and the potential decommissioning of certain EGUs of IPL and WPL;

issues related to the availability and operations of EGUs, including start-up risks, breakdown or failure of equipment, performance below expected or contracted levels of output or efficiency, operator error, transmission constraints, compliance with mandatory reliability standards and risks related to recovery of resulting incremental costs through rates;

disruptions in the supply and delivery of coal, natural gas and purchased electricity;

changes in the price of delivered coal, natural gas and purchased electricity due to shifts in supply and demand caused by market conditions and regulations, and the ability to recover and to retain the recovery of related changes in purchased power, fuel and fuel-related costs through rates in a timely manner;

impacts on equity income from unconsolidated investments due to potential changes to ATC’s authorized return on equity;

issues associated with environmental remediation and environmental compliance, including compliance with the Consent Decree between WPL, the EPA and the Sierra Club, the Consent Decree between IPL, the EPA, the Sierra Club, the State of Iowa and Linn County in Iowa, the CCR Rule, future changes in environmental laws and regulations, including the EPA’s regulations for carbon dioxide emissions reductions from new and existing fossil-fueled EGUs, and litigation associated with environmental requirements;

the ability to defend against environmental claims brought by state and federal agencies, such as the EPA, state natural resources agencies or third parties, such as the Sierra Club, and the impact on operating expenses of defending and resolving such claims;

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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;

~~Table of Contents~~

impacts that storms or natural disasters in IPL’s and WPL’s service territories may have on their operations and recovery of, and rate relief for, costs associated with restoration activities;

the direct or indirect effects resulting from terrorist incidents, including physical attacks and cyber attacks, or responses to such incidents;

the impact of penalties or third-party claims related to, or in connection with, a failure to maintain the security of personally identifiable information, including associated costs to notify affected persons and to mitigate their information security concerns;

the direct or indirect effects resulting from breakdown or failure of equipment in the operation of ~~natural~~ gas distribution systems, such as leaks, explosions and mechanical problems, and compliance with ~~natural~~ gas distribution safety regulations, such as those that may be issued by the Pipeline and Hazardous Materials Safety Administration;

risks associated with ~~implementing~~implementation of a new customer billing and information system, which is currently expected to be completed by the end of the first quarter of 2016;

impacts of IPL’s future tax benefits from Iowa rate-making practices, including deductions for repairs expenditures and allocation of mixed service costs, and recoverability of the associated regulatory assets from customers, when the differences reverse in future periods;

any material post-closing adjustments related to any past asset divestitures, including the sales of IPL’s Minnesota electric and natural gas distribution assets and RMT, which could result from, among other things, warranties, parental guarantees or litigation;

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, IPL and WPL have contractual arrangements, including participants in the energy markets and fuel suppliers and transporters;

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

current or future litigation, regulatory investigations, proceedings or inquiries, including the flood damage lawsuit pending against CRANDIC;

Alliant Energy’s ability to sustain its dividend payout ratio goal;

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

access to technological developments;

~~adverse developments in the food manufacturing industry, including animal flu and other illnesses;~~

changes in technology that alter the channels through which electric customers buy or utilize power;

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, including a new revenue recognition standard, which is currently expected to be adopted in 2018;

the impact of changes to production tax credits for wind ~~projects;~~farms;

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 and changes in tax accounting methods ~~including changes required by new tangible property regulations~~ with no material impact on earnings and cash flows; and


•	factors listed in MDA and Risk Factors in Item 1A in the 2014 Form 10-K.

Alliant Energy, IPL and WPL each assume no obligation, and disclaim any duty, to update the forward-looking statements in this report, except as required by law.

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PART I. FINANCIAL INFORMATION

ITEM 1. CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (UNAUDITED)

ALLIANT ENERGY CORPORATION

CONDENSED CONSOLIDATED STATEMENTS OF INCOME (UNAUDITED)


	For the Three Months						For the Six Months						For the Three Months						For the Nine Months
	Ended June 30,						Ended June 30,						Ended September 30,						Ended September 30,
	2015			2014			2015			2014			2015			2014			2015			2014
	(in millions, except per share amounts)												(in millions, except per share amounts)
Operating revenues:
Utility:
Electric		$640.4			$643.9			$1,311.7			$1,319.7			$835.8			$771.2			$2,147.5			$2,090.9
Gas	51.7			76.9			250.1			317.6			38.0			47.2			288.1			364.8
Other	14.8			15.6			31.2			38.4			13.4			12.2			44.6			50.6
Non-regulated	10.3			13.9			21.6			27.4			11.7			12.5			33.3			39.9
Total operating revenues	717.2			750.3			1,614.6			1,703.1			898.9			843.1			2,513.5			2,546.2
Operating expenses:
Utility:
Electric production fuel and purchased power	185.2			214.1			401.1			452.8			245.8			230.8			646.9			683.6
Electric transmission service	116.9			105.5			240.1			219.6			127.6			114.0			367.7			333.6
Cost of gas sold	21.9			45.0			152.7			206.9			13.6			21.8			166.3			228.7
Other operation and maintenance	157.3			160.7			303.9			321.7			151.1			159.0			456.3			483.8
Non-regulated operation and maintenance	—			1.8			1.3			3.1
Depreciation and amortization	100.4			95.8			200.6			191.3			99.3			97.1			299.9			288.4
Taxes other than income taxes	26.5			24.1			53.0			50.2			25.6			25.6			78.6			75.8
Total operating expenses	608.2			647.0			1,352.7			1,445.6			663.0			648.3			2,015.7			2,093.9
Operating income	109.0			103.3			261.9			257.5			235.9			194.8			497.8			452.3
Interest expense and other:
Interest expense	46.5			45.1			93.1			90.3			46.4			44.6			139.5			134.9
Equity income from unconsolidated investments, net	(11.3		)	(11.3		)	(17.8		)	(22.7		)	(11.1		)	(11.5		)	(28.9		)	(34.2		)
Allowance for funds used during construction	(8.6		)	(8.4		)	(15.4		)	(17.5		)	(9.7		)	(8.3		)	(25.1		)	(25.8		)
Interest income and other	(0.2		)	0.1			(0.3		)	(1.6		)	(0.1		)	(0.2		)	(0.4		)	(1.8		)
Total interest expense and other	26.4			25.5			59.6			48.5			25.5			24.6			85.1			73.1
Income from continuing operations before income taxes	82.6			77.8			202.3			209.0			210.4			170.2			412.7			379.2
Income taxes	11.2			13.2			31.7			33.8			27.8			12.4			59.5			46.2
Income from continuing operations, net of tax	71.4			64.6			170.6			175.2			182.6			157.8			353.2			333.0
Loss from discontinued operations, net of tax	(1.3		)	(0.3		)	(1.3		)	(0.3		)	(0.1		)	(1.9		)	(1.4		)	(2.2		)
Net income	70.1			64.3			169.3			174.9			182.5			155.9			351.8			330.8
Preferred dividend requirements of IPL	2.5			2.5			5.1			5.1
Preferred dividend requirements of Interstate Power and Light Company													2.6			2.6			7.7			7.7
Net income attributable to Alliant Energy common shareowners		$67.6			$61.8			$164.2			$169.8			$179.9			$153.3			$344.1			$323.1
Weighted average number of common shares outstanding (basic and diluted)	113.1			110.8			112.1			110.8			113.2			110.8			112.5			110.8
Earnings per weighted average common share attributable to Alliant Energy common shareowners (basic and diluted):
Income from continuing operations, net of tax		$0.61			$0.56			$1.47			$1.53			$1.59			$1.40			$3.07			$2.94
Loss from discontinued operations, net of tax	(0.01		)	—			(0.01		)	—			—			(0.02		)	(0.01		)	(0.02		)
Net income		$0.60			$0.56			$1.46			$1.53			$1.59			$1.38			$3.06			$2.92
Amounts attributable to Alliant Energy common shareowners:
Income from continuing operations, net of tax		$68.9			$62.1			$165.5			$170.1			$180.0			$155.2			$345.5			$325.3
Loss from discontinued operations, net of tax	(1.3		)	(0.3		)	(1.3		)	(0.3		)	(0.1		)	(1.9		)	(1.4		)	(2.2		)
Net income		$67.6			$61.8			$164.2			$169.8			$179.9			$153.3			$344.1			$323.1
Dividends declared per common share		$0.55			$0.51			$1.10			$1.02			$0.55			$0.51			$1.65			$1.53

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

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ALLIANT ENERGY CORPORATION

CONDENSED CONSOLIDATED BALANCE SHEETS (UNAUDITED)


	June 30, 2015		December 31, 2014		September 30, 2015		December 31, 2014
	(in millions, except per share and share amounts)				(in millions, except per share and share amounts)
ASSETS
Current assets:
Cash and cash equivalents		$54.8		$56.9		$139.2		$56.9
Accounts receivable, less allowance for doubtful accounts	297.3		427.3		427.3		427.3
Production fuel, at weighted average cost	78.8		83.8		87.8		83.8
Materials and supplies, at weighted average cost	82.3		72.9		83.7		72.9
Gas stored underground, at weighted average cost	24.1		67.1		40.0		67.1
Regulatory assets	71.1		68.1		92.3		68.1
Other	435.5		267.0		217.4		267.0
Total current assets	1,043.9		1,043.1		1,087.7		1,043.1
Property, plant and equipment, net	9,173.5		8,938.4		9,366.5		8,938.4
Investments:
Investment in American Transmission Company LLC	293.5		286.5		296.7		286.5
Other	56.4		58.4		56.4		58.4
Total investments	349.9		344.9		353.1		344.9
Other assets:
Regulatory assets	1,706.8		1,715.6		1,715.6		1,715.6
Deferred charges and other	38.2		43.9		35.7		43.9
Total other assets	1,745.0		1,759.5		1,751.3		1,759.5
Total assets		$12,312.3		$12,085.9		$12,558.6		$12,085.9


LIABILITIES AND EQUITY
Current liabilities:
Current maturities of long-term debt		$33.5			$183.0			$3.0			$183.0
Commercial paper	120.9			141.3			109.1			141.3
Accounts payable	374.9			427.9			438.3			427.9
Regulatory liabilities	197.7			200.1			189.7			200.1
Other	264.5			262.4			250.7			262.4
Total current liabilities	991.5			1,214.7			990.8			1,214.7
Long-term debt, net (excluding current portion)	3,717.4			3,606.7			3,855.8			3,606.7
Other liabilities:
Deferred income tax liabilities	2,449.1			2,321.1			2,462.1			2,321.1
Regulatory liabilities	572.4			621.1			554.4			621.1
Pension and other benefit obligations	417.4			421.7			416.4			421.7
Other	342.8			260.1			333.0			260.1
Total other liabilities	3,781.7			3,624.0			3,765.9			3,624.0
Commitments and contingencies (Note 13)
Equity:
Alliant Energy Corporation common equity:
Common stock - $0.01 par value - 240,000,000 shares authorized; 113,263,624 and 110,935,680 shares outstanding	1.1			1.1
Common stock - $0.01 par value - 240,000,000 shares authorized; 113,360,425 and 110,935,680 shares outstanding							1.1			1.1
Additional paid-in capital	1,649.0			1,509.1			1,656.0			1,509.1
Retained earnings	1,979.3			1,938.0			2,097.0			1,938.0
Accumulated other comprehensive loss	(0.6		)	(0.6		)	(0.6		)	(0.6		)
Shares in deferred compensation trust - 206,419 and 238,935 shares at a weighted average cost of $38.82 and $37.45 per share	(8.0		)	(8.9		)
Shares in deferred compensation trust - 210,647 and 238,935 shares at a weighted average cost of $39.28 and $37.45 per share							(8.3		)	(8.9		)
Total Alliant Energy Corporation common equity	3,620.8			3,438.7			3,745.2			3,438.7
Cumulative preferred stock of Interstate Power and Light Company	200.0			200.0			200.0			200.0
Noncontrolling interest	0.9			1.8			0.9			1.8
Total equity	3,821.7			3,640.5			3,946.1			3,640.5
Total liabilities and equity		$12,312.3			$12,085.9			$12,558.6			$12,085.9

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

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ALLIANT ENERGY CORPORATION

CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS (UNAUDITED)


	For the Six Months						For the Nine Months
	Ended June 30,						Ended September 30,
	2015			2014			2015			2014
	(in millions)						(in millions)
Cash flows from operating activities:
Net income		$169.3			$174.9			$351.8			$330.8
Adjustments to reconcile net income to net cash flows from operating activities:
Depreciation and amortization	200.6			191.3			299.9			288.4
Deferred tax expense and investment tax credits	43.0			37.3			101.0			54.2
Other	3.5			11.7			(2.5		)	13.6
Other changes in assets and liabilities:
Accounts receivable	33.7			47.6			11.7			87.1
Sales of accounts receivable	78.0			(19.0		)	(21.0		)	9.0
Regulatory assets	(22.7		)	(71.6		)	(51.3		)	(154.3		)
Derivative assets	3.6			(92.3		)
Accounts payable	(25.3		)	35.8
Regulatory liabilities	(40.0		)	45.2			(61.5		)	61.1
Deferred income taxes	48.0			51.5			74.1			109.5
Other	25.6			35.8			(6.9		)	(35.5		)
Net cash flows from operating activities	517.3			448.2			695.3			763.9
Cash flows used for investing activities:
Construction and acquisition expenditures:
Utility business	(436.2		)	(332.6		)	(678.9		)	(587.4		)
Alliant Energy Corporate Services, Inc. and non-regulated businesses	(32.2		)	(31.9		)	(47.5		)	(45.1		)
Proceeds from Minnesota electric and natural gas distribution asset sales							138.1			—
Other	(1.9		)	(4.5		)	(24.7		)	(7.9		)
Net cash flows used for investing activities	(470.3		)	(369.0		)	(613.0		)	(640.4		)
Cash flows used for financing activities:
Common stock dividends	(122.9		)	(112.9		)	(185.1		)	(169.3		)
Proceeds from issuance of common stock, net	139.5			—			145.4			—
Proceeds from issuance of long-term debt							250.7			2.9
Payments to retire long-term debt	(151.4		)	(0.8		)	(182.0		)	(47.7		)
Net change in commercial paper	90.8			28.5			(32.2		)	74.4
Other	(5.1		)	12.4			3.2			17.4
Net cash flows used for financing activities	(49.1		)	(72.8		)	—			(122.3		)
Net increase (decrease) in cash and cash equivalents	(2.1		)	6.4
Net increase in cash and cash equivalents							82.3			1.2
Cash and cash equivalents at beginning of period	56.9			9.8			56.9			9.8
Cash and cash equivalents at end of period		$54.8			$16.2			$139.2			$11.0
Supplemental cash flows information:
Cash (paid) refunded during the period for:
Interest, net of capitalized interest		($93.5	)		($90.5	)		($133.9	)		($131.8	)
Income taxes, net		$0.1			$3.8			$—			$5.3
Significant non-cash investing and financing activities:
Accrued capital expenditures		$162.1			$124.9			$180.0			$141.1

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

Table of Contents

INTERSTATE POWER AND LIGHT COMPANY

CONDENSED CONSOLIDATED STATEMENTS OF INCOME (UNAUDITED)


	For the Three Months						For the Six Months						For the Three Months						For the Nine Months
	Ended June 30,						Ended June 30,						Ended September 30,						Ended September 30,
	2015			2014			2015			2014			2015			2014			2015			2014
	(in millions)												(in millions)
Operating revenues:
Electric utility		$339.4			$354.6			$702.0			$728.8			$468.6			$435.9			$1,170.6			$1,164.7
Gas utility	29.8			43.7			141.0			179.4			23.1			28.7			164.1			208.1
Steam and other	13.0			13.6			28.2			32.6			12.9			11.6			41.1			44.2
Total operating revenues	382.2			411.9			871.2			940.8			504.6			476.2			1,375.8			1,417.0
Operating expenses:
Electric production fuel and purchased power	90.5			122.9			200.6			262.9			131.4			132.2			332.0			395.1
Electric transmission service	77.9			75.4			161.8			159.0			87.5			82.7			249.3			241.7
Cost of gas sold	13.0			25.7			84.0			113.8			9.4			14.6			93.4			128.4
Other operation and maintenance	100.6			92.1			193.2			189.3			94.3			89.8			287.5			279.1
Depreciation and amortization	52.1			48.9			103.9			97.6			51.2			49.3			155.1			146.9
Taxes other than income taxes	14.3			12.9			28.4			26.7			13.8			13.7			42.2			40.4
Total operating expenses	348.4			377.9			771.9			849.3			387.6			382.3			1,159.5			1,231.6
Operating income	33.8			34.0			99.3			91.5			117.0			93.9			216.3			185.4
Interest expense and other:
Interest expense	23.9			22.6			48.0			45.1			23.8			21.9			71.8			67.0
Allowance for funds used during construction	(6.7		)	(6.0		)	(12.0		)	(12.0		)	(7.3		)	(6.6		)	(19.3		)	(18.6		)
Interest income and other	—			(0.1		)	(0.1		)	(0.1		)	0.1			—			—			(0.1		)
Total interest expense and other	17.2			16.5			35.9			33.0			16.6			15.3			52.5			48.3
Income before income taxes	16.6			17.5			63.4			58.5			100.4			78.6			163.8			137.1
Income tax benefit	(2.6		)	(3.4		)	(6.2		)	(8.4		)	(19.6		)	(26.5		)	(25.8		)	(34.9		)
Net income	19.2			20.9			69.6			66.9			120.0			105.1			189.6			172.0
Preferred dividend requirements	2.5			2.5			5.1			5.1			2.6			2.6			7.7			7.7
Earnings available for common stock		$16.7			$18.4			$64.5			$61.8			$117.4			$102.5			$181.9			$164.3

Earnings per share data is not disclosed given Alliant Energy Corporation is the sole shareowner of all shares of IPL’s common stock outstanding during the periods presented.

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

Table of Contents

INTERSTATE POWER AND LIGHT COMPANY

CONDENSED CONSOLIDATED BALANCE SHEETS (UNAUDITED)


	June 30, 2015		December 31, 2014		September 30, 2015		December 31, 2014
	(in millions, except per share and share amounts)				(in millions, except per share and share amounts)
ASSETS
Current assets:
Cash and cash equivalents		$2.0		$5.3		$99.4		$5.3
Accounts receivable, less allowance for doubtful accounts	104.2		216.7		235.7		216.7
Production fuel, at weighted average cost	44.9		52.7		51.0		52.7
Materials and supplies, at weighted average cost	47.5		42.0		46.6		42.0
Gas stored underground, at weighted average cost	8.2		30.8		20.7		30.8
Regulatory assets	28.0		38.7		33.4		38.7
Other	308.1		169.9		115.0		169.9
Total current assets	542.9		556.1		601.8		556.1
Property, plant and equipment, net	4,687.8		4,554.7		4,804.7		4,554.7
Investments	19.5		19.1		19.4		19.1
Other assets:
Regulatory assets	1,322.7		1,319.2		1,336.8		1,319.2
Deferred charges and other	15.0		12.7		16.8		12.7
Total other assets	1,337.7		1,331.9		1,353.6		1,331.9
Total assets		$6,587.9		$6,461.8		$6,779.5		$6,461.8


LIABILITIES AND EQUITY
Current liabilities:
Current maturities of long-term debt		$—		$150.0		$—		$150.0
Accounts payable	222.1		259.6		251.3		259.6
Accounts payable to associated companies	43.6		31.3		49.2		31.3
Regulatory liabilities	129.5		129.7		126.3		129.7
Other	148.0		135.3		125.1		135.3
Total current liabilities	543.2		705.9		551.9		705.9
Long-term debt, net (excluding current portion)	1,730.2		1,618.7		1,868.5		1,618.7
Other liabilities:
Deferred income tax liabilities	1,418.8		1,341.4		1,419.9		1,341.4
Regulatory liabilities	402.5		453.8		376.2		453.8
Pension and other benefit obligations	141.5		142.4		141.0		142.4
Other	243.0		185.5		231.0		185.5
Total other liabilities	2,205.8		2,123.1		2,168.1		2,123.1
Commitments and contingencies (Note 13)
Equity:
Interstate Power and Light Company common equity:
Common stock - $2.50 par value - 24,000,000 shares authorized; 13,370,788 shares outstanding	33.4		33.4		33.4		33.4
Additional paid-in capital	1,342.8		1,242.8		1,342.8		1,242.8
Retained earnings	532.5		537.9		614.8		537.9
Total Interstate Power and Light Company common equity	1,908.7		1,814.1		1,991.0		1,814.1
Cumulative preferred stock	200.0		200.0		200.0		200.0
Total equity	2,108.7		2,014.1		2,191.0		2,014.1
Total liabilities and equity		$6,587.9		$6,461.8		$6,779.5		$6,461.8

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

Table of Contents

INTERSTATE POWER AND LIGHT COMPANY

CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS (UNAUDITED)


	For the Six Months						For the Nine Months
	Ended June 30,						Ended September 30,
	2015			2014			2015			2014
	(in millions)						(in millions)
Cash flows from operating activities:
Net income		$69.6			$66.9			$189.6			$172.0
Adjustments to reconcile net income to net cash flows from operating activities:
Depreciation and amortization	103.9			97.6			155.1			146.9
Other	24.9			(4.0		)	30.9			(12.8		)
Other changes in assets and liabilities:
Accounts receivable	16.9			48.3			(8.3		)	57.1
Sales of accounts receivable	78.0			(19.0		)	(21.0		)	9.0
Gas stored underground	23.6			7.5
Regulatory assets	(20.0		)	(48.5		)	(38.1		)	(126.1		)
Derivative assets	(2.7		)	(51.9		)
Accounts payable	(22.0		)	23.4			(24.6		)	17.9
Regulatory liabilities	(38.9		)	(2.7		)	(63.1		)	14.8
Deferred income taxes	44.7			54.7			72.0			112.5
Other	16.5			33.8			25.5			(17.7		)
Net cash flows from operating activities	294.5			206.1			318.0			373.6
Cash flows used for investing activities:
Utility construction and acquisition expenditures	(281.3		)	(184.9		)	(432.6		)	(358.2		)
Proceeds from Minnesota electric and natural gas distribution asset sales							138.1			—
Other	(3.9		)	(11.5		)	(24.9		)	(18.3		)
Net cash flows used for investing activities	(285.2		)	(196.4		)	(319.4		)	(376.5		)
Cash flows used for financing activities:
Cash flows from financing activities:
Common stock dividends	(69.9		)	(70.0		)	(105.0		)	(105.0		)
Capital contributions from parent	100.0			60.0			100.0			90.0
Proceeds from issuance of long-term debt							250.0			—
Payments to retire long-term debt	(150.0		)	—			(150.0		)	(38.4		)
Net change in commercial paper	111.2			—			—			38.0
Other	(3.9		)	1.3			0.5			18.5
Net cash flows used for financing activities	(12.6		)	(8.7		)
Net increase (decrease) in cash and cash equivalents	(3.3		)	1.0
Net cash flows from financing activities							95.5			3.1
Net increase in cash and cash equivalents							94.1			0.2
Cash and cash equivalents at beginning of period	5.3			4.4			5.3			4.4
Cash and cash equivalents at end of period		$2.0			$5.4			$99.4			$4.6
Supplemental cash flows information:
Cash (paid) refunded during the period for:
Interest		($48.3	)		($45.2	)		($66.7	)		($64.2	)
Income taxes, net		$18.6			$9.0			$31.1			$21.0
Significant non-cash investing and financing activities:
Accrued capital expenditures		$118.8			$76.1			$115.5			$96.7

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

Table of Contents

WISCONSIN POWER AND LIGHT COMPANY

CONDENSED CONSOLIDATED STATEMENTS OF INCOME (UNAUDITED)


	For the Three Months						For the Six Months						For the Three Months						For the Nine Months
	Ended June 30,						Ended June 30,						Ended September 30,						Ended September 30,
	2015			2014			2015			2014			2015			2014			2015			2014
	(in millions)												(in millions)
Operating revenues:
Electric utility		$301.0			$289.3			$609.7			$590.9			$367.2			$335.3			$976.9			$926.2
Gas utility	21.9			33.2			109.1			138.2			14.9			18.5			124.0			156.7
Other	1.8			2.0			3.0			5.8			0.5			0.6			3.5			6.4
Total operating revenues	324.7			324.5			721.8			734.9			382.6			354.4			1,104.4			1,089.3
Operating expenses:
Electric production fuel and purchased power	94.7			91.2			200.5			189.9			114.4			98.6			314.9			288.5
Electric transmission service	39.0			30.1			78.3			60.6			40.1			31.3			118.4			91.9
Cost of gas sold	8.9			19.3			68.7			93.1			4.2			7.2			72.9			100.3
Other operation and maintenance	56.7			68.6			110.7			132.4			57.0			66.9			167.7			199.3
Depreciation and amortization	45.8			44.7			91.8			89.4			45.7			45.6			137.5			135.0
Taxes other than income taxes	11.3			10.6			22.7			21.8			10.9			10.9			33.6			32.7
Total operating expenses	256.4			264.5			572.7			587.2			272.3			260.5			845.0			847.7
Operating income	68.3			60.0			149.1			147.7			110.3			93.9			259.4			241.6
Interest expense and other:
Interest expense	23.3			21.1			46.4			42.2			23.1			21.0			69.5			63.2
Equity income from unconsolidated investments	(11.3		)	(11.4		)	(19.1		)	(22.8		)	(11.1		)	(11.4		)	(30.2		)	(34.2		)
Allowance for funds used during construction	(1.9		)	(2.4		)	(3.4		)	(5.5		)	(2.4		)	(1.7		)	(5.8		)	(7.2		)
Interest income and other	(0.1		)	0.3			—			0.3			(0.3		)	0.5			(0.3		)	0.8
Total interest expense and other	10.0			7.6			23.9			14.2			9.3			8.4			33.2			22.6
Income before income taxes	58.3			52.4			125.2			133.5			101.0			85.5			226.2			219.0
Income taxes	18.8			17.8			40.9			44.1			33.1			23.9			74.0			68.0
Net income	39.5			34.6			84.3			89.4			67.9			61.6			152.2			151.0
Net income attributable to noncontrolling interest	0.5			—			0.7			—			0.4			—			1.1			—
Earnings available for common stock		$39.0			$34.6			$83.6			$89.4			$67.5			$61.6			$151.1			$151.0

Earnings per share data is not disclosed given Alliant Energy Corporation is the sole shareowner of all shares of WPL’s common stock outstanding during the periods presented.

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

Table of Contents

WISCONSIN POWER AND LIGHT COMPANY

CONDENSED CONSOLIDATED BALANCE SHEETS (UNAUDITED)


	June 30, 2015		December 31, 2014		September 30, 2015		December 31, 2014
	(in millions, except per share and share amounts)				(in millions, except per share and share amounts)
ASSETS
Current assets:
Cash and cash equivalents		$48.8		$46.7		$35.7		$46.7
Accounts receivable, less allowance for doubtful accounts	166.6		185.8		173.6		185.8
Production fuel, at weighted average cost	33.9		31.1		36.8		31.1
Materials and supplies, at weighted average cost	32.8		29.2		35.3		29.2
Gas stored underground, at weighted average cost	15.9		36.3		19.3		36.3
Regulatory assets	43.1		29.4		58.9		29.4
Deferred income tax assets	61.0		37.5
Other	51.9		61.2		94.1		98.7
Total current assets	454.0		457.2		453.7		457.2
Property, plant and equipment, net	4,028.4		3,938.9		4,094.4		3,938.9
Investments:
Investment in American Transmission Company LLC	293.5		286.5		296.7		286.5
Other	19.0		19.5		19.1		19.5
Total investments	312.5		306.0		315.8		306.0
Other assets:
Regulatory assets	384.1		396.4		378.8		396.4
Deferred charges and other	23.8		29.7		20.3		29.7
Total other assets	407.9		426.1		399.1		426.1
Total assets		$5,202.8		$5,128.2		$5,263.0		$5,128.2


LIABILITIES AND EQUITY
Current liabilities:
Current maturities of long-term debt		$30.6		$30.6		$—		$30.6
Accounts payable	98.0		112.9		122.5		112.9
Accounts payable to associated companies	18.0		25.5		23.3		25.5
Regulatory liabilities	68.2		70.4		63.4		70.4
Other	82.4		70.9		86.5		70.9
Total current liabilities	297.2		310.3		295.7		310.3
Long-term debt, net (excluding current portion)	1,543.5		1,543.3		1,543.6		1,543.3
Other liabilities:
Deferred income tax liabilities	1,014.9		970.0		1,030.1		970.0
Regulatory liabilities	169.9		167.3		178.2		167.3
Capital lease obligations - Sheboygan Falls Energy Facility	86.6		89.4		85.1		89.4
Pension and other benefit obligations	179.0		180.4		178.2		180.4
Other	177.9		155.2		181.6		155.2
Total other liabilities	1,628.3		1,562.3		1,653.2		1,562.3
Commitments and contingencies (Note 13)
Equity:
Wisconsin Power and Light Company common equity:
Common stock - $5 par value - 18,000,000 shares authorized; 13,236,601 shares outstanding	66.2		66.2		66.2		66.2
Additional paid-in capital	959.0		959.0		959.0		959.0
Retained earnings	698.7		678.6		734.4		678.6
Total Wisconsin Power and Light Company common equity	1,723.9		1,703.8		1,759.6		1,703.8
Noncontrolling interest	9.9		8.5		10.9		8.5
Total equity	1,733.8		1,712.3		1,770.5		1,712.3
Total liabilities and equity		$5,202.8		$5,128.2		$5,263.0		$5,128.2

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

Table of Contents

WISCONSIN POWER AND LIGHT COMPANY

CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS (UNAUDITED)


	For the Six Months						For the Nine Months
	Ended June 30,						Ended September 30,
	2015			2014			2015			2014
	(in millions)						(in millions)
Cash flows from operating activities:
Net income		$84.3			$89.4			$152.2			$151.0
Adjustments to reconcile net income to net cash flows from operating activities:
Depreciation and amortization	91.8			89.4			137.5			135.0
Other amortizations	2.7			24.9			4.0			36.1
Deferred tax expense and investment tax credits	20.4			37.1			61.0			58.4
Other	(8.1		)	(8.1		)	(12.3		)	(14.3		)
Other changes in assets and liabilities:
Regulatory assets	(2.7		)	(23.1		)
Derivative assets	6.3			(40.4		)	8.8			(32.8		)
Regulatory liabilities	(1.1		)	47.9			1.6			46.3
Derivative liabilities							19.0			(9.7		)
Other	36.6			18.4			4.1			(4.2		)
Net cash flows from operating activities	230.2			235.5			375.9			365.8
Cash flows used for investing activities:
Utility construction and acquisition expenditures	(154.9		)	(147.7		)	(246.3		)	(229.2		)
Other	(7.1		)	(3.4		)	(13.3		)	(4.6		)
Net cash flows used for investing activities	(162.0		)	(151.1		)	(259.6		)	(233.8		)
Cash flows used for financing activities:
Common stock dividends	(63.5		)	(59.4		)	(95.3		)	(89.1		)
Payments to retire long-term debt							(30.6		)	(8.5		)
Net change in commercial paper	—			(25.7		)	—			(37.0		)
Other	(2.6		)	6.6			(1.4		)	4.4
Net cash flows used for financing activities	(66.1		)	(78.5		)	(127.3		)	(130.2		)
Net increase in cash and cash equivalents	2.1			5.9
Net increase (decrease) in cash and cash equivalents							(11.0		)	1.8
Cash and cash equivalents at beginning of period	46.7			0.5			46.7			0.5
Cash and cash equivalents at end of period		$48.8			$6.4			$35.7			$2.3
Supplemental cash flows information:
Cash paid during the period for:
Interest		($46.5	)		($42.2	)		($69.2	)		($65.6	)
Income taxes, net		($3.7	)		($9.4	)		($10.0	)		($8.7	)
Significant non-cash investing and financing activities:
Accrued capital expenditures		$39.5			$46.7			$57.2			$39.9

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

Table of Contents

ALLIANT ENERGY CORPORATION

INTERSTATE POWER AND LIGHT COMPANY

WISCONSIN POWER AND LIGHT COMPANY

COMBINED NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (UNAUDITED)

~~(1)~~NOTE 1. SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES

(a) General - The interim unaudited Financial Statements included herein have been prepared pursuant to the rules and regulations of the Securities and Exchange Commission. Accordingly, certain information and note disclosures normally included in financial statements prepared in accordance with GAAP have been condensed or omitted, although management believes that the disclosures are adequate to make the information presented not misleading. These Financial Statements should be read in conjunction with the financial statements and the notes thereto included in the latest combined Annual Report on Form 10-K.

In the opinion of management, all adjustments, which unless otherwise noted are normal and recurring in nature, necessary for a fair presentation of the results of operations, financial position and cash flows have been made. Results for the ~~six~~nine months ended ~~June~~September 30, 2015 are not necessarily indicative of results that may be expected for the year ending December 31, 2015. A change in management’s estimates or assumptions could have a material impact on financial condition and results of operations during the period in which such change occurred. Certain prior period amounts in the Financial Statements and Notes have been reclassified to conform to the current period presentation for comparative purposes. Unless otherwise noted, the Notes herein exclude discontinued operations for all periods presented. In addition, the Notes herein exclude assets and liabilities held for sale. ~~As discussed in~~ ~~Note 16, IPL’s Minnesota electric distribution assets qualified as held for sale as of June 30, 2015.~~

(b) New Accounting Pronouncements -

Revenue Recognition - In May 2014, the Financial Accounting Standards Board issued an accounting standard providing principles for recognizing revenue for the transfer of promised goods or services to customers with the consideration to which the entity expects to be entitled in exchange for those goods or services. This standard also requires disclosures about the nature, amount, timing and uncertainty of revenue and cash flows arising from contracts with customers. In ~~July~~August 2015, the Financial Accounting Standards Board ~~deferred~~approved the deferral of the effective date of this standard. As a result, Alliant Energy, IPL and WPL are now required to adopt this standard on January 1, 2018. Early adoption on January 1, 2017 is permitted. Alliant Energy, IPL and WPL are currently evaluating the impact of this standard on their financial condition and results of operations.

Presentation of Debt Issuance Costs - In April 2015, the Financial Accounting Standards Board issued an accounting standard to simplify the presentation of debt issuance costs on the balance sheet. Under the new standard, debt issuance costs related to a recognized debt liability will be presented on the balance sheet as a direct deduction from the carrying amount of that debt liability, consistent with debt discounts. Alliant Energy, IPL and WPL are required to adopt this standard by January 1, 2016. Debt issuance costs represent less than 1% of total long-term debt.

~~(2)~~NOTE 2. REGULATORY MATTERS

Regulatory Assets and Regulatory Liabilities -

Regulatory assets were comprised of the following items (in millions):


	Alliant Energy				IPL				WPL				Alliant Energy				IPL				WPL
	June 30, 2015		December 31, 2014		June 30, 2015		December 31, 2014		June 30, 2015		December 31, 2014		September 30, 2015		December 31, 2014		September 30, 2015		December 31, 2014		September 30, 2015		December 31, 2014
Tax-related		$961.1		$955.3		$932.8		$928.0		$28.3		$27.3		$976.5		$955.3		$947.3		$928.0		$29.2		$27.3
Pension and OPEB costs	555.7		570.2		281.8		287.9		273.9		282.3		548.4		570.2		278.6		287.9		269.8		282.3
AROs	77.9		73.7		44.1		41.4		33.8		32.3		81.8		73.7		47.6		41.4		34.2		32.3
Derivatives	54.1		46.9		26.1		28.0		28.0		18.9		68.4		46.9		29.3		28.0		39.1		18.9
Commodity cost recovery	32.3		31.1		0.5		0.4		31.8		30.7		33.2		31.1		1.2		0.4		32.0		30.7
Emission allowances	26.7		27.4		26.7		27.4		—		—		26.5		27.4		26.5		27.4		—		—
Other	70.1		79.1		38.7		44.8		31.4		34.3		73.1		79.1		39.7		44.8		33.4		34.3
		$1,777.9		$1,783.7		$1,350.7		$1,357.9		$427.2		$425.8		$1,807.9		$1,783.7		$1,370.2		$1,357.9		$437.7		$425.8

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Regulatory liabilities were comprised of the following items (in millions):


	Alliant Energy				IPL				WPL				Alliant Energy				IPL				WPL
	June 30, 2015		December 31, 2014		June 30, 2015		December 31, 2014		June 30, 2015		December 31, 2014		September 30, 2015		December 31, 2014		September 30, 2015		December 31, 2014		September 30, 2015		December 31, 2014
Cost of removal obligations		$410.6		$421.7		$266.6		$279.1		$144.0		$142.6		$406.2		$421.7		$261.3		$279.1		$144.9		$142.6
IPL’s tax benefit riders	201.9		243.0		201.9		243.0		—		—		179.5		243.0		179.5		243.0		—		—
Energy efficiency cost recovery	58.5		64.3		1.7		—		56.8		64.3		53.0		64.3		—		—		53.0		64.3
IPL’s electric transmission cost recovery	24.3		19.4		24.3		19.4		—		—
Commodity cost recovery	16.6		15.4		11.6		15.1		5.0		0.3		33.8		15.4		22.9		15.1		10.9		0.3
Electric transmission cost recovery													31.4		19.4		15.8		19.4		15.6		—
Other	58.2		57.4		25.9		26.9		32.3		30.5		40.2		57.4		23.0		26.9		17.2		30.5
		$770.1		$821.2		$532.0		$583.5		$238.1		$237.7		$744.1		$821.2		$502.5		$583.5		$241.6		$237.7

Tax-related - Alliant Energy’s and IPL’s tax-related regulatory assets are generally 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. Deferred tax amounts for such property-related differences at IPL are recorded to regulatory assets, along with the necessary revenue requirement tax gross-ups. During the ~~six~~nine months ended ~~June~~September 30, 2015, Alliant Energy’s and IPL’s tax-related regulatory assets increased primarily due to property-related differences for qualifying repair expenditures.

~~Certain tax-related regulatory assets associated with~~The July 2015 sale of IPL’s Minnesota electric distribution assets ~~were classified as held for sale as~~resulted in a reduction of ~~June 30, 2015~~certain tax-related regulatory assets on Alliant Energy’s and IPL’s balance ~~sheets.~~sheets in 2015.

Derivatives - Refer to Note 12 for discussion of derivative assets and derivative liabilities.

IPL’s tax benefit riders - IPL’s tax benefit riders utilize regulatory liabilities to credit bills of IPL’s Iowa retail electric and gas customers to help offset the impact of 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, allocation of insurance proceeds from floods in 2008, and cost of removal expenditures. For the ~~six~~nine months ended ~~June~~September 30, 2015, Alliant Energy’s and IPL’s “IPL’s tax benefit riders” regulatory liabilities decreased by ~~$41~~$64 million as follows (in millions):



Electric tax benefit rider credits		$3555
Gas tax benefit rider credits	69
		$4164

Refer to Note 8 for additional details regarding IPL’s tax benefit riders.

Electric transmission cost recovery - Electric revenues established in WPL’s retail electric rate case (2015/2016 Test Period) included recovery of expected increases in electric transmission service expense largely due to System Support Resource costs expected to be incurred. Due to a revision in MISO’s method to allocate System Support Resource costs, WPL no longer expects to incur certain System Support Resource costs. The difference between actual electric transmission service expense incurred and amounts collected from customers as electric revenues in 2015 are recorded as electric transmission service expense with an offsetting amount recorded to regulatory liabilities due to the escrow treatment authorized for WPL in its 2015/2016 Test Period retail electric rate case.

Utility Rate Cases -

IPL’s Iowa Retail Electric Rate Settlement Agreement - The IUB approved a settlement agreement in 2014 related to rates charged to IPL’s Iowa retail electric customers. The settlement agreement extends IPL’s Iowa retail electric base rates authorized in its 2009 Test Year rate case through 2016 and provides targeted retail electric customer billing credits beginning May 2014. For the three and ~~six~~nine months ended ~~June~~September 30, IPL recorded billing credits to reduce retail electric customers’ bills as follows (in millions):

Three Months Six Months
2015 2014 2015 2014
Billing credits to reduce retail electric customers’ bills $6
$20

$12

$20



	Three Months			Nine Months
	2015	2014		2015		2014
Billing credits to reduce retail electric customers’ bills	$7		$26		$19		$46

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WPL’s Retail Fuel-related Rate Filing (2016 Test Year) - In July 2015, WPL filed a request with the PSCW to increase annual rates for WPL’s retail electric customers by $15 million, or approximately 1%, in 2016. The increase reflects anticipated increases in retail electric fuel-related costs in 2016. Any rate changes granted from this request are expected to be effective on January 1, 2016. WPL currently expects a decision from the PSCW regarding this rate filing by the end of 2015.

~~Table~~WPL’s Retail Fuel-related Rate Filing (2015 Test Year) - Pursuant to a 2014 PSCW order, WPL’s 2015 fuel-related costs will be subject to deferral if they are outside an annual bandwidth of ~~Contents~~plus or minus 2% of the approved annual forecasted fuel-related costs. Retail fuel-related costs incurred by WPL through September 30, 2015 were lower than fuel-related costs used to determine rates for such period resulting in an over-collection of fuel-related costs. As of September 30, 2015, fuel-related costs outside of the approved range were $5 million and are included in “Commodity cost recovery” in Alliant Energy’s and WPL’s regulatory liabilities table above.

WPL’s Retail Fuel-related Rate Filing (2014 Test Year) - Pursuant to a 2013 PSCW order, WPL’s 2014 fuel-related costs were subject to deferral since they were outside an annual bandwidth of plus or minus 2% of the approved annual forecasted fuel-related costs. Retail fuel-related costs incurred by WPL through December 31, 2014 were higher than fuel-related costs used to determine rates for such period resulting in an under-collection of fuel-related costs for 2014 of $33 million (including $28 million outside the approved range for 2014). The $28 million of deferred fuel-related costs is included in “Commodity cost recovery” in Alliant Energy’s and WPL’s regulatory assets table above. In July 2015, WPL received an order from the PSCW authorizing an annual retail electric rate increase of $28 million, or approximately 3%, effective January 1, 2016 to recover the 2014 Test Year deferred fuel-related costs.

~~(3)~~NOTE 3. PROPERTY, PLANT AND EQUIPMENT

Utility -

Emission Controls Project -

WPL’s Edgewater Unit 5 - WPL is currently constructing a scrubber and baghouse at Edgewater Unit 5 to reduce SO2 and mercury emissions at the EGU. Construction began in 2014 and is expected to be completed in 2016. As of ~~June~~September 30, 2015, Alliant Energy and WPL recorded capitalized expenditures for construction work in progress of ~~$132~~$171 million and AFUDC of $5$6 million for the scrubber and baghouse in “Property, plant and equipment, net” on their balance sheets.

Natural Gas-Fired Generation Project -

IPL’s Marshalltown Generating Station - IPL is currently constructing Marshalltown, an approximate 650 MW natural gas-fired combined-cycle EGU. Construction began in 2014 and is expected to be completed in 2017. As of ~~June~~September 30, 2015, Alliant Energy and IPL recorded capitalized expenditures for construction work in progress of ~~$343~~$414 million and AFUDC of ~~$12~~$17 million for Marshalltown in “Property, plant and equipment, net” on their balance sheets.

Sales of IPL’s Minnesota Electric and Natural Gas Distribution Assets - In April 2015, IPL completed the sale of its Minnesota natural gas distribution assets and received proceeds of $11 million, subject to post-closing adjustments based on the value of the net assets as of the closing date, and a promissory note of $2 million. In July 2015, IPL completed the sale of its Minnesota electric distribution assets (primarily related to property, plant and equipment) and received proceeds of $127 million, ~~which were used to reduce cash proceeds received from IPL’s sales of accounts receivable program. Final proceeds are~~ subject to post-closing adjustments based on the value of the net assets as of the closing ~~date~~date. The proceeds from the natural gas distribution assets were used for general corporate purposes and ~~are expected~~the proceeds from the electric distribution assets were used to ~~be approximately $130 million.~~reduce cash proceeds received from IPL’s sales of accounts receivable program. The premium received over the book value of the property, plant and equipment sold was more than offset by a reduction in tax-related regulatory assets associated with the distribution assets. As a result, Alliant Energy and IPL recorded pre-tax charges of $9 million and $3 million for the Minnesota electric and natural gas distribution asset transactions, respectively, in ~~“Utility - Other~~“Other operation and maintenance” in their income statements ~~for~~during the ~~three and six~~nine months ended ~~June 30, 2015. Refer to~~ ~~Note 16~~ ~~for details of the Minnesota electric distribution assets, which qualified as held for sale as of June~~September 30, 2015.

In July 2015, FERC approved the wholesale power supply agreement between IPL and Southern Minnesota Energy Cooperative, which became effective upon the sale of IPL’s Minnesota electric distribution assets.

Non-regulated and Other -

Corporate Services and Other - Corporate Services is implementing a new customer billing and information system for IPL and ~~WPL, which is currently expected to be placed in service by the end of the first quarter of 2016.~~WPL. As of ~~June~~September 30, 2015, Alliant Energy recorded capitalized expenditures of ~~$79~~$87 million and capitalized interest of $2 million for the system in “Property, plant and equipment, net” on its balance sheet.

~~(4)~~

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NOTE 4. RECEIVABLES

(a) Sales of Accounts Receivable - IPL maintains a Receivables Agreement whereby it may sell its ~~Iowa~~ customer accounts receivables, unbilled revenues and certain other accounts receivables to a third party through wholly-owned and consolidated special purpose entities. The transfers of receivables meet the criteria for sale accounting established by the transfer of financial assets accounting rules. As of ~~June~~September 30, 2015, IPL sold ~~$177.8~~$201.2 million of receivables to the third party, received ~~$100.0~~$1.0 million in cash proceeds and recorded deferred proceeds of ~~$73.4~~$195.5 million.

~~Table of Contents~~

IPL’s maximum and average outstanding cash proceeds related to the sales of accounts receivable program for the three and ~~six~~nine months ended ~~June~~September 30 were as follows (in millions):


	Three Months				Six Months				Three Months				Nine Months
	2015		2014		2015		2014		2015		2014		2015		2014
Maximum outstanding aggregate cash proceeds (based on daily outstanding balances)		$125.0		$75.0		$125.0		$75.0		$137.0		$92.0		$137.0		$92.0
Average outstanding aggregate cash proceeds (based on daily outstanding balances)	77.3		34.2		72.7		30.9		41.2		54.5		62.1		38.9

For the three and ~~six~~nine months ended ~~June~~September 30, 2015 and 2014, IPL’s costs incurred related to the sales of accounts receivable program were not material.

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


	June 30, 2015		December 31, 2014		September 30, 2015		December 31, 2014
Customer accounts receivable		$100.4		$134.8		$128.1		$134.8
Unbilled utility revenues	77.2		69.7		72.8		69.7
Other receivables	0.2		0.1		0.3		0.1
Receivables sold to third party	177.8		204.6		201.2		204.6
Less: cash proceeds (a)	100.0		22.0		1.0		22.0
Deferred proceeds	77.8		182.6		200.2		182.6
Less: allowance for doubtful accounts	4.4		5.4		4.7		5.4
Fair value of deferred proceeds		$73.4		$177.2		$195.5		$177.2
Outstanding receivables past due		$14.0		$19.9		$15.4		$19.9


(a)	Changes in cash proceeds are presented in “Sales of accounts receivable” in operating activities in Alliant Energy’s and IPL’s cash flows statements.

Additional attributes of IPL’s receivables sold under the Receivables Agreement for the three and ~~six~~nine months ended ~~June~~September 30 were as follows (in millions):


	Three Months				Six Months				Three Months				Nine Months
	2015		2014		2015		2014		2015		2014		2015		2014
Collections reinvested in receivables		$417.1		$475.8		$923.0		$1,017.2		$480.1		$520.1		$1,403.1		$1,537.3
Credit losses, net of recoveries	2.5		3.9		3.5		6.4		3.3		6.4		6.8		12.8

(b) Whiting Petroleum Tax Sharing Agreement - Prior to an initial public offering of Whiting Petroleum in 2003, Alliant Energy and Whiting Petroleum entered into a tax separation and indemnification agreement pursuant to which Alliant Energy and Whiting Petroleum made certain tax elections. These tax elections had the effect of increasing the tax basis of the assets of Whiting Petroleum’s consolidated tax group based on the sales price of Whiting Petroleum’s shares in the initial public offering. 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 Petroleum paid Resources the final payment of $26 million in March 2014, which represented the present value of certain future tax benefits expected to be realized by Whiting Petroleum through future tax deductions. The $26 million received by Alliant Energy is presented in operating activities in its cash flows statement for the ~~six~~nine months ended ~~June~~September 30, 2014.

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~~(5)~~NOTE 5. INVESTMENTS

Unconsolidated Equity Investments - Equity (income) loss from unconsolidated investments accounted for under the equity method of accounting for the three and ~~six~~nine months ended ~~June~~September 30 was as follows (in millions):


	Alliant Energy												WPL												Alliant Energy												WPL
	Three Months						Six Months						Three Months						Six Months						Three Months						Nine Months						Three Months						Nine Months
	2015			2014			2015			2014			2015			2014			2015			2014			2015			2014			2015			2014			2015			2014			2015			2014
ATC		($10.9	)		($11.1	)		($18.7	)		($22.3	)		($10.9	)		($11.1	)		($18.7	)		($22.3	)		($10.9	)		($11.2	)		($29.6	)		($33.5	)		($10.9	)		($11.2	)		($29.6	)		($33.5	)
Other	(0.4		)	(0.2		)	0.9			(0.4		)	(0.4		)	(0.3		)	(0.4		)	(0.5		)	(0.2		)	(0.3		)	0.7			(0.7		)	(0.2		)	(0.2		)	(0.6		)	(0.7		)
		($11.3	)		($11.3	)		($17.8	)		($22.7	)		($11.3	)		($11.4	)		($19.1	)		($22.8	)		($11.1	)		($11.5	)		($28.9	)		($34.2	)		($11.1	)		($11.4	)		($30.2	)		($34.2	)

~~(6)~~NOTE 6. COMMON EQUITY

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



Shares outstanding, January 1, 2015	110,935,680
At-the-market offering program	2,186,617
Shareowner Direct Plan	~~107,412~~204,213
Equity-based compensation plans (Note 9(b))	56,378
Other	(22,463	)
Shares outstanding, ~~June~~September 30, 2015	~~113,263,624~~113,360,425

At-the-Market Offering Program - In March 2015, Alliant Energy filed a prospectus supplement under which it may sell up to $150 million of its common stock through an at-the-market offering program. As of ~~June~~September 30, 2015, Alliant Energy issued 2,186,617 shares of common stock through this program and received cash proceeds of $133 million, net of $2 million in fees and commissions. The proceeds from the issuances of common stock were used for general corporate purposes. Alliant Energy currently has no plans to issue any additional common stock through the at-the-market offering program.

Dividend Restrictions - As of ~~June~~September 30, 2015, IPL’s amount of retained earnings that were free of dividend restrictions was $~~533~~615 million. As of ~~June~~September 30, 2015, WPL’s amount of retained earnings that were free of dividend restrictions was $6432 million for the remainder of 2015.

Restricted Net Assets of Subsidiaries - As of ~~June~~September 30, 2015, the amount of net assets of IPL and WPL that were not available to be transferred to their parent company, Alliant Energy, in the form of loans, advances or cash dividends without the consent of IPL’s and WPL’s regulatory authorities was $1.4 billion and $1.7 billion, respectively.

Capital Transactions with Subsidiaries - For the ~~six~~nine months ended ~~June~~September 30, 2015, IPL received capital contributions of $100.0 million from its parent company. For the ~~six~~nine months ended ~~June~~September 30, 2015, IPL and WPL each paid common stock dividends of $~~69.9~~105.0 million and $~~63.5~~95.3 million, respectively, to its parent company.

Comprehensive Income - For the three and ~~six~~nine months ended ~~June~~September 30, 2015 and 2014, Alliant Energy had no other comprehensive income; therefore, its comprehensive income was equal to its net income and its comprehensive income attributable to Alliant Energy common shareowners was equal to its net income attributable to Alliant Energy common shareowners for such periods. For the three and ~~six~~nine months ended ~~June~~September 30, 2015 and 2014,, IPL and WPL had no other comprehensive income; therefore, their comprehensive income was equal to their net income and their comprehensive income available for common stock was equal to their earnings available for common stock for such periods.

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~~(7)~~NOTE 7. DEBT

(a) Short-term Debt - Information regarding commercial paper classified as short-term debt and back-stopped by the credit facilities was as follows (dollars in millions):

Alliant Energy

Parent

Alliant Energy

Parent

June 30, 2015

(Consolidated)

Company

IPL

WPL

September 30, 2015

(Consolidated)

Company

IPL

WPL

Commercial paper:

Amount outstanding

$120.9

$—

$109.1

$—

Weighted average remaining maturity

6 days

N/A

3 days

N/A

Weighted average interest rates

0.4%

N/A

0.4%

N/A

Available credit facility capacity ~~(a)~~

$767.9

$179.1

$188.8

$400.0

$890.9

$190.9

$300.0

$400.0


	Alliant Energy						IPL						WPL				Alliant Energy						IPL						WPL
Three Months Ended June 30	2015			2014			2015			2014			2015	2014
Three Months Ended September 30																	2015			2014			2015			2014			2015	2014
Maximum amount outstanding (based on daily outstanding balances)		$152.6			$311.6			$9.7			$6.0		$—		$168.4			$181.2			$353.8			$18.4			$38.0		$—		$185.0
Average amount outstanding (based on daily outstanding balances)		$93.2			$262.7			$0.1			$0.1		$—		$141.8			$122.4			$307.1			$0.5			$0.4		$—		$157.9
Weighted average interest rates	0.5		%	0.2		%	0.5		%	0.2		%	N/A	0.1		%	0.4		%	0.2		%	0.4		%	0.3		%	N/A	0.1		%
Six Months Ended June 30
Nine Months Ended September 30
Maximum amount outstanding (based on daily outstanding balances)		$152.6			$316.2			$9.7			$10.0		$—		$204.7			$181.2			$353.8			$18.4			$38.0		$—		$204.7
Average amount outstanding (based on daily outstanding balances)		$110.5			$269.1			$0.1			$0.2		$—		$157.3			$114.5			$281.9			$0.2			$0.3		$—		$157.5
Weighted average interest rates	0.4		%	0.2		%	0.5		%	0.2		%	N/A	0.1		%	0.4		%	0.2		%	0.4		%	0.2		%	N/A	0.1		%


~~(a)~~	~~Alliant Energy’s and IPL’s available credit facility capacities reflect outstanding commercial paper classified as both short- and long-term debt at June 30, 2015. Refer to~~ ~~Note 7(b)~~ ~~for further discussion of $111.2 million of commercial paper outstanding at June 30, 2015 classified as long-term debt on Alliant Energy’s and IPL’s balance sheets.~~

(b) Long-term Debt - In June 2015, IPL retired its $150.0 million, 3.3% senior debentures. ~~As of June 30,~~In August 2015, ~~$111.2~~IPL issued $250.0 million of 3.4% senior debentures due 2025. The proceeds from the issuance were used by IPL to reduce commercial paper ~~was recorded in “Long-term~~classified as long-term debt ~~net” on Alliant Energy’s~~by $111 million, reduce cash proceeds received from its sales of accounts receivable program and IPL’s balance sheets due to the existence of long-term credit facilities that back-stop this commercial paper balance, along with Alliant Energy’s and IPL’s intent and ability to refinance these balances on a long-term basis. As of June 30,for general corporate purposes.

In August 2015, ~~this commercial paper balance had a weighted average remaining maturity of 6 days and a 0.5% interest rate.~~WPL retired its $14.6 million, 5.375% pollution control revenue bonds. In September 2015, WPL retired its $16.0 million, 5% pollution control revenue bonds.

~~(8)~~NOTE 8. INCOME TAXES

Income Tax Rates - The provision for income taxes for earnings from continuing operations is based on an estimated annual effective income tax rate that excludes the impact of significant unusual or infrequently occurring items, discontinued operations or extraordinary items. The overall income tax rates shown in the following table were computed by dividing income tax expense (benefit) by income from continuing operations before income taxes.


	Alliant Energy				IPL				WPL				Alliant Energy				IPL				WPL
Three Months Ended June 30	2015		2014		2015		2014		2015		2014
Three Months Ended September 30													2015		2014		2015		2014		2015		2014
Statutory federal income tax rate	35.0	%	35.0	%	35.0	%	35.0	%	35.0	%	35.0	%	35.0	%	35.0	%	35.0	%	35.0	%	35.0	%	35.0	%
IPL’s tax benefit riders	(10.6	)	(11.9	)	(25.3	)	(36.6	)	—		—		(11.0	)	(13.0	)	(30.0	)	(39.2	)	—		—
Effect of rate-making on property-related differences	(8.4	)	(4.8	)	(22.3	)	(14.4	)	(0.7	)	(0.2	)	(7.1	)	(8.6	)	(18.7	)	(22.4	)	(0.7	)	(0.8	)
Production tax credits	(6.5	)	(6.1	)	(7.2	)	(8.0	)	(6.7	)	(5.8	)	(6.7	)	(6.8	)	(8.7	)	(9.3	)	(6.0	)	(6.2	)
Other items, net	4.1		4.8		4.1		4.6		4.6		5.0		3.0		0.7		2.9		2.2		4.5		—
Overall income tax rate	13.6	%	17.0	%	(15.7	%)	(19.4	%)	32.2	%	34.0	%	13.2	%	7.3	%	(19.5	%)	(33.7	%)	32.8	%	28.0	%

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	Alliant Energy				IPL				WPL				Alliant Energy				IPL				WPL
Six Months Ended June 30	2015		2014		2015		2014		2015		2014
Nine Months Ended September 30													2015		2014		2015		2014		2015		2014
Statutory federal income tax rate	35.0	%	35.0	%	35.0	%	35.0	%	35.0	%	35.0	%	35.0	%	35.0	%	35.0	%	35.0	%	35.0	%	35.0	%
IPL’s tax benefit riders	(10.2	)	(11.9	)	(25.2	)	(32.8	)	—		—		(10.6	)	(12.4	)	(28.2	)	(36.5	)	—		—
Effect of rate-making on property-related differences	(7.0	)	(5.1	)	(16.6	)	(13.0	)	(0.6	)	(0.7	)	(7.1	)	(6.7	)	(17.9	)	(18.4	)	(0.6	)	(0.7	)
Production tax credits	(6.4	)	(6.5	)	(7.2	)	(8.2	)	(6.4	)	(6.2	)	(6.6	)	(6.6	)	(8.2	)	(8.8	)	(6.2	)	(6.2	)
Other items, net	4.3		4.7		4.2		4.6		4.7		4.9		3.7		2.9		3.5		3.2		4.5		3.0
Overall income tax rate	15.7	%	16.2	%	(9.8	%)	(14.4	%)	32.7	%	33.0	%	14.4	%	12.2	%	(15.8	%)	(25.5	%)	32.7	%	31.1	%

IPL’s tax benefit riders - Alliant Energy’s and IPL’s effective income tax rates include the impact of reducing income tax expense with offsetting reductions to regulatory liabilities as a result of implementing IPL’s tax benefit riders. Refer to Note 2 for additional details of the tax benefit riders.

~~Effect of rate-making on property-related differences -~~ Alliant Energy’s and IPL’s effective income tax rates are impacted by the effect of rate-making principles on certain property-related differences for which deferred tax is not recognized in the income statement, substantially all of which relates to IPL. The increased benefits from property-related differences recognized during the three and six months ended June 30, 2015 were primarily due to additional repairs deductions.

Deferred Tax Assets and Liabilities - For the ~~six~~nine months ended ~~June~~September 30, 2015, Alliant Energy’s, IPL’s and WPL’s non-current deferred tax liabilities increased ~~$128.0~~$141.0 million, ~~$77.4~~$78.5 million and ~~$44.9~~$60.1 million, respectively. These increases in non-current deferred tax liabilities were primarily due to utilization of federal net operating loss carryforwards, and property-related differences recorded during the ~~six~~nine months ended ~~June~~September 30, 2015, including an increase in qualifying repairs expenditures.

Carryforwards - At ~~June~~September 30, 2015, tax carryforwards and associated deferred tax assets and expiration dates were estimated as follows (dollars in millions):

Alliant Energy Tax Carryforwards
Deferred
Tax Assets

Earliest
Expiration Date
Federal net operating losses
$845

$290
2029
State net operating losses 860
44
2018
Federal tax credits 222
218
2022

$552

IPL Tax Carryforwards
Deferred
Tax Assets

Earliest
Expiration Date
Federal net operating losses
$396

$136
2029
State net operating losses 265
14
2018
Federal tax credits 77
75
2022

$225


WPL	Tax Carryforwards		Deferred Tax Assets		Earliest Expiration Date
							Alliant Energy				IPL				WPL
						Earliest Expiration Date	Tax Carryforwards		Deferred Tax Assets		Tax Carryforwards		Deferred Tax Assets		Tax Carryforwards		Deferred Tax Assets
Federal net operating losses		$342		$117	2029	2030		$527		$180		$231		$79		$218		$75
State net operating losses	170		8		2018	2018	731		37		183		9		126		6
Federal tax credits	86		85		2022	2022	227		224		80		78		89		87
				$210						$441				$166				$168

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~~(9)~~NOTE 9. BENEFIT PLANS

(a) Pension and Other Postretirement Benefits Plans -

Net Periodic Benefit Costs (Credits) - The components of net periodic benefit costs (credits) for sponsored defined benefit pension and OPEB plans for the three and ~~six~~nine months ended ~~June~~September 30 are included in the tables below (in millions). In the “IPL” and “WPL” tables below, the defined benefit pension plans costs represent those respective costs for IPL’s and WPL’s bargaining unit employees covered under the qualified plans that are sponsored by IPL and WPL, respectively, as well as amounts directly assigned to each of IPL and WPL related to their current and former non-bargaining employees who are participants in the Alliant Energy and Corporate Services sponsored qualified and non-qualified defined benefit pension plans. In the “IPL” and “WPL” tables below, the OPEB plans costs (credits) represent costs (credits) for IPL and WPL employees, respectively, as well as amounts directly assigned to each of IPL and WPL related to their current and former non-bargaining employees who are participants in the Corporate Services sponsored OPEB plan.

Defined Benefit Pension Plans OPEB Plans
Three Months Six Months Three Months Six Months
Alliant Energy 2015 2014 2015 2014 2015 2014 2015 2014
Service cost
$3.9

$3.3

$7.9

$6.6

$1.4

$1.3

$2.8

$2.6
Interest cost 13.4
13.5
26.8
27.0
2.3
2.3
4.5
4.7
Expected return on plan assets (18.8 ) (18.8 ) (37.5 ) (37.5 ) (2.1 ) (2.0 ) (4.2 ) (4.1 )
Amortization of prior service credit —
—
(0.1 ) —
(2.8 ) (2.9 ) (5.6 ) (5.9 )
Amortization of actuarial loss 8.9
5.0
17.7
9.8
1.2
0.6
2.4
1.2
Additional benefit costs 0.1
—
0.3
—
—
—
—
—

$7.5

$3.0

$15.1

$5.9

$—

($0.7 )
($0.1 )
($1.5 )

Defined Benefit Pension Plans OPEB Plans
Three Months Six Months Three Months Six Months
IPL 2015 2014 2015 2014 2015 2014 2015 2014
Service cost
$2.2

$1.8

$4.4

$3.6

$0.6

$0.6

$1.2

$1.2
Interest cost 6.3
6.3
12.5
12.6
1.0
1.0
1.9
2.0
Expected return on plan assets (9.0 ) (8.9 ) (17.9 ) (17.9 ) (1.4 ) (1.4 ) (2.8 ) (2.9 )
Amortization of prior service credit (0.1 ) —
(0.1 ) —
(1.6 ) (1.5 ) (3.1 ) (3.1 )
Amortization of actuarial loss 3.9
2.0
7.7
4.0
0.5
0.2
1.1
0.5

$3.3

$1.2

$6.6

$2.3

($0.9 )
($1.1 )
($1.7 )
($2.3 )


	Defined Benefit Pension Plans												OPEB Plans												Defined Benefit Pension Plans												OPEB Plans
	Three Months						Six Months						Three Months						Six Months						Three Months						Nine Months						Three Months						Nine Months
WPL	2015			2014			2015			2014			2015			2014			2015			2014
Alliant Energy																									2015			2014			2015			2014			2015			2014			2015			2014
Service cost		$1.5			$1.2			$2.9			$2.4			$0.5			$0.5			$1.1			$1.0			$4.0			$3.3			$11.9			$9.9			$1.3			$1.3			$4.1			$3.9
Interest cost	5.7			5.6			11.3			11.3			0.9			0.9			1.8			1.9			13.5			13.6			40.3			40.6			2.3			2.4			6.8			7.1
Expected return on plan assets	(8.1		)	(8.1		)	(16.2		)	(16.2		)	(0.4		)	(0.3		)	(0.8		)	(0.6		)	(18.7		)	(18.8		)	(56.2		)	(56.3		)	(2.1		)	(2.1		)	(6.3		)	(6.2		)
Amortization of prior service cost (credit)	—			0.1			0.1			0.2			(0.8		)	(0.9		)	(1.7		)	(1.9		)
Amortization of prior service credit																									(0.1		)	—			(0.2		)	—			(2.8		)	(3.0		)	(8.4		)	(8.9		)
Amortization of actuarial loss	4.2			2.3			8.4			4.6			0.5			0.3			1.1			0.6			8.8			4.8			26.5			14.6			1.2			0.6			3.6			1.8
Additional benefit costs	0.1			—			0.3			—			—			—			—			—			0.1			—			0.4			—			—			—			—			—
		$3.4			$1.1			$6.8			$2.3			$0.7			$0.5			$1.5			$1.0			$7.6			$2.9			$22.7			$8.8			($0.1	)		($0.8	)		($0.2	)		($2.3	)

2019

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	Defined Benefit Pension Plans												OPEB Plans
	Three Months						Nine Months						Three Months						Nine Months
IPL	2015			2014			2015			2014			2015			2014			2015			2014
Service cost		$2.2			$1.8			$6.6			$5.4			$0.6			$0.6			$1.8			$1.8
Interest cost	6.2			6.2			18.7			18.8			0.9			1.0			2.8			3.0
Expected return on plan assets	(8.9		)	(8.9		)	(26.8		)	(26.8		)	(1.4		)	(1.5		)	(4.2		)	(4.4		)
Amortization of prior service credit	—			—			(0.1		)	—			(1.5		)	(1.6		)	(4.6		)	(4.7		)
Amortization of actuarial loss	3.8			2.0			11.5			6.0			0.6			0.3			1.7			0.8
		$3.3			$1.1			$9.9			$3.4			($0.8	)		($1.2	)		($2.5	)		($3.5	)



	Defined Benefit Pension Plans												OPEB Plans
	Three Months						Nine Months						Three Months						Nine Months
WPL	2015			2014			2015			2014			2015			2014			2015			2014
Service cost		$1.4			$1.3			$4.3			$3.7			$0.5			$0.5			$1.6			$1.5
Interest cost	5.6			5.7			16.9			17.0			0.9			1.0			2.7			2.9
Expected return on plan assets	(8.1		)	(8.1		)	(24.3		)	(24.3		)	(0.3		)	(0.4		)	(1.1		)	(1.0		)
Amortization of prior service cost (credit)	0.1			—			0.2			0.2			(0.9		)	(1.0		)	(2.6		)	(2.9		)
Amortization of actuarial loss	4.2			2.3			12.6			6.9			0.6			0.3			1.7			0.9
Additional benefit costs	0.1			—			0.4			—			—			—			—			—
		$3.3			$1.2			$10.1			$3.5			$0.8			$0.4			$2.3			$1.4

401(k) Savings Plans - A significant number of employees participate in defined contribution retirement plans (401(k) savings plans). For the three and ~~six~~nine months ended ~~June~~September 30, costs related to the 401(k) savings plans, which are partially based on the participants’ contributions and include allocated costs associated with Corporate Services employees for IPL and WPL, were as follows (in millions):

Alliant Energy IPL (a) WPL (a)
Three Months Six Months Three Months Six Months Three Months Six Months
2015 2014 2015 2014 2015 2014 2015 2014 2015 2014 2015 2014
401(k) costs
$5.6

$6.1

$12.3

$12.0

$2.9

$2.6

$6.3

$5.7

$2.6

$3.3

$5.5

$5.9



	Alliant Energy								IPL								WPL
	Three Months				Nine Months				Three Months				Nine Months				Three Months				Nine Months
	2015		2014		2015		2014		2015		2014		2015		2014		2015		2014		2015		2014
401(k) costs		$6.4		$5.3		$18.7		$17.3		$3.3		$2.7		$9.6		$8.4		$2.9		$2.4		$8.4		$8.3


~~(a)~~	~~IPL’s and WPL’s amounts include allocated costs associated with Corporate Services employees.~~

Voluntary Employee Separation Charges - In the third quarter of 2015, Alliant Energy offered certain employees a voluntary separation package. Approximately 2% of total Alliant Energy employees accepted this package, which resulted in Alliant Energy, IPL and WPL recording charges of $8 million, $5 million and $3 million, respectively, in the third quarter of 2015.

(b) Equity-based Compensation Plans - A summary of compensation expense (including amounts allocated to IPL and WPL) and the related income tax benefits recognized for share-based compensation awards for the three and ~~six~~nine months ended ~~June~~September 30 was as follows (in millions):


	Alliant Energy								IPL								WPL								Alliant Energy								IPL								WPL
	Three Months				Six Months				Three Months				Six Months				Three Months				Six Months				Three Months				Nine Months				Three Months				Nine Months				Three Months				Nine Months
	2015		2014		2015		2014		2015		2014		2015		2014		2015		2014		2015		2014		2015		2014		2015		2014		2015		2014		2015		2014		2015		2014		2015		2014
Compensation expense		$2.3		$3.1		$5.5		$6.2		$1.2		$1.7		$2.9		$3.4		$1.0		$1.3		$2.4		$2.6		$0.3		$1.2		$5.8		$7.4		$0.2		$0.6		$3.1		$4.0		$0.1		$0.5		$2.5		$3.1
Income tax benefits	0.9		1.2		2.2		2.5		0.5		0.7		1.2		1.4		0.4		0.5		1.0		1.0		0.2		0.5		2.4		3.0		0.1		0.2		1.3		1.6		—		0.3		1.0		1.3

As of ~~June~~September 30, 2015, total unrecognized compensation cost related to share-based compensation awards was ~~$9.6~~$6.0 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~~“Other operation and maintenance” in the income statements.

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Performance Shares and Units -

Performance Shares - A summary of the performance shares activity, with share amounts representing the target number of performance shares, was as follows:


	2015 (a)		2014 (a)		2015		2014
Nonvested shares, January 1	144,424		139,940		144,424		139,940
Granted	45,403		51,221		45,403		51,221
Vested	(45,612	)	(45,235	)	(45,612	)	(45,235	)
Forfeited	—		(1,502	)	—		(1,502	)
Nonvested shares, June 30	144,215		144,424
Nonvested shares, September 30					144,215		144,424


~~(a)~~	~~Share amounts represent the target number of performance shares.~~

During the ~~six~~nine months ended ~~June~~September 30, certain performance shares vested, resulting in payouts (a combination of cash and common stock) as follows:



	2015			2014
	2012 Grant			2011 Grant
Performance shares vested	45,612			45,235
Percentage of target number of performance shares	167.5		%	147.5		%
Aggregate payout value (in millions)		$5.1			$3.4
Payout - cash (in millions)		$3.2			$2.9
Payout - common stock shares issued	10,975			4,810

~~Table of Contents~~

Performance Units - A summary of the performance units activity, with unit amounts representing the target number of performance units, was as follows:


	2015 (a)		2014 (a)		2015		2014
Nonvested units, January 1	63,665		65,912		63,665		65,912
Granted	17,837		20,422		17,837		20,422
Vested	(22,845	)	(20,751	)	(22,845	)	(20,751	)
Forfeited	(333	)	(761	)	(451	)	(958	)
Nonvested units, June 30	58,324		64,822
Nonvested units, September 30					58,206		64,625


~~(a)~~	~~Unit amounts represent the target number of performance units.~~

During the ~~six~~nine months ended ~~June~~September 30, certain performance units vested, resulting in cash payouts as follows:



	2015			2014
	2012 Grant			2011 Grant
Performance units vested	22,845			20,751
Percentage of target number of performance units	167.5		%	147.5		%
Payout value (in millions)		$1.6			$1.2

Fair Value of Awards - Information related to fair values of nonvested performance shares and units at ~~June~~September 30, 2015, by year of grant, was as follows:


	Performance Shares									Performance Units									Performance Shares									Performance Units
	2015 Grant			2014 Grant			2013 Grant			2015 Grant			2014 Grant			2013 Grant			2015 Grant			2014 Grant			2013 Grant			2015 Grant			2014 Grant			2013 Grant
Nonvested awards	45,403			49,719			49,093			17,504			19,440			21,380			45,403			49,719			49,093			17,386			19,440			21,380
Alliant Energy common stock closing price on June 30, 2015		$57.72			$57.72			$57.72
Alliant Energy common stock closing price on September 30, 2015																				$58.49			$58.49			$58.49
Alliant Energy common stock closing price on grant date											$65.09			$53.77			$47.58												$65.09			$53.77			$47.58
Estimated payout percentage based on performance criteria	100		%	133		%	180		%	100		%	133		%	180		%	70		%	105		%	150		%	70		%	105		%	150		%
Fair values of each nonvested award		$57.72			$76.77			$103.90			$65.09			$71.51			$85.64			$40.94			$61.41			$87.74			$45.56			$56.46			$71.37

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At ~~June~~September 30, 2015, fair values of nonvested performance shares and units were calculated based on Alliant Energy’s stock price and anticipated total shareowner returns of Alliant Energy and its investor-owned utility peer group over the performance period. The portion of the fair values based on anticipated total shareowner returns was estimated using a model that incorporates the probability of meeting performance targets based on historical returns relative to the peer group.

Performance Contingent Restricted Stock - A summary of the performance contingent restricted stock activity was as follows:


	2015				2014				2015				2014
	Shares		Weighted Average Fair Value		Shares		Weighted Average Fair Value		Shares		Weighted Average Fair Value		Shares		Weighted Average Fair Value
Nonvested shares, January 1	98,812			$50.69	158,922			$42.71	98,812			$50.69	158,922			$42.71
Granted	45,403		65.09		51,221		53.77		45,403		65.09		51,221		53.77
Vested (a)	(49,093	)	47.58		(90,847	)	40.91		(49,093	)	47.58		(90,847	)	40.91
Forfeited	—		—		(20,484	)	39.85		—		—		(20,484	)	39.85
Nonvested shares, June 30	95,122		59.17		98,812		50.69
Nonvested shares, September 30									95,122		59.17		98,812		50.69


(a)	In 2015, 49,093 performance contingent restricted shares granted in 2013 vested because the specified performance criteria for such shares were met. In 2014, 45,612 and 45,235 performance contingent restricted shares granted in 2012 and 2011, respectively, vested because the specified performance criteria for such shares were met.

~~Table of Contents~~

Performance Contingent Cash Awards - A summary of the performance contingent cash awards activity was as follows:


	2015		2014		2015		2014
Nonvested awards, January 1	78,930		96,977		78,930		96,977
Granted	41,105		42,446		41,105		42,446
Vested (a)	(37,332	)	(55,517	)	(37,332	)	(55,517	)
Forfeited	(709	)	(4,098	)	(827	)	(4,295	)
Nonvested awards, June 30	81,994		79,808
Nonvested awards, September 30					81,876		79,611


(a)	In 2015, 37,332 performance contingent cash awards granted in 2013 vested, resulting in cash payouts valued at $2.4 million. In 2014, 34,766 and 20,751 performance contingent cash awards granted in 2012 and 2011 vested, resulting in cash payouts valued at $1.9 million and $1.1 million, respectively.

~~(10)~~NOTE 10. ASSET RETIREMENT OBLIGATIONS

A reconciliation of the changes in AROs associated with long-lived assets is as follows (in millions):


	Alliant Energy						IPL						WPL						Alliant Energy						IPL						WPL
	2015			2014			2015			2014			2015			2014			2015			2014			2015			2014			2015			2014
Balance, January 1		$114.0			$109.7			$51.8			$47.9			$52.4			$52.4			$114.0			$109.7			$51.8			$47.9			$52.4			$52.4
Revisions in estimated cash flows ~~(a)~~	2.1			—			0.9			—			1.2			—			8.9			—			11.9			—			(1.9		)	—
Liabilities settled	(6.4		)	(0.7		)	(2.4		)	(0.4		)	(4.0		)	(0.3		)	(7.1		)	(1.0		)	(3.1		)	(0.5		)	(4.0		)	(0.5		)
Liabilities incurred (a)	72.3			16.5			56.1			16.3			16.2			0.2			76.1			16.5			59.9			16.3			16.2			0.2
Accretion expense	2.2			2.1			0.9			1.0			0.9			0.8			3.4			3.3			1.6			1.6			1.4			1.3
Balance, June 30		$184.2			$127.6			$107.3			$64.8			$66.7			$53.1
Balance, September 30																				$195.3			$128.5			$122.1			$65.3			$64.1			$53.4

(a)

In April 2015, the EPA published the final CCR Rule, which regulates CCR as a non-hazardous waste and is effective October 2015. IPL and WPL have nine and three coal-fired EGUs, respectively, with coal ash ponds that are impacted by this rule. In addition, IPL and WPL have four and two active CCR landfills, respectively, that are impacted by this rule. InDuring the ~~second quarter of~~nine months ended September 30, 2015, Alliant Energy, IPL and WPL recognized additional AROs of $74 million, $57 million and $17 million, respectively, as a result of the final CCR Rule. The increases in AROs resulted in corresponding increases in “Property, plant and equipment, net” on the respective balance sheets. Actual costs resulting from the CCR rule may be different than the amounts recorded induring the ~~second quarter of~~nine months ended September 30, 2015 due to potential changes in compliance strategies that will be used, as well as other potential cost estimate changes. Expenditures incurred by IPL and WPL to comply with the CCR Rule are anticipated to be recovered in rates from their customers.

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~~(11)~~NOTE 11. FAIR VALUE MEASUREMENTS

Fair Value of Financial Instruments - The carrying amounts of 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 were as follows (in millions):


	Alliant Energy				IPL				WPL				Alliant Energy				IPL				WPL
June 30, 2015	Carrying Amount		Fair Value		Carrying Amount		Fair Value		Carrying Amount		Fair Value
September 30, 2015													Carrying Amount		Fair Value		Carrying Amount		Fair Value		Carrying Amount		Fair Value
Assets:
Derivative assets (Note 12)		$35.0		$35.0		$30.7		$30.7		$4.3		$4.3		$20.3		$20.3		$18.5		$18.5		$1.8		$1.8
Deferred proceeds (sales of receivables) (Note 4(a))	73.4		73.4		73.4		73.4		—		—		195.5		195.5		195.5		195.5		—		—
Capitalization and liabilities:
Long-term debt (including current maturities) (Note 7(b))	3,750.9		4,214.4		1,730.2		1,937.2		1,574.1		1,824.0		3,858.8		4,394.3		1,868.5		2,115.3		1,543.6		1,825.5
Cumulative preferred stock	200.0		198.9		200.0		198.9		—		—		200.0		201.3		200.0		201.3		—		—
Derivative liabilities (Note 12)	47.0		47.0		20.7		20.7		26.3		26.3		59.1		59.1		22.0		22.0		37.1		37.1

~~Table of Contents~~



	Alliant Energy				IPL				WPL
December 31, 2014	Carrying Amount		Fair Value		Carrying Amount		Fair Value		Carrying Amount		Fair Value
Assets:
Derivative assets (Note 12)		$38.6		$38.6		$28.0		$28.0		$10.6		$10.6
Deferred proceeds (sales of receivables) (Note 4(a))	177.2		177.2		177.2		177.2		—		—
Capitalization and liabilities:
Long-term debt (including current maturities) (Note 7(b))	3,789.7		4,418.2		1,768.7		2,053.0		1,573.9		1,908.9
Cumulative preferred stock	200.0		200.2		200.0		200.2		—		—
Derivative liabilities (Note 12)	37.6		37.6		19.5		19.5		18.1		18.1

Valuation Hierarchy - At each reporting date, Level 1 items included IPL’s 5.1% cumulative preferred stock, Level 2 items included certain non-exchange traded commodity contracts and substantially all of the long-term debt instruments, and Level 3 items included FTRs, certain non-exchange traded commodity contracts and IPL’s deferred proceeds.

Valuation Techniques -

Derivative assets and derivative liabilities - Derivative instruments are periodically used for risk management purposes to mitigate exposures to fluctuations in certain commodity prices and transmission congestion costs, and risk policies are maintained that govern the use of such derivative instruments. Derivative instruments were not designated as hedging instruments and included the following:



Risk management purpose	Type of instrument
Mitigate pricing volatility for:
Electricity purchased to supply customers	Electric swap and physical forward contracts (IPL and WPL)
Fuel used to supply natural gas-fired EGUs	Natural gas swap ~~options~~ and physical forward contracts (IPL and WPL)
Natural gas supplied to retail customers	Natural gas options and physical forward contracts (IPL and WPL)
	Natural gas swap contracts (IPL)
Fuel used at coal-fired EGUs	Coal physical forward contracts (IPL and WPL)
Optimize the value of natural gas pipeline capacity	Natural gas physical forward contracts (IPL and WPL)
	Natural gas swap contracts (IPL)
Manage transmission congestion costs	FTRs (IPL and WPL)

Table of Contents

Swap, option and physical forward commodity contracts were non-exchange-based derivative instruments and were valued using indicative price quotations from 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. A portion of these indicative price quotations were corroborated using quoted prices for similar assets or liabilities in active markets and categorized derivative instruments based on such indicative price quotations as Level 2. 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. Swap, option and physical forward commodity contracts were predominately at liquid trading points. 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 fair value measurements of Level 3 derivative instruments include observable and unobservable inputs. The observable inputs are obtained from third-party pricing sources, counterparties and brokers and include bids, offers, historical transactions (including historical price differences between locations with both observable and unobservable prices) and executed trades. The significant unobservable inputs used in the fair value measurement of 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.

~~Table of Contents~~

Deferred proceeds (sales of receivables) - The fair value of IPL’s deferred proceeds related to its sales of accounts receivable 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) - The fair value of long-term debt instruments was based on quoted market prices for similar liabilities at each reporting date or on a discounted cash flow methodology, which utilizes assumptions of current market pricing curves at each reporting date. Refer to Note 7(b) for additional information regarding long-term debt.

Cumulative preferred stock - The fair value of IPL’s 5.1% cumulative preferred stock was based on its closing market price quoted by the New York Stock Exchange at each reporting date.

Items subject to fair value measurement disclosure requirements were as follows (in millions):


Alliant Energy	June 30, 2015								December 31, 2014								September 30, 2015								December 31, 2014
	Fair		Level		Level		Level		Fair		Level		Level		Level		Fair		Level		Level		Level		Fair		Level		Level		Level
	Value		1		2		3		Value		1		2		3		Value		1		2		3		Value		1		2		3
Assets:
Derivatives - commodity contracts		$35.0		$—		$3.0		$32.0		$38.6		$—		$2.6		$36.0		$20.3		$—		$2.6		$17.7		$38.6		$—		$2.6		$36.0
Deferred proceeds	73.4		—		—		73.4		177.2		—		—		177.2		195.5		—		—		195.5		177.2		—		—		177.2
Capitalization and liabilities:
Long-term debt (including current maturities)	4,214.4		—		4,210.7		3.7		4,418.2		—		4,414.9		3.3		4,394.3		—		4,390.6		3.7		4,418.2		—		4,414.9		3.3
Cumulative preferred stock	198.9		198.9		—		—		200.2		200.2		—		—		201.3		201.3		—		—		200.2		200.2		—		—
Derivatives - commodity contracts	47.0		—		15.6		31.4		37.6		—		19.5		18.1		59.1		—		16.8		42.3		37.6		—		19.5		18.1

Table of Contents



IPL	September 30, 2015								December 31, 2014
	Fair		Level		Level		Level		Fair		Level		Level		Level
	Value		1		2		3		Value		1		2		3
Assets:
Derivatives - commodity contracts		$18.5		$—		$2.1		$16.4		$28.0		$—		$2.4		$25.6
Deferred proceeds	195.5		—		—		195.5		177.2		—		—		177.2
Capitalization and liabilities:
Long-term debt (including current maturities)	2,115.3		—		2,115.3		—		2,053.0		—		2,053.0		—
Cumulative preferred stock	201.3		201.3		—		—		200.2		200.2		—		—
Derivatives - commodity contracts	22.0		—		9.4		12.6		19.5		—		13.3		6.2

IPL June 30, 2015 December 31, 2014
Fair Level Level Level Fair Level Level Level
Value 1 2 3 Value 1 2 3
Assets:
Derivatives - commodity contracts
$30.7

$—

$1.9

$28.8

$28.0

$—

$2.4

$25.6
Deferred proceeds 73.4
—
—
73.4
177.2
—
—
177.2
Capitalization and liabilities:
Long-term debt (including current maturities) 1,937.2
—
1,937.2
—
2,053.0
—
2,053.0
—
Cumulative preferred stock 198.9
198.9
—
—
200.2
200.2
—
—
Derivatives - commodity contracts 20.7
—
10.2
10.5
19.5
—
13.3
6.2


WPL	June 30, 2015								December 31, 2014								September 30, 2015								December 31, 2014
	Fair		Level		Level		Level		Fair		Level		Level		Level		Fair		Level		Level		Level		Fair		Level		Level		Level
	Value		1		2		3		Value		1		2		3		Value		1		2		3		Value		1		2		3
Assets:
Derivatives - commodity contracts		$4.3		$—		$1.1		$3.2		$10.6		$—		$0.2		$10.4		$1.8		$—		$0.5		$1.3		$10.6		$—		$0.2		$10.4
Capitalization and liabilities:
Long-term debt (including current maturities)	1,824.0		—		1,824.0		—		1,908.9		—		1,908.9		—		1,825.5		—		1,825.5		—		1,908.9		—		1,908.9		—
Derivatives - commodity contracts	26.3		—		5.4		20.9		18.1		—		6.2		11.9		37.1		—		7.4		29.7		18.1		—		6.2		11.9

Unrealized gains and losses from derivative instruments are generally recorded with offsets to regulatory assets or regulatory liabilities, based on 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.

~~Table of Contents~~

Information for fair value measurements using significant unobservable inputs (Level 3 inputs) was as follows (in millions):

Alliant Energy Commodity Contract Derivative
Assets and (Liabilities), net Deferred Proceeds
Three Months Ended June 30 2015 2014 2015 2014
Beginning balance, April 1
($13.1 )
$23.9

$117.7

$170.8
Total net gains (losses) (realized/unrealized) included in changes in net assets (19.6 ) 16.9
—
—
Transfers out of Level 3 1.0
—
—
—
Purchases 36.8
76.7
—
—
Sales (0.4 ) —
—
—
Settlements (a) (4.1 ) (16.3 ) (44.3 ) 22.9
Ending balance, June 30
$0.6

$101.2

$73.4

$193.7
The amount of total net gains (losses) for the period included in changes in net assets attributable to the change in unrealized gains (losses) relating to assets and liabilities held at June 30
($17.7 )
$16.3

$—

$—



Alliant Energy	Commodity Contract Derivative
	Assets and (Liabilities), net						Deferred Proceeds
Three Months Ended September 30	2015			2014			2015		2014
Beginning balance, July 1		$0.6			$101.2			$73.4		$193.7
Total net losses (realized/unrealized) included in changes in net assets	(21.1		)	(12.7		)	—		—
Sales	(0.4		)	(1.2		)	—		—
Settlements (a)	(3.7		)	(19.0		)	122.1		(33.4		)
Ending balance, September 30		($24.6	)		$68.3			$195.5		$160.3
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 September 30		($18.4	)		($10.3	)		$—		$—

Table of Contents



Alliant Energy	Commodity Contract Derivative
	Assets and (Liabilities), net						Deferred Proceeds
Nine Months Ended September 30	2015			2014			2015		2014
Beginning balance, January 1		$17.9			$4.4			$177.2		$203.5
Total net gains (losses) (realized/unrealized) included in changes in net assets	(58.2		)	43.0			—		—
Transfers out of Level 3	0.6			—			—		—
Purchases	36.9			76.7			—		—
Sales	(1.7		)	(1.2		)	—		—
Settlements (a)	(20.1		)	(54.6		)	18.3		(43.2		)
Ending balance, September 30		($24.6	)		$68.3			$195.5		$160.3
The amount of total net gains (losses) for the period included in changes in net assets attributable to the change in unrealized gains (losses) relating to assets and liabilities held at September 30		($52.2	)		$34.6			$—		$—

Alliant Energy Commodity Contract Derivative
Assets and (Liabilities), net Deferred Proceeds
Six Months Ended June 30 2015 2014 2015 2014
Beginning balance, January 1
$17.9

$4.4

$177.2

$203.5
Total net gains (losses) (realized/unrealized) included in changes in net assets (36.8 ) 54.7
—
—
Transfers out of Level 3 0.6
—
—
—
Purchases 36.8
76.7
—
—
Sales (1.2 ) —
—
—
Settlements (a) (16.7 ) (34.6 ) (103.8 ) (9.8 )
Ending balance, June 30
$0.6

$101.2

$73.4

$193.7
The amount of total net gains (losses) for the period included in changes in net assets attributable to the change in unrealized gains (losses) relating to assets and liabilities held at June 30
($33.9 )
$46.0

$—

$—



IPL	Commodity Contract Derivative
	Assets and (Liabilities), net						Deferred Proceeds
Three Months Ended September 30	2015			2014			2015		2014
Beginning balance, July 1		$18.3			$64.2			$73.4		$193.7
Total net losses (realized/unrealized) included in changes in net assets	(8.6		)	(10.1		)	—		—
Sales	(0.4		)	(1.0		)	—		—
Settlements (a)	(5.5		)	(16.6		)	122.1		(33.4		)
Ending balance, September 30		$3.8			$36.5			$195.5		$160.3
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 September 30		($8.0	)		($9.6	)		$—		$—

IPL Commodity Contract Derivative
Assets and (Liabilities), net Deferred Proceeds
Three Months Ended June 30 2015 2014 2015 2014
Beginning balance, April 1
($5.0 )
$7.8

$117.7

$170.8
Total net gains (losses) (realized/unrealized) included in changes in net assets (5.0 ) 0.6
—
—
Transfers out of Level 3 0.2
—
—
—
Purchases 33.1
68.8
—
—
Sales (0.4 ) —
—
—
Settlements (a) (4.6 ) (13.0 ) (44.3 ) 22.9
Ending balance, June 30
$18.3

$64.2

$73.4

$193.7
The amount of total net gains (losses) for the period included in changes in net assets attributable to the change in unrealized gains (losses) relating to assets and liabilities held at June 30
($4.2 )
$0.7

$—

$—



IPL	Commodity Contract Derivative
	Assets and (Liabilities), net						Deferred Proceeds
Nine Months Ended September 30	2015			2014			2015		2014
Beginning balance, January 1		$19.4			$14.6			$177.2		$203.5
Total net losses (realized/unrealized) included in changes in net assets	(26.0		)	(5.1		)	—		—
Purchases	33.1			68.8			—		—
Sales	(1.6		)	(1.0		)	—		—
Settlements (a)	(21.1		)	(40.8		)	18.3		(43.2		)
Ending balance, September 30		$3.8			$36.5			$195.5		$160.3
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 September 30		($21.2	)		($6.0	)		$—		$—



WPL	Commodity Contract Derivative
	Assets and (Liabilities), net
Three Months Ended September 30	2015			2014
Beginning balance, July 1		($17.7	)		$37.0
Total net losses (realized/unrealized) included in changes in net assets	(12.5		)	(2.6		)
Sales	—			(0.2		)
Settlements	1.8			(2.4		)
Ending balance, September 30		($28.4	)		$31.8
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 September 30		($10.4	)		($0.7	)

Table of Contents

IPL Commodity Contract Derivative
Assets and (Liabilities), net Deferred Proceeds
Six Months Ended June 30 2015 2014 2015 2014
Beginning balance, January 1
$19.4

$14.6

$177.2

$203.5
Total net gains (losses) (realized/unrealized) included in changes in net assets (17.4 ) 4.4
—
—
Purchases 33.1
68.8
—
—
Sales (1.1 ) —
—
—
Settlements (a) (15.7 ) (23.6 ) (103.8 ) (9.8 )
Ending balance, June 30
$18.3

$64.2

$73.4

$193.7
The amount of total net gains (losses) for the period included in changes in net assets attributable to the change in unrealized gains (losses) relating to assets and liabilities held at June 30
($14.3 )
$3.7

$—

$—

WPL Commodity Contract Derivative
Assets and (Liabilities), net
Three Months Ended June 30 2015 2014
Beginning balance, April 1
($8.1 )
$16.1
Total net gains (losses) (realized/unrealized) included in changes in net assets (14.6 ) 16.3
Transfers out of Level 3 0.8
—
Purchases 3.7
7.9
Settlements 0.5
(3.3 )
Ending balance, June 30
($17.7 )
$37.0
The amount of total net gains (losses) for the period included in changes in net assets attributable to the change in unrealized gains (losses) relating to assets and liabilities held at June 30
($13.5 )
$15.6


WPL	Commodity Contract Derivative						Commodity Contract Derivative
	Assets and (Liabilities), net						Assets and (Liabilities), net
Six Months Ended June 30	2015			2014
Nine Months Ended September 30							2015			2014
Beginning balance, January 1		($1.5	)		($10.2	)		($1.5	)		($10.2	)
Total net gains (losses) (realized/unrealized) included in changes in net assets	(19.4		)	50.3			(32.2		)	48.1
Transfers out of Level 3	0.6			—			0.6			—
Purchases	3.7			7.9			3.8			7.9
Sales	(0.1		)	—			(0.1		)	(0.2		)
Settlements	(1.0		)	(11.0		)	1.0			(13.8		)
Ending balance, June 30		($17.7	)		$37.0
The amount of total net gains (losses) for the period included in changes in net assets attributable to the change in unrealized gains (losses) relating to assets and liabilities held at June 30		($19.6	)		$42.3
Ending balance, September 30								($28.4	)		$31.8
The amount of total net gains (losses) for the period included in changes in net assets attributable to the change in unrealized gains (losses) relating to assets and liabilities held at September 30								($31.0	)		$40.6


(a)	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.

~~Table of Contents~~

Commodity Contracts - The fair value of electric, natural gas and coal commodity contracts categorized as Level 3 was recognized as net derivative assets (liabilities) as follows (in millions):


	Alliant Energy					IPL					WPL					Alliant Energy					IPL					WPL
	Excluding FTRs			FTRs		Excluding FTRs			FTRs		Excluding FTRs			FTRs		Excluding FTRs			FTRs		Excluding FTRs			FTRs		Excluding FTRs			FTRs
June 30, 2015		($28.3	)		$28.9		($9.0	)		$27.3		($19.3	)		$1.6
September 30, 2015																	($39.4	)		$14.8		($10.9	)		$14.7		($28.5	)		$0.1
December 31, 2014	(7.0		)	24.9		(3.2		)	22.6		(3.8		)	2.3		(7.0		)	24.9		(3.2		)	22.6		(3.8		)	2.3

~~(12)~~NOTE 12. DERIVATIVE INSTRUMENTS

Commodity Derivatives -

Purpose - Derivative instruments are periodically used 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.

Notional Amounts - As of ~~June~~September 30, 2015,, gross notional amounts by and settlement/delivery ~~year~~years 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):

2015 2016 2017 2018 Total
Alliant Energy
Electricity (MWhs) 2,432
3,240
1,314
1,314
8,300
FTRs (MWhs) 11,952
9,961
—
—
21,913
Natural gas (Dths) 36,167
34,330
9,079
126
79,702
Coal (tons) 897
2,260
1,073
1,113
5,343
IPL
Electricity (MWhs) 1,100
809
—
—
1,909
FTRs (MWhs) 6,664
5,696
—
—
12,360
Natural gas (Dths) 23,343
18,103
2,886
126
44,458
Coal (tons) 189
830
274
387
1,680
WPL
Electricity (MWhs) 1,332
2,431
1,314
1,314
6,391
FTRs (MWhs) 5,288
4,265
—
—
9,553
Natural gas (Dths) 12,824
16,227
6,193
—
35,244
Coal (tons) 708
1,430
799
726
3,663



	Electricity		FTRs		Natural Gas		Coal
	MWhs	Years	MWhs	Years	Dths	Years	Tons	Years
Alliant Energy	7,024	2015-2018	15,793	2015-2016	103,867	2015-2020	4,918	2015-2018
IPL	1,302	2015-2016	8,880	2015-2016	67,910	2015-2020	1,585	2015-2018
WPL	5,722	2015-2018	6,913	2015-2016	35,957	2015-2017	3,333	2015-2018

Financial Statement Presentation - Derivative instruments are recorded at fair value each reporting date on the balance sheets as assets or liabilities. The fair values of current derivative assets are included in “Other current assets,” non-current derivative assets are included in “Deferred charges and other,” current derivative liabilities are included in “Other current liabilities” and non-current derivative liabilities are included in “Other liabilities” on the balance sheets as follows (in millions):


	Alliant Energy				IPL				WPL				Alliant Energy				IPL				WPL
Commodity contracts	June 30, 2015		December 31, 2014		June 30, 2015		December 31, 2014		June 30, 2015		December 31, 2014		September 30, 2015		December 31, 2014		September 30, 2015		December 31, 2014		September 30, 2015		December 31, 2014
Current derivative assets		$34.2		$30.5		$30.0		$27.4		$4.2		$3.1		$19.5		$30.5		$17.8		$27.4		$1.7		$3.1
Non-current derivative assets	0.8		8.1		0.7		0.6		0.1		7.5		0.8		8.1		0.7		0.6		0.1		7.5
Current derivative liabilities	27.1		28.1		13.8		16.4		13.3		11.7		35.4		28.1		15.2		16.4		20.2		11.7
Non-current derivative liabilities	19.9		9.5		6.9		3.1		13.0		6.4		23.7		9.5		6.8		3.1		16.9		6.4

2827

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Changes in ~~unrealized~~ gains (losses) from commodity derivative instruments were recorded with offsets to regulatory assets or regulatory liabilities on the balance sheets as follows (in millions):


	Alliant Energy						IPL						WPL						Alliant Energy						IPL						WPL
	2015			2014			2015			2014			2015			2014			2015			2014			2015			2014			2015			2014
Three Months Ended June 30
Three Months Ended September 30
Regulatory assets		($21.2	)		($4.6	)		($12.1	)		($4.1	)		($9.1	)		($0.5	)		($27.4	)		$8.3			($9.5	)		$7.3			($17.9	)		$1.0
Regulatory liabilities	(4.6		)	21.3			3.6			3.8			(8.2		)	17.5			(2.5		)	(6.2		)	(1.2		)	(2.0		)	(1.3		)	(4.2		)
Six Months Ended June 30
Nine Months Ended September 30
Regulatory assets	(42.1		)	5.5			(23.8		)	1.4			(18.3		)	4.1			(69.5		)	13.8			(33.3		)	8.7			(36.2		)	5.1
Regulatory liabilities	(2.4		)	69.4			2.2			15.9			(4.6		)	53.5			(4.9		)	63.2			1.0			13.9			(5.9		)	49.3

Credit Risk-related Contingent Features - Various agreements contain credit risk-related contingent features, including requirements to maintain certain credit ratings and/or limitations on liability positions under the agreements based on credit ratings. Certain of these agreements with credit risk-related contingency features are accounted for as derivative instruments. In the event of a material change in creditworthiness or if liability positions exceed certain contractual limits, credit support may need to be provided in the form of letters of credit or cash collateral up to the amount of exposure under the contracts, or the contracts may need to be unwound and underlying liability positions paid. The aggregate fair value of all derivative instruments with credit risk-related contingent features in a net liability position, as well as amounts that would be required to be posted as credit support to counterparties by Alliant Energy, IPL or WPL if the most restrictive credit risk-related contingent features for derivative agreements in a net liability position were triggered, were as follows (in millions):


	Alliant Energy				IPL				WPL				Alliant Energy				IPL				WPL
	June 30, 2015		December 31, 2014		June 30, 2015		December 31, 2014		June 30, 2015		December 31, 2014		September 30, 2015		December 31, 2014		September 30, 2015		December 31, 2014		September 30, 2015		December 31, 2014
Aggregate fair value		$47.0		$37.6		$20.7		$19.5		$26.3		$18.1		$59.1		$37.6		$22.0		$19.5		$37.1		$18.1
Credit support to be posted if triggered	46.9		37.4		20.7		19.5		26.2		17.9		59.0		37.4		22.0		19.5		37.0		17.9

Balance Sheet Offsetting - The fair value amounts of derivative instruments subject to a master netting arrangement are not netted by counterparty on the balance sheets. However, if the fair value amounts of derivative instruments by counterparty were netted, derivative assets and derivative liabilities related to commodity contracts would have been presented on the balance sheets as follows (in millions):


	Alliant Energy				IPL				WPL				Alliant Energy				IPL				WPL
	Gross				Gross				Gross				Gross				Gross				Gross
	(as reported)		Net		(as reported)		Net		(as reported)		Net		(as reported)		Net		(as reported)		Net		(as reported)		Net
June 30, 2015
September 30, 2015
Derivative assets		$35.0		$32.0		$30.7		$29.3		$4.3		$2.7		$20.3		$18.0		$18.5		$17.3		$1.8		$0.7
Derivative liabilities	47.0		44.0		20.7		19.3		26.3		24.7		59.1		56.8		22.0		20.8		37.1		36.0
December 31, 2014
Derivative assets	38.6		33.0		28.0		24.7		10.6		8.3		38.6		33.0		28.0		24.7		10.6		8.3
Derivative liabilities	37.6		32.0		19.5		16.2		18.1		15.8		37.6		32.0		19.5		16.2		18.1		15.8

Fair value amounts recognized for the right to reclaim cash collateral (receivable) or the obligation to return cash collateral (payable) are not offset against fair value amounts recognized for derivative instruments executed with the same counterparty under the same master netting arrangement.

~~(13)~~NOTE 13. COMMITMENTS AND CONTINGENCIES

(a) Capital Purchase Obligations - Various contractual obligations contain minimum future commitments related to capital expenditures for certain construction projects. IPL’s projects include generation maintenance and performance improvements for Marshalltown Combustion Turbine Units 1-3. WPL’s projects include the installation of a scrubber and baghouse at Edgewater Unit 5 to reduce SO2 and mercury emissions, ~~and~~ generation maintenance and performance improvements at Columbia Units 1 and 2.2, and the installation of an SCR system at Columbia Unit 2 to reduce NOx emissions at the EGU. At ~~June~~September 30, 2015, Alliant Energy’s, IPL’s and WPL’s minimum future commitments related to certain contractual obligations for these projects were ~~$30 million.~~$27 million, $8 million and $19 million, respectively.

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(b) Operating Expense Purchase Obligations - Various commodity supply, transportation and storage contracts help meet obligations to provide electricity and natural gas to utility customers. Other operating expense purchase obligations with various vendors provide other goods and services. At ~~June~~September 30, 2015, minimum future commitments related to these operating expense purchase obligations were as follows (in millions):


	Alliant Energy		IPL		WPL		Alliant Energy		IPL		WPL
Purchased power (a):
DAEC (IPL)		$1,480		$1,480		$—		$1,448		$1,448		$—
Other	202		1		201		183		1		182
	1,682		1,481		201		1,631		1,449		182
Natural gas	270		165		105		389		265		124
Coal (b)	279		114		165		262		117		145
SO2 emission allowances	22		22		—		22		22		—
Other (c)	24		17		7		11		8		3
		$2,277		$1,799		$478		$2,315		$1,861		$454


(a)	Includes payments required by PPAs for capacity rights and minimum quantities of MWhs required to be purchased.


(b)	Corporate Services entered into system-wide coal contracts on behalf of IPL and WPL that include minimum future commitments. These commitments were assigned to IPL and WPL based on information available as of ~~June~~September 30, 2015 regarding expected future usage, which is subject to change.


(c)	Includes individual commitments incurred during the normal course of business that exceeded $1 million at ~~June~~September 30, 2015.

~~IPL Consent Decree~~ - In July 2015, IPL entered into a Consent Decree with the EPA, the Sierra Club, the State of Iowa and Linn County in Iowa to resolve potential claims regarding CAA issues associated with emissions from IPL’s coal-fired generating facilities in Iowa, while admitting no liability. In July 2015, the Consent Decree was lodged with, and is subject to approval by, the U.S. District Court for the Northern District of Iowa. Under the Consent Decree, IPL is required to install the following emission control systems:

~~Scrubber and baghouse at the Ottumwa Generating Station by December 31, 2015 (placed in service in 2014);~~

~~Scrubber and baghouse at the Lansing Generating Station by December 31, 2016 (placed in service in June 2015 and in 2010, respectively); and~~

~~SCR system or equivalent NOx reduction system at the Ottumwa Generating Station by December 31, 2019.~~

~~IPL is also required to fuel switch or retire the following EGUs:~~

~~M.L. Kapp Generating Station by August 31, 2015 (switched the fuel type from coal to natural gas in June 2015);~~

~~Prairie Creek Unit 4 by June 1, 2018;~~

~~Burlington Generating Station by December 31, 2021; and~~

~~Prairie Creek Units 1 and 3 by December 31, 2025.~~

In addition, IPL is required to either install combined cycle technology at, or retire, the Dubuque and Sutherland Generation Stations by June 1, 2019. IPL previously switched the fuel type from coal to natural gas at these EGUs.

The Consent Decree also establishes SO2, NOx and particulate matter emission rate limits with varying averaging times for the Burlington, Lansing, M.L. Kapp, Ottumwa and Prairie Creek Generating Stations. In addition, the Consent Decree includes calendar-year SO2 and NOx emission caps for the Prairie Creek Generating Station, and calendar-year SO2 and NOx emission caps in aggregate for the Burlington, Dubuque, Lansing, M.L. Kapp, Ottumwa, Prairie Creek and Sutherland Generating Stations. IPL will also pay a civil penalty of approximately $1 million and complete approximately $6 million in environmental mitigation projects.

Alliant Energy and IPL currently expect to recover costs incurred by IPL related to the emission control systems and environmental mitigation projects from IPL’s electric customers. The recovery of such costs will be decided by IPL’s regulators in future rate cases or other proceedings. Alliant Energy and IPL currently do not expect to recover costs related to the civil penalty from IPL’s electric customers.

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Flood Damage Claims - In June 2013, several plaintiffs purporting to represent a class of residential and commercial property owners filed a complaint against CRANDIC, Alliant Energy and various other defendants in the Iowa District Court for Linn County. Plaintiffs assert claims of negligence and strict liability based on their allegations that CRANDIC (along with other defendants) caused or exacerbated flooding of the Cedar River in June 2008. In July 2013, the case was removed from state court to federal court based on federal jurisdiction. In September 2013, the U.S. District Court for the Northern District of Iowa dismissed the Plaintiffs’ claims and transferred the case for resolution to the Surface Transportation Board, the administrative agency that oversees the Interstate Commerce Commission Termination Act. In October 2013, the Plaintiffs appealed the federal court’s dismissal of the case to the Eighth Circuit Court of Appeals. In May 2015, the Eighth Circuit Court of Appeals vacated the U.S. District Court for the Northern District of Iowa’s decision and ordered the case remanded back to the Iowa District Court for Linn County. Alliant Energy and CRANDIC believe the case is without merit and will continue to vigorously contest the case. As a result, Alliant Energy does not currently believe any material losses from these claims are both probable and reasonably estimated, and therefore, has not recognized any material loss contingency amounts for this complaint as of ~~June~~September 30, 2015. Due to the lack of specific damages identified and the procedural nature of the activity to date, Alliant Energy is currently unable to provide an estimate of potential loss or range of potential loss.

(d) Guarantees and Indemnifications -

RMT - In 2013, Alliant Energy sold RMT. RMT provided renewable energy services, including construction and high voltage connection services for wind and solar projects. As part of the sale, Alliant Energy indemnified the buyer for any claims, including claims of warranty under the project obligations that were commenced or are based on actions that occurred prior to the sale, except for liabilities already accounted for through adjustments to the purchase price. The indemnification obligations either cease to exist when the statute of limitation for such claims is met or, in the case of RMT’s projects, when the warranty period under the agreements expires. The contractual warranty periods for RMT’s projects generally range from 12 to 60 months with the latest expiring in 2016. Limited warranties may be extended in certain cases for warranty work performed.

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 ~~June~~September 30, 2015,, Alliant Energy had ~~$198~~$123 million of performance guarantees outstanding, with ~~$75 million,~~ $48 million and $75 million currently expected to expire in ~~2015,~~ 2016 and 2017, respectively. The expiration of these performance guarantees may be extended depending on when all valid warranty claims are resolved for the respective projects.

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Although Alliant Energy has received warranty claims related to certain of these projects, it does not currently believe that material losses are both probable and reasonably estimated, and therefore, has not recognized any material liabilities related to these matters as of ~~June~~September 30, 2015. Alliant Energy does not currently believe that the range of future potential loss from any warranty claims will be material. Refer to Note 16 for further discussion of RMT, including amounts Alliant Energy recorded to “Operating expenses” induring the ~~second quarter of~~nine months ended September 30, 2015 and 2014 related to certain warranty claims.

Whiting Petroleum - In 2004, Alliant Energy sold its remaining interest in Whiting Petroleum. Whiting Petroleum is an independent oil and gas company. Alliant Energy continues to guarantee the obligations related to the abandonment of certain platforms off the coast of California and related onshore plant and equipment that were owned by Whiting Petroleum prior to Alliant Energy’s sale of Whiting Petroleum. The guarantee does not include a maximum limit. As of ~~June~~September 30, 2015, the present value of the abandonment obligations is estimated at ~~$36~~$27 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 ~~June~~September 30, 2015.

IPL’s Minnesota Electric Distribution Assets - IPL provided indemnifications associated with the July 2015 sale of its Minnesota electric distribution assets for losses resulting from potential breach of IPL’s representations, warranties and obligations under the sale agreement. Alliant Energy and IPL believe the likelihood of having to make any material cash payments under these indemnifications is remote. IPL has not recorded any material liabilities related to these indemnifications as of September 30, 2015. The general terms of the indemnifications provided by IPL included a maximum limit of $17 million and expire in October 2020. Refer to Note 3 for further discussion of the sale of IPL’s Minnesota electric distribution assets.

(e) Environmental Matters -

MGP Sites - IPL and WPL have current or previous ownership interests in various sites that are previously associated with the production of gas for which IPL and WPL have, or may have in the future, liability for investigation, remediation and monitoring costs. 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 these former MGP sites in order to protect public health and the environment. IPL and WPL are currently monitoring and/or remediating 24 and 5 sites, respectively. No longer included in IPL’s sites is a Minnesota site for which responsibility of ~~monitoring and/or remediating~~ the site was transferred to the buyer as part of the sale of IPL’s Minnesota natural gas distribution assets completed in April 2015.

~~Table of Contents~~

Environmental liabilities related to the MGP sites are recorded 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. At ~~June~~September 30, 2015, estimated future costs expected to be incurred for the investigation, remediation and monitoring of the MGP sites, as well as environmental liabilities recorded on the balance sheets for these sites, were as follows (in millions):


	Alliant Energy				IPL				WPL				Alliant Energy				IPL				WPL
Range of estimated future costs		$12	-	$29		$10	-	$26		$2	-	$3		$11	-	$29		$10	-	$26		$1	-	$3
Current and non-current environmental liabilities	16				14				2				16				13				3

WPL Consent Decree - In 2009, the EPA sent a notice of violation to WPL as an owner and the operator of Edgewater, Nelson Dewey and Columbia alleging that the owners of such EGUs failed to comply with appropriate pre-construction review and permitting requirements and as a result violated the Prevention of Significant Deterioration program requirements, Title V Operating Permit requirements of the CAA and the Wisconsin State Implementation Plan. In 2010, the Sierra Club filed complaints against WPL, as owner and operator of Nelson Dewey and Columbia, and separately as owner and operator of Edgewater, based on allegations that modifications were made at the facilities without complying with the Prevention of Significant Deterioration program requirements, Title V Operating Permit requirements of the CAA and state regulatory counterparts contained within the Wisconsin State Implementation Plan designed to implement the CAA.

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In April 2013, WPL, along with the other owners of Edgewater and Columbia, entered into a Consent Decree with the EPA and the Sierra Club to resolve the claims relating to Edgewater, Columbia and Nelson Dewey, while admitting no liability. In June 2013, the Consent Decree was approved by the U.S. District Court for the Western District of Wisconsin, thereby resolving all claims against WPL. Under the Consent Decree, WPL is required to install the following emission controls systems:

SCR system at Edgewater Unit 5 by May 1, 2013 (placed in service in 2012);

Scrubbers and baghouses at Columbia Units 1 and 2 by December 31, 2014 (placed in service in 2014);

Scrubber and baghouse at Edgewater Unit 5 by December 31, 2016; and

SCR system at Columbia Unit 2 by December 31, 2018.

WPL is also required to fuel switch or retire Nelson Dewey Units 1 and 2 and Edgewater Unit 3 by December 31, 2015, and Edgewater Unit 4 by December 31, 2018. In addition, the Consent Decree establishes emission rate limits for SO2, NOx and particulate matter for Columbia Units 1 and 2, Nelson Dewey Units 1 and 2 and Edgewater Units 4 and 5. The Consent Decree also includes annual plant-wide emission caps for SO2 and NOx for Columbia, Edgewater and Nelson Dewey. In addition, WPL will complete approximately $7 million in environmental mitigation projects.

Final recovery of the costs expected to be incurred related to the Consent Decree will be decided by the PSCW in future rate cases or other proceedings. Alliant Energy and WPL currently expect to recover any material costs incurred by WPL related to compliance with the terms of the Consent Decree from WPL’s electric customers.

IPL Consent Decree - In July 2015, IPL entered into a Consent Decree with the EPA, the Sierra Club, the State of Iowa and Linn County in Iowa to resolve potential claims regarding CAA issues associated with emissions from IPL’s coal-fired generating facilities in Iowa, while admitting no liability. In September 2015, the Consent Decree was approved by the U.S. District Court for the Northern District of Iowa, thereby resolving all potential claims against IPL. Under the Consent Decree, IPL is required to install the following emission controls systems:

Scrubber and baghouse at the Ottumwa Generating Station by December 31, 2015 (placed in service in 2014);

Scrubber and baghouse at the Lansing Generating Station by December 31, 2016 (scrubber was placed in service in June 2015 and baghouse was placed in service in 2010); and

SCR system or equivalent NOx reduction system at the Ottumwa Generating Station by December 31, 2019.

IPL is also required to fuel switch or retire the following EGUs:

M.L. Kapp Generating Station by August 31, 2015 (switched the fuel type from coal to natural gas in June 2015);

Prairie Creek Unit 4 by June 1, 2018;

Burlington Generating Station by December 31, 2021; and

Prairie Creek Units 1 and 3 by December 31, 2025.

The Consent Decree also establishes SO2, NOx and particulate matter emission rate limits with varying averaging times for the Burlington, Lansing, M.L. Kapp, Ottumwa and Prairie Creek Generating Stations. In addition, the Consent Decree includes calendar-year SO2 and NOx emission caps for the Prairie Creek Generating Station, and calendar-year SO2 and NOx emission caps in aggregate for the Burlington, Dubuque, Lansing, M.L. Kapp, Ottumwa, Prairie Creek and Sutherland Generating Stations. Pursuant to the Consent Decree, IPL paid a civil penalty of $1 million in September 2015 and will complete approximately $6 million in environmental mitigation projects.

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Other Environmental Contingencies - In addition to the environmental liabilities discussed above, various environmental rules are monitored that may have a significant impact on future operations. Several of these environmental rules are subject to legal challenges, reconsideration and/or other uncertainties. Given uncertainties regarding the outcome, timing and compliance plans for these environmental matters, the complete financial impact of each of these rules is not able to be determined; however future capital investments and/or modifications to EGUs to comply with certain of these rules could be significant. Specific current, proposed or potential environmental matters include, among others: Cross-State Air Pollution Rule, Clean Air Visibility Rule, Mercury and Air Toxic Standard Rule, Industrial Boiler and Process Heater Maximum Achievable Control Technology Rule, Ozone ~~National Ambient Air Quality Standards~~NAAQS Rule, SO2 ~~National Ambient Air Quality Standards~~NAAQS Rule, Federal Clean Water Act including Section 316(b), Effluent Limitation Guidelines, Hydroelectric Fish Passage Device, CCR Rule, and various legislation and EPA regulations to monitor and regulate the emission of greenhouse gases, including carbon emissions from new (CAA Section 111(b)) and existing (CAA Section 111(d)) fossil-fueled EGUs. Some recent developments concerning these environmental matters are included below:

~~Table of Contents~~

Air Quality -

Clean Air Act Section 111(b) - In ~~August~~October 2015, the EPA ~~issued~~published final standards under Section 111(b) of the CAA, which establish carbon dioxide emissions limits for certain new fossil-fueled EGUs. Marshalltown and WPL’s proposed Riverside expansion are expected to be impacted by these standards. Marshalltown is being constructed, and WPL’s proposed Riverside expansion is being designed, to achieve compliance with these standards.

Water Quality -

Effluent Limitation Guidelines - In November 2015, the EPA published final effluent limitation guidelines, which require changes to discharge limits for wastewater from steam generating facilities. Compliance will be required after November 1, 2018 but before December 31, 2023, depending on each facility’s wastewater permit renewal cycle for existing steam generating facilities and immediately upon operation for new steam generating facilities constructed after the effective date of the final guidelines.

Land and Solid Waste -

CCR Rule - Refer to Note 10 for discussion of the final CCR Rule, including additional AROs that were recognized induring the ~~second quarter of~~nine months ended September 30, 2015 related to such rule.

~~(14)~~

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NOTE 14. SEGMENTS OF BUSINESS

Alliant Energy - Certain financial information relating to Alliant Energy’s business segments is as follows. Intersegment revenues were not material to Alliant Energy’s operations.


	Utility									Non-Regulated,			Alliant Energy			Utility									Non-Regulated,			Alliant Energy
	Electric		Gas			Other		Total		Parent and Other			Consolidated			Electric		Gas			Other		Total		Parent and Other			Consolidated
	(in millions)															(in millions)
Three Months Ended June 30, 2015
Three Months Ended September 30, 2015
Operating revenues		$640.4		$51.7			$14.8		$706.9		$10.3			$717.2			$835.8		$38.0			$13.4		$887.2		$11.7			$898.9
Operating income (loss)	100.9		(2.0		)	3.2		102.1		6.9			109.0			232.8		(5.7		)	0.2		227.3		8.6			235.9
Amounts attributable to Alliant Energy common shareowners:
Income from continuing operations, net of tax								55.7		13.2			68.9
Income (loss) from continuing operations, net of tax																							184.9		(4.9		)	180.0
Loss from discontinued operations, net of tax								—		(1.3		)	(1.3		)								—		(0.1		)	(0.1		)
Net income								55.7		11.9			67.6
Three Months Ended June 30, 2014
Net income (loss)																							184.9		(5.0		)	179.9
Three Months Ended September 30, 2014
Operating revenues		$643.9		$76.9			$15.6		$736.4		$13.9			$750.3			$771.2		$47.2			$12.2		$830.6		$12.5			$843.1
Operating income	89.1		2.7			2.2		94.0		9.3			103.3
Operating income (loss)																190.8		(4.4		)	1.4		187.8		7.0			194.8
Amounts attributable to Alliant Energy common shareowners:
Income from continuing operations, net of tax								53.0		9.1			62.1
Income (loss) from continuing operations, net of tax																							164.1		(8.9		)	155.2
Loss from discontinued operations, net of tax								—		(0.3		)	(0.3		)								—		(1.9		)	(1.9		)
Net income								53.0		8.8			61.8
Net income (loss)																							164.1		(10.8		)	153.3



	Utility								Non-Regulated,			Alliant Energy
	Electric		Gas		Other		Total		Parent and Other			Consolidated
	(in millions)
Nine Months Ended September 30, 2015
Operating revenues		$2,147.5		$288.1		$44.6		$2,480.2		$33.3			$2,513.5
Operating income	438.4		28.6		8.7		475.7		22.1			497.8
Amounts attributable to Alliant Energy common shareowners:
Income from continuing operations, net of tax							333.0		12.5			345.5
Loss from discontinued operations, net of tax							—		(1.4		)	(1.4		)
Net income							333.0		11.1			344.1
Nine Months Ended September 30, 2014
Operating revenues		$2,090.9		$364.8		$50.6		$2,506.3		$39.9			$2,546.2
Operating income	374.2		41.3		11.5		427.0		25.3			452.3
Amounts attributable to Alliant Energy common shareowners:
Income from continuing operations, net of tax							315.3		10.0			325.3
Loss from discontinued operations, net of tax							—		(2.2		)	(2.2		)
Net income							315.3		7.8			323.1

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Utility Non-Regulated, Alliant Energy
Electric Gas Other Total Parent and Other Consolidated
(in millions)
Six Months Ended June 30, 2015
Operating revenues
$1,311.7

$250.1

$31.2

$1,593.0

$21.6

$1,614.6
Operating income 205.6
34.3
8.5
248.4
13.5
261.9
Amounts attributable to Alliant Energy common shareowners:

Income from continuing operations, net of tax 148.1
17.4
165.5
Loss from discontinued operations, net of tax —
(1.3 ) (1.3 )
Net income 148.1
16.1
164.2
Six Months Ended June 30, 2014
Operating revenues
$1,319.7

$317.6

$38.4

$1,675.7

$27.4

$1,703.1
Operating income 183.4
45.7
10.1
239.2
18.3
257.5
Amounts attributable to Alliant Energy common shareowners:
Income from continuing operations, net of tax 151.2
18.9
170.1
Loss from discontinued operations, net of tax —
(0.3 ) (0.3 )
Net income 151.2
18.6
169.8

IPL - Certain financial information relating to IPL’s business segments is as follows. Intersegment revenues were not material to IPL’s operations.


	Electric		Gas			Other		Total		Electric		Gas			Other		Total
	(in millions)									(in millions)
Three Months Ended June 30, 2015
Three Months Ended September 30, 2015
Operating revenues		$339.4		$29.8			$13.0		$382.2		$468.6		$23.1			$12.9		$504.6
Operating income (loss)	33.9		(2.4		)	2.3		33.8		119.4		(2.9		)	0.5		117.0
Earnings available for common stock								16.7									117.4
Three Months Ended June 30, 2014
Three Months Ended September 30, 2014
Operating revenues											$435.9		$28.7			$11.6		$476.2
Operating income (loss)										94.7		(2.8		)	2.0		93.9
Earnings available for common stock																	102.5
Nine Months Ended September 30, 2015
Operating revenues		$354.6		$43.7			$13.6		$411.9		$1,170.6		$164.1			$41.1		$1,375.8
Operating income	29.0		1.6			3.4		34.0		193.6		15.3			7.4		216.3
Earnings available for common stock								18.4									181.9
Six Months Ended June 30, 2015
Nine Months Ended September 30, 2014
Operating revenues		$702.0		$141.0			$28.2		$871.2		$1,164.7		$208.1			$44.2		$1,417.0
Operating income	74.2		18.2			6.9		99.3		150.2		22.1			13.1		185.4
Earnings available for common stock								64.5									164.3
Six Months Ended June 30, 2014
Operating revenues		$728.8		$179.4			$32.6		$940.8
Operating income	55.5		24.9			11.1		91.5
Earnings available for common stock								61.8

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WPL - Certain financial information relating to WPL’s business segments is as follows. Intersegment revenues were not material to WPL’s operations.


	Electric		Gas		Other			Total		Electric		Gas			Other			Total
	(in millions)									(in millions)
Three Months Ended June 30, 2015
Three Months Ended September 30, 2015
Operating revenues											$367.2		$14.9			$0.5			$382.6
Operating income (loss)										113.4		(2.8		)	(0.3		)	110.3
Earnings available for common stock																		67.5
Three Months Ended September 30, 2014
Operating revenues											$335.3		$18.5			$0.6			$354.4
Operating income (loss)										96.1		(1.6		)	(0.6		)	93.9
Earnings available for common stock																		61.6
Nine Months Ended September 30, 2015
Operating revenues		$301.0		$21.9		$1.8			$324.7		$976.9		$124.0			$3.5			$1,104.4
Operating income	67.0		0.4		0.9			68.3		244.8		13.3			1.3			259.4
Earnings available for common stock								39.0										151.1
Three Months Ended June 30, 2014
Nine Months Ended September 30, 2014
Operating revenues		$289.3		$33.2		$2.0			$324.5		$926.2		$156.7			$6.4			$1,089.3
Operating income (loss)	60.1		1.1		(1.2		)	60.0		224.0		19.2			(1.6		)	241.6
Earnings available for common stock								34.6										151.0
Six Months Ended June 30, 2015
Operating revenues		$609.7		$109.1		$3.0			$721.8
Operating income	131.4		16.1		1.6			149.1
Earnings available for common stock								83.6
Six Months Ended June 30, 2014
Operating revenues		$590.9		$138.2		$5.8			$734.9
Operating income (loss)	127.9		20.8		(1.0		)	147.7
Earnings available for common stock								89.4

~~(15)~~

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NOTE 15. RELATED PARTIES

Service Agreements - IPL and WPL are parties to service agreements with an affiliate, Corporate Services. Pursuant to these service agreements, IPL and WPL receive various administrative and general services. These services are billed to IPL and WPL at cost based on expenses incurred by Corporate Services for the benefit of IPL and WPL, respectively. These costs consisted primarily of employee compensation and benefits, fees associated with various professional services and a return on net assets. Corporate Services also acts as agent on behalf of IPL and WPL pursuant to the service agreements. As agent, Corporate Services enters into energy, capacity, ancillary services, and transmission sale and purchase transactions within MISO and PJM. Corporate Services assigns such sales and purchases among IPL and WPL based on statements received from MISO and PJM. The amounts billed for services provided, sales credited and purchases for the three and ~~six~~nine months ended ~~June~~September 30 were as follows (in millions):


	IPL								WPL								IPL								WPL
	Three Months				Six Months				Three Months				Six Months				Three Months				Nine Months				Three Months				Nine Months
	2015		2014		2015		2014		2015		2014		2015		2014		2015		2014		2015		2014		2015		2014		2015		2014
Corporate Services billings		$40		$41		$76		$74		$32		$31		$60		$59		$38		$37		$114		$111		$30		$30		$90		$89
Sales credited	2		2		6		4		6		3		12		2		2		2		8		6		9		2		21		4
Purchases billed	89		108		168		207		19		28		33		58		110		106		278		313		16		34		49		92

Net intercompany payables to Corporate Services were as follows (in millions):

IPL WPL
June 30, 2015 December 31, 2014 June 30, 2015 December 31, 2014
Net payables to Corporate Services $95 $84 $49 $58



	IPL		WPL
	September 30, 2015	December 31, 2014	September 30, 2015	December 31, 2014
Net payables to Corporate Services	$101	$84	$55	$58

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. The related amounts billed between the parties for the three and ~~six~~nine months ended ~~June~~September 30 were as follows (in millions):


	Three Months				Six Months				Three Months				Nine Months
	2015		2014		2015		2014		2015		2014		2015		2014
ATC billings to WPL		$25		$24		$50		$48		$25		$24		$75		$72
WPL billings to ATC	3		1		5		4		4		3		9		7

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WPL owed ATC net amounts of $8$7 million as of ~~June~~September 30, 2015 and $8 million as of December 31, 2014.

~~(16)~~NOTE 16. DISCONTINUED OPERATIONS AND ASSETS AND LIABILITIES HELD FOR SALE

In 2013, Alliant Energy sold RMT to narrow its strategic focus and risk profile. The operating results of RMT have been separately classified and reported as discontinued operations in Alliant Energy’s income statements. A summary of the components of discontinued operations in Alliant Energy’s income statements for the three and ~~six~~nine months ended ~~June~~September 30 was as follows (in millions):


	Three Months						Six Months						Three Months						Nine Months
	2015			2014			2015			2014			2015			2014			2015			2014
Operating expenses		$2.0			$0.6			$2.0			$0.6			$0.3			$2.8			$2.3			$3.4
Loss before income taxes	(2.0		)	(0.6		)	(2.0		)	(0.6		)	(0.3		)	(2.8		)	(2.3		)	(3.4		)
Income tax benefit	(0.7		)	(0.3		)	(0.7		)	(0.3		)	(0.2		)	(0.9		)	(0.9		)	(1.2		)
Loss from discontinued operations, net of tax		($1.3	)		($0.3	)		($1.3	)		($0.3	)		($0.1	)		($1.9	)		($1.4	)		($2.2	)

Refer to Note 13(d) for further discussion of warranty claims associated with RMT that have resulted in operating expenses subsequent to the sale.

In April 2015, IPL completed the sale of its Minnesota natural gas distribution assets, which qualified as held for sale as of December 31, 2014. In July 2015, IPL completed the sale of its Minnesota electric distribution ~~assets, which qualified as held for sale as of June 30, 2015.~~assets. Alliant Energy and IPL evaluated the sales of IPL’s Minnesota electric and natural gas distribution assets and believe such sales did not represent a strategic shift that has, or will have, a major effect on their operational and financial results. As a result, the operating results of IPL’s Minnesota electric and natural gas distribution assets have not been separately classified and reported as discontinued operations in Alliant Energy’s and IPL’s income statements.

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As of December 31, 2014, Alliant Energy’s and IPL’s balance sheets included assets held for sale related to IPL’s Minnesota natural gas distribution assets recorded in “Other current assets” and liabilities held for sale recorded in “Other current liabilities” as follows (in millions):

Electric Natural Gas
Distribution Assets Distribution Assets
June 30, 2015 December 31, 2014
Assets held for sale:
Current assets
$9.3

$1.1
Property, plant and equipment, net 125.0
11.0
Non-current regulatory assets 20.5
7.0
Carrying value adjustment of net assets sold (a) (8.8 ) —
Total assets held for sale 146.0
19.1
Liabilities held for sale:
Current liabilities 2.4
1.0
Other liabilities 12.6
7.1
Total liabilities held for sale 15.0
8.1
Net assets held for sale
$131.0

$11.0



~~(a)~~	~~The carrying value of IPL’s Minnesota electric distribution assets classified as~~Assets held for ~~sale exceeded the expected proceeds, less costs to sell. As a result, Alliant Energy~~sale:
Current assets		$1.1
Property, plant and ~~IPL recorded a pre-tax charge of $9 million in the second quarter of 2015 related to the Minnesota electric distribution assets.~~equipment, net	11.0
Non-current regulatory assets	7.0
Total assets held for sale	19.1
Liabilities held for sale:
Current liabilities	1.0
Other liabilities	7.1
Total liabilities held for sale	8.1
Net assets held for sale		$11.0

Refer to Note 3 for further discussion of IPL’s sales of its Minnesota electric and natural gas distribution assets.

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ITEM 2. MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS

This MDA includes information relating to Alliant Energy, IPL and WPL, as well as Resources and Corporate Services. Where appropriate, information relating to a specific entity has been segregated and labeled as such. The following discussion and analysis should be read in conjunction with the Financial Statements and the Notes included in this report as well as the financial statements, notes and MDA included in the 2014 Form 10-K. Unless otherwise noted, all “per share” references in MDA refer to earnings per diluted share.

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


•	New Accounting Pronouncements


•	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 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 select markets in Iowa. WPL is a public utility engaged principally in the generation and distribution of electricity and the distribution and transportation of natural gas in select markets in southern and central Wisconsin. At ~~June~~September 30, 2015, WPL and Resources, through their ownership interests in WPL Transco, LLC, in aggregate held an approximate 16% ownership interest in ATC, a transmission-only utility operating primarily in the Midwest. 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.

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	Alliant Energy


Utilities, ATC and Corporate Services		Non-regulated and Parent
- Electric and gas services in IA (IPL)		- Transportation (Resources)
- Electric and gas services in WI (WPL)		- Non-regulated Generation (Resources)
- 16% interest in ATC (primarily WPL)		- Parent Company
- Wholesale electric service in MN (IPL)
- Corporate Services

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Financial Results - Alliant Energy’s net income and EPS attributable to Alliant Energy common shareowners for the ~~second~~third quarter were as follows (dollars in millions, except per share amounts):


	2015						2014					2015						2014
	Income (Loss)			EPS			Income (Loss)			EPS		Income (Loss)			EPS			Income (Loss)			EPS
Continuing operations:
Utilities, ATC and Corporate Services		$58.9			$0.52			$55.3			$0.50		$188.1			$1.66			$166.7			$1.50
Non-regulated and Parent	10.0			0.09			6.8			0.06		(8.1		)	(0.07		)	(11.5		)	(0.10		)
Income from continuing operations	68.9			0.61			62.1			0.56		180.0			1.59			155.2			1.40
Loss from discontinued operations	(1.3		)	(0.01		)	(0.3		)	—		(0.1		)	—			(1.9		)	(0.02		)
Net income		$67.6			$0.60			$61.8			$0.56		$179.9			$1.59			$153.3			$1.38

The table above includes EPS from continuing operations for utilities, ATC and Corporate Services, and non-regulated and parent, ~~EPS from continuing operations,~~ which are non-GAAP financial measures. Alliant Energy believes EPS from continuing operations for utilities, ATC 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.

Utilities, ATC and Corporate Services - Higher EPS in the ~~second~~third quarter of 2015 compared to the ~~second~~third quarter of 2014 was primarily due to:

$~~0.08~~0.11 per share of lower retail electric customer billing credits at IPL in the ~~second~~third quarter of 2015 compared to the ~~second~~third quarter of 2014 related to an approved settlement agreement in 2014 for its Iowa retail electric base rates;

an estimated $0.06 per share of higher estimated temperature-normalized retail electric sales in the third quarter of 2015 compared to the third quarter of 2014;

$~~0.05~~0.06 per share of lower energy efficiency cost recovery amortizations at WPL in the ~~second~~third quarter of 2015 compared to the ~~second~~third quarter of 2014; ~~and~~

an estimated ~~$0.03~~$0.05 per share of increases in revenues from higher ~~estimated temperature-normalized retail~~ electric sales in the ~~second~~third quarter of 2015 compared to the ~~second~~third quarter of ~~2014.~~2014 due to colder temperatures in the third quarter of 2014; and

$0.04 per share of lower other operation and maintenance expenses.

These items were ~~substantially~~partially offset by:

$~~0.06 per share of charges recorded in the second quarter of 2015 related to the sales of IPL’s Minnesota electric and natural gas distribution assets;~~

~~$0.05~~0.04 per share of higher electric transmission service expense at WPL in the ~~second~~third quarter of 2015 compared to the ~~second~~third quarter of 2014;

$0.04 per share related to the dilution impact of shares issued under the at-the-market offering program and Shareowner Direct Plan in 2015; and

~~an estimated $0.05~~$0.04 per share ~~of decreases in revenues from lower electric and gas sales~~related to voluntary employee separation charges in the ~~second~~third quarter of ~~2015 compared to the second quarter of 2014 due to milder temperatures.~~2015.

Non-regulated and Parent - Higher EPS in the ~~second~~third quarter of 2015 compared to the ~~second~~third quarter of 2014 was primarily due to ~~$0.03~~$0.02 per share related to the timing of income tax expense at the Parent in the ~~second~~third quarter of 2015 compared to the ~~second~~third quarter of 2014, which is not expected to have a material impact on the full year results.

Refer to “Results of Operations” for additional details regarding the various factors impacting earnings during the ~~second~~third quarters of 2015 and 2014.

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Strategic Overview Highlights

The strategic plan focuses on the core business of delivering regulated electric and natural gas service in Iowa and Wisconsin, and is built upon three key elements: competitive value, exceptional service, and responsible resources. Key strategic plan developments since the filing of the 2014 Form 10-K include the following. Refer to “Strategic Overview” for a more detailed discussion of strategic plan developments.

March 2015 - The IUB approved IPL’s most recent Emissions Plan and Budget, which includes a scrubber that IPL placed in service at Lansing Unit 4 in June 2015 to reduce SO2 emissions at the EGU.

April 2015 - WPL filed a Certificate of Public Convenience and Necessity application with the PSCW for approval to construct an approximate 650 MW natural gas-fired combined-cycle EGU in Beloit, Wisconsin, referred to as the Riverside expansion. In November 2015, WPL filed testimony with the PSCW that included an updated cost estimate for the Riverside expansion. Capital expenditures, excluding AFUDC, are currently estimated to be approximately $680 million to $720 million to construct the EGU and a pipeline to supply natural gas to the EGU. A decision from the PSCW on WPL’s application is currently expected by May 2016.

April 2015 - IPL completed the sale of its Minnesota natural gas distribution assets and received proceeds of $11 million and a promissory note of $2 million. The proceeds were used for general corporate purposes.

July 2015 - IPL completed the sale of its Minnesota electric distribution assets and received proceeds of $127 million, which were used to reduce cash proceeds received from IPL’s sales of accounts receivable program. ~~Final proceeds are subject to post-closing adjustments based on the value of the net assets as of the closing date and are expected to be approximately $130 million.~~

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July 2015 - Alliant Energy announced plans to fuel switch Prairie Creek Unit 4 by December 31, 2017 and the Burlington Generating Station by December 31, 2021, and fuel switch or retire Prairie Creek Units 1 and 3 by December 31, 2025. Alliant Energy also ~~announced~~ plans to install an SCR system at Ottumwa Unit 1 by December 31, 2019 to reduce NOx emissions at the EGU. IPL’s portion of the capital expenditures, excluding AFUDC, for the SCR system is currently estimated to be between $75 million and $100 million.

Rate Matters Highlights

Federal regulation of wholesale electric rates is administered by FERC and state regulation of retail utility rates is administered by the IUB and PSCW. Key regulatory developments since the filing of the 2014 Form 10-K include the following. Refer to “Rate Matters” for a more detailed discussion of regulatory developments.

July 2015 - WPL filed a request with the PSCW to increase annual rates for WPL’s retail electric customers by $15 million, or approximately 1%, in 2016. The increase reflects anticipated increases in retail electric fuel-rated costs in 2016. Any rate changes granted from this request are expected to be effective on January 1, 2016.

July 2015 - WPL received an order from the PSCW authorizing an annual retail electric rate increase of $28 million, or approximately 3%, effective January 1, 2016 to recover 2014 Test Year deferred fuel-related costs.

Environmental Matters Highlights

Environmental matters are regulated by various federal, state and local authorities. Key environmental developments since the filing of the 2014 Form 10-K include the following. Refer to “Environmental Matters” for a more detailed discussion of environmental developments.

April 2015 - The EPA published the final CCR Rule, which regulates CCR as a non-hazardous waste and is effective October 2015. IPL and WPL have nine and three coal-fired EGUs, respectively, with coal ash ponds that are impacted by this rule. In addition, IPL and WPL have four and two active CCR landfills, respectively, that are impacted by this rule. InDuring the ~~second quarter of~~nine months ended September 30, 2015, Alliant Energy, IPL and WPL recognized additional AROs of $74 million, $57 million and $17 million, respectively, as a result of the final CCR Rule. Expenditures incurred by IPL and WPL to comply with the CCR Rule are anticipated to be recovered in rates from their customers.

July 2015 - IPL entered into a Consent Decree with the EPA, the Sierra Club, the State of Iowa and Linn County in Iowa to resolve potential claims regarding CAA issues associated with emissions from IPL’s coal-fired generating facilities in Iowa, while admitting no liability. ~~The~~In September 2015, the Consent Decree was ~~lodged with, and is subject to approval~~approved by the U.S. District Court for the Northern District of ~~Iowa.~~Iowa thereby resolving all potential claims against IPL.

~~August~~October 2015 - The EPA published a final revised Ozone NAAQS Rule, which is more stringent than the previous version of the rule and may require NOx emission reductions in certain non-attainment areas designated by the EPA. The EPA’s final designations of non-attainment areas for this revised rule are currently expected to be issued by October 2017. Compliance deadlines range from 2020 through 2037 depending on the level of NOx emissions in non-attainment areas.

October 2015 - The EPA published final standards under Section 111(d) of the CAA, which establish guidelines for states to follow in developing plans to reduce carbon dioxide emissions from existing fossil-fueled EGUs. The final standards include an interim compliance period from 2022 through 2029 and a final compliance ~~goal~~requirement beginning in 2030. ~~In August 2015, the~~The EPA also ~~issued~~published a proposed federal plan that would be implemented in states that do not ~~have~~complete a fully approved state plan.

~~August~~

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October 2015 - The EPA ~~issued~~published final standards under Section 111(b) of the CAA, which establish carbon dioxide emissions limits for certain new fossil-fueled EGUs. Marshalltown and WPL’s proposed Riverside expansion are expected to be impacted by these standards.

November 2015 - The EPA published final effluent limitation guidelines, which require changes to discharge limits for wastewater from steam generating facilities. Compliance with the final guidelines will be required after November 1, 2018 but before December 31, 2023, depending on each facility’s wastewater permit renewal cycle for existing steam generating facilities and immediately upon operation for new steam generating facilities constructed after the effective date of the final guidelines.

Liquidity and Capital Resources Highlights

Based on current liquidity positions and capital structures, the additional capital required to implement the strategic plan and to meet long-term contractual obligations is expected to be available. Key financing developments since the filing of the 2014 Form 10-K include the following. Refer to “Liquidity and Capital Resources” for a more detailed discussion of financing developments.

March 2015 - Alliant Energy filed a prospectus supplement under which it may sell up to $150 million of its common stock through an at-the-market offering program. As of ~~June~~September 30, 2015, Alliant Energy issued 2,186,617 shares of common stock through this program and received net cash proceeds of $133 million. Alliant Energy currently has no plans to issue any additional common stock through the at-the-market offering program.

June 2015 - IPL retired its $150 million, 3.3% senior debentures.

August 2015 - IPL issued $250 million of 3.4% senior debentures due 2025. The proceeds from the issuance were used by IPL to reduce commercial paper classified as long-term debt by $111 million, reduce cash proceeds received from its sales of accounts receivable program and for general corporate purposes.

August 2015 - Moody’s Investors Service changed each of Alliant Energy’s, IPL’s and WPL’s outlooks from stable to negative.

September 2015 - At ~~June~~September 30, 2015, Alliant Energy and its subsidiaries had ~~$768~~$891 million of available capacity under the revolving credit facilities, ~~$50~~$179 million of available capacity at IPL under its sales of accounts receivable program and ~~$55~~$139 million of cash and cash equivalents.

~~June~~November 2015 - Alliant Energy, IPL ~~retired~~and WPL announced their future financing plans. Alliant Energy currently expects to issue approximately $25 million of common stock in 2016 through its ~~$150.0~~Shareowner Direct Plan. IPL currently expects to issue up to $300 million ~~3.3% senior debentures.~~of long-term debt in 2016. Alliant Energy and Franklin County Holdings LLC currently anticipate refinancing $250 million and $60 million, respectively, of variable-rate term loan credit agreements in 2016.

November 2015 - Alliant Energy announced an increase in its targeted 2016 annual common stock dividend to $2.35 per share, which is equivalent to a quarterly rate of $0.5875 per share, beginning with the February 2016 dividend payment.

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Other Matters Highlights

Other key developments since the filing of the 2014 Form 10-K that could impact future financial condition or results of operations include the following. Refer to “Other Matters” for a more detailed discussion of potential impacts to future financial condition and results of operations.

March 2015 - FERC issued an order allowing ITC to implement a 50 basis point incentive adder to its return on equity for being an independent transmission company. The implementation of the adder will be retroactively applied back to April 2015 after resolution of a MISO transmission owner return on equity complaint filed in 2013 by a group of MISO industrial customer organizations. Alliant Energy and IPL are currently unable to determine any resulting changes to future electric transmission service charges pending a decision by FERC on the 2013 complaint.

STRATEGIC OVERVIEW

A strategic overview summary is included in the 2014 Form 10-K and has not changed materially from the items reported in the 2014 Form 10-K, except as described below.

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Generation Plans -

Natural Gas-Fired Generation -

WPL’s Proposed Construction of the Riverside Expansion - In April 2015, WPL filed a Certificate of Public Convenience and Necessity application with the PSCW for approval to construct an approximate 650 MW natural gas-fired combined-cycle EGU in Beloit, Wisconsin, referred to as the Riverside expansion. In November 2015, WPL filed testimony with the PSCW that included an updated cost estimate for the Riverside expansion. Capital expenditures, excluding AFUDC, are currently estimated to be approximately $680 million to $720 million to construct the EGU and a pipeline to supply natural gas to the EGU. Intervenors in the docket have challenged the Riverside expansion by raising questions about the project need and have offered alternatives. A decision from the PSCW on WPL’s application is currently expected by ~~mid-2016. Intervenors in the docket may attempt to challenge the Riverside expansion by raising questions over project need or alternatives, among other issues.~~May 2016. The Riverside expansion is also subject to the receipt of various approvals and permits necessary to construct and operate the EGU and connect such EGU to the transmission system.

Coal-Fired Generation -

Plant Retirements or Fuel Switching - IPL currently plans to fuel switch from coal to natural gas at, or retire, the following EGUs:



EGU (In-Service Year)	Nameplate Capacity	Expected Action
Prairie Creek Unit 4 (1967)	149 MW	Fuel switch by December 31, 2017
Burlington Generating Station (1968)	212 MW	Fuel switch by December 31, 2021
Prairie Creek Units 1 and 3 (1997 and 1958, respectively)	64 MW	Fuel switch or retire by December 31, 2025

In addition, IPL’s M.L. Kapp Unit 2 fuel type was switched from coal to natural gas in June 2015.

The above plans are consistent with IPL’s requirements specified in the Consent Decree, which is discussed in Note ~~13(c)~~13(e).

Electric and Gas Distribution Systems - An important aspect of the strategic plan focuses resources on providing safe and reliable electric and natural gas service to IPL’s and WPL’s customers. Investments are expected to be targeted in replacing, modernizing and upgrading aging infrastructure in the electric and gas distribution systems. These investments will make the electric distribution system more resilient, robust and flexible to be able to meet customers’ changing and growing needs. Investments are also expected in the gas distribution system to ensure the system is appropriately maintained and operated safely. In addition, investments are expected to be made to extend various gas transmission and distribution systems in IPL’s and WPL’s service territories to serve new customer demand. Estimated capital expenditures for these expected and current projects for 2015 through 2019 are included in the “Electric and gas distribution systems” lines in the construction and acquisition expenditures table in “Liquidity and Capital Resources.”

IPL’s Proposed Clinton Natural Gas Pipeline - In September 2015, IPL filed a petition with the IUB for a pipeline permit to construct, maintain, and operate a natural gas pipeline in Scott and Clinton Counties in Iowa, referred to as the Clinton pipeline. IPL currently expects to receive the IUB’s decision on its petition in the second quarter of 2016. Subject to such approval, construction is expected to be completed by December 31, 2016. Capital expenditures to construct the pipeline, excluding AFUDC, are currently estimated to be approximately $60 million to $70 million.

Utility Business Divestitures -

IPL’s Minnesota Electric and Natural Gas Distribution Assets - Refer to Note 3 for discussion of the sales of IPL’s Minnesota electric and natural gas distribution assets, which were completed in July 2015 and April 2015, respectively.

Environmental Compliance Plans - Environmental compliance plans have been developed to help ensure cost effective compliance with current and proposed environmental laws and regulations. The following table provides current estimates of the total (past and future) project costs for certain emission controls projects included in the current environmental compliance plans (in millions):



	Actual/Expected		Total
Generating Unit	In-service Date	Technology	Project Cost
IPL:
Lansing Unit 4	2015	Scrubber	$55
Ottumwa Unit 1	2018/2019	SCR	75-100
WPL:
Edgewater Unit 5	2016	Scrubber & Baghouse	260-280
Columbia Unit 2	2018	SCR	40-60

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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.

IPL’s Emission Controls Projects - In March 2015, the IUB approved IPL’s most recent Emissions Plan and Budget, which includes a scrubber that IPL placed in service at Lansing Unit 4 in June 2015 to reduce SO2 emissions at the EGU. IPL’s previous Emissions Plan and Budget also included the scrubber at Lansing Unit 4.

Ottumwa Unit 1 - IPL currently plans to install an SCR system at Ottumwa Unit 1 ~~by December 31, 2019~~ to reduce NOx emissions at the EGU. The SCR is expected to support compliance obligations for current and anticipated air quality requirements, including the Cross-State Air Pollution Rule, and requirements under IPL’s Consent Decree. IPL’s portion of the capital expenditures, excluding AFUDC, for the SCR system is currently estimated to be between $75 million and $100 million and was included in Alliant Energy’s and IPL’s estimated capital expenditures planned for 2015 to 2018.

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RATE MATTERS

A rate matters summary is included in the 2014 Form 10-K and has not changed materially from the items reported in the 2014 Form 10-K, except as described below.

WPL’s Retail Fuel-related Rate Filings -

~~2016 Test Year -~~Refer to Note 2 for discussion of WPL’s ~~July 2015 request filed with~~retail fuel-related rate filings for the ~~PSCW to increase annual rates for WPL’s retail electric customers for anticipated increases in retail electric fuel-related costs in~~Test Years 2014 though 2016.

~~2014~~Planned Utility Rate Cases -

WPL’s Wisconsin Retail Electric and Gas Rate Case (2017/2018 Test ~~Year~~Period) - ~~Refer~~WPL currently expects to ~~Note 2~~ ~~for discussion of amounts recorded~~make a retail electric and gas rate filing by ~~Alliant Energy and WPL on their balance sheets as of~~ June 30, ~~2015~~2016 based on a forward-looking test period that may include calendar years 2017 and 2018. The key drivers for ~~fuel-related costs incurred~~the anticipated filing include recovery of the SCR project at Columbia Unit 2, return on construction work in progress capital expenditures for the proposed Riverside expansion and other capital projects. Any rate changes granted are expected to be effective in January 2017.

IPL’s Iowa Retail Electric and Gas Rate Cases (2016 Test Year) - IPL currently expects to make separate retail electric and gas rate filings in the second quarter of 2017 based on a 2016 historical test year. The key drivers for the anticipated filings include recovery of capital projects, including Marshalltown for the electric filing and the proposed Clinton natural gas pipeline for the gas filing. Any rate changes are expected to be implemented in two phases with interim rates effective approximately 10 days after the filing and final rates effective approximately 10 months after the filing date.

Planned Retirement of WPL’s Nelson Dewey Units 1 and 2 and Edgewater Unit 3 - WPL previously announced plans to retire Nelson Dewey Units 1 and 2 and Edgewater Unit 3 by December 31, 2015. WPL ~~in 2014 that were outside~~is currently recovering the ~~approved bandwidth, as well as an order received~~remaining net book value of these EGUs from both its retail and wholesale customers over a 10-year period beginning January 1, 2013 pursuant to orders previously issued by the PSCW and FERC. In October 2015, WPL filed a request with FERC to continue recovery of the wholesale portion of the remaining net book value of these EGUs over the same 10-year recovery period subsequent to the retirement of such EGUs. A decision is currently expected from FERC by December 31, 2015. Continued recovery of the retail portion of the remaining net book value of these EGUs is expected to be addressed in ~~July 2015 authorizing WPL to recover such costs from its~~WPL’s next retail electric ~~customers beginning in 2016.~~base rate case.

ENVIRONMENTAL MATTERS

An environmental matters summary is included in the 2014 Form 10-K and has not changed materially from the items reported in the 2014 Form 10-K, except as described below.

Air Quality -

Ozone NAAQS Rule - In October 2015, the EPA published a final revised Ozone NAAQS Rule, which is more stringent than the previous version of the rule and may require NOx emission reductions in certain non-attainment areas designated by the EPA. The EPA’s final designations of non-attainment areas for this revised rule are currently expected to be issued by October 2017. Compliance deadlines range from 2020 through 2037 depending on the level of NOx emissions in non-attainment areas. Depending on the level and location of non-attainment areas, Alliant Energy, IPL and WPL may be subject to additional NOx emissions reduction requirements to meet the revised ozone NAAQS rule. However, Alliant Energy, IPL and WPL do not currently believe there will be a significant impact on their financial condition and results of operations.

Table of Contents

Greenhouse Gases Emissions -

Clean Air Act Section 111(d) - In ~~August~~October 2015, the EPA ~~issued~~published final standards under Section 111(d) of the CAA, which establish guidelines for states to follow in developing plans to reduce carbon dioxide emissions from existing fossil-fueled EGUs. The final standards include an interim compliance period from 2022 through 2029 and a final compliance ~~goal~~requirement beginning in 2030. ~~In August 2015, the~~The EPA also ~~issued~~published a proposed federal plan that would be implemented in states that do not ~~have~~complete a fully approved state plan. Given Alliant Energy, IPL and WPL are currently reviewing the final standards and proposed federal plan, and the EPA’s rulemaking remains subject to legal challenges, Alliant Energy, IPL and WPL are currently unable to predict with certainty the impact of these standards, but expect that expenditures to comply with these standards could be significant.

IPL Consent Decree - Refer to Note ~~13(c)~~13(e) for discussion of a Consent Decree ~~that IPL entered into with the EPA, the Sierra Club, the State of Iowa and Linn County in Iowa in July 2015 and IPL’s obligations thereunder. If~~ approved by the U.S. District Court for the Northern District of Iowa ~~the~~in September 2015 and IPL’s obligations thereunder. The Consent Decree ~~will resolve~~resolves discussions regarding CAA issues associated with emissions from IPL’s coal-fired generating facilities in Iowa.

Water Quality -

Effluent Limitation Guidelines - In November 2015, the EPA published final effluent limitation guidelines, which require changes to discharge limits for wastewater from steam generating facilities. IPL and WPL have identified ten (Emery Units 1-3, Ottumwa Unit 1, Prairie Creek Units 3-4, Fox Lake Units 1 and 3, Lansing Unit 4, Dubuque Units 3-4, Burlington Unit 1, Sutherland Units 1 and 3, George Neal Units 3-4 and Louisa Unit 1) and four (Riverside Units 1-3, Columbia Units 1-2, Nelson Dewey Units 1-2 and Edgewater Units 3-5) existing steam generating facilities, respectively, that are expected to be impacted by these guidelines. In addition, Marshalltown and WPL’s proposed Riverside expansion are expected to be impacted by these guidelines. Compliance with the final guidelines will be required after November 1, 2018 but before December 31, 2023, depending on each facility’s wastewater permit renewal cycle for existing steam generating facilities and immediately upon operation for new steam generating facilities constructed after the effective date of the final guidelines. Alliant Energy, IPL and WPL are currently unable to predict with certainty the impact of these guidelines on their financial condition and results of operations, but believe the expenditures to comply with these guidelines could be significant.

Land and Solid Waste -

Coal Combustion Residuals Rule - Refer to Note 10 for discussion of the final CCR Rule, including additional AROs that were recognized by Alliant Energy, IPL and WPL induring the ~~second quarter of~~nine months ended September 30, 2015 related to such rule.

LEGISLATIVE MATTERS

A legislative matters summary is included in the 2014 Form 10-K and has not changed materially from the items reported in the 2014 Form 10-K.

RESULTS OF OPERATIONS

Overview - ~~Second~~Third Quarter Results -

Alliant Energy - “Executive Summary” provides an overview of Alliant Energy’s ~~second~~third quarter 2015 and 2014 earnings and the various components of its business. Additional details of Alliant Energy’s earnings for the three months ended ~~June~~September 30, 2015 and 2014 are discussed below.

~~Table of Contents~~

IPL - Earnings available for common stock ~~decreased $2~~increased $15 million primarily due to losses recorded in the second quarter of 2015 related to IPL’s sales of its Minnesota electric and natural gas distribution assets and higher depreciation expense in the second quarter of 2015. These items were substantially offset by lower retail electric customer billing credits in the ~~second~~third quarter of 2015 compared to the ~~second~~third quarter of ~~2014.~~2014 and higher electric sales.

WPL - Earnings available for common stock increased $4$6 million primarily due to lower energy efficiency cost recovery amortizations during the ~~second~~third quarter of ~~2015. This item was~~2015 and higher electric sales. These items were partially offset by higher electric transmission service expense in the ~~second~~third quarter of 2015.

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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.

~~Second~~Third Quarter 2015 vs. ~~Second~~Third Quarter 2014 Summary - Electric margins and MWh sales for the three months ended ~~June~~September 30 were as follows:


Alliant Energy	Revenues and Costs (dollars in millions)						MWhs Sold (MWhs in thousands)				Revenues and Costs (dollars in millions)						MWhs Sold (MWhs in thousands)
	2015		2014		Change		2015	2014	Change		2015		2014		Change		2015	2014	Change
Residential(a)		$215.2		$221.5	(3	%)	1,580	1,661	(5	%)		$303.2		$279.8	8	%	2,047	1,945	5	%
Commercial(a)	157.4		156.0		1	%	1,526	1,523	—	%	200.3		188.9		6	%	1,694	1,643	3	%
Industrial(a)	203.2		200.3		1	%	2,966	2,958	—	%	243.9		233.1		5	%	3,091	3,098	—	%
Retail subtotal(a)	575.8		577.8		—	%	6,072	6,142	(1	%)	747.4		701.8		6	%	6,832	6,686	2	%
Sales for resale:
Wholesale(a)	46.9		51.5		(9	%)	771	852	(10	%)	66.6		53.5		24	%	1,028	921	12	%
Bulk power and other	6.5		2.3		183	%	255	106	141	%	9.5		2.4		296	%	378	80	373	%
Other	11.2		12.3		(9	%)	37	36	3	%	12.3		13.5		(9	%)	28	34	(18	%)
Total revenues/sales	640.4		643.9		(1	%)	7,135	7,136	—	%	835.8		771.2		8	%	8,266	7,721	7	%
Electric production fuel expense	83.8		100.7		(17	%)					155.7		119.4		30	%
Energy purchases expense	100.9		113.4		(11	%)					89.6		111.3		(19	%)
Purchased electric capacity expense	0.5		—		100	%					0.5		0.1		400	%
Electric margins ~~(a)~~(b)		$455.2		$429.8	6	%						$590.0		$540.4	9	%


IPL	Revenues and Costs (dollars in millions)						MWhs Sold (MWhs in thousands)				Revenues and Costs (dollars in millions)						MWhs Sold (MWhs in thousands)
	2015		2014		Change		2015	2014	Change		2015		2014		Change		2015	2014	Change
Residential(a)		$118.0		$122.8	(4	%)	843	876	(4	%)		$173.7		$162.9	7	%	1,081	1,055	2	%
Commercial(a)	95.9		97.3		(1	%)	971	966	1	%	126.5		119.7		6	%	1,053	1,027	3	%
Industrial(a)	109.9		116.5		(6	%)	1,776	1,794	(1	%)	138.2		135.9		2	%	1,782	1,846	(3	%)
Retail subtotal(a)	323.8		336.6		(4	%)	3,590	3,636	(1	%)	438.4		418.5		5	%	3,916	3,928	—	%
Sales for resale:
Wholesale(a)	7.6		8.7		(13	%)	115	120	(4	%)	20.4		8.3		146	%	275	124	122	%
Bulk power and other	0.4		0.8		(50	%)	11	9	22	%	1.1		0.1		1,000	%	28	23	22	%
Other	7.6		8.5		(11	%)	21	19	11	%	8.7		9.0		(3	%)	14	21	(33	%)
Total revenues/sales	339.4		354.6		(4	%)	3,737	3,784	(1	%)	468.6		435.9		8	%	4,233	4,096	3	%
Electric production fuel expense	27.1		47.4		(43	%)					72.0		67.7		6	%
Energy purchases expense	63.3		75.5		(16	%)					59.3		64.4		(8	%)
Purchased electric capacity expense	0.1		—		100	%					0.1		0.1		—	%
Electric margins ~~(a)~~(b)		$248.9		$231.7	7	%						$337.2		$303.7	11	%

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WPL	Revenues and Costs (dollars in millions)						MWhs Sold (MWhs in thousands)				Revenues and Costs (dollars in millions)						MWhs Sold (MWhs in thousands)
	2015		2014		Change		2015	2014	Change		2015		2014		Change		2015	2014	Change
Residential		$97.2		$98.7	(2	%)	737	785	(6	%)		$129.5		$116.9	11	%	966	890	9	%
Commercial	61.5		58.7		5	%	555	557	—	%	73.8		69.2		7	%	641	616	4	%
Industrial	93.3		83.8		11	%	1,190	1,164	2	%	105.7		97.2		9	%	1,309	1,252	5	%
Retail subtotal	252.0		241.2		4	%	2,482	2,506	(1	%)	309.0		283.3		9	%	2,916	2,758	6	%
Sales for resale:
Wholesale	39.3		42.8		(8	%)	656	732	(10	%)	46.2		45.2		2	%	753	797	(6	%)
Bulk power and other	6.1		1.5		307	%	244	97	152	%	8.4		2.3		265	%	350	57	514	%
Other	3.6		3.8		(5	%)	16	17	(6	%)	3.6		4.5		(20	%)	14	13	8	%
Total revenues/sales	301.0		289.3		4	%	3,398	3,352	1	%	367.2		335.3		10	%	4,033	3,625	11	%
Electric production fuel expense	56.7		53.3		6	%					83.7		51.7		62	%
Energy purchases expense	37.6		37.9		(1	%)					30.3		46.9		(35	%)
Purchased electric capacity expense	0.4		—		100	%					0.4		—		100	%
Electric margins		$206.3		$198.1	4	%						$252.8		$236.7	7	%


(a)	In July 2015, IPL sold its electric distribution assets in Minnesota. Prior to the asset sale, the electric sales to retail customers are included in residential, commercial and industrial sales. Subsequent to the asset sale, the related electric sales are included in wholesale electric sales pursuant to the wholesale power supply agreement between IPL and Southern Minnesota Energy Cooperative.


(b)	Includes ~~$17~~$20 million and ~~$19~~$22 million of credits on IPL’s Iowa retail electric customers’ bills for the ~~second~~third quarters of 2015 and 2014, respectively, resulting from the electric tax benefit rider. The electric tax benefit rider results in reductions in electric revenues that are offset by reductions in income tax expense for the years ended December 31, 2015 and 2014.

~~Six~~Nine Months Ended ~~June~~September 30, 2015 vs. ~~Six~~Nine Months Ended ~~June~~September 30, 2014 Summary - Electric margins and MWh sales for the ~~six~~nine months ended ~~June~~September 30 were as follows:


Alliant Energy	Revenues and Costs (dollars in millions)							MWhs Sold (MWhs in thousands)				Revenues and Costs (dollars in millions)						MWhs Sold (MWhs in thousands)
	2015		2014			Change		2015	2014	Change		2015		2014		Change		2015	2014	Change
Residential(a)		$472.5		$489.7		(4	%)	3,632	3,885	(7	%)		$775.7		$769.5	1	%	5,679	5,830	(3	%)
Commercial(a)	312.6		317.0			(1	%)	3,122	3,177	(2	%)	512.9		505.9		1	%	4,816	4,820	—	%
Industrial(a)	390.4		385.6			1	%	5,826	5,782	1	%	634.3		618.7		3	%	8,917	8,880	—	%
Retail subtotal(a)	1,175.5		1,192.3			(1	%)	12,580	12,844	(2	%)	1,922.9		1,894.1		2	%	19,412	19,530	(1	%)
Sales for resale:
Wholesale(a)	98.9		105.0			(6	%)	1,635	1,788	(9	%)	165.5		158.5		4	%	2,663	2,709	(2	%)
Bulk power and other	14.7		(1.8		)	917	%	673	196	243	%	24.2		0.6		3,933	%	1,051	276	281	%
Other	22.6		24.2			(7	%)	74	78	(5	%)	34.9		37.7		(7	%)	102	112	(9	%)
Total revenues/sales	1,311.7		1,319.7			(1	%)	14,962	14,906	—	%	2,147.5		2,090.9		3	%	23,228	22,627	3	%
Electric production fuel expense	220.6		229.8			(4	%)					376.3		349.2		8	%
Energy purchases expense	179.8		198.2			(9	%)					269.4		309.5		(13	%)
Purchased electric capacity expense	0.7		24.8			(97	%)					1.2		24.9		(95	%)
Electric margins ~~(a)~~(b)		$910.6		$866.9		5	%						$1,500.6		$1,407.3	7	%

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IPL	Revenues and Costs (dollars in millions)						MWhs Sold (MWhs in thousands)				Revenues and Costs (dollars in millions)						MWhs Sold (MWhs in thousands)
	2015		2014		Change		2015	2014	Change		2015		2014		Change		2015	2014	Change
Residential(a)		$261.1		$273.3	(4	%)	1,974	2,110	(6	%)		$434.8		$436.2	—	%	3,055	3,165	(3	%)
Commercial(a)	192.4		197.3		(2	%)	1,990	2,012	(1	%)	318.9		317.0		1	%	3,043	3,039	—	%
Industrial(a)	214.9		224.1		(4	%)	3,509	3,504	—	%	353.1		360.0		(2	%)	5,291	5,350	(1	%)
Retail subtotal(a)	668.4		694.7		(4	%)	7,473	7,626	(2	%)	1,106.8		1,113.2		(1	%)	11,389	11,554	(1	%)
Sales for resale:
Wholesale(a)	15.2		16.4		(7	%)	234	241	(3	%)	35.6		24.7		44	%	509	365	39	%
Bulk power and other	2.9		1.0		190	%	135	14	864	%	4.0		1.1		264	%	163	37	341	%
Other	15.5		16.7		(7	%)	40	41	(2	%)	24.2		25.7		(6	%)	54	62	(13	%)
Total revenues/sales	702.0		728.8		(4	%)	7,882	7,922	(1	%)	1,170.6		1,164.7		1	%	12,115	12,018	1	%
Electric production fuel expense	90.6		113.6		(20	%)					162.6		181.3		(10	%)
Energy purchases expense	109.9		124.5		(12	%)					169.2		188.9		(10	%)
Purchased electric capacity expense	0.1		24.8		(100	%)					0.2		24.9		(99	%)
Electric margins ~~(a)~~(b)		$501.4		$465.9	8	%						$838.6		$769.6	9	%


WPL	Revenues and Costs (dollars in millions)							MWhs Sold (MWhs in thousands)				Revenues and Costs (dollars in millions)							MWhs Sold (MWhs in thousands)
	2015		2014			Change		2015	2014	Change		2015		2014			Change		2015	2014	Change
Residential		$211.4		$216.4		(2	%)	1,658	1,775	(7	%)		$340.9		$333.3		2	%	2,624	2,665	(2	%)
Commercial	120.2		119.7			—	%	1,132	1,165	(3	%)	194.0		188.9			3	%	1,773	1,781	—	%
Industrial	175.5		161.5			9	%	2,317	2,278	2	%	281.2		258.7			9	%	3,626	3,530	3	%
Retail subtotal	507.1		497.6			2	%	5,107	5,218	(2	%)	816.1		780.9			5	%	8,023	7,976	1	%
Sales for resale:
Wholesale	83.7		88.6			(6	%)	1,401	1,547	(9	%)	129.9		133.8			(3	%)	2,154	2,344	(8	%)
Bulk power and other	11.8		(2.8		)	521	%	538	182	196	%	20.2		(0.5		)	4,140	%	888	239	272	%
Other	7.1		7.5			(5	%)	34	37	(8	%)	10.7		12.0			(11	%)	48	50	(4	%)
Total revenues/sales	609.7		590.9			3	%	7,080	6,984	1	%	976.9		926.2			5	%	11,113	10,609	5	%
Electric production fuel expense	130.0		116.2			12	%					213.7		167.9			27	%
Energy purchases expense	69.9		73.7			(5	%)					100.2		120.6			(17	%)
Purchased electric capacity expense	0.6		—			100	%					1.0		—			100	%
Electric margins		$409.2		$401.0		2	%						$662.0		$637.7		4	%


(a)	In July 2015, IPL sold its electric distribution assets in Minnesota. Prior to the asset sale, the electric sales to retail customers are included in residential, commercial and industrial sales. Subsequent to the asset sale, the related electric sales are included in wholesale electric sales pursuant to the wholesale power supply agreement between IPL and Southern Minnesota Energy Cooperative.

(b)

Includes ~~$35~~$55 million and ~~$42~~$64 million of credits on Iowa retail electric customers’ bills for the ~~six~~nine months ended ~~June~~September 30, 2015 and 2014, respectively, resulting from IPL’s electric tax benefit rider. The electric tax benefit rider results in reductions in electric revenues that are offset by reductions in income tax expense for the years ended December 31, 2015 and 2014.

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Variances - Variances between periods in electric margins for the three and ~~six~~nine months ended ~~June~~September 30, 2015 compared to the same periods in 2014 were as follows (in millions):

Three Months Six Months
Alliant Energy IPL WPL Alliant Energy IPL WPL
Purchased electric capacity expense at IPL in 2014 (a)
$—

$—

$—

$25

$25

$—
Changes in electric fuel-related costs, net of recoveries at WPL 3
—
3
10
—
10
Retail electric customer billing credits at IPL (b) 14
14
—
8
8
—
Higher revenues at IPL due to changes in credits on Iowa retail electric customers’ bills resulting from the electric tax benefit rider (c) 2
2
—
7
7
—
Earnings deferral for excess return on equity at WPL in 2014 3
—
3
3
—
3
Estimated changes in sales caused by temperatures (9 ) (4 ) (5 ) (17 ) (9 ) (8 )
Other (d) 12
5
7
8
5
3

$25

$17

$8

$44

$36

$8



	Three Months						Nine Months
	Alliant Energy		IPL		WPL		Alliant Energy			IPL			WPL
Retail electric customer billing credits at IPL (a)		$19		$19		$—		$27			$27			$—
Purchased electric capacity expense at IPL in 2014 (b)	—		—		—		25			25			—
Changes in electric fuel-related costs, net of recoveries at WPL	2		—		2		12			—			12
Higher revenues at IPL due to changes in credits on Iowa retail electric customers’ bills resulting from the electric tax benefit rider (Refer to Note 2 for further details)	2		2		—		9			9			—
Higher revenues at WPL from the impact of increased sales volumes approved in its retail electric base rate case for 2015 (c)	2		—		2		6			—			6
Higher revenues at IPL related to changes in recovery amounts for transmission costs through the transmission rider (d)	4		4		—		5			5			—
Estimated changes in sales caused by temperatures	10		5		5		(7		)	(4		)	(3		)
Other (e)	11		4		7		16			7			9
		$50		$34		$16		$93			$69			$24


(a)	Refer to Note 2 for further discussion of billing credits that began in May 2014 related to the approved settlement agreement for IPL’s Iowa retail electric rates.


(b)	IPL’s previous DAEC PPA that expired in February 2014 included minimum payments for IPL’s rights to electric generating capacity. IPL’s new DAEC PPA effective February 2014 does not contain minimum payments for electric generating capacity.

~~(b)~~(c)

~~Refer to~~ ~~Note 2~~The PSCW order received for ~~further discussion~~WPL’s retail fuel-related rate filing (2015 Test Year) contained an increase in retail electric fuel-related revenues in 2015. A portion of ~~billing credits that began in May 2014 related~~the approved increase was attributable to the impact of increased sales volumes approved ~~settlement agreement for IPL’s Iowa~~in WPL’s retail electric ~~rates.~~


~~(c)~~	~~Refer to~~ ~~Note 2~~base rate case for ~~further discussion of IPL’s~~2015 resulting in higher electric ~~tax benefit rider.~~ margin in 2015.


(d)	Higher transmission rider revenues were offset by higher electric transmission service expense.


(e)	Includes increases in temperature-normalized retail sales volumes at IPL and WPL for the ~~three-month period. For the six-month period, temperature-normalized retail sales volumes at IPL~~three- and ~~WPL were relatively unchanged.~~nine-month periods. Refer to “Sales Trends” below for further details.

Forecast - Refer to Note 2 for discussion of WPL’s retail fuel-related rate cases for 2014 through 2016. IPL currently expects to reduce the amount of billing credits on its Iowa retail electric customers’ bills in 2016 compared to 2015 related to the approved settlement agreement for IPL’s Iowa retail electric rates.

Temperatures - As measured by CDD in Alliant Energy’s service territories, temperatures during the second quarter of 2015 were approximately 10% cooler than normal. Temperatures during the second quarter of 2014 were 20-30% warmer than normal. The cooler temperatures during the second quarter of 2015 compared to the second quarter of 2014 caused a decrease in IPL’s and WPL’s electric sales for the three and six months ended June 30, 2015 due to lower demand by customers for air cooling. As measured by HDD in Alliant Energy’s service territories, temperatures during the first quarter of 2015 were approximately 10% colder than normal. Temperatures during the first quarter of 2014 were 20-25% colder than normal. The warmer temperatures during the first quarter of 2015 compared to the first quarter of 2014 caused a decrease in IPL’s and WPL’s electric and gas sales for the six months ended June 30, 2015 due to lower demand by customers for heating. HDD and CDD in Alliant Energy’s service territories for the three and ~~six~~nine months ended ~~June~~September 30 were as follows:


	Three Months			Six Months			Three Months			Nine Months
	Actual			Actual			Actual			Actual
	2015	2014	Normal	2015	2014	Normal	2015	2014	Normal	2015	2014	Normal
HDD (a):
Cedar Rapids, Iowa (IPL)	582	711	701	4,272	4,903	4,118	83	160	140	4,355	5,063	4,258
Madison, Wisconsin (WPL)	721	797	833	4,555	5,072	4,339	98	183	173	4,653	5,255	4,512
CDD (a):
Cedar Rapids, Iowa (IPL)	200	263	219	200	263	221	530	407	535	730	670	756
Madison, Wisconsin (WPL)	161	233	180	161	233	182	503	387	474	664	620	656


(a)	HDD and 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 HDD and CDD.

Table of Contents

The following table summarizes the quarterly temperature statistics and resulting impacts on IPL’s and WPL’s electric and gas sales.



	2015	2014	Resulting Impact in 2015 Compared to 2014
First quarter (HDD)	10% colder than normal	20%-25% colder than normal	Decrease in IPL’s and WPL’s electric and gas sales due to lower demand by customers for heating
Second quarter (CDD)	10% colder than normal	20%-30% warmer than normal	Decrease in IPL’s and WPL’s electric sales due to lower demand by customers for air cooling
Third quarter (CDD)	Normal	20% colder than normal	Increase in IPL’s and WPL’s electric sales due to higher demand by customers for air cooling

Estimated increases (decreases) to electric margins from the impacts of temperatures for the three and ~~six~~nine months ended ~~June~~September 30 were as follows (in millions):


	Three Months								Six Months							Three Months								Nine Months
	2015			2014		Change			2015		2014		Change			2015			2014			Change		2015			2014		Change
IPL		($2	)		$2		($4	)		$—		$9		($9	)		($2	)		($7	)		$5		($2	)		$2		($4	)
WPL	(2		)	3		(5		)	1		9		(8		)	1			(4		)	5		2			5		(3		)
Total Alliant Energy		($4	)		$5		($9	)		$1		$18		($17	)		($1	)		($11	)		$10		$—			$7		($7	)

~~Table of Contents~~

Sales Trends - Alliant Energy’s retail sales volumes increased 2% and decreased 1% ~~and 2%~~ for the three and ~~six~~nine months ended ~~June~~September 30, 2015 compared to the same periods in 2014, respectively. ~~These decreases were~~The three-month increase was primarily due to the impact of temperatures on residential and commercial sales due to the ~~warmer~~colder than normal temperatures ~~during~~and resulting lower air cooling demand in the ~~second~~third quarter of ~~2014~~2014. The nine-month decrease was primarily due to the impact of temperatures on residential and commercial sales due to the extremely cold temperatures and resulting higher heating demand during the first quarter of 2014, partially offset by the warmer temperatures in the third quarter of 2015 compared to the same period in 2014.

IPL’s industrial sales volumes decreased 3% and 1% for the three and nine months ended September 30, 2015 compared to the same periods in 2014, respectively, primarily due to lower usage by industrial customers that have their own generation. WPL’s industrial sales volumes increased 5% and 3% for the three and nine months ended September 30, 2015 compared to the same periods in 2014, respectively, primarily due to industrial customer expansions.

Alliant Energy’s wholesale sales volumes increased 12% and decreased ~~10% and 9%~~2% for the three and ~~six~~nine months ended ~~June~~September 30, 2015 compared to the same periods in 2014, respectively. The ~~three-~~three-month increase was primarily due to a new wholesale power supply agreement between IPL and ~~six-month decreases were~~Southern Minnesota Energy Cooperative. The new wholesale power supply agreement became effective in July 2015 following the sale of IPL’s Minnesota electric distribution assets. The nine-month decrease was primarily due to decreased 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, and the impact of ~~unseasonably~~the extremely cold temperatures during the first quarter of 2014. These decreases were partially offset by additional sales from IPL’s new wholesale power supply agreement with Southern Minnesota Energy Cooperative.

Alliant Energy’s bulk power and other revenue changes were largely due to changes in sales in the wholesale energy markets operated by MISO and PJM. These changes are impacted by several factors including the availability and dispatch of Alliant Energy’s EGUs 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.

Forecast - Alliant Energy, IPL and WPL are currently expecting a modest increase in temperature-normalized retail electric sales in 2016 compared to 2015.

Table of Contents

Electric Production Fuel and Energy Purchases (Fuel-related) Cost Recoveries - Fossil fuels, such as coal and natural gas, are burned to produce electricity at EGUs. The cost of fossil fuels used during each period is included in electric production fuel expense. Electricity is also purchased to meet customer demand and these costs are charged to energy purchases expense.

Due to IPL’s cost 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 and IPL’s electric margins. WPL’s cost 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 and WPL’s electric margins.

WPL’s cost recovery mechanism for retail fuel-related costs supports deferrals of amounts that fall outside an approved bandwidth of plus or minus 2% of forecasted fuel-related costs determined by the PSCW each year. The difference between revenue collected and actual fuel-related costs incurred within the bandwidth increases or decreases Alliant Energy’s and WPL’s electric margins. WPL estimates the increase to electric margins from amounts within the bandwidth were approximately $3$2 million and $4$6 million for the three and ~~six~~nine months ended ~~June~~September 30, 2015, respectively. WPL estimates the decrease to electric margins from amounts within the bandwidth were approximately $0 and $6 million for the three and ~~six~~nine months ended ~~June~~September 30, 2014, respectively. Refer to Note 2 for discussion of an order received from the PSCW in July 2015 authorizing WPL to recover $28 million, including interest, from its retail electric customers beginning in 2016 for deferred fuel-related costs incurred in 2014.

Alliant Energy’s electric production fuel expense ~~decreased $17~~increased $36 million and $9$27 million for the three and ~~six~~nine months ended ~~June~~September 30, 2015, respectively. The ~~decreases for the three- and six-month periods~~increases were primarily due to ~~changes in the under-/over-collection of fuel-related costs at IPL partially offset by~~ deferrals recorded during the three and ~~six~~nine months ended ~~June~~September 30, 2014 for fuel-related costs that were outside the approved bandwidth at ~~WPL.~~WPL, and higher dispatch of WPL’s coal-fired EGUs during the third quarter of 2015. The nine-month increase was partially offset by changes in the under-/over-collection of fuel-related costs at IPL.

Alliant Energy’s energy purchases expense decreased ~~$13~~$22 million and ~~$18~~$40 million for the three and ~~six~~nine months ended ~~June~~September 30, 2015, respectively, primarily due to lower prices for electricity purchased by IPL and WPL from wholesale energy markets (primarily MISO) during the three- and ~~six-month periods.~~nine-month periods and decreased volumes purchased. The decreased volumes purchased were due to higher dispatch of WPL’s coal-fired EGUs during the third quarter of 2015 and lower retail and wholesale electric sales during the nine-month period.

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.

~~Table of Contents~~

~~Second~~Third Quarter 2015 vs. ~~Second~~Third Quarter 2014 Summary - Gas margins and Dth sales for the three months ended ~~June~~September 30 were as follows:


Alliant Energy	Revenues and Costs (dollars in millions)						Dths Sold (Dths in thousands)				Revenues and Costs (dollars in millions)						Dths Sold (Dths in thousands)
	2015		2014		Change		2015	2014	Change		2015		2014		Change		2015	2014	Change
Residential		$27.6		$41.0	(33	%)	3,285	4,060	(19	%)		$17.6		$21.7	(19	%)	1,204	1,452	(17	%)
Commercial	15.0		24.6		(39	%)	2,695	3,137	(14	%)	11.0		15.0		(27	%)	1,616	1,746	(7	%)
Industrial	2.1		4.4		(52	%)	528	634	(17	%)	2.4		3.9		(38	%)	541	620	(13	%)
Retail subtotal	44.7		70.0		(36	%)	6,508	7,831	(17	%)	31.0		40.6		(24	%)	3,361	3,818	(12	%)
Transportation/other	7.0		6.9		1	%	15,854	13,583	17	%	7.0		6.6		6	%	18,772	14,910	26	%
Total revenues/sales	51.7		76.9		(33	%)	22,362	21,414	4	%	38.0		47.2		(19	%)	22,133	18,728	18	%
Cost of gas sold	21.9		45.0		(51	%)					13.6		21.8		(38	%)
Gas margins (a)		$29.8		$31.9	(7	%)						$24.4		$25.4	(4	%)

Table of Contents



IPL	Revenues and Costs (dollars in millions)						Dths Sold (Dths in thousands)
	2015		2014		Change		2015	2014	Change
Residential		$10.3		$12.8	(20	%)	638	824	(23	%)
Commercial	6.8		8.9		(24	%)	854	952	(10	%)
Industrial	2.0		3.3		(39	%)	442	518	(15	%)
Retail subtotal	19.1		25.0		(24	%)	1,934	2,294	(16	%)
Transportation/other	4.0		3.7		8	%	7,819	7,062	11	%
Total revenues/sales	23.1		28.7		(20	%)	9,753	9,356	4	%
Cost of gas sold	9.4		14.6		(36	%)
Gas margins (a)		$13.7		$14.1	(3	%)

IPL Revenues and Costs (dollars in millions) Dths Sold (Dths in thousands)
2015 2014 Change 2015 2014 Change
Residential
$15.5

$22.9
(32 %) 1,681
2,233
(25 %)
Commercial 8.2
13.3
(38 %) 1,333
1,607
(17 %)
Industrial 1.7
3.3
(48 %) 419
493
(15 %)
Retail subtotal 25.4
39.5
(36 %) 3,433
4,333
(21 %)
Transportation/other 4.4
4.2
5 % 8,126
7,097
14 %
Total revenues/sales 29.8
43.7
(32 %) 11,559
11,430
1 %
Cost of gas sold 13.0
25.7
(49 %)
Gas margins (a)
$16.8

$18.0
(7 %)


WPL	Revenues and Costs (dollars in millions)						Dths Sold (Dths in thousands)				Revenues and Costs (dollars in millions)						Dths Sold (Dths in thousands)
	2015		2014		Change		2015	2014	Change		2015		2014		Change		2015	2014	Change
Residential		$12.1		$18.1	(33	%)	1,604	1,827	(12	%)		$7.3		$8.9	(18	%)	566	628	(10	%)
Commercial	6.8		11.3		(40	%)	1,362	1,530	(11	%)	4.2		6.1		(31	%)	762	794	(4	%)
Industrial	0.4		1.1		(64	%)	109	141	(23	%)	0.4		0.6		(33	%)	99	102	(3	%)
Retail subtotal	19.3		30.5		(37	%)	3,075	3,498	(12	%)	11.9		15.6		(24	%)	1,427	1,524	(6	%)
Transportation/other	2.6		2.7		(4	%)	7,728	6,486	19	%	3.0		2.9		3	%	10,953	7,848	40	%
Total revenues/sales	21.9		33.2		(34	%)	10,803	9,984	8	%	14.9		18.5		(19	%)	12,380	9,372	32	%
Cost of gas sold	8.9		19.3		(54	%)					4.2		7.2		(42	%)
Gas margins		$13.0		$13.9	(6	%)						$10.7		$11.3	(5	%)


(a)	Includes $3 million of credits on IPL’s Iowa retail gas customers’ bills for both the ~~second~~third quarters of 2015 and 2014 resulting from the gas tax benefit rider. The gas tax benefit rider results in reductions in gas revenues that are offset by reductions in income tax expense for the years ended December 31, 2015 and 2014.

~~Six~~Nine Months Ended ~~June~~September 30, 2015 vs. ~~Six~~Nine Months Ended ~~June~~September 30, 2014 - Gas margins and Dth sales for the ~~six~~nine months ended ~~June~~September 30 were as follows:


Alliant Energy	Revenues and Costs (dollars in millions)						Dths Sold (Dths in thousands)				Revenues and Costs (dollars in millions)						Dths Sold (Dths in thousands)
	2015		2014		Change		2015	2014	Change		2015		2014		Change		2015	2014	Change
Residential		$144.5		$185.0	(22	%)	18,271	20,895	(13	%)		$162.1		$206.7	(22	%)	19,475	22,347	(13	%)
Commercial	80.3		102.8		(22	%)	12,263	13,712	(11	%)	91.3		117.8		(22	%)	13,879	15,458	(10	%)
Industrial	8.0		11.6		(31	%)	1,551	1,757	(12	%)	10.4		15.5		(33	%)	2,092	2,377	(12	%)
Retail subtotal	232.8		299.4		(22	%)	32,085	36,364	(12	%)	263.8		340.0		(22	%)	35,446	40,182	(12	%)
Transportation/other	17.3		18.2		(5	%)	38,441	31,611	22	%	24.3		24.8		(2	%)	57,213	46,521	23	%
Total revenues/sales	250.1		317.6		(21	%)	70,526	67,975	4	%	288.1		364.8		(21	%)	92,659	86,703	7	%
Cost of gas sold	152.7		206.9		(26	%)					166.3		228.7		(27	%)
Gas margins (a)		$97.4		$110.7	(12	%)						$121.8		$136.1	(11	%)



IPL	Revenues and Costs (dollars in millions)						Dths Sold (Dths in thousands)
	2015		2014		Change		2015	2014	Change
Residential		$90.9		$117.0	(22	%)	10,709	12,575	(15	%)
Commercial	50.7		64.7		(22	%)	7,335	8,289	(12	%)
Industrial	7.6		11.2		(32	%)	1,562	1,744	(10	%)
Retail subtotal	149.2		192.9		(23	%)	19,606	22,608	(13	%)
Transportation/other	14.9		15.2		(2	%)	25,962	22,858	14	%
Total revenues/sales	164.1		208.1		(21	%)	45,568	45,466	—	%
Cost of gas sold	93.4		128.4		(27	%)
Gas margins (a)		$70.7		$79.7	(11	%)

4749

Table of Contents

IPL Revenues and Costs (dollars in millions) Dths Sold (Dths in thousands)
2015 2014 Change 2015 2014 Change
Residential
$80.6

$104.2
(23 %) 10,071
11,751
(14 %)
Commercial 43.9
55.8
(21 %) 6,481
7,337
(12 %)
Industrial 5.6
7.9
(29 %) 1,120
1,226
(9 %)
Retail subtotal 130.1
167.9
(23 %) 17,672
20,314
(13 %)
Transportation/other 10.9
11.5
(5 %) 18,143
15,796
15 %
Total revenues/sales 141.0
179.4
(21 %) 35,815
36,110
(1 %)
Cost of gas sold 84.0
113.8
(26 %)
Gas margins (a)
$57.0

$65.6
(13 %)


WPL	Revenues and Costs (dollars in millions)						Dths Sold (Dths in thousands)				Revenues and Costs (dollars in millions)						Dths Sold (Dths in thousands)
	2015		2014		Change		2015	2014	Change		2015		2014		Change		2015	2014	Change
Residential		$63.9		$80.8	(21	%)	8,200	9,144	(10	%)		$71.2		$89.7	(21	%)	8,766	9,772	(10	%)
Commercial	36.4		47.0		(23	%)	5,782	6,375	(9	%)	40.6		53.1		(24	%)	6,544	7,169	(9	%)
Industrial	2.4		3.7		(35	%)	431	531	(19	%)	2.8		4.3		(35	%)	530	633	(16	%)
Retail subtotal	102.7		131.5		(22	%)	14,413	16,050	(10	%)	114.6		147.1		(22	%)	15,840	17,574	(10	%)
Transportation/other	6.4		6.7		(4	%)	20,298	15,815	28	%	9.4		9.6		(2	%)	31,251	23,663	32	%
Total revenues/sales	109.1		138.2		(21	%)	34,711	31,865	9	%	124.0		156.7		(21	%)	47,091	41,237	14	%
Cost of gas sold	68.7		93.1		(26	%)					72.9		100.3		(27	%)
Gas margins		$40.4		$45.1	(10	%)						$51.1		$56.4	(9	%)


(a)	Includes $6$9 million of credits on IPL’s Iowa retail gas customers’ bills for both the ~~six~~nine months ended ~~June~~September 30, 2015 and 2014 resulting from the gas tax benefit rider. The gas tax benefit rider results in reductions in gas revenues that are offset by reductions in income tax expense for the years ended December 31, 2015 and 2014.

Variances - Variances between periods in gas margins for the three and ~~six~~nine months ended ~~June~~September 30, 2015 compared to the same periods in 2014 were as follows (in millions):


	Three Months									Six Months									Three Months								Nine Months
	Alliant Energy			IPL			WPL			Alliant Energy			IPL			WPL			Alliant Energy			IPL		WPL			Alliant Energy			IPL			WPL
Estimated decrease from changes in sales caused by temperatures		$—			$—			$—			($6	)		($3	)		($3	)		($1	)		$—		($1	)		($7	)		($3	)		($4	)
Lower revenues at IPL related to changes in recovery amounts for energy efficiency costs through the energy efficiency rider (a)	—			—			—			(6		)	(6		)	—			—			—		—			(6		)	(6		)	—
Lower revenues at WPL due to the impact of changes in retail gas base rates effective January 2015	—			—			—			(3		)	—			(3		)	—			—		—			(3		)	—			(3		)
Other	(2		)	(1		)	(1		)	2			—			1			—			—		—			2			—			2
		($2	)		($1	)		($1	)		($13	)		($9	)		($5	)		($1	)		$—		($1	)		($14	)		($9	)		($5	)


(a)	Changes in energy efficiency revenues were mostly offset by changes in energy efficiency expense included in other operation and maintenance expenses.

Temperatures - Estimated increases (decreases) to gas margins from the impacts of temperatures for the three and ~~six~~nine months ended ~~June~~September 30 were as follows (in millions):


	Three Months								Six Months							Three Months								Nine Months
	2015			2014			Change		2015		2014		Change			2015			2014		Change			2015		2014		Change
IPL		$—			$—			$—		$1		$4		($3	)		$—			$—		$—			$1		$4		($3	)
WPL	(1		)	(1		)	—		1		4		(3		)	(1		)	—		(1		)	—		4		(4		)
Total Alliant Energy		($1	)		($1	)		$—		$2		$8		($6	)		($1	)		$—		($1	)		$1		$8		($7	)

Refer to “Utility Electric Margins” for HDD data details. Refer to Note 2 for discussion of IPL’s gas tax benefit rider.

~~Table of Contents~~

Utility Other Revenues - Variances between periods in utility other revenues for the three and ~~six~~nine months ended ~~June~~September 30, 2015 compared to the same periods in 2014 were as follows (in millions):


	Three Months								Six Months									Three Months						Nine Months
	Alliant Energy			IPL			WPL		Alliant Energy			IPL			WPL			Alliant Energy		IPL		WPL		Alliant Energy			IPL			WPL
Lower margins from IPL’s sharing mechanism related to optimizing gas capacity contracts (a)		$—			$—			$—		($4	)		($4	)		$—			$—		$—		$—		($4	)		($4	)		$—
Other	(1		)	(1		)	—		(3		)	—			(3		)	1		1		—		(2		)	1			(3		)
		($1	)		($1	)		$—		($7	)		($4	)		($3	)		$1		$1		$—		($6	)		($3	)		($3	)

Table of Contents

(a)

Approximately 50% of all margins earned from IPL’s sharing mechanism relating to optimizing gas capacity contracts flow through the purchased gas adjustment clause to reduce retail gas customer bills in Iowa. The remaining margins are retained by IPL and recorded in utility other revenues. Due to the extreme cold temperatures causing natural gas price fluctuations in the first quarter of 2014, margins were higher than normal for the ~~six~~nine months ended ~~June~~September 30, 2014.

Electric Transmission Service Expense - Variances between periods in electric transmission service expense for the three and ~~six~~nine months ended ~~June~~September 30, 2015 compared to the same periods in 2014 were as follows (in millions):


	Three Months							Six Months								Three Months							Nine Months
	Alliant Energy			IPL		WPL		Alliant Energy			IPL			WPL		Alliant Energy		IPL			WPL		Alliant Energy			IPL			WPL
Higher electric transmission service costs billed from ITC, ATC and MISO (a)		$4			$1		$3		$10			$4			$6		$9		$6			$3		$19			$10			$9
Escrow treatment for the difference between actual electric transmission service costs and those costs used to determine rates during 2015 at WPL (b)	6			—		6		12			—			12
Changes in the under-/over-collection of electric transmission service expense through the transmission cost rider at IPL (c)	2			2		—		(1		)	(1		)	—
Escrow treatment for the difference between actual electric transmission service costs and those costs used to determine rates during 2015 at WPL (Refer to Note 2 for further details)																4		—			4		16			—			16
Other	(1		)	—		—		—			—			—		1		(1		)	2		(1		)	(2		)	2
		$11			$3		$9		$21			$3			$18		$14		$5			$9		$34			$8			$27


(a)	Primarily due to increased electric transmission service rates.

~~(b)~~

Electric revenues established in WPL’s retail electric rate case (2015/2016 Test Period) included recovery of expected increases in electric transmission service expense largely due to System Support Resource costs expected to be incurred. Due to a revision in MISO’s method utilized to allocate System Support Resource costs, WPL no longer expects to incur certain System Support Resource costs. The difference between actual electric transmission service expense incurred and amounts collected from customers as electric revenues in 2015 and 2016 will be recorded as electric transmission service expense with an offsetting amount recorded to regulatory liabilities due to the escrow treatment WPL received as part of its approved retail electric rate case.

~~(c)~~

IPL is currently recovering the Iowa retail portion of its increased electric transmission service costs from its retail electric customers in Iowa through a transmission cost rider approved by the IUB in January 2011 and extended as part of the rate settlement approved in September 2014. The difference between electric transmission service expense and amounts collected from customers as electric revenues results in temporary costs (credits) recorded in electric transmission service expense until the amounts are reflected in future customer billings.

Forecast - Refer to “~~Table~~Other Future Considerations” for discussion of ~~Contents~~a potential increase in future electric transmission service expense in 2016 compared to 2015.

~~Utility~~ Other Operation and Maintenance Expenses - Variances between periods in ~~utility~~ other operation and maintenance expenses for the three and ~~six~~nine months ended ~~June~~September 30, 2015 compared to the same periods in 2014 were as follows (in millions):

Three Months Six Months
Alliant Energy IPL WPL Alliant Energy IPL WPL
Lower energy efficiency cost recovery amortizations at WPL (a)
($9 )
$—

($9 )
($19 )
$—

($19 )
Lower generation expense at IPL (b) (2 ) (2 ) —
(4 ) (4 ) —
Lower energy efficiency expense at IPL (c) —
—
—
(4 ) (4 ) —
Losses on sales of IPL’s Minnesota distribution assets recorded in the second quarter of 2015 (d) 12
12
—
12
12
—
Higher employee benefits-related expense (e) 3
2
1
6
3
3
Other (7 ) (3 ) (4 ) (9 ) (3 ) (6 )

($3 )
$9

($12 )
($18 )
$4

($22 )



	Three Months									Nine Months
	Alliant Energy			IPL			WPL			Alliant Energy			IPL			WPL
Lower energy efficiency cost recovery amortizations at WPL (a)		($10	)		$—			($10	)		($29	)		$—			($29	)
Lower generation expense (b)	(5		)	(1		)	(4		)	(9		)	(5		)	(4		)
Changes in energy efficiency expense at IPL (c)	1			1			—			(3		)	(3		)	—
Losses on sales of IPL’s Minnesota distribution assets recorded in the second quarter of 2015 (Refer to Note 3 for further details)	—			—			—			12			12			—
Higher employee benefits-related expense (d)	3			2			1			9			5			4
Voluntary employee separation charges (e)	8			5			3			8			5			3
Other (includes lower costs due to cost controls and operational efficiencies)	(5		)	(2		)	—			(16		)	(6		)	(6		)
		($8	)		$5			($10	)		($28	)		$8			($32	)


(a)	The July ~~2012~~2014 PSCW order for WPL’s ~~2013/2014~~2015/2016 Test Period electric and gas base rate case authorized lower energy efficiency cost recovery amortizations for 2015.


(b)	Primarily resulting from the timing of maintenance projects at IPL’s and WPL’s EGUs.


(c)	Changes in IPL’s energy efficiency expense were offset by changes in electric and gas energy efficiency revenues.


(d)	~~Refer to~~ ~~Note 3~~ ~~for discussion of IPL’s sales of its Minnesota electric and natural gas distribution assets.~~


~~(e)~~	Primarily due to an increase in retirement plans costs and other employee benefits-related costs. The increased retirement plan costs were largely due to decreases in discount rates and a change to the life expectancy assumption in 2014.


(e)	In the third quarter of 2015, Alliant Energy offered certain employees voluntary separation agreements of which approximately 2% of total Alliant Energy employees accepted.

Forecast - Alliant Energy and WPL currently expect decreases in energy efficiency cost recovery amortizations at WPL in 2016 compared to 2015 as approved by the PSCW in a July 2014 order. Partially offsetting this expected decrease, Alliant Energy, IPL and WPL currently expect an increase in retirement plan costs in 2016 compared to 2015, resulting from lower than expected returns on retirement plan assets in 2015.

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Depreciation and Amortization Expenses - ~~Alliant Energy’s~~Variances between periods in depreciation and amortization expenses ~~increased $5 million and $9 million~~ for the ~~three-~~three and ~~six-month~~nine months ended September 30, 2015 compared to the same periods ~~respectively, primarily~~in 2014 were as follows (in millions):



	Three Months						Nine Months
	Alliant Energy		IPL		WPL		Alliant Energy		IPL		WPL
Higher depreciation expense for IPL’s Ottumwa Unit 1 scrubber and baghouse completed in 2014		$1		$1		$—		$4		$4		$—
Higher depreciation expense for WPL’s Columbia Units 1 and 2 scrubbers and baghouses completed in 2014	—		—		—		2		—		2
Other	1		1		—		6		4		1
		$2		$2		$—		$12		$8		$3

Forecast - Alliant Energy currently expects its depreciation and amortization expenses to increase in 2016 compared to 2015 due to ~~increased~~ property additions, including various emission controls projects at IPL and WPL placed in service in ~~2014.~~2015 and expected to be placed in service in 2016.

Interest Expense - Variances between periods in interest expense for the three and nine months ended September 30, 2015 compared to the same periods in 2014 were as follows (in millions):



	Three Months								Nine Months
	Alliant Energy			IPL		WPL			Alliant Energy			IPL			WPL
Higher interest expense from the issuance of WPL’s $250 million, 4.1% debentures in October 2014		$3			$—		$3			$8			$—			$8
Higher interest expense from the issuance of IPL’s $250 million, 3.25% senior debentures in November 2014	2			2		—			6			6			—
Lower interest expense from the retirement of Alliant Energy’s $250 million, 4% senior notes in October 2014	(3		)	—		—			(8		)	—			—
Other	—			—		(1		)	(1		)	(1		)	(2		)
		$2			$2		$2			$5			$5			$6

Forecast - Alliant Energy currently expects its interest expense to increase in 2016 compared to 2015 due to financings in 2015 and 2016. Refer to “Liquidity and Capital Resources” for details of Alliant Energy’s financing forecast.

Equity Income from Unconsolidated Investments, Net - Alliant Energy’s and WPL’s equity income from unconsolidated investments decreased $5 million and $4 million for the ~~six-month~~nine-month period, respectively, primarily due to reserves for rate refunds recorded during the ~~six~~nine months ended ~~June~~September 30, 2015 at ATC. Refer to “Other Future Considerations” for discussion of a complaint pending with FERC regarding the level of return on equity that MISO transmission owners (including ATC) should be allowed to utilize in calculating the rates they charge their customers.

AFUDC -

Forecast - Alliant Energy currently expects AFUDC to increase in 2016 compared to 2015 primarily due to increased construction work in progress balances related to Marshalltown.

Income Taxes - Refer to Note 8 for details of effective income tax rates for continuing ~~operations, including discussion of the impacts of~~operations.

Forecast - Alliant Energy currently expects to record higher tax ~~benefit riders,~~benefits from the effect of rate-making on ~~property-related~~property related differences ~~and production tax credits.~~in 2016 compared to 2015.

LIQUIDITY AND CAPITAL RESOURCES

A liquidity and capital resources matters summary is included in the 2014 Form 10-K and has not changed materially from the items reported in the 2014 Form 10-K, except as described below.

Liquidity Position - At ~~June~~September 30, 2015, Alliant Energy had ~~$55~~$139 million of cash and cash equivalents, ~~$768~~$891 million ($~~179~~191 million at the parent company, ~~$189~~$300 million at IPL and $400 million at WPL) of available capacity under the revolving credit facilities and ~~$50~~$179 million of available capacity at IPL under its sales of accounts receivable program.

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Capital Structures - Capital structures at ~~June~~September 30, 2015 were as follows (dollars in millions):


	Alliant Energy (Consolidated)				IPL				WPL				Alliant Energy (Consolidated)				IPL				WPL
Common equity		$3,620.8	47	%		$1,908.7	50	%		$1,723.9	52	%		$3,745.2	47	%		$1,991.0	49	%		$1,759.6	53	%
Preferred stock	200.0		3	%	200.0		5	%	—		—	%	200.0		3	%	200.0		5	%	—		—	%
Noncontrolling interest	0.9		—	%	—		—	%	9.9		—	%	0.9		—	%	—		—	%	10.9		—	%
Long-term debt (incl. current maturities)	3,750.9		49	%	1,730.2		45	%	1,574.1		48	%	3,858.8		49	%	1,868.5		46	%	1,543.6		47	%
Short-term debt	120.9		1	%	—		—	%	—		—	%	109.1		1	%	—		—	%	—		—	%
		$7,693.5	100	%		$3,838.9	100	%		$3,307.9	100	%		$7,914.0	100	%		$4,059.5	100	%		$3,314.1	100	%

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Cash Flows - Selected information from the cash flows statements was as follows (in millions):


	Alliant Energy						IPL						WPL						Alliant Energy						IPL						WPL
	2015			2014			2015			2014			2015			2014			2015			2014			2015			2014			2015			2014
Cash and cash equivalents, January 1		$56.9			$9.8			$5.3			$4.4			$46.7			$0.5			$56.9			$9.8			$5.3			$4.4			$46.7			$0.5
Cash flows from (used for):
Operating activities	517.3			448.2			294.5			206.1			230.2			235.5			695.3			763.9			318.0			373.6			375.9			365.8
Investing activities	(470.3		)	(369.0		)	(285.2		)	(196.4		)	(162.0		)	(151.1		)	(613.0		)	(640.4		)	(319.4		)	(376.5		)	(259.6		)	(233.8		)
Financing activities	(49.1		)	(72.8		)	(12.6		)	(8.7		)	(66.1		)	(78.5		)	—			(122.3		)	95.5			3.1			(127.3		)	(130.2		)
Net increase (decrease)	(2.1		)	6.4			(3.3		)	1.0			2.1			5.9			82.3			1.2			94.1			0.2			(11.0		)	1.8
Cash and cash equivalents, June 30		$54.8			$16.2			$2.0			$5.4			$48.8			$6.4
Cash and cash equivalents, September 30																				$139.2			$11.0			$99.4			$4.6			$35.7			$2.3

Operating Activities -

~~Six~~Nine Months Ended ~~June~~September 30, 2015 vs. ~~Six~~Nine Months Ended ~~June~~September 30, 2014 - ~~Alliant Energy’s~~The following items contributed to increased (decreased) operating activity cash flows ~~from operating activities increased $69 million primarily due to $97 million of higher cash flows from changes in~~for the ~~level of IPL’s accounts receivable sold during the six~~nine months ended ~~June~~September 30, 2015 compared to the same period in 2014 ~~higher~~(in millions):



	Alliant Energy			IPL			WPL
Changes in the level of IPL’s accounts receivable sold (Refer to Note 4(a) for details)		($30	)		($30	)		$—
Final receipt related to Alliant Energy’s tax separation and indemnification agreement with Whiting Petroleum in 2014 (Refer to Note 4(b) for details)	(26		)	—			—
Changes in IPL’s retail electric customer billing credits	27			27			—
Other (a)	(40		)	(53		)	10
		($69	)		($56	)		$10


(a)	Includes other changes in working capital largely related to changes in inventory levels and the timing of fuel-related cost recoveries from customers.

Investing Activities -

Nine Months Ended September 30, 2015 vs. Nine Months Ended September 30, 2014 - The following items contributed to increased (decreased) investing activity cash flows ~~from lower fuel-related costs at WPL during~~for the ~~six~~nine months ended ~~June~~September 30, 2015 compared to the same period in 2014 (in millions):



	Alliant Energy			IPL			WPL
Proceeds from IPL’s Minnesota distribution asset sales in 2015		$138			$138			$—
Higher utility construction expenditures, including Marshalltown expenditures for Alliant Energy and IPL	(92		)	(74		)	(17		)
Other	(19		)	(7		)	(9		)
		$27			$57			($26	)

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Construction and ~~$25 million~~Acquisition Expenditures - Construction and acquisition expenditures for 2015 through 2019 are currently anticipated as follows (in millions). Cost estimates represent Alliant Energy’s, IPL’s and WPL’s estimated portion of ~~purchased electric capacity payments during the six months ended June 30, 2014~~total escalated construction expenditures and exclude AFUDC and capitalized interest, if applicable. Refer to “Strategic Overview” for further discussion of certain key projects impacting construction and acquisition plans related to the ~~previous DAEC PPA. These~~utility business.



	Alliant Energy										IPL										WPL
	2015		2016		2017		2018		2019		2015		2016		2017		2018		2019		2015		2016		2017		2018		2019
Generation:
Marshalltown		$280		$190		$10		$—		$—		$280		$190		$10		$—		$—		$—		$—		$—		$—		$—
Proposed Riverside expansion	10		100		325		240		30		—		—		—		—		—		10		100		325		240		30
Environmental compliance	145		100		70		60		25		30		25		40		50		10		115		75		30		10		15
Other	120		175		170		135		140		55		80		75		60		60		65		95		95		75		80
Distribution:
Electric systems	280		280		355		430		470		175		150		220		230		225		105		130		135		200		245
Gas systems	95		200		150		210		165		45		155		90		115		95		50		45		60		95		70
Other	120		90		170		175		260		30		25		35		40		80		20		35		35		20		15
		$1,050		$1,135		$1,250		$1,250		$1,090		$615		$625		$470		$495		$470		$365		$480		$680		$640		$455

Financing Activities -

Nine Months Ended September 30, 2015 vs. Nine Months Ended September 30, 2014 - The following items ~~were partially offset by the final receipt of $26 million related~~contributed to ~~Alliant Energy’s tax separation and indemnification agreement with Whiting Petroleum in March 2014, lower~~increased (decreased) financing activity cash flows ~~from changes in production fuel inventory levels at IPL and WPL, and decreased collections from IPL’s and WPL’s retail customers during~~for the ~~six~~nine months ended ~~June~~September 30, 2015 compared to the same period in 2014 ~~caused by temperature impacts on electric and gas sales. Refer to~~ (in millions):~~Note 4~~ ~~for discussion of IPL’s sales of accounts receivable program and the tax separation and indemnification agreement with Whiting Petroleum.~~



	Alliant Energy			IPL			WPL
Proceeds from the issuance of IPL’s 3.4% senior debentures in August 2015		$250			$250			$—
Net proceeds from common stock issuances in 2015	145			—			—
Payments to retire IPL’s 5% pollution control revenue bonds in July 2014	38			38			—
Payments to retire IPL’s 3.3% senior debentures in June 2015	(150		)	(150		)	—
Net changes in the amount of commercial paper outstanding	(107		)	(38		)	37
Payments to retire WPL’s pollution control revenue bonds in the third quarter of 2015	(31		)	—			(31		)
Other	(23		)	(8		)	(3		)
		$122			$92			$3

~~IPL’s cash flows from operating activities increased $88 million primarily due to $97~~FERC Financing Authorization - After issuing $250 million of ~~higher cash flows from changes~~long-term debt in ~~the level of accounts receivable sold during the six months ended June 30,~~August 2015, ~~compared~~IPL currently has remaining authority to ~~the same period in 2014 and $25~~issue up to $250 million of ~~purchased electric capacity payments during the six months ended June 30, 2014 related~~long-term debt securities in aggregate in 2015 pursuant to the previous DAEC PPA. These items were partially offset by lower cash flows from changes in production fuel inventory levels and decreased collections from retail customers during the six months ended June 30, 2015 compared to the same period in 2014 caused by temperature impacts on electric and gas sales.

WPL’s cash flows from operating activities decreased $5 million primarily due to decreased collections from retail customers during the six months ended June 30, 2015 compared to the same period in 2014 caused by temperature impacts on electric and gas sales, and lower cash flows from changes in production fuel inventory levels. These items were partially offset by higher cash flows from lower fuel-related costs during the six months ended June 30, 2015 compared to the same period in 2014.

~~Investing Activities -~~

~~Six Months Ended June 30, 2015 vs. Six Months Ended June 30, 2014~~a 2013 FERC order. - Alliant Energy’s cash flows used for investing activities increased $101 million primarily due to $104 million of higher utility construction expenditures. The higher utility construction expenditures were largely due to higher expenditures during the six months ended June 30, 2015 for Marshalltown.

IPL’s cash flows used for investing activities increased $89 million primarily due to $96 million of higher construction expenditures. The higher construction expenditures were largely due to higher expenditures during the six months ended June 30, 2015 for Marshalltown.

~~WPL’s cash flows used for investing activities increased $11 million primarily due to $7 million of higher construction expenditures.~~

~~Financing Activities -~~

~~Six Months Ended June 30, 2015 vs. Six Months Ended June 30, 2014~~ - Alliant Energy’s cash flows used for financing activities decreased $24 million primarily due to $140 million of net proceeds from common stock issuances during the six months ended June 30, 2015 and net changes in the amount of commercial paper outstanding. These items were partially offset by payments to retire IPL’s $150 million, 3.3% senior debentures in June 2015.

~~Table of Contents~~

IPL’s cash flows used for financing activities increased $4 million primarily due to payments to retire its $150 million, 3.3% senior debentures in June 2015. This item was partially offset by changes in the amount of commercial paper outstanding and higher capital contributions from its parent company during the six months ended June 30, 2015 compared to the same period in 2014.

~~WPL’s cash flows used for financing activities decreased $12 million primarily due to changes in the amount of commercial paper outstanding.~~

Common Stock Issuances and Capital Contributions - Refer to Note 6 for discussion of common stock issuances by Alliant Energy, payments of common stock dividends by IPL and WPL to their parent company, and capital contributions from Alliant Energy to IPL during the ~~six~~nine months ended ~~June~~September 30, 2015. Refer to Note 9(b) for discussion of Alliant Energy’s common stock issuances during the ~~six~~nine months ended ~~June~~September 30, 2015 under its equity-based compensation plans for employees.

Long-term Debt - Refer to Note 77(b) for discussion of ~~$111.2~~various long-term debt issuances and retirements.

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Financing Forecast - The following financing activities are currently anticipated to occur in the future:

Long-term Debt - IPL currently expects to issue up to $300 million of ~~commercial paper outstanding at June 30, 2015 classified as~~additional long-term debt atin 2016. In addition, Alliant Energy and Franklin County Holdings LLC currently anticipate refinancing $250 million and $60 million, respectively, of variable-rate term loan credit agreements in 2016.

Common Stock Issuances and Capital Contributions - Alliant Energy currently expects to issue approximately $25 million of common stock in 2016 through its Shareowner Direct Plan. IPL and ~~IPL’s retirement~~WPL currently expect to receive capital contributions of approximately $165 million and $25 million, respectively, from their parent company in 2016.

Common Stock Dividends - In November 2015, Alliant Energy announced an increase in its targeted 2016 annual common stock dividend to $2.35 per share, which is equivalent to a quarterly rate of $0.5875 per share, beginning with the February 2016 dividend payment. The timing and amount of future dividends is subject to an approved dividend declaration from its Board of Directors, and is dependent upon earnings expectations, capital requirements, and general financial business conditions, among other factors. In addition, IPL and WPL currently expect to pay common stock dividends of approximately $150 million ~~3.3% senior debentures~~and $135 million, respectively, to their parent company in ~~June 2015.~~2016.

Impact of Credit Ratings on Liquidity and Collateral Obligations -

Ratings Triggers - In August 2015, Moody’s Investors Service changed each of Alliant Energy’s, IPL’s and WPL’s outlooks from stable to negative. As discussed in the 2014 Form 10-K, 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.”

Off-Balance Sheet Arrangements - A summary of Alliant Energy’s off-balance sheet arrangements is included in the 2014 Form 10-K and has not changed materially from the items reported in the 2014 Form 10-K, except as described below. Refer to Note 4(a) for information regarding IPL’s sales of accounts receivable program. IPL currently expects to amend and extend in March 2016 the purchase commitment from the third party to which it sells its receivables. Refer to Note 13(d) for information regarding various guarantees and indemnifications related to Alliant Energy’s and IPL’s prior divestiture activities.

Certain Financial Commitments -

Contractual Obligations - A summary of Alliant Energy’s, IPL’s and WPL’s contractual obligations is included in the 2014 Form 10-K and has not changed materially from the items reported in the 2014 Form 10-K, except for the items described in Notes 7(b), 13(a) and 13(b).

OTHER MATTERS

Market Risk Sensitive Instruments and Positions - A summary of market risks is included in the 2014 Form 10-K and such market risks have not changed materially from those reported in the 2014 Form 10-K, except as described below.

Commodity Price - Refer to Note 2 for discussion of ~~amounts recorded by Alliant Energy and WPL on their balance sheets as of June 30, 2015~~WPL’s retail fuel-related rate filings for ~~fuel-related costs incurred by WPL in~~the Test Years 2014 ~~that were outside the approved bandwidth, as well as an order received from the PSCW in July 2015 authorizing WPL to recover such costs from its retail electric customers beginning in~~though 2016.

New Accounting Pronouncements - Refer to Note 1(b) for discussion of new accounting pronouncements impacting Alliant Energy, IPL and WPL.

Critical Accounting Policies and Estimates - A summary of critical accounting policies and estimates is included in the 2014 Form 10-K and such policies and estimates have not changed materially from those reported in the 2014 Form 10-K.

Other Future Considerations - A summary of other future considerations is included in the 2014 Form 10-K and has not changed materially from the items reported in the 2014 Form 10-K except as described below, and as discussed earlier in MDA, the Notes in Item 1 and “Risk Factors” in Item 1A.

Electric Transmission Service Expense - IPL and WPL currently receive substantially all their transmission services from ITC and ATC, respectively. Due to the formula rates used by ITC and ATC to charge their customers and possible future changes to these rates as discussed below, there is uncertainty regarding the long-term trends of IPL’s and WPL’s future electric transmission service expense. Alliant Energy, IPL and WPL currently anticipate changes to their electric transmission service expense in 2016 as follows:

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Attachment “O” Rates - 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 referred to as Attachment “O.” 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 either FERC or customers. 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, ITC’s or ATC’s rates would change accordingly.

2016 Rates Charged by ITC to IPL - In August 2015, ITC filed with MISO the Attachment “O” rate it proposes to charge its customers in 2016 for electric transmission services. The proposed rate was based on ITC’s estimated net revenue requirement for 2016 as well as a true-up adjustment credit related to amounts that ITC over-recovered from its customers in 2014. Amounts billed under the 2016 Attachment “O” rate are currently expected to be approximately 6% higher than the amounts ITC is charging its customers in 2015.

2016 Rates Charged by ATC to WPL - In September 2015, ATC shared with its customers the Attachment “O” rate it proposes to charge them in 2016 for electric transmission services. The proposed rate was based on ATC’s estimated net revenue requirement for 2016 as well as a true-up adjustment credit related to amounts that ATC over-recovered from its customers in 2014. Amounts billed under the 2016 Attachment “O” rate are currently expected to be approximately 7% higher than the amounts ATC is charging its customers in 2015.

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. Multi-value Projects 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. Multi-value Project 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 reliability standards. The costs of these projects are primarily 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 number of shared transmission projects expected to be completed in the MISO region.

2016 Electric Transmission Service Expense - Alliant Energy, IPL and WPL currently estimate their total electric transmission service expense in 2016 will be higher than the comparable expense in 2015 by approximately $35 million, $25 million and $10 million, respectively, as a result of the items discussed above. A significant portion of the increase in IPL’s electric transmission service expense is expected to be offset with increases in retail electric revenues through the transmission cost recovery rider. Any difference between WPL’s actual electric transmission service expense incurred and amounts collected from customers as electric revenues in 2016 will be recorded as a regulatory asset or regulatory liability due to the escrow treatment authorized for WPL in its 2015/2016 Test Period retail electric rate case.

MISO Transmission Owner Return on Equity Complaints - In 2013, a group of MISO industrial customer organizations filed a complaint with FERC requesting to reduce the base return on equity used by MISO transmission owners, including ITC and ATC, among other items. ITC’s and ATC’s current authorized return on equity is 12.38% and 12.2%, respectively. In 2014, FERC issued an order on the complaint, established hearing and settlement procedures on the return on equity component of the complaint, and established an effective refund date of November 12, 2013. ~~Through June 2015, various~~Various parties to the proceeding have filed testimony with FERC identifying base return on equity ranges with stated midpoints between 8.58% and 11.39%, excluding any incentive adders granted by FERC. A final decision from FERC on this complaint is currently expected in 2016.

~~Table of Contents~~

In June 2015, FERC issued an order on an additional complaint filed with FERC by a group of MISO cooperative and municipal utilities requesting to reduce the base return on equity used by MISO transmission owners, including ITC and ATC, to 8.67%. FERC’s June 2015 order established hearing procedures and an effective refund date of February 12, 2015. A final decision from FERC on this complaint is currently expected in 2017.

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Based on other recent FERC return on equity decisions, Alliant Energy, IPL and WPL currently anticipate FERC’s decision on the MISO transmission owner complaints will reduce transmission owners’ current authorized return on equity, which is expected to reduce electric transmission service expense costs billed by ITC and ATC to their customers and result in lower equity income and dividends from ATC in the future. Alliant Energy and WPL have realized $7 million of reductions in the amount of equity income from ATC for the period from November 12, 2013 through ~~June~~September 30, 2015, including $4 million of reductions recorded during the ~~six~~nine months ended ~~June~~September 30, 2015. These reductions assume the final ~~base~~ return on equity awarded to ~~MISO transmission owners~~ATC will be ~~toward the top end of the midpoints included in the testimony filed by the various parties to the MISO complaints.~~11.5% (including a 50 basis point incentive adder). Alliant Energy and WPL currently estimate each 25 basis point reduction in ATC’s authorized return on equity would reduce their annual pre-tax equity income from ATC by approximately $1 million.

ITC Request for Equity Adder - In January 2015, ITC requested approval from FERC to implement a 100 basis point incentive adder to its base return on equity for being an independent transmission company. In March 2015, FERC issued an order granting a 50 basis point incentive adder to ITC’s base return on equity for being an independent transmission company. The implementation of the adder will be retroactively applied back to April 2015 after resolution of a MISO transmission owner return on equity complaint filed in 2013 by a group of MISO industrial customer organizations. Alliant Energy and IPL are currently unable to determine any resulting changes to future electric transmission service charges pending a decision by FERC on the 2013 complaint. Alliant Energy and IPL currently expect to pass on the retail portion of any changes in electric transmission service costs billed by ITC to IPL to IPL’s retail electric customers through the transmission cost recovery rider.

ITEM 3. QUANTITATIVE AND QUALITATIVE DISCLOSURES ABOUT MARKET RISK

Quantitative and Qualitative Disclosures About Market Risk are reported in “Other Matters - Market Risk Sensitive Instruments and Positions” in MDA.

ITEM 4. CONTROLS AND PROCEDURES

Alliant Energy’s, IPL’s and WPL’s management evaluated, with the participation of each of Alliant Energy’s, IPL’s and WPL’s CEO, CFO and Disclosure Committee, the effectiveness of the design and operation of Alliant Energy’s, IPL’s and WPL’s disclosure controls and procedures (as defined in Rule 13a-15(e) of the Securities Exchange Act of 1934) as of ~~June~~September 30, 2015 pursuant to the requirements of the Securities Exchange Act of 1934. Based on their evaluation, the CEO and the CFO concluded that Alliant Energy’s, IPL’s and WPL’s disclosure controls and procedures were effective as of ~~June~~September 30, 2015.

There was no change in Alliant Energy’s, IPL’s and WPL’s internal control over financial reporting that occurred during the quarter ended ~~June~~September 30, 2015 that has materially affected, or is reasonably likely to materially affect, Alliant Energy’s, IPL’s or WPL’s internal control over financial reporting.

PART II. OTHER INFORMATION

ITEM 1. LEGAL PROCEEDINGS

IPL Consent Decree - ~~Refer~~As discussed in the combined Quarterly Report on Form 10-Q filed by Alliant Energy, IPL and WPL for the quarterly period ended June 30, 2015, refer to Note ~~13(c)~~13(e) for discussion of a Consent Decree that IPL entered into with the EPA, the Sierra Club, the State of Iowa and Linn County in Iowa in July 2015 and IPL’s obligations thereunder. ~~If approved by~~In September 2015, the U.S. District Court for the Northern District of Iowa approved the Consent Decree, ~~will resolve discussions~~thereby resolving potential claims regarding CAA issues associated with emissions from IPL’s coal-fired generating facilities in Iowa.

ITEM 1A. RISK FACTORS

A summary of risk factors is included in Item 1A in the 2014 Form 10-K and such risk factors have not changed materially from the items reported in the 2014 Form 10-K.

5357

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ITEM 2. UNREGISTERED SALES OF EQUITY SECURITIES AND USE OF PROCEEDS

A summary of Alliant Energy common stock repurchases for the quarter ended ~~June~~September 30, 2015 was as follows:

Total Number Average Price Total Number of Shares Maximum Number (or Approximate
of Shares Paid Per Purchased as Part of Dollar Value) of Shares That May Yet
Period Purchased (a) Share Publicly Announced Plan Be Purchased Under the Plan (a)
April 1 through April 30 2,415

$62.52
— N/A
May1 through May 31 2,158
61.00
— N/A
June 1 through June 30 40
58.71
— N/A
4,613
61.77
—



	Total Number	Average Price		Total Number of Shares	Maximum Number (or Approximate
	of Shares	Paid Per		Purchased as Part of	Dollar Value) of Shares That May Yet
Period	Purchased (a)	Share		Publicly Announced Plan	Be Purchased Under the Plan (a)
July 1 through July 31	2,553		$59.61	—	N/A
August 1 through August 31	1,901	61.70		—	N/A
September 1 through September 30	42	56.58		—	N/A
	4,496	60.46		—


(a)	All shares were purchased on the open market and held in a rabbi trust under the Alliant Energy Deferred Compensation Plan. There is no limit on the number of shares of Alliant Energy common stock that may be held under the Deferred Compensation Plan, which currently does not have an expiration date.

Refer to Note 6 for discussion of restrictions on each of IPL’s and WPL’s distributions to its parent company.

ITEM 5. OTHER INFORMATION

On November 4, 2015, the Compensation and Personnel Committee of the Board of Directors of Alliant Energy approved an amendment to the Key Executive Employment and Severance Agreement (KEESA) with the current named executive officers of Alliant Energy, except for the CEO. Each KEESA provides executive officers with certain severance benefits in the event of a qualifying termination of employment in connection with a change in control. The KEESA amendment provides that if any portion of the payments under the KEESA or any other agreement with an executive officer would constitute an excess parachute payment subject to an excise tax under the Internal Revenue Code, then those payments will be reduced to $1 less than the maximum amount that the executive officer could receive without becoming subject to the excise tax, provided that this reduction will not apply if the fully calculated payment would result in a greater net after-tax amount payable to the executive officer. The KEESA of the CEO already includes this provision. Alliant Energy cannot currently determine the benefits, if any, to be paid in the future to its executive officers under the KEESA. The foregoing description of the KEESA amendment is qualified in its entirety by reference to the KEESA amendment, which is filed herewith as Exhibit 10.1 and is incorporated herein by reference.

ITEM 6. EXHIBITS

Exhibits for Alliant Energy, IPL and WPL are listed in the Exhibit Index, which is incorporated herein by reference.

Table of Contents

SIGNATURES

Pursuant to the requirements of the Securities Exchange Act of 1934, Alliant Energy Corporation, Interstate Power and Light Company and Wisconsin Power and Light Company have each duly caused this report to be signed on its behalf by the undersigned thereunto duly authorized on the 6th day of ~~August~~November 2015.



ALLIANT ENERGY CORPORATION
Registrant

By: /s/ Robert J. Durian	Vice President, Chief Accounting Officer and Controller
Robert J. Durian	(Principal Accounting Officer and Authorized Signatory)



INTERSTATE POWER AND LIGHT COMPANY
Registrant

By: /s/ Robert J. Durian	Vice President, Chief Accounting Officer and Controller
Robert J. Durian	(Principal Accounting Officer and Authorized Signatory)



WISCONSIN POWER AND LIGHT COMPANY
Registrant

By: /s/ Robert J. Durian	Vice President, Chief Accounting Officer and Controller
Robert J. Durian	(Principal Accounting Officer and Authorized Signatory)

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Table of Contents

ALLIANT ENERGY CORPORATION

INTERSTATE POWER AND LIGHT COMPANY

WISCONSIN POWER AND LIGHT COMPANY

EXHIBIT INDEX

The following Exhibits are filed herewith or incorporated herein by reference.



Exhibit Number		Description

~~3.1~~4.1		~~Amended and Restated Bylaws~~Officer’s Certificate, dated as of ~~Alliant Energy, effective May 7,~~August 18, 2015, creating IPL’s 3.40% Senior Debentures due August 15, 2025 (incorporated by reference to Exhibit ~~3.1 to Alliant Energy’s Form 8-K, filed May 13, 2015 (File No. 1-9894))~~

~~3.2~~		~~Amended and Restated Bylaws of IPL, effective May 7, 2015 (incorporated by reference to Exhibit 3.2~~4.1 to IPL’s Form 8-K, filed ~~May 13,~~August 18, 2015 (File No. 1-4117))

~~3.3~~		~~Amended and Restated Bylaws of WPL, effective May 7, 2015 (incorporated by reference to Exhibit 3.3 to WPL’s Form 8-K, filed May 13, 2015 (File No. 0-337))~~

10.1		Alliant Energy Amended and Restated 2010 Omnibus Incentive Plan (incorporated by reference to Appendix A to Alliant Energy’s definitive proxy statement filed on Schedule 14A on March 24, 2015 (File No. 1-9894))

~~10.2~~		~~Amendment to the Alliant Energy Rabbi Trust Agreement for Deferred Compensation Plans~~

~~10.3~~		~~Second Amendment to the Alliant Energy Rabbi Trust Agreement for Deferred Compensation Plans~~

~~10.4~~		Form of ~~Key Executive Employment and Severance Agreement,~~Amendment to KEESA, by and between Alliant Energy and each of J.H. Gallegos, T.L. Hanson, D.R. Kopp, J.O. Larsen and R.J. Durian ~~(incorporated by reference to Exhibit 10.3 to Alliant Energy’s Form 10-Q for the quarter ended June 30, 2008 (File No. 1-9894))~~

~~10.5~~		Form of Amendment Number One to Key Executive Employment and Severance Agreement, by and between Alliant Energy and each of P.L. Kampling, J.H. Gallegos, T.L. Hanson, D.R. Kopp, J.O. Larsen and R.J. Durian (incorporated by reference to Exhibit 10.6 to Alliant Energy’s Form 8-K, filed December 5, 2011 (File No. 1-9894))

12.1		Ratio of Earnings to Fixed Charges for Alliant Energy

12.2		Ratio of Earnings to Fixed Charges and Ratio of Earnings to Combined Fixed Charges and Preferred Dividend Requirements for IPL

12.3		Ratio of Earnings to Fixed Charges for WPL

31.1		Certification of the Chairman, President and CEO for Alliant Energy

31.2		Certification of the Senior Vice President and CFO for Alliant Energy

31.3		Certification of the Chairman and CEO for IPL

31.4		Certification of the Senior Vice President and CFO for IPL

31.5		Certification of the Chairman and CEO for WPL

31.6		Certification of the Senior Vice President and CFO for WPL

32.1		Written Statement of the CEO and CFO Pursuant to 18 U.S.C.§1350 for Alliant Energy

32.2		Written Statement of the CEO and CFO Pursuant to 18 U.S.C.§1350 for IPL

32.3		Written Statement of the CEO and CFO Pursuant to 18 U.S.C.§1350 for WPL

101.INS*		XBRL Instance Document

101.SCH*		XBRL Taxonomy Extension Schema Document

101.CAL*		XBRL Taxonomy Extension Calculation Linkbase Document

101.LAB*		XBRL Taxonomy Extension Label Linkbase Document

101.PRE*		XBRL Taxonomy Extension Presentation Linkbase Document

101.DEF*		XBRL Taxonomy Extension Definition Linkbase Document

* Filed as Exhibit 101 to this report are the following documents formatted in Extensible Business Reporting Language (XBRL): (i) Alliant Energy’s, IPL’s and WPL’s Condensed Consolidated Statements of Income for the three and ~~six~~nine months ended ~~June~~September 30, 2015 and 2014~~2014;~~; (ii) Alliant Energy’s, IPL’s and WPL’s Condensed Consolidated Balance Sheets as of ~~June~~September 30, 2015 and December 31, 2014; (iii) Alliant Energy’s, IPL’s and WPL’s Condensed Consolidated Statements of Cash Flows for the ~~six~~nine months ended ~~June~~September 30, 2015 and 2014; and (iv) the Combined Notes to Condensed Consolidated Financial Statements.

5560



	Alliant Energy								IPL (a)								WPL (a)
	Three Months				Six Months				Three Months				Six Months				Three Months				Six Months
	2015		2014		2015		2014		2015		2014		2015		2014		2015		2014		2015		2014
401(k) costs		$5.6		$6.1		$12.3		$12.0		$2.9		$2.6		$6.3		$5.7		$2.6		$3.3		$5.5		$5.9



	Electric			Natural Gas
	Distribution Assets			Distribution Assets
	June 30, 2015			December 31, 2014
Assets held for sale:
Current assets		$9.3			$1.1
Property, plant and equipment, net	125.0			11.0
Non-current regulatory assets	20.5			7.0
Carrying value adjustment of net assets sold (a)	(8.8		)	—
Total assets held for sale	146.0			19.1
Liabilities held for sale:
Current liabilities	2.4			1.0
Other liabilities	12.6			7.1
Total liabilities held for sale	15.0			8.1
Net assets held for sale		$131.0			$11.0