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 ~~March 31,~~September 30, 2016



¨☐	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 ~~March 31,~~September 30, 2016:



Alliant Energy Corporation	Common stock, $0.01 par value, ~~113,562,651~~227,500,428 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 Nine Months Ended ~~March 31,~~September 30, 2016 and 2015	4
Condensed Consolidated Balance Sheets as of ~~March 31,~~September 30, 2016 and December 31, 2015	5
Condensed Consolidated Statements of Cash Flows for the ~~Three~~Nine Months Ended ~~March 31,~~September 30, 2016 and 2015	6
Interstate Power and Light Company:
Condensed Consolidated Statements of Income for the Three and Nine Months Ended ~~March 31,~~September 30, 2016 and 2015	7
Condensed Consolidated Balance Sheets as of ~~March 31,~~September 30, 2016 and December 31, 2015	8
Condensed Consolidated Statements of Cash Flows for the ~~Three~~Nine Months Ended ~~March 31,~~September 30, 2016 and 2015	9
Wisconsin Power and Light Company:
Condensed Consolidated Statements of Income for the Three and Nine Months Ended ~~March 31,~~September 30, 2016 and 2015	10
Condensed Consolidated Balance Sheets as of ~~March 31,~~September 30, 2016 and December 31, 2015	11
Condensed Consolidated Statements of Cash Flows for the ~~Three~~Nine Months Ended ~~March 31,~~September 30, 2016 and 2015	12
Combined Notes to Condensed Consolidated Financial Statements	13
1. Summary of Significant Accounting Policies	13
2. Regulatory Matters	1314
3. Property, Plant and Equipment	1415
4. Receivables	1516
5. Investments	1517
6. Common Equity	1617
7. Debt	1618
8. Income Taxes	1719
9. Benefit Plans	1719
10. Asset Retirement Obligations	2123
11. Fair Value Measurements	2124
12. Derivative Instruments	2427
13. Commitments and Contingencies	2528
14. Segments of Business	2831
15. Related Parties	2933
16. Discontinued Operations	3034
Item 2. Management’s Discussion and Analysis of Financial Condition and Results of Operations	3034
Executive Summary	3034
Results of Operations	3237
Strategic Overview	3745
Rate Matters	3846
Environmental Matters	3848
Legislative Matters	3848
Liquidity and Capital Resources	3848
Other Matters	4051
Market Risk Sensitive Instruments and Positions	4051
New Accounting ~~Pronouncements~~Standards	4051
Critical Accounting Policies and Estimates	4051
Other Future Considerations	4051
Item 3. Quantitative and Qualitative Disclosures About Market Risk	4053
Item 4. Controls and Procedures	4153
Part II. Other Information	4153
Item 1A. Risk Factors	4153
Item 2. Unregistered Sales of Equity Securities and Use of Proceeds	41
~~Item 5. Other Information~~	4153
Item 6. Exhibits	4253
Signatures	4254

Table of Contents

DEFINITIONS

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



Abbreviation or Acronym		Definition
2015 Form 10-K		Combined Annual Report on Form 10-K filed by Alliant Energy, IPL and WPL for the year ended Dec. 31, 2015
AEF		Alliant Energy Finance, LLC
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~~purchased power
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.
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
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



	1

Table of Contents

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 of 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 2016;

the ~~impact~~impacts of WPL’s retail electric and gas base rate freeze in Wisconsin during ~~2016;~~2016 and WPL’s pending retail base rate case for the 2017/2018 Test Period;

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 planned and potential new wind generation projects, IPL’s Marshalltown EGU, WPL’s Riverside expansion and related third party purchase options, new environmental control equipment for various fossil-fueled EGUs of IPL and WPL, ~~IPL’s construction of Marshalltown, WPL’s Riverside expansion,~~ various replacements, modernization and expansion of IPL’s and WPL’s electric and gas distribution systems, ~~Resources’ electricity output and selling price~~the proposed transfer of ~~such output from its~~the Franklin County wind farm to IPL, and the potential decommissioning of certain EGUs of IPL and WPL;

the ability to qualify for the full level of production tax credits on planned and potential new wind farms and the impact of changes to production tax credits for wind farms;

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, employee safety, 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 natural gas, purchased electricity and coal, including due to the bankruptcy of coal mining companies;

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 further 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, the Clean Power Plan, 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;



	2

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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;

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 gas distribution systems, such as leaks, explosions and mechanical problems, and compliance with gas transmission and distribution safety regulations, such as proposed rules recently issued by the Pipeline and Hazardous Materials Safety Administration;

risks associated with integration of a new customer billing and information system, which was completed in 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 assets, RMT and Whiting Petroleum, 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;

reputational damage from negative publicity, protests, fines, penalties and other negative consequences resulting in regulatory and/or legal actions;

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;

inability to access technological developments, including those related to wind turbines, solar generation, smart technology, battery storage and other future technologies;

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

impacts of ATC’s potential restructuring;

material changes in retirement and benefit plan costs;

the impact of performance-based compensation plans accruals;

the effect of accounting standards issued periodically by standard-setting bodies, including revenue recognition and lease standards;

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

impacts of the extension of bonus depreciation deductions;

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


•	factors listed in MDA and Risk Factors in Item 1A in the 2015 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.



	3

Table of Contents

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 Three Months						For the Nine Months
	Ended March 31,						Ended September 30,						Ended September 30,
	2016			2015			2016			2015			2016			2015
	(in millions, except per share amounts)						(in millions, except per share amounts)
Operating revenues:
Electric utility		$668.9			$671.3			$864.3			$835.8			$2,209.1			$2,147.5
Gas utility	152.2			198.4			39.5			38.0			248.7			288.1
Other utility	13.2			16.4			9.4			13.4			35.0			44.6
Non-regulated	9.5			11.3			11.4			11.7			30.2			33.3
Total operating revenues	843.8			897.4			924.6			898.9			2,523.0			2,513.5
Operating expenses:
Electric production fuel and purchased power	200.9			215.9			245.9			245.8			646.3			646.9
Electric transmission service	127.9			123.2			138.6			127.6			396.8			367.7
Cost of gas sold	95.2			130.8			12.5			13.6			132.3			166.3
Asset valuation charges for Franklin County wind farm							86.4			—			86.4			—
Other operation and maintenance	145.1			147.9			148.6			151.1			438.2			456.3
Depreciation and amortization	102.5			100.2			104.1			99.3			308.7			299.9
Taxes other than income taxes	26.3			26.5			25.9			25.6			77.2			78.6
Total operating expenses	697.9			744.5			762.0			663.0			2,085.9			2,015.7
Operating income	145.9			152.9			162.6			235.9			437.1			497.8
Interest expense and other:
Interest expense	48.0			46.6			48.8			46.4			144.8			139.5
Equity income from unconsolidated investments, net	(10.5		)	(6.5		)	(9.2		)	(11.1		)	(28.8		)	(28.9		)
Allowance for funds used during construction	(13.2		)	(6.8		)	(15.8		)	(9.7		)	(44.3		)	(25.1		)
Interest income and other	(0.2		)	(0.1		)	(0.1		)	(0.1		)	(0.3		)	(0.4		)
Total interest expense and other	24.1			33.2			23.7			25.5			71.4			85.1
Income from continuing operations before income taxes	121.8			119.7			138.9			210.4			365.7			412.7
Income taxes	21.6			20.5			7.5			27.8			47.2			59.5
Income from continuing operations, net of tax	100.2			99.2			131.4			182.6			318.5			353.2
Loss from discontinued operations, net of tax	(1.1		)	—			(0.4		)	(0.1		)	(2.0		)	(1.4		)
Net income	99.1			99.2			131.0			182.5			316.5			351.8
Preferred dividend requirements of Interstate Power and Light Company	2.6			2.6			2.6			2.6			7.7			7.7
Net income attributable to Alliant Energy common shareowners		$96.5			$96.6			$128.4			$179.9			$308.8			$344.1
Weighted average number of common shares outstanding (basic and diluted) (a)	113.4			111.1			227.2			226.4			227.0			225.0
Earnings per weighted average common share attributable to Alliant Energy common shareowners (basic and diluted) (a):
Income from continuing operations, net of tax		$0.86			$0.87			$0.57			$0.79			$1.37			$1.54
Loss from discontinued operations, net of tax	(0.01		)	—			—			—			(0.01		)	(0.01		)
Net income		$0.85			$0.87			$0.57			$0.79			$1.36			$1.53
Amounts attributable to Alliant Energy common shareowners:
Income from continuing operations, net of tax		$97.6			$96.6			$128.8			$180.0			$310.8			$345.5
Loss from discontinued operations, net of tax	(1.1		)	—			(0.4		)	(0.1		)	(2.0		)	(1.4		)
Net income		$96.5			$96.6			$128.4			$179.9			$308.8			$344.1
Dividends declared per common share (a)		$0.5875			$0.55			$0.29375			$0.275			$0.88125			$0.825


(a)	Amounts ~~do not~~ reflect the effects of a two-for-one common stock split ~~approved by Alliant Energy’s Board of Directors on April 20,~~distributed in May 2016. Refer to Note 6 for additional details.

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)


	March 31, 2016		December 31, 2015		September 30, 2016		December 31, 2015
	(in millions, except per share and share amounts)				(in millions, except per share and share amounts)
ASSETS
Current assets:
Cash and cash equivalents		$4.8		$5.8		$84.7		$5.8
Accounts receivable, less allowance for doubtful accounts	390.6		397.6		491.5		397.6
Production fuel, at weighted average cost	98.0		98.8		92.6		98.8
Gas stored underground, at weighted average cost	15.9		43.3		37.8		43.3
Materials and supplies, at weighted average cost	83.3		81.4		89.5		81.4
Regulatory assets	111.5		120.2		63.1		120.2
Other	64.4		79.7		98.9		79.7
Total current assets	768.5		826.8		958.1		826.8
Property, plant and equipment, net	9,626.6		9,519.1		9,920.4		9,519.1
Investments:
Investment in American Transmission Company LLC	302.5		293.3		309.9		293.3
Other	21.0		53.0		19.7		53.0
Total investments	323.5		346.3		329.6		346.3
Other assets:
Regulatory assets	1,805.7		1,788.4		1,811.7		1,788.4
Deferred charges and other	10.7		14.6		9.4		14.6
Total other assets	1,816.4		1,803.0		1,821.1		1,803.0
Total assets		$12,535.0		$12,495.2		$13,029.2		$12,495.2


LIABILITIES AND EQUITY
Current liabilities:
Current maturities of long-term debt		$313.4			$313.4			$314.0			$313.4
Commercial paper	213.4			159.8			238.3			159.8
Accounts payable	323.8			402.4			365.1			402.4
Regulatory liabilities	193.1			187.1			178.4			187.1
Other	304.8			296.6			273.9			296.6
Total current liabilities	1,348.5			1,359.3			1,369.7			1,359.3
Long-term debt, net (excluding current portion)	3,522.7			3,522.2			3,816.9			3,522.2
Other liabilities:
Deferred tax liabilities	2,424.6			2,381.2			2,530.6			2,381.2
Regulatory liabilities	517.9			550.6			497.4			550.6
Pension and other benefit obligations	446.5			451.8			455.3			451.8
Other	310.2			306.0			300.2			306.0
Total other liabilities	3,699.2			3,689.6			3,783.5			3,689.6
Commitments and contingencies (Note 13)
Equity:
Alliant Energy Corporation common equity:
Common stock - $0.01 par value - 240,000,000 shares authorized; 113,562,651 and 113,459,216 shares outstanding (a)	1.1			1.1
Common stock - $0.01 par value - 480,000,000 shares authorized; 227,500,428 and 226,918,432 shares outstanding (a)							2.3			2.3
Additional paid-in capital	1,673.7			1,663.0			1,686.0			1,661.8
Retained earnings	2,098.9			2,068.9			2,181.0			2,068.9
Accumulated other comprehensive loss	(0.4		)	(0.4		)	(0.4		)	(0.4		)
Shares in deferred compensation trust - 214,881 and 215,093 shares at a weighted average cost of $40.36 and $39.69 per share (a)	(8.7		)	(8.5		)
Shares in deferred compensation trust - 432,619 and 430,186 shares at a weighted average cost of $22.54 and $19.84 per share (a)							(9.8		)	(8.5		)
Total Alliant Energy Corporation common equity	3,764.6			3,724.1			3,859.1			3,724.1
Cumulative preferred stock of Interstate Power and Light Company	200.0			200.0			200.0			200.0
Total equity	3,964.6			3,924.1			4,059.1			3,924.1
Total liabilities and equity		$12,535.0			$12,495.2			$13,029.2			$12,495.2


(a)	Share and per share amounts ~~do not~~ reflect the effects of a two-for-one common stock split ~~approved by Alliant Energy’s Board of Directors on April 20,~~distributed in May 2016. Refer to Note 6 for additional details.

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 Three Months						For the Nine Months
	Ended March 31,						Ended September 30,
	2016			2015			2016			2015
	(in millions)						(in millions)
Cash flows from operating activities:
Net income		$99.1			$99.2			$316.5			$351.8
Adjustments to reconcile net income to net cash flows from operating activities:
Depreciation and amortization	102.5			100.2			308.7			299.9
Deferred tax expense and investment tax credits	22.8			29.7			76.7			101.0
Asset valuation charges for Franklin County wind farm							86.4			—
Other	(17.6		)	(0.1		)	(44.0		)	(2.5		)
Other changes in assets and liabilities:
Accounts receivable	(47.8		)	6.6			(101.0		)	11.7
Sales of accounts receivable	57.0			52.0			(4.0		)	(21.0		)
Gas stored underground	27.4			49.5
Accounts payable	(31.2		)	(32.8		)
Regulatory assets							36.6			(51.3		)
Regulatory liabilities	(28.7		)	(6.6		)	(66.5		)	(61.5		)
Deferred income taxes							71.8			74.1
Other	44.8			17.0			(27.2		)	(6.9		)
Net cash flows from operating activities	228.3			314.7			654.0			695.3
Cash flows used for investing activities:
Construction and acquisition expenditures:
Utility business	(220.4		)	(226.0		)	(743.6		)	(678.9		)
Alliant Energy Corporate Services, Inc. and non-regulated businesses	(18.8		)	(19.8		)	(43.3		)	(47.5		)
Proceeds from Minnesota electric and natural gas distribution asset sales							—			138.1
Other	19.2			(5.1		)	15.1			(24.7		)
Net cash flows used for investing activities	(220.0		)	(250.9		)	(771.8		)	(613.0		)
Cash flows used for financing activities:
Cash flows from financing activities:
Common stock dividends	(66.5		)	(60.7		)	(199.8		)	(185.1		)
Proceeds from issuance of common stock, net	6.2			122.1			20.4			145.4
Proceeds from issuance of long-term debt							300.0			250.7
Payments to retire long-term debt							(1.9		)	(182.0		)
Net change in commercial paper	53.6			(99.8		)	78.5			(32.2		)
Other	(2.6		)	15.3			(0.5		)	3.2
Net cash flows used for financing activities	(9.3		)	(23.1		)
Net increase (decrease) in cash and cash equivalents	(1.0		)	40.7
Net cash flows from financing activities							196.7			—
Net increase in cash and cash equivalents							78.9			82.3
Cash and cash equivalents at beginning of period	5.8			56.9			5.8			56.9
Cash and cash equivalents at end of period		$4.8			$97.6			$84.7			$139.2
Supplemental cash flows information:
Cash (paid) refunded during the period for:
Interest, net of capitalized interest		($44.5	)		($40.2	)		($140.7	)		($133.9	)
Income taxes, net		$—			$0.1			($8.3	)		$—
Significant non-cash investing and financing activities:
Accrued capital expenditures		$105.0			$119.0			$99.9			$180.0

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



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Table of Contents

INTERSTATE POWER AND LIGHT COMPANY

CONDENSED CONSOLIDATED STATEMENTS OF INCOME (UNAUDITED)


	For the Three Months						For the Three Months						For the Nine Months
	Ended March 31,						Ended September 30,						Ended September 30,
	2016			2015			2016			2015			2016			2015
	(in millions)						(in millions)
Operating revenues:
Electric utility		$361.6			$362.6			$483.2			$468.6			$1,209.2			$1,170.6
Gas utility	84.2			111.2			23.9			23.1			142.6			164.1
Steam and other	12.9			15.2			9.1			12.9			34.1			41.1
Total operating revenues	458.7			489.0			516.2			504.6			1,385.9			1,375.8
Operating expenses:
Electric production fuel and purchased power	99.4			110.1			125.0			131.4			324.8			332.0
Electric transmission service	86.5			83.9			95.9			87.5			270.7			249.3
Cost of gas sold	52.4			71.0			8.0			9.4			76.3			93.4
Other operation and maintenance	92.0			92.6			94.8			94.3			279.8			287.5
Depreciation and amortization	52.7			51.8			52.7			51.2			157.8			155.1
Taxes other than income taxes	13.7			14.1			13.9			13.8			40.6			42.2
Total operating expenses	396.7			423.5			390.3			387.6			1,150.0			1,159.5
Operating income	62.0			65.5			125.9			117.0			235.9			216.3
Interest expense and other:
Interest expense	24.9			24.1			25.5			23.8			75.4			71.8
Allowance for funds used during construction	(10.3		)	(5.3		)	(13.8		)	(7.3		)	(36.2		)	(19.3		)
Interest income and other	—			(0.1		)	—			0.1			(0.1		)	—
Total interest expense and other	14.6			18.7			11.7			16.6			39.1			52.5
Income before income taxes	47.4			46.8			114.2			100.4			196.8			163.8
Income tax benefit	(0.8		)	(3.3		)	(2.5		)	(18.7		)	(2.5		)	(24.4		)
Net income	48.2			50.1			116.7			119.1			199.3			188.2
Preferred dividend requirements	2.6			2.6			2.6			2.6			7.7			7.7
Earnings available for common stock		$45.6			$47.5			$114.1			$116.5			$191.6			$180.5

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.



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Table of Contents

INTERSTATE POWER AND LIGHT COMPANY

CONDENSED CONSOLIDATED BALANCE SHEETS (UNAUDITED)


	March 31, 2016		December 31, 2015		September 30, 2016		December 31, 2015
	(in millions, except per share and share amounts)				(in millions, except per share and share amounts)
ASSETS
Current assets:
Cash and cash equivalents		$3.0		$4.5		$77.7		$4.5
Accounts receivable, less allowance for doubtful accounts	180.9		200.0		266.8		200.0
Production fuel, at weighted average cost	60.8		60.2		70.0		60.2
Gas stored underground, at weighted average cost	3.1		18.2		17.4		18.2
Materials and supplies, at weighted average cost	47.0		45.7		50.0		45.7
Regulatory assets	29.7		39.6		15.0		39.6
Other	13.8		28.2		37.2		28.2
Total current assets	338.3		396.4		534.1		396.4
Property, plant and equipment, net	4,993.8		4,925.1		5,220.1		4,925.1
Investments	0.7		19.6		0.8		19.6
Other assets:
Regulatory assets	1,376.2		1,363.0		1,402.2		1,363.0
Deferred charges and other	4.4		5.0		3.8		5.0
Total other assets	1,380.6		1,368.0		1,406.0		1,368.0
Total assets		$6,713.4		$6,709.1		$7,161.0		$6,709.1


LIABILITIES AND EQUITY
Current liabilities:
Accounts payable		$153.5		$197.2		$172.6		$197.2
Accounts payable to associated companies					55.0		37.7
Regulatory liabilities	133.1		130.9		132.5		130.9
Accrued taxes					41.2		67.6
Other	198.3		203.0		85.9		97.7
Total current liabilities	484.9		531.1		487.2		531.1
Long-term debt, net (excluding current portion)	1,857.4		1,856.9		2,153.1		1,856.9
Other liabilities:
Deferred tax liabilities	1,408.9		1,378.0		1,493.6		1,378.0
Regulatory liabilities	335.1		358.3		298.9		358.3
Pension and other benefit obligations	160.5		160.2		161.2		160.2
Other	223.7		229.3		229.1		229.3
Total other liabilities	2,128.2		2,125.8		2,182.8		2,125.8
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	1,447.9		1,407.8		1,472.8		1,407.8
Retained earnings	561.6		554.1		631.7		554.1
Total Interstate Power and Light Company common equity	2,042.9		1,995.3		2,137.9		1,995.3
Cumulative preferred stock	200.0		200.0		200.0		200.0
Total equity	2,242.9		2,195.3		2,337.9		2,195.3
Total liabilities and equity		$6,713.4		$6,709.1		$7,161.0		$6,709.1

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



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INTERSTATE POWER AND LIGHT COMPANY

CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS (UNAUDITED)


	For the Three Months						For the Nine Months
	Ended March 31,						Ended September 30,
	2016			2015			2016			2015
	(in millions)						(in millions)
Cash flows from operating activities:
Net income		$48.2			$50.1			$199.3			$188.2
Adjustments to reconcile net income to net cash flows from operating activities:
Depreciation and amortization	52.7			51.8			157.8			155.1
Other	3.2			12.8			24.3			32.3
Other changes in assets and liabilities:
Accounts receivable	(37.5		)	(2.2		)	(66.5		)	(8.3		)
Sales of accounts receivable	57.0			52.0			(4.0		)	(21.0		)
Gas stored underground	15.1			26.4
Accounts payable	(19.5		)	(36.1		)
Regulatory assets							(14.1		)	(38.1		)
Regulatory liabilities	(23.6		)	(11.8		)	(64.5		)	(63.1		)
Deferred income taxes							67.7			72.0
Other	20.8			27.1			(43.5		)	0.9
Net cash flows from operating activities	116.4			170.1			256.5			318.0
Cash flows used for investing activities:
Utility construction and acquisition expenditures	(135.3		)	(150.6		)	(436.5		)	(432.6		)
Proceeds from Minnesota electric and natural gas distribution asset sales							—			138.1
Other	12.1			(5.7		)	1.1			(24.9		)
Net cash flows used for investing activities	(123.2		)	(156.3		)	(435.4		)	(319.4		)
Cash flows from (used for) financing activities:
Cash flows from financing activities:
Common stock dividends	(38.1		)	(35.0		)	(114.0		)	(105.0		)
Capital contributions from parent	40.0			—			65.0			100.0
Proceeds from issuance of long-term debt							300.0			250.0
Payments to retire long-term debt							—			(150.0		)
Other	3.4			18.5			1.1			0.5
Net cash flows from (used for) financing activities	5.3			(16.5		)
Net decrease in cash and cash equivalents	(1.5		)	(2.7		)
Net cash flows from financing activities							252.1			95.5
Net increase in cash and cash equivalents							73.2			94.1
Cash and cash equivalents at beginning of period	4.5			5.3			4.5			5.3
Cash and cash equivalents at end of period		$3.0			$2.6			$77.7			$99.4
Supplemental cash flows information:
Cash (paid) refunded during the period for:
Interest		($22.6	)		($18.4	)		($72.5	)		($66.7	)
Income taxes, net		$1.1			$6.2			$0.7			$31.1
Significant non-cash investing and financing activities:
Accrued capital expenditures		$47.6			$82.8			$44.5			$115.5

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



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WISCONSIN POWER AND LIGHT COMPANY

CONDENSED CONSOLIDATED STATEMENTS OF INCOME (UNAUDITED)


	For the Three Months						For the Three Months						For the Nine Months
	Ended March 31,						Ended September 30,						Ended September 30,
	2016			2015			2016			2015			2016			2015
	(in millions)						(in millions)
Operating revenues:
Electric utility		$307.3			$308.7			$381.1			$367.2			$999.9			$976.9
Gas utility	68.0			87.2			15.6			14.9			106.1			124.0
Other	0.3			1.2			0.3			0.5			0.9			3.5
Total operating revenues	375.6			397.1			397.0			382.6			1,106.9			1,104.4
Operating expenses:
Electric production fuel and purchased power	101.5			105.8			120.9			114.4			321.5			314.9
Electric transmission service	41.4			39.3			42.7			40.1			126.1			118.4
Cost of gas sold	42.8			59.8			4.5			4.2			56.0			72.9
Other operation and maintenance	52.1			54.0			54.2			57.0			157.2			167.7
Depreciation and amortization	47.4			46.0			48.7			45.7			143.5			137.5
Taxes other than income taxes	11.6			11.4			11.0			10.9			33.8			33.6
Total operating expenses	296.8			316.3			282.0			272.3			838.1			845.0
Operating income	78.8			80.8			115.0			110.3			268.8			259.4
Interest expense and other:
Interest expense	22.9			23.1			22.9			23.1			68.7			69.5
Equity income from unconsolidated investments	(10.7		)	(7.8		)	(9.3		)	(11.1		)	(29.0		)	(30.2		)
Allowance for funds used during construction	(2.9		)	(1.5		)	(2.0		)	(2.4		)	(8.1		)	(5.8		)
Interest income and other	(0.1		)	0.1			0.1			(0.3		)	(0.2		)	(0.3		)
Total interest expense and other	9.2			13.9			11.7			9.3			31.4			33.2
Income before income taxes	69.6			66.9			103.3			101.0			237.4			226.2
Income taxes	22.6			21.8			33.7			32.6			77.1			73.0
Net income	47.0			45.1			69.6			68.4			160.3			153.2
Net income attributable to noncontrolling interest	0.5			0.2			0.6			0.4			1.6			1.1
Earnings available for common stock		$46.5			$44.9			$69.0			$68.0			$158.7			$152.1

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

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



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Table of Contents

WISCONSIN POWER AND LIGHT COMPANY

CONDENSED CONSOLIDATED BALANCE SHEETS (UNAUDITED)


	March 31, 2016		December 31, 2015		September 30, 2016		December 31, 2015
	(in millions, except per share and share amounts)				(in millions, except per share and share amounts)
ASSETS
Current assets:
Cash and cash equivalents		$1.3		$0.4		$5.6		$0.4
Accounts receivable, less allowance for doubtful accounts	192.6		185.4		190.7		185.4
Production fuel, at weighted average cost	37.2		38.6		22.6		38.6
Gas stored underground, at weighted average cost	12.8		25.1		20.4		25.1
Materials and supplies, at weighted average cost	34.0		33.5		35.7		33.5
Regulatory assets	81.8		80.6		48.1		80.6
Other	51.2		59.9		53.9		59.9
Total current assets	410.9		423.5		377.0		423.5
Property, plant and equipment, net	4,141.6		4,103.7		4,289.1		4,103.7
Investments:
Investment in American Transmission Company LLC	302.5		293.3		309.9		293.3
Other	14.7		15.4		13.4		15.4
Total investments	317.2		308.7		323.3		308.7
Other assets:
Regulatory assets	429.5		425.4		409.5		425.4
Deferred charges and other	6.7		9.1		6.9		9.1
Total other assets	436.2		434.5		416.4		434.5
Total assets		$5,305.9		$5,270.4		$5,405.8		$5,270.4


LIABILITIES AND EQUITY
Current liabilities:
Commercial paper		$25.5		$19.9		$11.8		$19.9
Accounts payable	111.0		136.0		122.3		136.0
Accounts payable to associated companies					32.8		21.6
Regulatory liabilities	60.0		56.2		45.9		56.2
Other	146.7		124.8		91.0		103.2
Total current liabilities	343.2		336.9		303.8		336.9
Long-term debt, net (excluding current portion)	1,534.2		1,533.9		1,534.9		1,533.9
Other liabilities:
Deferred tax liabilities	1,025.1		1,005.4		1,108.8		1,005.4
Regulatory liabilities	182.8		192.3		198.5		192.3
Capital lease obligations - Sheboygan Falls Energy Facility	82.1		83.6		78.9		83.6
Pension and other benefit obligations	186.4		188.7		186.2		188.7
Other	169.0		162.0		162.4		162.0
Total other liabilities	1,645.4		1,632.0		1,734.8		1,632.0
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	959.1		959.0		959.0		959.0
Retained earnings	743.8		731.1		788.6		731.1
Total Wisconsin Power and Light Company common equity	1,769.1		1,756.3		1,813.8		1,756.3
Noncontrolling interest	14.0		11.3		18.5		11.3
Total equity	1,783.1		1,767.6		1,832.3		1,767.6
Total liabilities and equity		$5,305.9		$5,270.4		$5,405.8		$5,270.4

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



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WISCONSIN POWER AND LIGHT COMPANY

CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS (UNAUDITED)


	For the Three Months						For the Nine Months
	Ended March 31,						Ended September 30,
	2016			2015			2016			2015
	(in millions)						(in millions)
Cash flows from operating activities:
Net income		$47.0			$45.1			$160.3			$153.2
Adjustments to reconcile net income to net cash flows from operating activities:
Depreciation and amortization	47.4			46.0			143.5			137.5
Deferred tax expense and investment tax credits	18.8			10.1			97.9			60.0
Other	(10.9		)	(0.9		)	(20.3		)	(8.3		)
Other changes in assets and liabilities:
Gas stored underground	12.3			23.1
Accounts payable	(15.3		)	4.0
Regulatory assets							50.7			(13.2		)
Derivative liabilities	19.5			4.6			(13.3		)	19.0
Other	4.8			25.8			20.5			27.7
Net cash flows from operating activities	123.6			157.8			439.3			375.9
Cash flows used for investing activities:
Utility construction and acquisition expenditures	(85.1		)	(75.4		)	(307.1		)	(246.3		)
Other	(6.3		)	(3.0		)	(19.6		)	(13.3		)
Net cash flows used for investing activities	(91.4		)	(78.4		)	(326.7		)	(259.6		)
Cash flows used for financing activities:
Common stock dividends	(33.8		)	(31.8		)	(101.2		)	(95.3		)
Payments to retire long-term debt							—			(30.6		)
Other	2.5			(3.4		)	(6.2		)	(1.4		)
Net cash flows used for financing activities	(31.3		)	(35.2		)	(107.4		)	(127.3		)
Net increase in cash and cash equivalents	0.9			44.2
Net increase (decrease) in cash and cash equivalents							5.2			(11.0		)
Cash and cash equivalents at beginning of period	0.4			46.7			0.4			46.7
Cash and cash equivalents at end of period		$1.3			$90.9			$5.6			$35.7
Supplemental cash flows information:
Cash (paid) refunded during the period for:
Interest		($21.9	)		($22.6	)		($67.7	)		($69.2	)
Income taxes, net		($7.4	)		$9.1			$19.6			($10.0	)
Significant non-cash investing and financing activities:
Accrued capital expenditures		$49.7			$32.9			$50.8			$57.2

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



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ALLIANT ENERGY CORPORATION

INTERSTATE POWER AND LIGHT COMPANY

WISCONSIN POWER AND LIGHT COMPANY

COMBINED NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (UNAUDITED)

NOTE 1. SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES

NOTE 1(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 ~~three~~nine months ended ~~March 31,~~September 30, 2016 are not necessarily indicative of results that may be expected for the year ending December 31, 2016. 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 the fourth quarter of 2015, IPL and WPL implemented a change in method of recording income taxes that impacts the separate financial statements of IPL and WPL. As discussed in Note 6, all Alliant Energy share and per share amounts have been adjusted to reflect a two-for-one common stock split distributed in May 2016. As required by GAAP, all prior period financial statements and disclosures presented herein have been restated to reflect ~~these changes.~~the tax method change and common stock split.

NOTE 1(b) New Accounting Standards -

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. Alliant Energy, IPL and WPL currently expect to adopt this standard on January 1, 2018 and are ~~currently~~ evaluating the impact of this standard on their financial condition and results of operations.

Leases - In February 2016, the Financial Accounting Standards Board issued an accounting standard requiring lease assets and lease liabilities, including operating leases, to be recognized on the balance sheet for all leases with terms longer than 12 months. The standard also requires disclosure of key information about leasing arrangements. Alliant Energy, IPL and WPL are required to adopt this standard on January 1, 2019 and are currently evaluating the impact of this standard on their financial condition and results of operations. Early adoption of this standard is permitted.

NOTE 1(c) Property, Plant and Equipment -

Utility Plant -

Depreciation - In September 2016, the PSCW issued an order approving the implementation of updated depreciation rates for WPL effective January 1, 2017 as a result of a recently completed depreciation study. WPL estimates the new average rates of depreciation for its electric generation, electric distribution and gas properties will be approximately 3.2%, 2.6% and 2.3%, respectively, during 2017.



	13

Table of Contents

NOTE 2. REGULATORY MATTERS

Regulatory Assets and Regulatory Liabilities -

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

Alliant Energy IPL WPL
March 31,
2016 December 31,
2015 March 31,
2016 December 31,
2015 March 31,
2016 December 31,
2015
Tax-related
$1,002.7

$987.7

$972.0

$958.2

$30.7

$29.5
Pension and OPEB costs 570.0
579.5
293.6
298.1
276.4
281.4
AROs 96.1
92.4
54.1
50.8
42.0
41.6
Derivatives 86.6
70.6
25.5
28.2
61.1
42.4
WPL’s EGUs retired early 43.2
45.0
—
—
43.2
45.0
Emission allowances 26.7
26.9
26.7
26.9
—
—
Commodity cost recovery 26.3
35.9
0.3
2.8
26.0
33.1
Other 65.6
70.6
33.7
37.6
31.9
33.0

$1,917.2

$1,908.6

$1,405.9

$1,402.6

$511.3

$506.0



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	Alliant Energy				IPL				WPL
	September 30, 2016		December 31, 2015		September 30, 2016		December 31, 2015		September 30, 2016		December 31, 2015
Tax-related		$1,033.5		$987.7		$1,000.7		$958.2		$32.8		$29.5
Pension and OPEB costs	551.0		579.5		284.7		298.1		266.3		281.4
AROs	103.9		92.4		61.5		50.8		42.4		41.6
WPL’s EGUs retired early	43.1		45.0		—		—		43.1		45.0
Derivatives	39.0		70.6		10.6		28.2		28.4		42.4
Emission allowances	26.3		26.9		26.3		26.9		—		—
Commodity cost recovery	10.1		35.9		0.4		2.8		9.7		33.1
Other	67.9		70.6		33.0		37.6		34.9		33.0
		$1,874.8		$1,908.6		$1,417.2		$1,402.6		$457.6		$506.0

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


	Alliant Energy				IPL				WPL				Alliant Energy				IPL				WPL
	March 31, 2016		December 31, 2015		March 31, 2016		December 31, 2015		March 31, 2016		December 31, 2015		September 30, 2016		December 31, 2015		September 30, 2016		December 31, 2015		September 30, 2016		December 31, 2015
Cost of removal obligations		$408.1		$406.0		$263.1		$260.4		$145.0		$145.6		$410.6		$406.0		$267.2		$260.4		$143.4		$145.6
IPL’s tax benefit riders	141.1		159.2		141.1		159.2		—		—		103.1		159.2		103.1		159.2		—		—
Electric transmission cost recovery	51.4		43.5		25.5		21.9		25.9		21.6		54.5		43.5		25.0		21.9		29.5		21.6
Commodity cost recovery													39.1		37.6		15.1		23.5		24.0		14.1
Energy efficiency cost recovery	41.6		48.3		—		—		41.6		48.3		28.0		48.3		—		—		28.0		48.3
Commodity cost recovery	35.2		37.6		20.4		23.5		14.8		14.1
Other	33.6		43.1		18.1		24.2		15.5		18.9		40.5		43.1		21.0		24.2		19.5		18.9
		$711.0		$737.7		$468.2		$489.2		$242.8		$248.5		$675.8		$737.7		$431.4		$489.2		$244.4		$248.5

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 ~~three~~nine months ended ~~March 31,~~September 30, 2016, Alliant Energy’s and IPL’s tax-related regulatory assets increased primarily due to property-related differences for qualifying repair expenditures.

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 ~~three~~nine months ended ~~March 31,~~September 30, 2016, Alliant Energy’s and IPL’s “IPL’s tax benefit riders” regulatory liabilities decreased by ~~$18~~$56 million as follows (in millions):



Electric tax benefit rider credits		$1547
Gas tax benefit rider credits	39
		$1856

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

Utility Rate Cases -

WPL’s Wisconsin Retail Electric and Gas Rate Case (2017/2018 Test Period) - In May 2016, WPL filed a retail base rate case with the PSCW based on a forward-looking test period that includes 2017 and 2018. WPL’s filing was based on a stipulated agreement reached between PSCW staff, intervener groups and WPL. The filing requested approval for WPL to implement a $13 million, or approximately 1%, increase in annual rates for WPL’s retail electric customers. The net requested increase for 2017 compared to WPL’s retail electric rate case for the 2015/2016 Test Period reflected a $65 million increase in base rates, partially offset by a $52 million reduction in fuel-related costs, using a preliminary estimate for 2017 fuel-related costs. The filing also requested approval for WPL to implement a $9 million, or approximately 13%, increase in



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annual base rates for WPL’s retail gas customers. Any rate changes granted from this request are expected to be effective January 1, 2017 and extend through the end of 2018. WPL currently expects a decision from the PSCW regarding this base rate case filing in the fourth quarter of 2016.

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. For the three and nine months ended ~~March 31,~~September 30, IPL recorded billing credits to reduce retail electric customers’ bills as follows (in millions):

2016 2015
Billing credits to reduce retail electric customers’ bills $2
$6



	Three Months			Nine Months
	2016	2015		2016		2015
Billing credits to reduce retail electric customers’ bills	$3		$7		$7		$19

WPL’s Retail Fuel-related Rate Filing (2016 Test Year) - Pursuant to a 2015 PSCW order, WPL’s 2016 fuel-related costs will be subject to deferral if they are 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 September 30, 2016 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, 2016, fuel-related costs outside of the approved range were $9 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 (2015 Test Year) - Pursuant to a 2014 PSCW order, WPL’s 2015 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 in 2015 were lower than fuel-related costs used to determine rates for such period resulting in an over-collection of fuel-related costs. Pursuant to an August 2016 PSCW order, WPL will refund $10 million, including interest, to its retail electric customers in the fourth quarter of 2016 for these over-collections.

NOTE 3. PROPERTY, PLANT AND EQUIPMENT

Utility -

Emission Controls Project -

WPL’s Edgewater Unit 5 - ~~WPL is currently constructing a~~Construction of the scrubber and baghouse at Edgewater Unit 5 ~~to reduce SO2 and mercury emissions at the EGU. Construction began~~was completed in ~~2014 and is expected to be completed in~~July 2016. As of ~~March 31,~~September 30, 2016, Alliant Energy and WPL recorded capitalized expenditures ~~for construction work in progress~~ of ~~$207~~$223 million and AFUDC of ~~$10~~$12 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 the second quarter of 2017. As of ~~March 31,~~September 30, 2016, Alliant Energy and IPL recorded capitalized expenditures for construction work in progress of ~~$492~~$600 million and AFUDC of ~~$33~~$56 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 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. In 2015, IPL completed the sale of its Minnesota electric distribution assets and received proceeds of $129 million. The proceeds from the natural gas distribution assets were used for general corporate purposes and the proceeds from the electric distribution assets were used to reduce cash amounts 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 “Other operation and maintenance” in their income statements for the nine months ended September 30, 2015.

Non-regulated and Other -

Non-regulated Generation -

Franklin County Wind Farm - Based on an evaluation of the strategic options for the Franklin County wind farm performed in the third quarter of 2016, Alliant Energy concluded, as of September 30, 2016, it was probable the Franklin County wind farm will be transferred to IPL. As a result, Alliant Energy performed an impairment analysis of such assets in the third quarter of 2016. The impairment analysis evaluated the value of the assets and a reasonable estimate of the amount of costs associated with the Franklin County wind farm that would be allowed for recovery for IPL’s electric rate-making purposes. Based on various analyses, including discounted cash flows projected from the Franklin County wind farm, recently executed purchased power agreements associated with wind generating facilities located near the Franklin County wind farm, and the



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cost of new wind farms identified through IPL’s planned wind expansion, the current value of the Franklin County wind farm assets as of September 30, 2016 was determined to be approximately $33 million, subject to working capital adjustments. Alliant Energy concluded such value represents a reasonable estimate of the amount IPL will be allowed for recovery for IPL’s electric rate-making purposes. As a result, the carrying amount of the Franklin County wind farm was reduced to its current value, resulting in non-cash, pre-tax asset valuation charges of $86 million (after-tax charges of $51 million, or $0.23 per share) in the third quarter of 2016. Alliant Energy recorded such charges as a reduction to “Property, plant and equipment, net” on its balance sheet in 2016 and charges to “Asset valuation charges for Franklin County wind farm” in its income statements for the three and nine months ended September 30, 2016.

IPL currently anticipates requesting approval from FERC in the fourth quarter of 2016 to transfer the Franklin County wind farm to IPL and expects to complete such transfer in the first quarter of 2017. The final amount to be recovered for IPL’s electric rate-making purposes will be determined by the IUB as part of IPL’s Iowa retail electric rate case for the 2016 Test Year, currently anticipated to be filed in the second quarter of 2017, and therefore the final asset valuation charges are subject to change.

NOTE 4. RECEIVABLES

Sales of Accounts Receivable - IPL maintains a Receivables Agreement whereby it may sell its customer accounts receivables, unbilled revenues and certain other accounts receivables to a third party through wholly-owned and consolidated special purpose entities. In March 2016, IPL extended through March 2018 the purchase commitment from the third party to which it sells its receivables. The transfers of receivables meet the criteria for sale accounting established by the transfer of financial assets accounting rules. As of ~~March 31,~~September 30, 2016, IPL sold ~~$220.5~~$252.9 million of receivables to the third party, received ~~$62.0~~$1.0 million in cash proceeds and recorded deferred proceeds of ~~$154.2~~$239.7 million.

IPL’s maximum and average outstanding cash proceeds related to the sales of accounts receivable program for the three and nine months ended ~~March 31~~September 30 were as follows (in millions):


					Three Months				Nine Months
	2016		2015		2016		2015		2016		2015
Maximum outstanding aggregate cash proceeds (based on daily outstanding balances)		$75.0		$118.0		$172.0		$137.0		$172.0		$137.0
Average outstanding aggregate cash proceeds (based on daily outstanding balances)	39.1		68.0		112.3		41.2		91.5		62.1

For the three and nine months ended ~~March 31,~~September 30, 2016 and 2015, 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):


	March 31, 2016		December 31, 2015		September 30, 2016		December 31, 2015
Customer accounts receivable		$142.7		$109.7		$172.9		$109.7
Unbilled utility revenues	77.5		71.3		79.8		71.3
Other receivables	0.3		0.1		0.2		0.1
Receivables sold to third party	220.5		181.1		252.9		181.1
Less: cash proceeds (a)	62.0		5.0		1.0		5.0
Deferred proceeds	158.5		176.1		251.9		176.1
Less: allowance for doubtful accounts	4.3		4.1		12.2		4.1
Fair value of deferred proceeds		$154.2		$172.0		$239.7		$172.0


(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.

As of ~~March 31,~~September 30, 2016, outstanding receivables past due under the Receivables Agreement were ~~$47.5~~$64.5 million. Additional attributes of IPL’s receivables sold under the Receivables Agreement for the three and nine months ended ~~March 31~~September 30 were as follows (in millions):


					Three Months					Nine Months
	2016		2015		2016			2015		2016			2015
Collections reinvested in receivables		$440.2		$505.9		$499.7			$480.1		$1,362.1			$1,403.1
Credit losses, net of recoveries	0.4		1.0
Write-offs (recoveries), net					(0.3		)	3.3		(0.6		)	6.8



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In connection with the implementation of IPL’s new customer billing and information system in the first quarter of 2016, IPL postponed the write-off of customer bills, resulting in lower write-offs for the three and nine months ended September 30, 2016.

NOTE 5. INVESTMENTS

NOTE 5(a) Unconsolidated Equity Investments - Equity (income) loss from unconsolidated investments accounted for under the equity method of accounting for the three and nine months ended ~~March 31~~September 30 was as follows (in millions):


													Alliant Energy												WPL
	Alliant Energy						WPL						Three Months						Nine Months						Three Months						Nine Months
	2016			2015			2016			2015			2016			2015			2016			2015			2016			2015			2016			2015
ATC		($10.7	)		($7.8	)		($10.7	)		($7.8	)		($9.1	)		($10.9	)		($28.6	)		($29.6	)		($9.1	)		($10.9	)		($28.6	)		($29.6	)
Other	0.2			1.3			—			—			(0.1		)	(0.2		)	(0.2		)	0.7			(0.2		)	(0.2		)	(0.4		)	(0.6		)
		($10.5	)		($6.5	)		($10.7	)		($7.8	)		($9.2	)		($11.1	)		($28.8	)		($28.9	)		($9.3	)		($11.1	)		($29.0	)		($30.2	)

MISO Transmission Owner Return on Equity Complaints- A group of MISO cooperative and municipal utilities previously filed two complaints with FERC requesting a reduction of the base return on equity used by MISO transmission owners, including ATC. In September 2016, FERC issued an order on the first complaint to reduce the base return on equity for the refund period from November 12, 2013 through February 11, 2015. In June 2016, a FERC administrative law judge issued an initial decision regarding the second complaint recommending a reduction of the base return on equity for the refund period from February 12, 2015 through May 11, 2016. A final decision on the second complaint from FERC is currently expected in the first half of 2017. Alliant Energy and WPL have realized a cumulative $24 million of reductions in the amount of equity income from ATC as a result of the two complaints through September 30, 2016, including $9 million during the nine months ended September 30, 2016.

NOTE 5(b) Cash Surrender Value of Life Insurance Policies - During the ~~three~~nine months ended ~~March 31,~~September 30, 2016, certain of Alliant Energy’s and IPL’s company-owned life insurance policies were liquidated. The related proceeds of ~~$26~~$31 million and ~~$18~~$19 million were recorded in investing activities in Alliant Energy’s and IPL’s cash flows statements, respectively.



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NOTE 6. COMMON EQUITY

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



Shares outstanding, January 1, 2016	~~113,459,216~~226,918,432
Shareowner Direct Plan issuances	~~92,231~~559,588
Equity-based compensation plans (Note 9(b))	~~11,204~~22,408
Shares outstanding, ~~March 31,~~September 30, 2016	~~113,562,651~~227,500,428

At-the-Market Offering Program - During the nine months ended September 30, 2015, Alliant Energy issued 4,373,234 shares of common stock through an at-the-market offering 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.

Common Stock Split - On April 20, 2016, Alliant Energy’s Board of Directors approved a two-for-one common stock split and a proportionate increase in the number of authorized shares of common stock of Alliant Energy from 240 million shares to 480 million shares to implement the stock split. Alliant Energy shareowners of record at the close of business on May 4, 2016 ~~will receive~~received one additional share of Alliant Energy common stock for each share held on that date. The proportionate interest that a shareowner owns in Alliant Energy ~~will~~did not change as a result of the stock split. The additional shares ~~are expected to be~~were distributed on May 19, 2016 and post-split trading ~~is expected to begin~~began on May 20, 2016. ~~Based on common shares outstanding as of March 31, 2016, upon the completion of the stock split,~~All Alliant Energy ~~will have approximately 227 million shares of common stock outstanding. Except as disclosed in the pro forma EPS information below, all~~ share and per share amounts ~~for the~~ ~~three months ended March 31~~, ~~2016~~ ~~and 2015~~ in this report have been reflected on a ~~pre-split~~post-split basis. ~~The stock split will require all historical common stock shares and EPS data to be recast in the~~ ~~second~~ ~~quarter of 2016. For the~~ ~~three months ended March 31, pro forma basic and diluted EPS attributable to Alliant Energy common shareowners to reflect the two-for-one common stock split is as follows:~~

2016 2015
Basic and diluted EPS:
As reported
$0.85

$0.87
Pro forma 0.43
0.43

Dividend Restrictions - As of ~~March 31,~~September 30, 2016, IPL’s amount of retained earnings that were free of dividend restrictions was $~~562~~632 million. As of ~~March 31,~~September 30, 2016, WPL’s amount of retained earnings that were free of dividend restrictions was $~~101~~34 million for the remainder of 2016.

Restricted Net Assets of Subsidiaries - As of ~~March 31,~~September 30, 2016, 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 $1.5 billion and $~~1.7~~1.8 billion, respectively.



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Capital Transactions with Subsidiaries - For the ~~three~~nine months ended ~~March 31,~~September 30, 2016, IPL received capital contributions of ~~$40.0~~$65.0 million from its parent company. For the ~~three~~nine months ended ~~March 31,~~September 30, 2016, IPL and WPL paid common stock dividends of $~~38.1~~114.0 million and $~~33.8~~101.2 million, respectively, to their parent company.

Comprehensive Income - For the three and nine months ended ~~March 31,~~September 30, 2016 and 2015, 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 nine months ended ~~March 31,~~September 30, 2016 and 2015, 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.

NOTE 7. DEBT

NOTE 7(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
March 31, 2016	(Consolidated)	Company	IPL	WPL
September 30, 2016					(Consolidated)	Company	IPL	WPL
Commercial paper:
Amount outstanding	$213.4	$187.9	$—	$25.5	$238.3	$226.5	$—	$11.8
Weighted average remaining maturity	2 days	2 days	N/A	1 day	4 days	4 days	N/A	3 days
Weighted average interest rates	0.6%	0.6%	N/A	0.4%	0.6%	0.7%	N/A	0.4%
Available credit facility capacity	$786.6	$112.1	$300.0	$374.5	$761.7	$73.5	$300.0	$388.2



	Alliant Energy						IPL						WPL
Three Months Ended September 30	2016			2015			2016			2015			2016	2015
Maximum amount outstanding (based on daily outstanding balances)		$248.0			$181.2			$3.1			$18.4		$55.4	$—
Average amount outstanding (based on daily outstanding balances)		$220.1			$122.4			$0.1			$0.5		$36.4	$—
Weighted average interest rates	0.6		%	0.4		%	0.6		%	0.4		%	0.4%	N/A
Nine Months Ended September 30
Maximum amount outstanding (based on daily outstanding balances)		$248.0			$181.2			$3.1			$18.4		$62.9	$—
Average amount outstanding (based on daily outstanding balances)		$210.7			$114.5			$—			$0.2		$33.2	$—
Weighted average interest rates	0.6		%	0.4		%	0.6		%	0.4		%	0.4%	N/A

NOTE 7(b) Long-term Debt - In September 2016, IPL issued $300 million of 3.7% senior debentures due 2046. The proceeds from the issuance were used by IPL to reduce cash amounts received from its sales of accounts receivable program, reduce commercial paper classified as long-term debt by $100 million and for general corporate purposes.

In October 2016, AEF entered into a $500 million variable-rate (1.3% at October 31, 2016) term loan credit agreement and used the proceeds from borrowings under this agreement to retire borrowings under Alliant Energy’s and Franklin County Holdings LLC’s variable-rate term loan credit agreements that matured in 2016, reduce outstanding commercial paper and for general corporate purposes. AEF’s term loan credit agreement expires in October 2018 and includes substantially the same financial covenants that are included in Alliant Energy’s credit facility agreement.



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Alliant Energy IPL WPL
Three Months Ended March 31 2016 2015 2016 2015 2016 2015
Maximum amount outstanding
(based on daily outstanding balances)

$242.6

$151.3

$—

$1.4
$55.7
$—
Average amount outstanding
(based on daily outstanding balances)

$199.0

$127.9

$—

$—
$25.8
$—
Weighted average interest rates 0.6 % 0.4 % N/A
0.4 % 0.4% N/A

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 March 31	2016		2015		2016		2015		2016		2015
Three Months Ended September 30													2016		2015		2016		2015		2016		2015
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	(8.7	)	(9.9	)	(20.7	)	(25.2	)	—		—		(13.1	)	(11.0	)	(20.1	)	(30.0	)	—		—
Effect of rate-making on property-related differences	(6.8	)	(6.1	)	(15.2	)	(14.6	)	(0.8	)	(0.6	)	(11.9	)	(7.1	)	(16.5	)	(18.7	)	(0.7	)	(0.7	)
Production tax credits	(6.3	)	(6.2	)	(6.7	)	(7.1	)	(6.5	)	(6.2	)	(9.0	)	(6.7	)	(6.0	)	(8.6	)	(5.7	)	(6.1	)
Other items, net	4.5		4.3		5.9		4.8		4.8		4.4		4.4		3.0		5.4		3.7		4.0		4.1
Overall income tax rate	17.7	%	17.1	%	(1.7	%)	(7.1	%)	32.5	%	32.6	%	5.4	%	13.2	%	(2.2	%)	(18.6	%)	32.6	%	32.3	%



	Alliant Energy				IPL				WPL
Nine Months Ended September 30	2016		2015		2016		2015		2016		2015
Statutory federal income tax rate	35.0	%	35.0	%	35.0	%	35.0	%	35.0	%	35.0	%
IPL’s tax benefit riders	(10.2	)	(10.6	)	(19.6	)	(28.2	)	—		—
Effect of rate-making on property-related differences	(8.2	)	(7.1	)	(14.8	)	(17.9	)	(0.8	)	(0.6	)
Production tax credits	(7.2	)	(6.6	)	(6.1	)	(8.0	)	(6.1	)	(6.3	)
Other items, net	3.5		3.7		4.2		4.2		4.4		4.2
Overall income tax rate	12.9	%	14.4	%	(1.3	%)	(14.9	%)	32.5	%	32.3	%

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.

Deferred Tax Assets and Liabilities - For the ~~three~~nine months ended ~~March 31,~~September 30, 2016, Alliant Energy’s, IPL’s and WPL’s ~~non-current~~ deferred tax liabilities increased ~~$43.4~~$149.4 million, ~~$30.9~~$115.6 million and ~~$19.7~~$103.4 million, respectively. These increases in ~~non-current~~ deferred tax liabilities were primarily due to property-related differences recorded during the ~~three~~nine months ended ~~March 31,~~September 30, 2016.

Carryforwards - At ~~March 31,~~September 30, 2016, tax carryforwards and associated deferred tax assets and expiration dates were estimated as follows (dollars in millions):


		Alliant Energy				IPL				WPL					Alliant Energy				IPL				WPL
	Earliest Expiration Date	Tax Carryforwards		Deferred Tax Assets		Tax Carryforwards		Deferred Tax Assets		Tax Carryforwards		Deferred Tax Assets		Earliest Expiration Date	Tax Carryforwards		Deferred Tax Assets		Tax Carryforwards		Deferred Tax Assets		Tax Carryforwards		Deferred Tax Assets
Federal net operating losses	2030		$733		$252		$330		$111		$298		$104	2030		$587		$201		$255		$86		$242		$85
State net operating losses	2018	748		39		20		1		47		2		2018	674		35		15		1		3		—
Federal tax credits	2022	250		246		89		86		101		101		2022	264		260		95		91		108		107
					$537				$198				$207					$496				$178				$192

NOTE 9. BENEFIT PLANS

NOTE 9(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 nine months ended ~~March 31~~September 30 are included in the tables below (in millions). In IPL’s and WPL’s tables below, the defined benefit pension plans costs represent those respective costs for their bargaining unit employees covered under the qualified plans that they sponsor, as well as amounts directly assigned to them 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 IPL’s and WPL’s tables below, the OPEB plans costs (credits) represent respective costs (credits) for their employees, as well as amounts directly assigned to them related to their current and former non-bargaining employees who are participants in the Corporate Services sponsored OPEB plan.



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													Defined Benefit Pension Plans												OPEB Plans
	Defined Benefit Pension Plans						OPEB Plans						Three Months						Nine Months						Three Months						Nine Months
Alliant Energy	2016			2015			2016			2015			2016			2015			2016			2015			2016			2015			2016			2015
Service cost		$3.2			$4.0			$1.3			$1.4			$3.2			$4.0			$9.5			$11.9			$1.4			$1.3			$4.0			$4.1
Interest cost	13.3			13.4			2.3			2.2			13.2			13.5			39.7			40.3			2.3			2.3			7.0			6.8
Expected return on plan assets	(16.4		)	(18.7		)	(1.5		)	(2.1		)	(16.3		)	(18.7		)	(49.1		)	(56.2		)	(1.6		)	(2.1		)	(4.6		)	(6.3		)
Amortization of prior service credit	(0.1		)	(0.1		)	(1.0		)	(2.8		)	(0.1		)	(0.1		)	(0.2		)	(0.2		)	(1.0		)	(2.8		)	(3.1		)	(8.4		)
Amortization of actuarial loss	9.3			8.8			1.2			1.2			9.3			8.8			28.0			26.5			1.2			1.2			3.6			3.6
Additional benefit costs	—			0.2			—			—			—			0.1			—			0.4			—			—			—			—
		$9.3			$7.6			$2.3			($0.1	)		$9.3			$7.6			$27.9			$22.7			$2.3			($0.1	)		$6.9			($0.2	)


													Defined Benefit Pension Plans												OPEB Plans
	Defined Benefit Pension Plans						OPEB Plans						Three Months						Nine Months						Three Months						Nine Months
IPL	2016			2015			2016			2015			2016			2015			2016			2015			2016			2015			2016			2015
Service cost		$1.9			$2.2			$0.6			$0.6			$1.8			$2.2			$5.6			$6.6			$0.5			$0.6			$1.7			$1.8
Interest cost	6.1			6.2			1.0			0.9			6.1			6.2			18.4			18.7			1.0			0.9			2.9			2.8
Expected return on plan assets	(7.7		)	(8.9		)	(1.0		)	(1.4		)	(7.7		)	(8.9		)	(23.2		)	(26.8		)	(1.0		)	(1.4		)	(3.2		)	(4.2		)
Amortization of prior service credit	—			—			(0.7		)	(1.5		)	—			—			(0.1		)	(0.1		)	(0.7		)	(1.5		)	(2.0		)	(4.6		)
Amortization of actuarial loss	4.1			3.8			0.6			0.6			4.2			3.8			12.4			11.5			0.7			0.6			2.0			1.7
		$4.4			$3.3			$0.5			($0.8	)		$4.4			$3.3			$13.1			$9.9			$0.5			($0.8	)		$1.4			($2.5	)


													Defined Benefit Pension Plans												OPEB Plans
	Defined Benefit Pension Plans						OPEB Plans						Three Months						Nine Months						Three Months						Nine Months
WPL	2016			2015			2016			2015			2016			2015			2016			2015			2016			2015			2016			2015
Service cost		$1.2			$1.4			$0.5			$0.6			$1.3			$1.4			$3.7			$4.3			$0.5			$0.5			$1.5			$1.6
Interest cost	5.6			5.6			0.9			0.9			5.5			5.6			16.7			16.9			0.9			0.9			2.8			2.7
Expected return on plan assets	(7.1		)	(8.1		)	(0.2		)	(0.4		)	(7.0		)	(8.1		)	(21.2		)	(24.3		)	(0.2		)	(0.3		)	(0.6		)	(1.1		)
Amortization of prior service cost (credit)	0.1			0.1			(0.2		)	(0.9		)	—			0.1			0.1			0.2			(0.3		)	(0.9		)	(0.7		)	(2.6		)
Amortization of actuarial loss	4.4			4.2			0.5			0.6			4.4			4.2			13.2			12.6			0.5			0.6			1.4			1.7
Additional benefit costs	—			0.2			—			—			—			0.1			—			0.4			—			—			—			—
		$4.2			$3.4			$1.5			$0.8			$4.2			$3.3			$12.5			$10.1			$1.4			$0.8			$4.4			$2.3

401(k) Savings ~~Plans~~Plan - A significant number of employees participate in a defined contribution retirement ~~plans~~plan (401(k) savings ~~plans)~~plan). For the three and nine months ended ~~March 31,~~September 30, costs related to the 401(k) savings ~~plans,~~plan, 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 WPL
2016 2015 2016 2015 2016 2015
401(k) costs
$6.2

$6.7

$3.1

$3.4

$2.8

$2.9



	Alliant Energy								IPL								WPL
	Three Months				Nine Months				Three Months				Nine Months				Three Months				Nine Months
	2016		2015		2016		2015		2016		2015		2016		2015		2016		2015		2016		2015
401(k) costs		$5.6		$6.4		$17.5		$18.7		$2.8		$3.3		$8.8		$9.6		$2.6		$2.9		$8.0		$8.4

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.

NOTE 9(b) Equity-based Compensation Plans - All shares, units and awards included below have been adjusted to reflect the common stock split discussed in Note 6.



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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 nine months ended ~~March 31~~September 30 was as follows (in millions):


													Alliant Energy								IPL								WPL
	Alliant Energy				IPL				WPL				Three Months				Nine Months				Three Months				Nine Months				Three Months				Nine Months
	2016		2015		2016		2015		2016		2015		2016		2015		2016		2015		2016		2015		2016		2015		2016		2015		2016		2015
Compensation expense		$5.3		$3.2		$2.8		$1.7		$2.3		$1.4		$4.4		$0.3		$16.8		$5.8		$2.4		$0.2		$8.9		$3.1		$1.9		$0.1		$7.3		$2.5
Income tax benefits	2.2		1.3		1.1		0.7		0.9		0.6		1.7		0.2		6.8		2.4		1.0		0.1		3.7		1.3		0.7		—		2.9		1.0

As of ~~March 31,~~September 30, 2016, total unrecognized compensation cost related to share-based compensation awards was ~~$12.9~~$8.2 million, which is expected to be recognized over a weighted average period of between one and two years. Share-based compensation expense is recognized on a straight-line basis over the requisite service periods and is primarily recorded in “Other operation and maintenance” in the income statements.



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


	Performance Shares				Performance Units				Performance Shares				Performance Units
	2016		2015		2016		2015		2016		2015		2016		2015
Nonvested awards, January 1	144,215		144,424		58,206		63,665		288,430		288,848		116,412		127,330
Granted	33,776		45,403		11,959		17,837		68,585		90,806		23,918		35,674
Vested	(49,093	)	(45,612	)	(21,380	)	(22,845	)	(98,186	)	(91,224	)	(42,760	)	(45,690	)
Forfeited	(615	)	—		(382	)	(93	)	(1,230	)	—		(4,250	)	(902	)
Nonvested awards, March 31	128,283		144,215		48,403		58,564
Nonvested awards, September 30									257,599		288,430		93,320		116,412

Granted Awards - For ~~the~~ performance units granted in 2016, ~~each performance unit’s~~the final value is based on the closing market price of one share of Alliant Energy’s common stock at the end of the performance period. ~~For~~Compensation expense for performance shares and performance units is recorded ratably over the performance ~~units granted prior to 2016, each performance unit’s value is~~period based on the ~~closing market price of one share of Alliant Energy’s common stock on the grant date~~fair value of the ~~award.~~awards at each reporting period.

Vested Awards - During the ~~three~~nine months ended ~~March 31,~~September 30, certain performance shares and performance units vested, resulting in payouts (a combination of cash and common stock for the performance shares and cash only for the performance units) as follows:


	Performance Shares						Performance Units						Performance Shares						Performance Units
	2016			2015			2016			2015			2016			2015			2016			2015
	2013 Grant			2012 Grant			2013 Grant			2012 Grant			2013 Grant			2012 Grant			2013 Grant			2012 Grant
Performance awards vested	49,093			45,612			21,380			22,845			98,186			91,224			42,760			45,690
Percentage of target number of performance awards	165.0		%	167.5		%	165.0		%	167.5		%	165.0		%	167.5		%	165.0		%	167.5		%
Aggregate payout value (in millions)		$5.1			$5.1			$1.7			$1.6			$5.1			$5.1			$1.7			$1.6
Payout - cash (in millions)		$2.9			$3.2			$1.7			$1.6			$2.9			$3.2			$1.7			$1.6
Payout - common stock shares issued	11,204			10,975			N/A			N/A			22,408			21,950			N/A			N/A

Fair Value of Awards - Information related to fair values of nonvested performance shares and performance units at ~~March 31,~~September 30, 2016, by year of grant, was as follows:


	Performance Shares									Performance Units									Performance Shares									Performance Units
	2016 Grant			2015 Grant			2014 Grant			2016 Grant			2015 Grant			2014 Grant			2016 Grant			2015 Grant			2014 Grant			2016 Grant			2015 Grant			2014 Grant
Nonvested awards	33,161			45,403			49,719			11,959			17,209			19,235			67,355			90,806			99,438			22,657			33,268			37,395
Alliant Energy common stock closing price on March 31, 2016		$74.28			$74.28			$74.28			$74.28		N/A			N/A
Alliant Energy common stock closing price on September 30, 2016																				$38.31			$38.31			$38.31			$38.31		N/A			N/A
Alliant Energy common stock closing price on grant date	N/A			N/A			N/A			N/A				$65.09			$53.77		N/A			N/A			N/A			N/A				$32.55			$26.89
Estimated payout percentage based on performance criteria	108		%	90		%	138		%	108		%	90		%	138		%	125		%	168		%	175		%	125		%	168		%	175		%
Fair values of each nonvested award		$80.22			$66.85			$102.51			$80.22			$58.58			$74.20			$47.89			$64.36			$67.04			$47.89			$54.68			$47.05

~~At March 31, 2016, fair values~~



	21

Table of nonvested performance shares and performance 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.Contents

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

2016 2015
Shares
Weighted Average
Grant Date Fair Value
Shares
Weighted Average
Grant Date Fair Value
Nonvested shares, January 1 95,122

$59.17
98,812

$50.69
Granted —
—
45,403
65.09
Vested (a) —
—
(49,093 ) 47.58
Nonvested shares, March 31 95,122
59.17
95,122
59.17



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	2016			2015
	Shares	Weighted Average Grant Date Fair Value		Shares		Weighted Average Grant Date Fair Value
Nonvested shares, January 1	190,244		$29.59	197,624			$25.35
Granted	—	—		90,806		32.55
Vested (a)	—	—		(98,186	)	23.79
Nonvested shares, September 30	190,244	29.59		190,244		29.59


(a)	In 2015, ~~49,093~~98,186 performance contingent restricted shares granted in 2013 vested because the specified performance criteria for such shares were met.

Performance Restricted Stock Units and Performance Restricted Units - Alliant Energy granted new types of share-based compensation awards to key employees in the first quarter of 2016 referred to as performance restricted stock units, performance restricted units and key employee performance restricted units. Payouts of these units are based on the achievement of certain performance targets (currently specified growth of consolidated income from continuing operations) during the three-year performance period. The actual number of units that will be paid out upon vesting is dependent upon actual performance and may range from zero to 200% of the target number of units. If performance targets are not met during the performance period, these units are forfeited. Subject to achievement of the performance criteria, payouts of nonvested units are prorated in the event of retirement, death or disability during the first year of the performance period based on time worked during the first year of the period, and are prorated upon involuntary termination without cause based on time worked during the entire period. Subject to achievement of the performance criteria, payouts of units to participants who terminate employment after the first year of the performance period due to retirement, death or disability are not prorated. Participants’ nonvested units are forfeited if the participant voluntarily leaves Alliant Energy or is terminated for cause during the performance period.

Performance Restricted Stock Units - Performance restricted stock units must be paid out in shares and are accounted for as equity awards. Each performance restricted stock unit’s value is based on the closing market price of one share of Alliant Energy’s common stock on the grant date of the award. A summary of the performance restricted stock units activity, with amounts representing the target number of units, was as follows:


	2016				2016
	Units		Weighted Average Grant Date Fair Value		Units		Weighted Average Grant Date Fair Value
Granted	33,776			$67.85	68,585			$33.96
Forfeited	(615	)	67.80		(1,230	)	33.90
Nonvested units, March 31	33,161		67.85
Nonvested units, September 30					67,355		33.96

Performance Restricted Units - Performance restricted units must be paid out in cash and are accounted for as liability awards. Each performance restricted unit’s final value is based on the closing market price of one share of Alliant Energy’s common stock at the end of the performance period. Compensation expense is recorded ratably over the performance period based on the fair value of the awards at each reporting period. A summary of the performance restricted units activity, with amounts representing the target number of units, was as follows:



	2016
Granted	~~11,959~~23,918
Forfeited	(1,261	)
Nonvested units, ~~March 31~~September 30	~~11,959~~22,657

Key Employee Performance Restricted Units - Key employee performance restricted units must be paid out in cash and are accounted for as liability awards. Each key employee performance restricted unit’s final value is based on the closing market price of one share of Alliant Energy’s common stock on the grant date of the award. Compensation expense is recorded ratably over the performance period based on a probability assessment of payouts for the awards at each reporting period. A summary of the key employee performance restricted units activity, with amounts representing the target number of units, was as follows:



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2016
Units
Weighted Average
Grant Date Fair Value
Granted 22,528

$67.80
Nonvested units, March 31 22,528
67.80



	2016
Granted	45,056
Forfeited	(2,016	)
Nonvested units, September 30	43,040

Restricted Stock Units and Restricted Units - Alliant Energy granted new types of share-based compensation awards to key employees in the first quarter of 2016 referred to as restricted stock units and restricted units. Payouts of these units are based on the expiration of a three-year time-vesting period. Payouts of nonvested units are prorated in the event of retirement, death or disability during the first year of the time-vesting period based on time worked during the first year of the period, and are prorated upon involuntary termination without cause based on time worked during the entire period. Upon expiration of the time-vesting period, payouts of units to participants who terminate employment after the first year of the period due to retirement, death or disability are not prorated. Participants’ nonvested units are forfeited if the participant voluntarily leaves Alliant Energy or is terminated for cause during the time-vesting period. Each restricted stock unit’s and restricted unit’s final value is based on the closing market price of one share of Alliant Energy’s common stock at the end of the time-vesting period. Compensation expense is recorded ratably over the performance period based on the fair value of the awards at each reporting period. Restricted stock units can be paid out in shares of Alliant Energy common stock, cash or a combination



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of cash and stock. Restricted units must be paid out in cash. Alliant Energy assumes it will make future payouts of its restricted stock units and restricted units in cash; therefore, restricted stock units and restricted units are accounted for as liability awards. A summary of the restricted stock units and restricted units activity was as follows:


	2016			2016
	Restricted Stock Units		Restricted Units	Restricted Stock Units		Restricted Units
Granted	28,952		10,251	58,790		20,502
Forfeited	(527	)	—	(1,054	)	(1,082	)
Nonvested units, March 31	28,425		10,251
Nonvested units, September 30				57,736		19,420

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


	2016		2015		2016		2015
Nonvested awards, January 1	81,876		78,930		163,752		157,860
Granted	—		41,105		—		82,210
Vested (a)	—		(37,332	)	—		(74,664	)
Forfeited	(382	)	(469	)	(3,652	)	(1,654	)
Nonvested awards, March 31	81,494		82,234
Nonvested awards, September 30					160,100		163,752


(a)	In 2015, ~~37,332~~74,664 performance-contingent cash awards granted in 2013 vested, resulting in cash payouts valued at $2.4 million.

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
	2016			2015			2016			2015			2016			2015		2016			2015			2016			2015			2016			2015
Balance, January 1		$214.0			$114.0			$132.9			$51.8			$71.9			$52.4		$214.0			$114.0			$132.9			$51.8			$71.9			$52.4
Revisions in estimated cash flows(a)	0.5			—			0.5			—			—			—		3.9			8.9			4.2			11.9			(0.3		)	(1.9		)
Liabilities settled	(2.7		)	(2.2		)	(0.7		)	(2.2		)	(2.0		)	—		(11.2		)	(7.1		)	(5.0		)	(3.1		)	(6.2		)	(4.0		)
Liabilities incurred(a)	0.7			—			0.7			—			—			—		2.6			76.1			0.7			59.9			1.9			16.2
Accretion expense	1.6			1.0			0.9			0.4			0.6			0.4		4.8			3.4			2.8			1.6			1.7			1.4
Balance, March 31		$214.1			$112.8			$134.3			$50.0			$70.5			$52.8
Balance, September 30																			$214.1			$195.3			$135.6			$122.1			$69.0			$64.1

(a)

In April 2015, the EPA published the final CCR Rule, which regulates CCR as a non-hazardous waste and was 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. During the 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.



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NOTE 11. FAIR VALUE MEASUREMENTS

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, transmission congestion costs and rail transportation costs. 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 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)
Manage rail transportation costs	Diesel fuel swap contracts (WPL)



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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.

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 amounts 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 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.



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Table of Contents

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 related estimated fair values of other financial instruments were as follows (in millions):

Alliant Energy March 31, 2016 December 31, 2015
Fair Value Fair Value
Carrying Level Level Level Carrying Level Level Level
Amount 1 2 3 Total Amount 1 2 3 Total
Assets:
Derivatives
$7.7

$—

$1.2

$6.5

$7.7

$18.4

$—

$2.5

$15.9

$18.4
Deferred proceeds 154.2
—
—
154.2
154.2
172.0
—
—
172.0
172.0
Liabilities and equity:
Derivatives 84.0
—
11.6
72.4
84.0
64.6
—
16.0
48.6
64.6
Long-term debt (including current maturities) 3,836.1
—
4,452.3
3.3
4,455.6
3,835.6
—
4,332.4
3.7
4,336.1
Cumulative preferred stock of IPL 200.0
208.3
—
—
208.3
200.0
206.6
—
—
206.6



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~~Table of Contents~~



Alliant Energy	September 30, 2016										December 31, 2015
			Fair Value										Fair Value
	Carrying		Level		Level		Level				Carrying		Level		Level		Level
	Amount		1		2		3		Total		Amount		1		2		3		Total
Assets:
Derivatives		$27.8		$—		$1.9		$25.9		$27.8		$18.4		$—		$2.5		$15.9		$18.4
Deferred proceeds	239.7		—		—		239.7		239.7		172.0		—		—		172.0		172.0
Liabilities and equity:
Derivatives	36.9		—		3.1		33.8		36.9		64.6		—		16.0		48.6		64.6
Long-term debt (including current maturities)	4,130.9		—		4,868.3		3.3		4,871.6		3,835.6		—		4,332.4		3.7		4,336.1
Cumulative preferred stock of IPL	200.0		215.4		—		—		215.4		200.0		206.6		—		—		206.6


IPL	March 31, 2016										December 31, 2015										September 30, 2016										December 31, 2015
			Fair Value										Fair Value										Fair Value										Fair Value
	Carrying		Level		Level		Level				Carrying		Level		Level		Level				Carrying		Level		Level		Level				Carrying		Level		Level		Level
	Amount		1		2		3		Total		Amount		1		2		3		Total		Amount		1		2		3		Total		Amount		1		2		3		Total
Assets:
Derivatives		$5.8		$—		$1.1		$4.7		$5.8		$15.5		$—		$2.0		$13.5		$15.5		$22.2		$—		$1.2		$21.0		$22.2		$15.5		$—		$2.0		$13.5		$15.5
Deferred proceeds	154.2		—		—		154.2		154.2		172.0		—		—		172.0		172.0		239.7		—		—		239.7		239.7		172.0		—		—		172.0		172.0
Liabilities and equity:
Derivatives	23.3		—		5.5		17.8		23.3		23.4		—		8.0		15.4		23.4		9.0		—		1.4		7.6		9.0		23.4		—		8.0		15.4		23.4
Long-term debt (including current maturities)	1,857.4		—		2,147.2		—		2,147.2		1,856.9		—		2,092.7		—		2,092.7		2,153.1		—		2,495.8		—		2,495.8		1,856.9		—		2,092.7		—		2,092.7
Cumulative preferred stock	200.0		208.3		—		—		208.3		200.0		206.6		—		—		206.6		200.0		215.4		—		—		215.4		200.0		206.6		—		—		206.6


WPL	March 31, 2016										December 31, 2015										September 30, 2016										December 31, 2015
			Fair Value										Fair Value										Fair Value										Fair Value
	Carrying		Level		Level		Level				Carrying		Level		Level		Level				Carrying		Level		Level		Level				Carrying		Level		Level		Level
	Amount		1		2		3		Total		Amount		1		2		3		Total		Amount		1		2		3		Total		Amount		1		2		3		Total
Assets:
Derivatives		$1.9		$—		$0.1		$1.8		$1.9		$2.9		$—		$0.5		$2.4		$2.9		$5.6		$—		$0.7		$4.9		$5.6		$2.9		$—		$0.5		$2.4		$2.9
Liabilities and equity:
Derivatives	60.7		—		6.1		54.6		60.7		41.2		—		8.0		33.2		41.2		27.9		—		1.7		26.2		27.9		41.2		—		8.0		33.2		41.2
Long-term debt (including current maturities)	1,534.2		—		1,854.3		—		1,854.3		1,533.9		—		1,793.0		—		1,793.0		1,534.9		—		1,920.4		—		1,920.4		1,533.9		—		1,793.0		—		1,793.0

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.



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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 March 31 2016 2015 2016 2015
Beginning balance, January 1
($32.7 )
$17.9

$172.0

$177.2
Total net losses included in changes in net assets (realized/unrealized) (31.4 ) (18.1 ) —
—
Transfers into Level 3 0.9
—
—
—
Sales (0.6 ) (0.9 ) —
—
Settlements (a) (2.1 ) (12.0 ) (17.8 ) (59.5 )
Ending balance, March 31
($65.9 )
($13.1 )
$154.2

$117.7
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 March 31
($30.0 )
($16.5 )
$—

$—



Alliant Energy	Commodity Contract Derivative
	Assets and (Liabilities), net						Deferred Proceeds
Three Months Ended September 30	2016			2015			2016		2015
Beginning balance, July 1		$0.6			$0.6			$74.4		$73.4
Total net losses included in changes in net assets (realized/unrealized)	(5.1		)	(21.1		)	—		—
Transfers out of Level 3	0.8			—			—		—
Sales	(0.2		)	(0.4		)	—		—
Settlements (a)	(4.0		)	(3.7		)	165.3		122.1
Ending balance, September 30		($7.9	)		($24.6	)		$239.7		$195.5
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		($5.0	)		($18.4	)		$—		$—



Alliant Energy	Commodity Contract Derivative
	Assets and (Liabilities), net						Deferred Proceeds
Nine Months Ended September 30	2016			2015			2016		2015
Beginning balance, January 1		($32.7	)		$17.9			$172.0		$177.2
Total net gains (losses) included in changes in net assets (realized/unrealized)	8.0			(58.2		)	—		—
Transfers into Level 3	0.9			—			—		—
Transfers out of Level 3	1.2			0.6			—		—
Purchases	22.0			36.9			—		—
Sales	(0.9		)	(1.7		)	—		—
Settlements (a)	(6.4		)	(20.1		)	67.7		18.3
Ending balance, September 30		($7.9	)		($24.6	)		$239.7		$195.5
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		$9.7			($52.2	)		$—		$—



IPL	Commodity Contract Derivative
	Assets and (Liabilities), net						Deferred Proceeds
Three Months Ended September 30	2016			2015			2016		2015
Beginning balance, July 1		$18.3			$18.3			$74.4		$73.4
Total net losses included in changes in net assets (realized/unrealized)	(0.4		)	(8.6		)	—		—
Transfers out of Level 3	0.3			—			—		—
Sales	(0.2		)	(0.4		)	—		—
Settlements (a)	(4.6		)	(5.5		)	165.3		122.1
Ending balance, September 30		$13.4			$3.8			$239.7		$195.5
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		($0.4	)		($8.0	)		$—		$—



IPL	Commodity Contract Derivative
	Assets and (Liabilities), net						Deferred Proceeds
Nine Months Ended September 30	2016			2015			2016		2015
Beginning balance, January 1		($1.9	)		$19.4			$172.0		$177.2
Total net gains (losses) included in changes in net assets (realized/unrealized)	4.8			(26.0		)	—		—
Transfers into Level 3	0.5			—			—		—
Transfers out of Level 3	0.2			—			—		—
Purchases	20.6			33.1			—		—
Sales	(0.9		)	(1.6		)	—		—
Settlements (a)	(9.9		)	(21.1		)	67.7		18.3
Ending balance, September 30		$13.4			$3.8			$239.7		$195.5
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		$5.7			($21.2	)		$—		$—



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IPL Commodity Contract Derivative
Assets and (Liabilities), net Deferred Proceeds
Three Months Ended March 31 2016 2015 2016 2015
Beginning balance, January 1
($1.9 )
$19.4

$172.0

$177.2
Total net losses included in changes in net assets (realized/unrealized) (7.6 ) (12.5 ) —
—
Transfers into Level 3 0.5
—
—
—
Sales (0.6 ) (0.9 ) —
—
Settlements (a) (3.5 ) (11.0 ) (17.8 ) (59.5 )
Ending balance, March 31
($13.1 )
($5.0 )
$154.2

$117.7
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 March 31
($6.6 )
($10.7 )
$—

$—



WPL	Commodity Contract Derivative
	Assets and (Liabilities), net
Three Months Ended September 30	2016			2015
Beginning balance, July 1		($17.7	)		($17.7	)
Total net losses included in changes in net assets (realized/unrealized)	(4.7		)	(12.5		)
Transfers out of Level 3	0.5			—
Settlements	0.6			1.8
Ending balance, September 30		($21.3	)		($28.4	)
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		($4.6	)		($10.4	)


WPL	Commodity Contract Derivative						Commodity Contract Derivative
	Assets and (Liabilities), net						Assets and (Liabilities), net
Three Months Ended March 31	2016			2015
Nine Months Ended September 30							2016			2015
Beginning balance, January 1		($30.8	)		($1.5	)		($30.8	)		($1.5	)
Total net losses included in changes in net assets (realized/unrealized)	(23.8		)	(5.6		)
Total net gains (losses) included in changes in net assets (realized/unrealized)							3.2			(32.2		)
Transfers into Level 3	0.4			—			0.4			—
Transfers out of Level 3							1.0			0.6
Purchases							1.4			3.8
Sales							—			(0.1		)
Settlements	1.4			(1.0		)	3.5			1.0
Ending balance, March 31		($52.8	)		($8.1	)
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 March 31		($23.4	)		($5.8	)
Ending balance, September 30								($21.3	)		($28.4	)
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								$4.0			($31.0	)


(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.

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
March 31, 2016		($67.9	)		$2.0		($15.0	)		$1.9		($52.9	)		$0.1
September 30, 2016																	($26.3	)		$18.4		($3.5	)		$16.9		($22.8	)		$1.5
December 31, 2015	(43.1		)	10.4		(12.3		)	10.4		(30.8		)	—		(43.1		)	10.4		(12.3		)	10.4		(30.8		)	—

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 ~~March 31,~~September 30, 2016, gross notional amounts and settlement/delivery years related to outstanding swap contracts, option contracts, physical forward contracts, FTRs, coal contracts and diesel fuel contracts that were accounted for as commodity derivative instruments were as follows (units in thousands):


	Electricity		FTRs		Natural Gas		Coal		Diesel Fuel		Electricity		FTRs		Natural Gas		Coal		Diesel Fuel
	MWhs	Years	MWhs	Years	Dths	Years	Tons	Years	Gallons	Years	MWhs	Years	MWhs	Years	Dths	Years	Tons	Years	Gallons	Years
Alliant Energy	5,115	2016-2018	3,768	2016	94,635	2016-2020	4,240	2016-2018	5,292	2016-2017	3,427	2016-2018	14,437	2016-2017	82,277	2016-2020	4,640	2016-2019	3,780	2016-2017
IPL	660	2016	2,232	2016	49,747	2016-2020	1,661	2016-2018	—	—	187	2016	8,865	2016-2017	47,141	2016-2020	2,202	2016-2019	—	—
WPL	4,455	2016-2018	1,536	2016	44,888	2016-2020	2,579	2016-2018	5,292	2016-2017	3,240	2016-2018	5,572	2016-2017	35,136	2016-2020	2,438	2016-2018	3,780	2016-2017



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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	March 31, 2016		December 31, 2015		March 31, 2016		December 31, 2015		March 31, 2016		December 31, 2015		September 30, 2016		December 31, 2015		September 30, 2016		December 31, 2015		September 30, 2016		December 31, 2015
Current derivative assets		$6.1		$15.1		$4.8		$13.8		$1.3		$1.3		$25.1		$15.1		$20.5		$13.8		$4.6		$1.3
Non-current derivative assets	1.6		3.3		1.0		1.7		0.6		1.6		2.7		3.3		1.7		1.7		1.0		1.6
Current derivative liabilities	56.3		47.3		18.7		18.5		37.6		28.8		21.2		47.3		5.4		18.5		15.8		28.8
Non-current derivative liabilities	27.7		17.3		4.6		4.9		23.1		12.4		15.7		17.3		3.6		4.9		12.1		12.4

Unrealized gains and losses from commodity derivative instruments were recorded with offsets to regulatory assets or regulatory liabilities on the balance sheets. Refer to Notes 2 and 11 for further discussion.

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. At ~~March 31,~~September 30, 2016 and December 31, 2015, the aggregate fair value of all derivative instruments with credit risk-related contingent features in a net liability position was not materially different than 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.

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, amounts would not be materially different from gross amounts of derivative assets and derivative liabilities at ~~March 31,~~September 30, 2016 and December 31, 2015. 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.

NOTE 13. COMMITMENTS AND CONTINGENCIES

NOTE 13(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.~~the installation of an SCR system at Ottumwa Unit 1 to reduce NOx emissions at the EGU. WPL’s projects include ~~generation maintenance and performance improvements at Columbia Units 1 and 2,~~ the ~~installation of a scrubber and baghouse at Edgewater Unit 5 to reduce SO2 and mercury emissions, and~~Riverside expansion, the installation of an SCR system at Columbia Unit 2 to reduce NOx emissions at the ~~EGU.~~EGU, and generation maintenance and performance improvements at Columbia Units 1 and 2. At ~~March 31,~~September 30, 2016, Alliant Energy’s, IPL’s and WPL’s minimum future commitments related to certain contractual obligations for these projects were ~~$30~~$27 million, ~~$15~~$1 million and ~~$15~~$26 million, respectively.



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NOTE 13(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 ~~March 31,~~September 30, 2016, 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)		$1,390		$1,390		$—		$1,320		$1,320		$—
Other	145		1		144		139		1		138
	1,535		1,391		144		1,459		1,321		138
Natural gas	408		225		183		557		231		326
Coal (b)	238		102		136		193		85		108
SO2 emission allowances	8		8		—		8		8		—
Other (c)	24		5		2		21		4		1
		$2,213		$1,731		$465		$2,238		$1,649		$573



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(a)	Includes payments required by purchased power agreements 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 ~~March 31,~~September 30, 2016 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 ~~March 31,~~September 30, 2016.

NOTE 13(c) Legal Proceedings -

Flood Damage Claims - In 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 February 2016, the Iowa District Court for Linn County ruled in favor of Alliant Energy and CRANDIC and dismissed all claims against them, resulting in no loss. In ~~March~~August 2016, the Iowa District Court for Linn County dismissed all claims against the remaining defendants. In September 2016, plaintiffs filed a notice of appeal with the Supreme Court of ~~Iowa,~~Iowa. Alliant Energy does not currently believe any material losses for this complaint are both probable and ~~the plaintiffs’ right to appeal~~reasonably estimated, and therefore has ~~been challenged by another defendant. There is no deadline for the Supreme Court~~not recognized any material loss contingency amounts as of ~~Iowa to rule on the motion challenging the appeal.~~September 30, 2016.

NOTE 13(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 ~~March 31,~~September 30, 2016, Alliant Energy had $123 million of performance guarantees outstanding, with $48 million and $75 million currently expected to expire in 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.

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 ~~March 31, 2016~~.September 30, 2016. 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” during the ~~three~~nine months ended ~~March 31,~~September 30, 2016 and 2015 related to certain warranty claims.



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~~Table of Contents~~

Whiting Petroleum - In 2004, Alliant Energy sold its remaining interest in Whiting Petroleum. Whiting Petroleum is an independent oil and gas company. Resources, as the successor to a predecessor entity that owned Whiting Petroleum, continues to guarantee the partnership obligations of an affiliate of Whiting Petroleum under general partnership agreements in the oil and gas industry, including with respect to the future abandonment of certain platforms off the coast of California and related onshore plant and equipment owned by the partnerships. The guarantees do not include a maximum limit. As of ~~March 31,~~September 30, 2016, the present value of the abandonment obligations is estimated at ~~$29~~$30 million. Alliant Energy is not aware of any material liabilities related to these guarantees of which it is probable that Resources will be obligated to pay and therefore has not recognized any material liabilities related to this guarantee as of ~~March 31, 2016~~.September 30, 2016.

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 ~~March 31,~~September 30, 2016. The general terms of the indemnifications provided by IPL included a maximum limit of $17 million and expire in October 2020.



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NOTE 13(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 2423 and 5 sites, respectively.

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 ~~March 31,~~September 30, 2016, 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	-	$28		$10	-	$24		$2	-	$4		$11	-	$27		$9	-	$23		$2	-	$4
Current and non-current environmental liabilities	16				13				3				15				12				3

WPL Consent Decree - In 2013, the U.S. District Court for the Western District of Wisconsin approved a Consent Decree that WPL, along with the other owners of Edgewater and Columbia, entered into with the EPA and the Sierra Club, thereby resolving claims against WPL. Such claims included allegations that the owners of Edgewater, Nelson Dewey and Columbia violated the Prevention of Significant Deterioration program requirements, Title V Operating Permit requirements of the CAA and the Wisconsin State Implementation Plan designed to implement the CAA.

WPL has completed various requirements under the Consent Decree. WPL’s remaining requirements include installing ~~a scrubber and baghouse at Edgewater Unit 5 by December 31, 2016 and~~ an SCR system at Columbia Unit 2 by December 31, 2018. WPL is also required to fuel switch or retire 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.~~Edgewater. WPL is in the process of completing approximately $7$7 million in environmental mitigation projects.

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



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IPL Consent Decree - In 2015, the U.S. District Court for the Northern District of Iowa approved a Consent Decree that IPL entered into with the EPA, the Sierra Club, the State of Iowa and Linn County in Iowa, thereby resolving potential CAA issues associated with emissions from IPL’s coal-fired generating facilities in Iowa. IPL has completed various requirements under the Consent Decree. IPL’s remaining requirements include installing an SCR system or equivalent NOx reduction system at the Ottumwa Generating Station by December 31, 2019; fuel switching or retiring Prairie Creek Unit 4 by June 1, 2018, the Burlington Generating Station by December 31, 2021 and Prairie Creek Units 1 and 3 by December 31, 2025; and either installing combined cycle technology at, or retiring, the Dubuque and Sutherland Generating Stations by June 1, 2019.

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 complete approximately $6 million in environmental mitigation projects.



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Alliant Energy and IPL currently expect to recover material costs incurred by IPL related to the environmental 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.

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, Ozone 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.

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. Refer to Note 3 for discussion of asset valuation charges recorded in the third quarter of 2016 related to the Franklin County wind farm, which decreased the assets for “Non-Regulated, Parent and Other.”

Utility Non-Regulated, Alliant Energy
Electric Gas Other Total Parent and Other Consolidated
(in millions)
Three Months Ended March 31, 2016
Operating revenues
$668.9

$152.2

$13.2

$834.3

$9.5

$843.8
Operating income 109.8
28.8
2.2
140.8
5.1
145.9
Amounts attributable to Alliant Energy common shareowners:
Income from continuing operations, net of tax 92.1
5.5
97.6
Loss from discontinued operations, net of tax —
(1.1 ) (1.1 )
Net income 92.1
4.4
96.5
Three Months Ended March 31, 2015
Operating revenues
$671.3

$198.4

$16.4

$886.1

$11.3

$897.4
Operating income 104.7
36.3
5.3
146.3
6.6
152.9
Net income attributable to Alliant Energy common shareowners 92.4
4.2
96.6



	Utility									Non-Regulated,			Alliant Energy
	Electric		Gas			Other		Total		Parent and Other			Consolidated
	(in millions)
Three Months Ended September 30, 2016
Operating revenues		$864.3		$39.5			$9.4		$913.2		$11.4			$924.6
Operating income (loss)	244.2		(3.7		)	0.4		240.9		(78.3		)	162.6
Amounts attributable to Alliant Energy common shareowners:
Income (loss) from continuing operations, net of tax								183.1		(54.3		)	128.8
Loss from discontinued operations, net of tax								—		(0.4		)	(0.4		)
Net income (loss)								183.1		(54.7		)	128.4
Three Months Ended September 30, 2015
Operating revenues		$835.8		$38.0			$13.4		$887.2		$11.7			$898.9
Operating income (loss)	232.8		(5.7		)	0.2		227.3		8.6			235.9
Amounts attributable to Alliant Energy common shareowners:
Income (loss) from continuing operations, net of tax								184.5		(4.5		)	180.0
Loss from discontinued operations, net of tax								—		(0.1		)	(0.1		)
Net income (loss)								184.5		(4.6		)	179.9



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	Utility								Non-Regulated,			Alliant Energy
	Electric		Gas		Other		Total		Parent and Other			Consolidated
	(in millions)
Nine Months Ended September 30, 2016
Operating revenues		$2,209.1		$248.7		$35.0		$2,492.8		$30.2			$2,523.0
Operating income (loss)	473.3		27.0		4.4		504.7		(67.6		)	437.1
Amounts attributable to Alliant Energy common shareowners:
Income (loss) from continuing operations, net of tax							350.3		(39.5		)	310.8
Loss from discontinued operations, net of tax							—		(2.0		)	(2.0		)
Net income (loss)							350.3		(41.5		)	308.8
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							332.6		12.9			345.5
Loss from discontinued operations, net of tax							—		(1.4		)	(1.4		)
Net income							332.6		11.5			344.1

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 March 31, 2016
Three Months Ended September 30, 2016
Operating revenues										$483.2		$23.9			$9.1		$516.2
Operating income (loss)									125.9		(1.4		)	1.4		125.9
Earnings available for common stock																114.1
Three Months Ended September 30, 2015
Operating revenues										$468.6		$23.1			$12.9		$504.6
Operating income (loss)									119.4		(2.9		)	0.5		117.0
Earnings available for common stock																116.5
Nine Months Ended September 30, 2016
Operating revenues		$361.6		$84.2		$12.9		$458.7		$1,209.2		$142.6			$34.1		$1,385.9
Operating income	43.4		15.8		2.8		62.0		213.8		15.3			6.8		235.9
Earnings available for common stock							45.6									191.6
Three Months Ended March 31, 2015
Nine Months Ended September 30, 2015
Operating revenues		$362.6		$111.2		$15.2		$489.0		$1,170.6		$164.1			$41.1		$1,375.8
Operating income	40.3		20.6		4.6		65.5		193.6		15.3			7.4		216.3
Earnings available for common stock							47.5									180.5



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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 March 31, 2016
Three Months Ended September 30, 2016
Operating revenues		$307.3		$68.0		$0.3			$375.6		$381.1		$15.6			$0.3			$397.0
Operating income (loss)	66.4		13.0		(0.6		)	78.8		118.3		(2.3		)	(1.0		)	115.0
Earnings available for common stock								46.5										69.0
Three Months Ended March 31, 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																		68.0
Nine Months Ended September 30, 2016
Operating revenues											$999.9		$106.1			$0.9			$1,106.9
Operating income (loss)										259.5		11.7			(2.4		)	268.8
Earnings available for common stock																		158.7
Nine Months Ended September 30, 2015
Operating revenues		$308.7		$87.2		$1.2			$397.1		$976.9		$124.0			$3.5			$1,104.4
Operating income	64.4		15.7		0.7			80.8		244.8		13.3			1.3			259.4
Earnings available for common stock								44.9										152.1

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, depreciation and amortization of property, plant and equipment, 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. Corporate Services assigns such sales and purchases among IPL and WPL based on statements received from MISO. The amounts billed for services provided, sales credited and purchases for the three and nine months ended ~~March 31~~September 30 were as follows (in millions):


									IPL								WPL
	IPL				WPL				Three Months				Nine Months				Three Months				Nine Months
	2016		2015		2016		2015		2016		2015		2016		2015		2016		2015		2016		2015
Corporate Services billings		$38		$36		$33		$28		$41		$38		$124		$114		$33		$30		$103		$90
Sales credited	1		4		1		6		4		2		7		8		3		9		6		21
Purchases billed	96		79		19		14		126		110		324		278		23		16		65		49

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

IPL WPL
March 31, 2016 December 31, 2015 March 31, 2016 December 31, 2015
Net payables to Corporate Services $100 $93 $59 $54



	IPL		WPL
	September 30, 2016	December 31, 2015	September 30, 2016	December 31, 2015
Net payables to Corporate Services	$114	$93	$68	$54

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 nine months ended ~~March 31~~September 30 were as follows (in millions):

2016 2015
ATC billings to WPL
$27

$25
WPL billings to ATC 3
2



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	Three Months				Nine Months
	2016		2015		2016		2015
ATC billings to WPL		$28		$25		$82		$75
WPL billings to ATC	4		4		10		9

WPL owed ATC net amounts of $8$9 million as of ~~March 31,~~September 30, 2016 and $8 million as of December 31, 2015.



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Franklin County Wind Farm - Refer to Note 3 for discussion of IPL’s anticipated filing with FERC in the fourth quarter of 2016 requesting approval to transfer the Franklin County wind farm assets from AEF to IPL in 2017.

NOTE 16. DISCONTINUED OPERATIONS

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 nine months ended ~~March 31~~September 30 was as follows (in millions):



	~~2016~~
~~Operating expenses~~		~~$1.9~~
~~Loss before income taxes~~	~~(1.9~~		)
~~Income tax benefit~~	~~(0.8~~		)
~~Loss from discontinued operations, net of tax~~		~~($1.1~~	)



	Three Months						Nine Months
	2016			2015			2016			2015
Operating expenses		$0.6			$0.3			$3.3			$2.3
Loss before income taxes	(0.6		)	(0.3		)	(3.3		)	(2.3		)
Income tax benefit	(0.2		)	(0.2		)	(1.3		)	(0.9		)
Loss from discontinued operations, net of tax		($0.4	)		($0.1	)		($2.0	)		($1.4	)

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

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~~AEF 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 2015 Form 10-K. Unless otherwise noted, all “per share” references in MDA refer to earnings per diluted share.

EXECUTIVE SUMMARY

Description of Business

General - Alliant Energy is an investor-owned public utility holding company whose primary subsidiaries are IPL, WPL, ~~Resources~~AEF 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 to retail customers in select markets in Iowa. IPL also sells electricity to wholesale customers in Minnesota, Illinois and Iowa. WPL is a public utility engaged principally in the generation and distribution of electricity and the distribution and transportation of natural gas to retail customers in select markets in Wisconsin. WPL also sells electricity to wholesale customers in Wisconsin. At ~~March 31,~~September 30, 2016, 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~~Effective October 1, 2016, AEF 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.



	Alliant Energy


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



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


	2016						2015				2016						2015
	Income (Loss)			EPS (a)			Income (Loss)		EPS (a)		Income (Loss)			EPS (a)			Income (Loss)			EPS (a)
Continuing operations:
Utilities, ATC and Corporate Services		$95.4			$0.84			$95.1		$0.86		$186.7			$0.82			$187.7			$0.83
Non-regulated and Parent	2.2			0.02			1.5		0.01		(57.9		)	(0.25		)	(7.7		)	(0.04		)
Income from continuing operations	97.6			0.86			96.6		0.87		128.8			0.57			180.0			0.79
Loss from discontinued operations	(1.1		)	(0.01		)	—		—		(0.4		)	—			(0.1		)	—
Net income		$96.5			$0.85			$96.6		$0.87		$128.4			$0.57			$179.9			$0.79


(a)	Amounts ~~do not~~ reflect the effects of a two-for-one common stock split ~~approved by Alliant Energy’s Board of Directors on April 20,~~distributed in May 2016. Refer to Note 6 for additional details.

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

Lower net income and EPS from continuing operations in the ~~first~~third quarter of 2016 compared to the ~~first~~third quarter of 2015 was primarily due to ~~lower electric~~asset valuation charges related to the Franklin County wind farm in the third quarter of 2016, timing of income tax expense, higher reserves for ATC return on equity at WPL, and ~~gas sales attributed to warmer temperatures in early 2016 compared to early 2015,~~ higher ~~depreciation expense and the dilution impact of common shares issued in 2015.~~stock-based performance compensation expense. These items were partially offset by estimated temperature impacts on retail electric and gas sales in the third quarter of 2016, higher AFUDC, ~~lower retail electric customer billing credits at IPL, higher electric sales due to~~and voluntary employee separation charges in the ~~additional day for leap year in 2016, and lower energy efficiency cost recovery amortization at WPL.~~third quarter of 2015.

Refer to “Results of Operations” for additional details regarding the various factors impacting earnings during the ~~first~~third quarters of 2016 and 2015.

2016 Overview - Alliant Energy, IPL and WPL continue to focus on achieving financial objectives and executing their strategic plan, including providing competitive value and exceptional service for their customers and finding innovative ways to operate the business more efficiently and provide flexible energy resources. Key developments since the filing of the 2015 Form 10-K include the following:

•

IPL’s Expansion of Wind Generation - In October 2016, IPL and the Iowa Office of Consumer Advocate, among other customer groups, filed a settlement agreement with the IUB regarding the appropriate rate-making principles for up to 500 MW of additional wind generation at IPL. In October 2016, the IUB issued an order approving the settlement agreement, with limited modifications, and establishing rate-making principles, which IPL accepted, with key terms as follows. Refer to “Strategic Overview” for further discussion.


▪	Up to 500 MW of additional wind generation that qualifies for the full level of production tax credits, regardless of the location in Iowa, with a cost cap of $1,830/kilowatt, including AFUDC and transmission costs. Any costs incurred in excess of this $1,830/kilowatt cost cap are expected to be incorporated into rates if determined to be reasonable and prudent.


▪	A depreciable life of the wind generation of 40 years, unless changed as a result of a contested case before the IUB.


▪	An 11.0% return on common equity, with the exception of certain transmission facilities classified as intangible assets, which would earn the rate of return on common equity the IUB finds reasonable during a future rate case.

Franklin County Wind Farm - In addition to IPL’s expansion of wind generation discussed above, IPL currently anticipates requesting approval from FERC in the fourth quarter of 2016 to transfer the 99 MW Franklin County wind farm from AEF to IPL in 2017.

WPL’s Construction of the Riverside Expansion - In ~~March~~May 2016, WPL received ~~a decision~~an order from the PSCW authorizing WPL to construct a natural gas-fired combined-cycle EGU in Beloit, Wisconsin, referred to as the Riverside expansion. ~~The Riverside expansion is subject to~~After receiving the ~~receipt of various other~~final necessary regulatory approvals and permits ~~necessary~~in the third quarter of 2016, WPL began constructing the Riverside expansion. WPL currently expects to ~~construct and operate~~place the Riverside expansion in service by early 2020. In November 2016, various electric cooperatives notified WPL of their intent to exercise their options to acquire approximately 60 MW of the Riverside expansion while the EGU is being constructed. As a result of the various electric



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cooperatives funding a portion of the capital expenditures during construction, WPL’s estimated portion of capital expenditures is now expected to be approximately $640 million.

WPL’s Wisconsin Retail Electric and ~~connect such EGU~~Gas Rate Case (2017/2018 Test Period) - In May 2016, WPL filed a retail base rate case with the PSCW based on a forward-looking test period that includes 2017 and 2018. WPL’s filing was based on a stipulated agreement reached between PSCW staff, intervener groups and WPL. The filing requested approval for WPL to implement a $13 million, or approximately 1%, increase in annual rates for WPL’s retail electric customers. Based on updated fuel-related cost information at the time of rate case hearings in September 2016, the current estimate of the net increase in annual rates for WPL’s retail electric customers is $17 million. The filing also requested approval for WPL to implement a $9 million, or approximately 13%, increase in annual base rates for WPL’s retail gas customers. Any rate changes granted from this request are expected to be effective January 1, 2017 and extend through the end of 2018. WPL currently expects a decision from the PSCW regarding this base rate filing in the fourth quarter of 2016.

MISO Transmission Owner Return on Equity Complaints - A group of MISO cooperative and municipal utilities previously filed two complaints with FERC requesting a reduction to the base return on equity used by MISO transmission ~~system. Subject~~owners, including ITC and ATC. In September 2016, FERC issued an order on the first complaint and established a base return on equity of 10.32%, excluding any incentive adders granted by FERC, for the refund period from November 12, 2013 through February 11, 2015. In October 2016, in response to ~~such approvals, construction~~MISO’s and the MISO transmission owners’ request, FERC ordered the related refunds be issued by July 2017. In June 2016, a FERC administrative law judge issued an initial decision regarding the second complaint and recommended a base return on equity of 9.70%, excluding any incentive adders granted by FERC, for the refund period from February 12, 2015 through May 11, 2016. A final decision from FERC on the second complaint is currently expected in the first half of 2017.

WPL’s Future Transfer of Investment in ATC - In June 2016, WPL received an order from the PSCW requiring WPL to ~~begin~~transfer its investment in ATC to Alliant Energy or an Alliant Energy subsidiary by December 31, 2022. In addition, WPL is required to obtain PSCW approval prior to transferring any additional capital or assets to ATC.Subsequent to WPL transferring its investment in ATC, future contributions to, and equity earnings and dividends from, the investment in ATC would occur at the entity to which the investment in ATC was transferred and would not be reflected in WPL’s consolidated financial statements. As a result, WPL’s earnings and cash flows from operations are expected to decrease subsequent to the transfer. This transfer is not expected to impact Alliant Energy’s consolidated financial statements.

Credit Ratings - In July 2016, Moody’s Investors Service changed Alliant Energy’s and ~~be completed by early 2020.~~IPL’s corporate/issuer and senior unsecured long-term debt credit ratings from A3 to Baa1. IPL’s preferred stock credit rating also changed from Baa2 to Baa3. In addition, WPL’s corporate/issuer and senior unsecured long-term debt credit ratings changed from A1 to A2. Alliant Energy’s, IPL’s and WPL’s outlooks also changed from negative to stable. Alliant Energy’s, IPL’s and WPL’s commercial paper ratings remained unchanged. These credit ratings changes are not expected to have a material impact on Alliant Energy’s, IPL’s, and WPL’s liquidity or collateral obligations.

Common Stock Split - In April 2016, Alliant Energy’s Board of Directors approved a two-for-one common stock split and a proportionate increase in the number of authorized shares of common stock of Alliant Energy from 240 million shares to 480 million shares to implement the stock split. Alliant Energy shareowners of record at the close of business on May 4, 2016 ~~will receive~~received one additional share of Alliant Energy common stock for each share held on that date. The proportionate interest that a shareowner owns in Alliant Energy ~~will~~did not change as a result of the stock split. The additional shares ~~are expected to be~~were distributed on May 19, 2016 and post-split trading ~~is expected to begin~~began on May 20, 2016. ~~Based on common shares outstanding as of March 31, 2016, upon the completion of the stock split,~~All Alliant Energy ~~will~~share and per share amounts in this report have ~~approximately 227 million shares of common stock outstanding. The stock split will require all historical common stock shares and EPS data to be recast in the~~ ~~second~~ ~~quarter of 2016.~~been reflected on a post-split basis.

Future Developments - The following includes key items expected to impact Alliant Energy, IPL and WPL in the future that have been identified since the filing of the 2015 Form 10-K:

~~Gas Transmission and Distribution Systems~~2017 Forecast - In ~~March 2016,~~2017, the ~~Pipeline~~following financing activities, and ~~Hazardous Materials Safety Administration announced proposed regulations~~impacts to ~~update safety requirements for gas pipelines. The proposed regulations would add new assessment~~results of operations, are currently anticipated to occur:

Financing Plans - Alliant Energy currently expects to issue up to $150 million of common stock in 2017 through one or more offerings and ~~repair criteria for gas pipelines, and require a systematic approach to verify a pipeline’s maximum allowable operating pressure.~~its Shareowner Direct Plan. IPL and WPL currently ~~anticipate final regulations will be issued~~expect to receive capital contributions of approximately $150 million and $90 million, respectively, from their parent company, Alliant Energy, in 2017. IPL and WPL currently expect to issue up to $250 million and $300 million, respectively, of long-term debt securities in 2017.

Common Stock Dividends - Alliant Energy announced an increase in its targeted 2017 annual common stock dividend to $1.26 per share, which is equivalent to a quarterly rate of $0.315 per share, beginning with the February 2017 dividend payment. The timing and amount of future dividends is subject to an approved dividend declaration from Alliant Energy’s 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 $156 million and $126 million, respectively, to their parent company in 2017.



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~~Attachment “O” Rates~~Electric Transmission Service Expense - In March 2016, FERC issued an order concluding that ITC acted imprudently by failing to take advantage of tax savings benefits available through bonus tax depreciation deductions. The FERC order requires ITC to recalculate its Attachment “O” rate to simulate taking bonus tax depreciation deductions beginning January 1, 2015. In April 2016, ITC filed a request for rehearing of FERC’s March 2016 order. IPL subsequently filed a response to ITC’s request for rehearing, requesting that FERC require ITC to also take bonus tax depreciation deductions for 2012 through 2014. Alliant Energy ~~and IPL are unable to determine the magnitude of resulting changes to future~~currently expects a decrease in electric transmission service ~~charges~~expense in 2017 compared to 2016 primarily due to expected lower return on equity resulting from ~~this proceeding, but~~the MISO transmission owner return on equity complaints. Alliant Energy’s estimated 2017 electric transmission service expense remains subject to change pending the IUB’s approval of IPL’s 2017 transmission rates and the PSCW’s final decision in WPL’s retail electric rate case for the 2017/2018 Test Period. Based on IPL’s and WPL’s electric transmission cost recovery mechanisms, IPL and WPL currently do not expect ~~such charges~~that any changes to ~~be lower as~~electric transmission service costs billed by ITC and ATC will have a ~~result~~material impact on their financial condition and results of ~~FERC’s March 2016 order.~~operations. IPL and WPL could have a material impact on their cash flows depending on the final timing of refunds resulting from the MISO return on equity complaints, and the subsequent timing of the refunds being credited to their customers.

RESULTS OF OPERATIONS

Overview - ~~First~~Third Quarter Results -

Alliant Energy - “Executive Summary” provides an overview of Alliant Energy’s ~~first~~third quarter 2016 and 2015 earnings and the various components of its business.

IPL - Earnings available for common stock decreased $2 million primarily due to ~~lower~~timing of income tax expense, partially offset by higher retail electric ~~and gas~~ sales due to changes in temperatures in IPL’s service territory ~~partially offset by~~and higher AFUDC ~~lower retail electric customer billing credits~~ in the ~~first~~third quarter of 2016 compared to the ~~first~~third quarter of 2015 ~~and higher electric sales due~~related to ~~the additional day for leap year in 2016.~~Marshalltown.

WPL - Earnings available for common stock increased $2$1 million primarily due to lower energy efficiency cost recovery amortizations during the ~~first~~third quarter of 2016 ~~higher equity income from ATC~~ and higher ~~electric sales due to the additional day for leap year in 2016, partially offset by lower~~ retail electric ~~and gas~~ sales due to changes in temperatures in WPL’s service ~~territory.~~territory, partially offset by lower equity income from WPL’s ATC investment.

Additional details of Alliant Energy’s, IPL’s and WPL’s ~~first~~third quarter 2016 and 2015 earnings are discussed below.

Utility Electric Margins - Electric margins are defined as electric operating revenues less electric production fuel, ~~energy purchases,~~ purchased ~~electric capacity~~power and electric transmission service 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,~~ purchased ~~electric capacity~~power and electric transmission service 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, purchased electric capacity and electric transmission service~~such expenses.

~~First~~Third Quarter 2016 vs. ~~First~~Third Quarter 2015 Summary - Electric margins and MWh sales for the three months ended ~~March 31~~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)
	2016		2015		Change		2016	2015	Change		2016		2015		Change		2016	2015	Change
Residential (a)		$241.3		$257.3	(6	%)	1,841	2,052	(10	%)		$313.5		$303.2	3	%	2,091	2,047	2	%
Commercial (a)	162.1		155.2		4	%	1,596	1,596	—	%	212.8		200.3		6	%	1,771	1,694	5	%
Industrial - IPL co-generation customers	17.5		14.6		20	%	262	231	13	%	15.4		16.9		(9	%)	218	242	(10	%)
Industrial - other (a)	175.1		172.6		1	%	2,504	2,629	(5	%)	230.8		227.0		2	%	2,855	2,849	—	%
Retail subtotal (a)	596.0		599.7		(1	%)	6,203	6,508	(5	%)	772.5		747.4		3	%	6,935	6,832	2	%
Sales for resale:
Wholesale (a)	62.0		52.0		19	%	980	864	13	%	73.0		66.6		10	%	1,120	1,028	9	%
Bulk power and other	1.3		8.2		(84	%)	99	418	(76	%)	4.5		9.5		(53	%)	151	378	(60	%)
Other	9.6		11.4		(16	%)	25	37	(32	%)	14.3		12.3		16	%	24	28	(14	%)
Total revenues/sales	668.9		671.3		—	%	7,307	7,827	(7	%)	864.3		835.8		3	%	8,230	8,266	—	%
Electric production fuel expense	99.0		136.8		(28	%)					139.1		155.7		(11	%)
Energy purchases expense	101.5		78.9		29	%
Purchased electric capacity expense	0.4		0.2		100	%
Purchased power expense											106.8		90.1		19	%
Electric transmission service expense	127.9		123.2		4	%					138.6		127.6		9	%
Electric margins (b)		$340.1		$332.2	2	%						$479.8		$462.4	4	%



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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)
	2016		2015			Change		2016	2015	Change		2016		2015		Change		2016	2015	Change
Residential (a)		$129.8		$143.1		(9	%)	970	1,131	(14	%)		$173.7		$173.7	—	%	1,062	1,081	(2	%)
Commercial (a)	98.3		96.5			2	%	1,005	1,019	(1	%)	133.1		126.5		5	%	1,092	1,053	4	%
Industrial - IPL co-generation customers	17.5		14.6			20	%	262	231	13	%	15.4		16.9		(9	%)	218	242	(10	%)
Industrial - other (a)	86.0		90.4			(5	%)	1,354	1,502	(10	%)	121.5		121.3		—	%	1,526	1,540	(1	%)
Retail subtotal (a)	331.6		344.6			(4	%)	3,591	3,883	(8	%)	443.7		438.4		1	%	3,898	3,916	—	%
Sales for resale:
Wholesale (a)	23.2		7.6			205	%	340	119	186	%	28.1		20.4		38	%	366	275	33	%
Bulk power and other	0.6		2.5		��	(76	%)	8	124	(94	%)	1.4		1.1		27	%	23	28	(18	%)
Other	6.2		7.9			(22	%)	9	19	(53	%)	10.0		8.7		15	%	11	14	(21	%)
Total revenues/sales	361.6		362.6			—	%	3,948	4,145	(5	%)	483.2		468.6		3	%	4,298	4,233	2	%
Electric production fuel expense	35.2		63.5			(45	%)					54.7		72.0		(24	%)
Energy purchases expense	64.1		46.6			38	%
Purchased electric capacity expense	0.1		—			N/A
Purchased power expense												70.3		59.4		18	%
Electric transmission service expense	86.5		83.9			3	%					95.9		87.5		10	%
Electric margins (b)		$175.7		$168.6		4	%						$262.3		$249.7	5	%


WPL	Revenues and Costs (dollars in millions)						MWhs Sold (MWhs in thousands)				Revenues and Costs (dollars in millions)						MWhs Sold (MWhs in thousands)
	2016		2015		Change		2016	2015	Change		2016		2015		Change		2016	2015	Change
Residential		$111.5		$114.2	(2	%)	871	921	(5	%)		$139.8		$129.5	8	%	1,029	966	7	%
Commercial	63.8		58.7		9	%	591	577	2	%	79.7		73.8		8	%	679	641	6	%
Industrial	89.1		82.2		8	%	1,150	1,127	2	%	109.3		105.7		3	%	1,329	1,309	2	%
Retail subtotal	264.4		255.1		4	%	2,612	2,625	—	%	328.8		309.0		6	%	3,037	2,916	4	%
Sales for resale:
Wholesale	38.8		44.4		(13	%)	640	745	(14	%)	44.9		46.2		(3	%)	754	753	—	%
Bulk power and other	0.7		5.7		(88	%)	91	294	(69	%)	3.1		8.4		(63	%)	128	350	(63	%)
Other	3.4		3.5		(3	%)	16	18	(11	%)	4.3		3.6		19	%	13	14	(7	%)
Total revenues/sales	307.3		308.7		—	%	3,359	3,682	(9	%)	381.1		367.2		4	%	3,932	4,033	(3	%)
Electric production fuel expense	63.8		73.3		(13	%)					84.4		83.7		1	%
Energy purchases expense	37.4		32.3		16	%
Purchased electric capacity expense	0.3		0.2		50	%
Purchased power expense											36.5		30.7		19	%
Electric transmission service expense	41.4		39.3		5	%					42.7		40.1		6	%
Electric margins		$164.4		$163.6	—	%						$217.5		$212.7	2	%

(a)

InOn July 31, 2015, IPL sold its electric distribution assets in Minnesota to Southern Minnesota Energy Cooperative. 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 ~~$15~~$17 million and ~~$18~~$20 million of credits on IPL’s Iowa retail electric customers’ bills for the ~~first~~third quarters of 2016 and 2015, 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, 2016 and 2015.



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~~Variances~~Nine Months Ended September 30, 2016 vs. Nine Months Ended September 30, 2015Summary - ~~Variances between periods in electric~~Electric margins and MWh sales for the ~~three~~nine months ended ~~March 31, 2016 compared to the same period in 2015~~September 30 were as ~~follows (in millions):~~follows:

Alliant Energy IPL WPL
Retail electric customer billing credits at IPL (Refer to Note 2 for further details)

$4

$4

$—
Higher retail electric sales due to one additional day in 2016 for leap year 4
2
2
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)
3
3
—
Estimated changes in sales caused by temperatures (11 ) (6 ) (5 )
Other (a) 8
4
4

$8

$7

$1



Alliant Energy	Revenues and Costs (dollars in millions)						MWhs Sold (MWhs in thousands)
	2016		2015		Change		2016	2015	Change
Residential (a)		$779.9		$775.7	1	%	5,518	5,679	(3	%)
Commercial (a)	543.0		512.9		6	%	4,904	4,816	2	%
Industrial - IPL co-generation customers	48.2		45.5		6	%	704	700	1	%
Industrial - other (a)	599.3		588.8		2	%	8,013	8,217	(2	%)
Retail subtotal (a)	1,970.4		1,922.9		2	%	19,139	19,412	(1	%)
Sales for resale:
Wholesale (a)	196.7		165.5		19	%	3,025	2,663	14	%
Bulk power and other	8.2		24.2		(66	%)	347	1,051	(67	%)
Other	33.8		34.9		(3	%)	75	102	(26	%)
Total revenues/sales	2,209.1		2,147.5		3	%	22,586	23,228	(3	%)
Electric production fuel expense	325.8		376.3		(13	%)
Purchased power expense	320.5		270.6		18	%
Electric transmission service expense	396.8		367.7		8	%
Electric margins (b)		$1,166.0		$1,132.9	3	%



IPL	Revenues and Costs (dollars in millions)						MWhs Sold (MWhs in thousands)
	2016		2015		Change		2016	2015	Change
Residential (a)		$422.2		$434.8	(3	%)	2,827	3,055	(7	%)
Commercial (a)	336.1		318.9		5	%	3,076	3,043	1	%
Industrial - IPL co-generation customers	48.2		45.5		6	%	704	700	1	%
Industrial - other (a)	304.3		307.6		(1	%)	4,337	4,591	(6	%)
Retail subtotal (a)	1,110.8		1,106.8		—	%	10,944	11,389	(4	%)
Sales for resale:
Wholesale (a)	72.7		35.6		104	%	1,012	509	99	%
Bulk power and other	2.8		4.0		(30	%)	44	163	(73	%)
Other	22.9		24.2		(5	%)	31	54	(43	%)
Total revenues/sales	1,209.2		1,170.6		3	%	12,031	12,115	(1	%)
Electric production fuel expense	120.6		162.6		(26	%)
Purchased power expense	204.2		169.4		21	%
Electric transmission service expense	270.7		249.3		9	%
Electric margins (b)		$613.7		$589.3	4	%



WPL	Revenues and Costs (dollars in millions)						MWhs Sold (MWhs in thousands)
	2016		2015		Change		2016	2015	Change
Residential		$357.7		$340.9	5	%	2,691	2,624	3	%
Commercial	206.9		194.0		7	%	1,828	1,773	3	%
Industrial	295.0		281.2		5	%	3,676	3,626	1	%
Retail subtotal	859.6		816.1		5	%	8,195	8,023	2	%
Sales for resale:
Wholesale	124.0		129.9		(5	%)	2,013	2,154	(7	%)
Bulk power and other	5.4		20.2		(73	%)	303	888	(66	%)
Other	10.9		10.7		2	%	44	48	(8	%)
Total revenues/sales	999.9		976.9		2	%	10,555	11,113	(5	%)
Electric production fuel expense	205.2		213.7		(4	%)
Purchased power expense	116.3		101.2		15	%
Electric transmission service expense	126.1		118.4		7	%
Electric margins		$552.3		$543.6	2	%



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(a)

~~Includes increases~~On July 31, 2015, IPL sold its electric distribution assets in Minnesota. Prior to the asset sale, the electric sales to retail ~~temperature-normalized~~customers are included in residential, commercial and industrial sales. Subsequent to the asset sale, the related electric sales ~~volumes at~~are included in wholesale electric sales pursuant to the wholesale power supply agreement between IPL and ~~WPL. Refer to “Sales Trends” below~~Southern Minnesota Energy Cooperative.

(b)

Includes $47 million and $55 million of credits on Iowa retail electric customers’ bills for ~~further details.~~the nine months ended September 30, 2016 and 2015, 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, 2016 and 2015.

Variances - Variances between periods in electric margins for the three and nine months ended September 30, 2016 compared to the same periods in 2015 were as follows (in millions):



	Three Months								Nine Months
	Alliant Energy			IPL			WPL		Alliant Energy			IPL			WPL
Retail electric customer billing credits at IPL (Refer to Note 2 for further details)		$4			$4			$—		$12			$12			$—
Estimated changes in sales caused by temperatures	12			9			3		10			9			1
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)	3			3			—		8			8			—
Higher retail electric sales due to one additional day in 2016 for leap year	—			—			—		4			2			2
Other	(2		)	(3		)	2		(1		)	(7		)	6
		$17			$13			$5		$33			$24			$9

Temperatures - 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. HDD and CDD in Alliant Energy’s service territories for the three and nine months ended ~~March 31~~September 30 were as follows:


	Actual			Three Months			Nine Months
	2016	2015	Normal	Actual			Actual
HDD (a):
				2016	2015	Normal	2016	2015	Normal
HDD:
Cedar Rapids, Iowa (IPL)	3,069	3,690	3,432	39	83	142	3,759	4,355	4,276
Madison, Wisconsin (WPL)	3,258	3,834	3,519	49	98	175	4,135	4,653	4,529
CDD:
Cedar Rapids, Iowa (IPL)				651	530	534	948	730	754
Madison, Wisconsin (WPL)				570	503	474	771	664	655


~~(a)~~	~~HDD are calculated using a simple average of the high and low temperatures each day compared to a 65 degree base. Normal degree days are calculated using a rolling 20-year average of historical HDD.~~

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

2016 2015 Resulting Impact in 2016 Compared to 2015
First quarter (HDD) 10% warmer than normal 10% colder than normal Decrease in IPL’s and WPL’s electric and gas sales due to lower demand by customers for heating



	2016	2015	Resulting Impact in 2016 Compared to 2015
First quarter (HDD)	10% warmer than normal	10% 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% - 35% warmer than normal	10% colder than normal	Increase in IPL’s and WPL’s electric sales due to higher demand by customers for air cooling
Third quarter (CDD)	20% warmer than normal	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 nine months ended ~~March 31~~September 30 were as follows (in millions):


									Three Months							Nine Months
	2016			2015		Change			2016		2015			Change		2016		2015			Change
IPL		($4	)		$2		($6	)		$7		($2	)		$9		$7		($2	)		$9
WPL	(2		)	3		(5		)	4		1			3		3		2			1
Total Alliant Energy		($6	)		$5		($11	)		$11		($1	)		$12		$10		$—			$10



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Sales Trends - Alliant Energy’s retail sales volumes increased 2% and decreased 5%1% for the three and nine months ended ~~March 31,~~September 30, 2016 compared to the same ~~period~~periods in ~~2015.~~2015, respectively. The three-month ~~decrease~~increase was primarily due to the impact of temperatures on residential and commercial sales due to the warmer than normal temperatures and resulting ~~lower heating~~higher air cooling demand in the ~~first~~third quarter of 2016. The nine-month decrease was primarily due to decreases in IPL’s industrial sales due to large customer maintenance outages in 2016 and decreased retail sales related to IPL’s sale of its Minnesota electric distribution assets in July ~~2015. These items were~~2015, partially offset by ~~increases in temperature-normalized sales volumes due to customer expansions in WPL’s service territory and~~ an extra day of retail sales during the first quarter of 2016 due to the leap ~~year.~~year, and increases in WPL’s commercial and industrial sales due to customer expansions.

Alliant Energy’s wholesale sales volumes increased ~~13%~~9% and 14% for the three and nine months ended ~~March 31,~~September 30, 2016 compared to the same ~~period~~periods in ~~2015. The three-month increase was~~2015, respectively. These increases were primarily due to additional sales from IPL’s new wholesale power supply agreement with Southern Minnesota Energy ~~Cooperative. This increase was~~Cooperative effective August 1, 2015. These increases were partially offset by 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.

Alliant Energy’s bulk power and other ~~revenue~~sales volumes changes were largely due to changes in sales in the wholesale energy markets operated by MISO. 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.

Electric Production Fuel and ~~Energy Purchases~~Purchased Power (Fuel-related) Expenses - Fossil fuels, such as ~~coal~~natural gas and ~~natural gas,~~coal, 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~~purchased power expense.

Due to IPL’s cost recovery mechanisms for fuel-related expenses, changes in fuel-related expenses 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 expenses 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.



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~~Table of Contents~~

WPL’s cost recovery mechanism for retail fuel-related expenses supports deferrals of amounts that fall outside an approved bandwidth of plus or minus 2% of forecasted fuel-related expenses determined by the PSCW each year. The difference between revenue collected and actual fuel-related expenses incurred within the bandwidth increases or decreases Alliant Energy’s and WPL’s electric margins. WPL estimates the increases to electric margins from amounts within the bandwidth were approximately $2 million and $1$5 million for the three and nine months ended ~~March 31,~~September 30, 2016, respectively. WPL estimates the increases to electric margins from amounts within the bandwidth were approximately $2 million and ~~March 31,~~$6 million for the three and nine months ended September 30, 2015, respectively.

Alliant Energy’s electric production fuel expense decreased ~~$38~~$17 million and $51 million for the three and nine months ended ~~March 31,~~September 30, 2016 compared to the same ~~period~~periods in ~~2015.~~2015, respectively. The ~~decrease was~~decreases were primarily due to lower dispatch of IPL’s and WPL’s coal-fired EGUs during the ~~first quarter of~~three and nine months ended September 30, 2016 ~~primarily~~partially due to lower wholesale energy market prices and WPL’s retirement of Nelson Dewey Units 1 and 2 in December 2015. The decreases were also due to changes in the under-/over-collection of fuel-related expenses at IPL and lower natural gas prices. These items were partially offset by amortizations during the three and nine months ended ~~March 31,~~September 30, 2016 of $7$8 million and $22 million, respectively, of ~~deferred~~under-recovered fuel-related expenses ~~incurred~~deferred by WPL in ~~2014. These~~2014, and $4 million and $9 million of deferrals recorded during the three and nine months ended September 30, 2016, respectively, for over-recovered fuel-related costs in 2016 that were outside the approved bandwidth for WPL. The amortizations are based upon a July 2015 PSCW order authorizing WPL to recover $28 million, including interest, from its retail electric customers during 2016 for deferred fuel-related expenses incurred in 2014.

Alliant Energy’s ~~energy purchases~~purchased power expense increased ~~$23~~$17 million and $50 million for the three and nine months ended ~~March 31,~~September 30, 2016 compared to the same ~~period~~periods in 2015, respectively, primarily due to increased volumes purchased resulting from lower dispatch of IPL’s and WPL’s coal-fired EGUs during the ~~first quarter of 2016.~~three- and nine-month periods.

Electric Transmission Service Expense - Costs incurred each period for the transmission of electricity to meet the demands of IPL’s and WPL’s customers are included in electric transmission service expense. Electric transmission service expense is recovered from IPL’s Iowa retail electric customers through a transmission cost rider and from WPL’s retail electric customers through changes in base rates determined during periodic rate ~~proceedings.~~proceedings, subject to an over/under escrow



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treatment. IPL and WPL arrange transmission service for the majority of their respective wholesale electric customers. The wholesale portion of electric transmission service expense is allocated to and recovered from these wholesale customers based on a load ratio share computation. Due to IPL’s and WPL’s cost recovery mechanisms for electric transmission service expense, changes in electric transmission service expense resulted in comparable changes in electric revenues and, therefore, did not have a significant impact on Alliant Energy’s, IPL’s and WPL’s electric margins. Alliant Energy’s electric transmission service expense increased $5$11 million and $29 million for the three and nine months ended ~~March 31,~~September 30, 2016 compared to the same ~~period~~periods in 2015, respectively, primarily due to higher electric transmission service rates billed by ITC, ATC and MISO.

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.

~~First~~Third Quarter 2016 vs. ~~First~~Third Quarter 2015 Summary - Gas margins and Dth sales for the three months ended ~~March 31~~September 30 were as follows:

Alliant Energy Revenues and Costs (dollars in millions) Dths Sold (Dths in thousands)
2016 2015 Change 2016 2015 Change
Residential
$88.1

$116.9
(25 %) 12,116
14,986
(19 %)
Commercial 49.9
65.3
(24 %) 8,084
9,568
(16 %)
Industrial 5.0
5.9
(15 %) 971
1,023
(5 %)
Retail subtotal 143.0
188.1
(24 %) 21,171
25,577
(17 %)
Transportation/other 9.2
10.3
(11 %) 22,235
22,587
(2 %)
Total revenues/sales 152.2
198.4
(23 %) 43,406
48,164
(10 %)
Cost of gas sold 95.2
130.8
(27 %)
Gas margins (a)
$57.0

$67.6
(16 %)



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~~Table of Contents~~



Alliant Energy	Revenues and Costs (dollars in millions)						Dths Sold (Dths in thousands)
	2016		2015		Change		2016	2015	Change
Residential		$17.8		$17.6	1	%	1,397	1,204	16	%
Commercial	10.6		11.0		(4	%)	1,972	1,616	22	%
Industrial	2.5		2.4		4	%	557	541	3	%
Retail subtotal	30.9		31.0		—	%	3,926	3,361	17	%
Transportation/other	8.6		7.0		23	%	20,302	18,772	8	%
Total revenues/sales	39.5		38.0		4	%	24,228	22,133	9	%
Cost of gas sold	12.5		13.6		(8	%)
Gas margins (a)		$27.0		$24.4	11	%


IPL	Revenues and Costs (dollars in millions)						Dths Sold (Dths in thousands)				Revenues and Costs (dollars in millions)						Dths Sold (Dths in thousands)
	2016		2015		Change		2016	2015	Change		2016		2015		Change		2016	2015	Change
Residential		$48.8		$65.1	(25	%)	6,616	8,390	(21	%)		$10.3		$10.3	—	%	799	638	25	%
Commercial	27.1		35.7		(24	%)	4,175	5,148	(19	%)	6.6		6.8		(3	%)	1,245	854	46	%
Industrial	2.9		3.9		(26	%)	552	701	(21	%)	2.0		2.0		—	%	442	442	—	%
Retail subtotal	78.8		104.7		(25	%)	11,343	14,239	(20	%)	18.9		19.1		(1	%)	2,486	1,934	29	%
Transportation/other	5.4		6.5		(17	%)	9,418	10,017	(6	%)	5.0		4.0		25	%	8,783	7,819	12	%
Total revenues/sales	84.2		111.2		(24	%)	20,761	24,256	(14	%)	23.9		23.1		3	%	11,269	9,753	16	%
Cost of gas sold	52.4		71.0		(26	%)					8.0		9.4		(15	%)
Gas margins (a)		$31.8		$40.2	(21	%)						$15.9		$13.7	16	%


WPL	Revenues and Costs (dollars in millions)						Dths Sold (Dths in thousands)				Revenues and Costs (dollars in millions)						Dths Sold (Dths in thousands)
	2016		2015		Change		2016	2015	Change		2016		2015		Change		2016	2015	Change
Residential		$39.3		$51.8	(24	%)	5,500	6,596	(17	%)		$7.5		$7.3	3	%	598	566	6	%
Commercial	22.8		29.6		(23	%)	3,909	4,420	(12	%)	4.0		4.2		(5	%)	727	762	(5	%)
Industrial	2.1		2.0		5	%	419	322	30	%	0.5		0.4		25	%	115	99	16	%
Retail subtotal	64.2		83.4		(23	%)	9,828	11,338	(13	%)	12.0		11.9		1	%	1,440	1,427	1	%
Transportation/other	3.8		3.8		—	%	12,817	12,570	2	%	3.6		3.0		20	%	11,519	10,953	5	%
Total revenues/sales	68.0		87.2		(22	%)	22,645	23,908	(5	%)	15.6		14.9		5	%	12,959	12,380	5	%
Cost of gas sold	42.8		59.8		(28	%)					4.5		4.2		7	%
Gas margins		$25.2		$27.4	(8	%)						$11.1		$10.7	4	%


(a)	Includes $3 million of credits on IPL’s Iowa retail gas customers’ bills for both the ~~first~~third quarters of 2016 and 2015 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, 2016 and ~~2015~~.2015.



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Nine Months Ended September 30, 2016 vs. Nine Months Ended September 30, 2015 - Gas margins and Dth sales for the nine months ended September 30 were as follows:



Alliant Energy	Revenues and Costs (dollars in millions)						Dths Sold (Dths in thousands)
	2016		2015		Change		2016	2015	Change
Residential		$135.7		$162.1	(16	%)	17,317	19,475	(11	%)
Commercial	77.1		91.3		(16	%)	13,194	13,879	(5	%)
Industrial	10.1		10.4		(3	%)	2,209	2,092	6	%
Retail subtotal	222.9		263.8		(16	%)	32,720	35,446	(8	%)
Transportation/other	25.8		24.3		6	%	61,615	57,213	8	%
Total revenues/sales	248.7		288.1		(14	%)	94,335	92,659	2	%
Cost of gas sold	132.3		166.3		(20	%)
Gas margins (a)		$116.4		$121.8	(4	%)



IPL	Revenues and Costs (dollars in millions)						Dths Sold (Dths in thousands)
	2016		2015		Change		2016	2015	Change
Residential		$76.5		$90.9	(16	%)	9,477	10,709	(12	%)
Commercial	43.7		50.7		(14	%)	7,119	7,335	(3	%)
Industrial	7.0		7.6		(8	%)	1,501	1,562	(4	%)
Retail subtotal	127.2		149.2		(15	%)	18,097	19,606	(8	%)
Transportation/other	15.4		14.9		3	%	27,066	25,962	4	%
Total revenues/sales	142.6		164.1		(13	%)	45,163	45,568	(1	%)
Cost of gas sold	76.3		93.4		(18	%)
Gas margins (a)		$66.3		$70.7	(6	%)



WPL	Revenues and Costs (dollars in millions)						Dths Sold (Dths in thousands)
	2016		2015		Change		2016	2015	Change
Residential		$59.2		$71.2	(17	%)	7,840	8,766	(11	%)
Commercial	33.4		40.6		(18	%)	6,075	6,544	(7	%)
Industrial	3.1		2.8		11	%	708	530	34	%
Retail subtotal	95.7		114.6		(16	%)	14,623	15,840	(8	%)
Transportation/other	10.4		9.4		11	%	34,549	31,251	11	%
Total revenues/sales	106.1		124.0		(14	%)	49,172	47,091	4	%
Cost of gas sold	56.0		72.9		(23	%)
Gas margins		$50.1		$51.1	(2	%)


(a)	Includes $9 million of credits on IPL’s Iowa retail gas customers’ bills for both the nine months ended September 30, 2016 and 2015 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, 2016 and 2015.

Variances - Variances between periods in gas margins for the three and nine months ended ~~March 31,~~September 30, 2016 compared to the same ~~period~~periods in 2015 were as follows (in millions):

Alliant Energy IPL WPL
Estimated decrease from changes in sales caused by temperatures
($6 )
($3 )
($3 )
Lower revenues at IPL related to changes in recovery amounts for energy efficiency costs through the energy efficiency rider (a) (3 ) (3 ) —
Other (2 ) (2 ) 1

($11 )
($8 )
($2 )



	Three Months						Nine Months
	Alliant Energy		IPL		WPL		Alliant Energy			IPL			WPL
Estimated changes in sales caused by temperatures		$—		$—		$—		($5	)		($3	)		($2	)
Higher (lower) revenues at IPL related to changes in recovery amounts for energy efficiency costs through the energy efficiency rider (a)	1		1		—		(3		)	(3		)	—
Other	2		1		—		3			2			1
		$3		$2		$—		($5	)		($4	)		($1	)


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



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Temperatures - Estimated increases (decreases) to gas margins from the impacts of temperatures for the three and nine months ended ~~March 31~~September 30 were as follows (in millions):


									Three Months								Nine Months
	2016			2015		Change			2016			2015			Change		2016			2015		Change
IPL		($2	)		$1		($3	)		$—			$—			$—		($2	)		$1		($3	)
WPL	(1		)	2		(3		)	(1		)	(1		)	—		(2		)	—		(2		)
Total Alliant Energy		($3	)		$3		($6	)		($1	)		($1	)		$—		($4	)		$1		($5	)

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



	36

Asset Valuation Charges for Franklin County Wind Farm - Refer to ~~Table~~Note 3 for details of ~~Contents~~

asset valuation charges recorded in the third quarter of 2016 by Alliant Energy for the Franklin County wind farm.

Other Operation and Maintenance Expenses - Variances between periods in other operation and maintenance expenses for the three and nine months ended ~~March 31,~~September 30, 2016 compared to the same ~~period~~periods in 2015 were as follows (in millions):


	Alliant Energy			IPL			WPL			Three Months									Nine Months
										Alliant Energy			IPL			WPL			Alliant Energy			IPL			WPL
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	)		$—
Lower energy efficiency cost recovery amortizations at WPL (a)		($4	)		$—			($4	)	(4		)	—			(4		)	(11		)	—			(11		)
Voluntary employee separation charges in the third quarter of 2015 (Refer to Note 9(a) for further details)										(8		)	(5		)	(3		)	(8		)	(5		)	(3		)
Changes in energy efficiency expense at IPL (b)	(3		)	(3		)	—			—			—			—			(4		)	(4		)	—
Higher stock-based performance compensation expense										4			2			2			11			6			5
Higher employee benefits-related expense										2			1			1			5			4			1
Other	4			2			2			3			3			1			1			3			(3		)
		($3	)		($1	)		($2	)		($3	)		$1			($3	)		($18	)		($8	)		($11	)


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


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

Depreciation and Amortization Expenses - Variances between periods in depreciation and amortization expenses for the three and nine months ended ~~March 31,~~September 30, 2016 compared to the same ~~period~~periods in 2015 were as follows (in millions):


	Alliant Energy			IPL			WPL		Three Months						Nine Months
									Alliant Energy		IPL		WPL		Alliant Energy			IPL			WPL
Higher amortization expense from the new customer billing and information system placed in service in 2015										$3		$2		$1		$7			$4			$3
Lower depreciation expense from the sale of IPL’s Minnesota distribution assets in 2015		($2	)		($2	)		$—	—		—		—		(3		)	(3		)	—
Other (includes the impact of property additions)	4			3			1		2		—		2		5			2			3
		$2			$1			$1		$5		$2		$3		$9			$3			$6

Equity Income from Unconsolidated Investments, Net - Alliant Energy’s and WPL’s equity income from unconsolidated investments ~~increased $4 million and $3~~both decreased $2 million for the three-month period, ~~respectively,~~ primarily due to higher reserves for rate refunds recorded at ATC during the three months ended ~~March 31, 2015~~September 30, 2016 compared to the same period in ~~2016.~~2015. Refer to “Other Future Considerations” for discussion of WPL’s future transfer of its investment in ATC to Alliant Energy or an Alliant Energy subsidiary.



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AFUDC - Variances between periods in AFUDC for the three and nine months ended ~~March 31,~~September 30, 2016 compared to the same ~~period~~periods in 2015 were as follows (in millions):


	Alliant Energy		IPL			WPL		Three Months						Nine Months
Marshalltown at IPL		$6		$6			$—
								Alliant Energy		IPL		WPL		Alliant Energy		IPL		WPL
Marshalltown (IPL)									$5		$5		$—		$17		$17		$—
Other	—		(1		)	1		1		2		—		2		—		2
		$6		$5			$1		$6		$7		$—		$19		$17		$2

Income Taxes - Refer to Note 8 for details of effective income tax rates for continuing operations.

STRATEGIC OVERVIEW

AThe strategic overview summary is included in the 2015 Form 10-K ~~and~~ has not changed materially, ~~from the items reported in the~~ ~~2015~~ ~~Form 10-K,~~ except as described below.

Gas Transmission and Distribution Systems - In ~~March~~April 2016, the Pipeline and Hazardous Materials Safety Administration ~~announced~~published proposed regulations to update safety requirements for gas transmission pipelines. The proposed regulations would add new assessment and repair criteria for gas pipelines, and require a systematic approach to verify a pipeline’s maximum allowable operating pressure. Alliant Energy, IPL and WPL currently anticipate final regulations will be issued in 2017. Given that the Pipeline and Hazardous Materials Safety Administration has not finalized these gas transmission regulations, Alliant Energy, IPL and WPL are currently unable to predict with certainty the impact of these regulations on their financial condition and results of operations.

IPL’s Clinton Natural Gas Pipeline - In August 2016, IPL received an order from the IUB authorizing IPL to construct, maintain, and operate a natural gas pipeline in Scott and Clinton Counties in Iowa, referred to as the Clinton pipeline. Construction is expected to be completed in the first quarter of 2017. Capital expenditures to construct the pipeline, excluding AFUDC, are currently estimated to be approximately $30 million to $35 million.

Generation Plans -

Natural Gas-Fired Generation -

WPL’s Construction of the Riverside Expansion - In ~~March~~May 2016, WPL received ~~a decision~~an order from the PSCW authorizing WPL to construct a natural gas-fired combined-cycle EGU in Beloit, Wisconsin, referred to as the Riverside expansion. ~~The~~In June 2016, WPL executed a design, engineering, procurement and construction contract for the Riverside expansion. After receiving the final necessary regulatory approvals and permits in the third quarter of 2016, WPL began constructing the Riverside expansion. WPL currently expects to place the Riverside expansion in service by early 2020.

In November 2016, various electric cooperatives notified WPL of their intent to exercise their options to acquire approximately 60 MW of the Riverside expansion while the EGU is being constructed. As a result of the various electric cooperatives funding a portion of the capital expenditures during construction, WPL’s estimated portion of capital expenditures is now expected to be approximately $640 million. The capital expenditures include costs to construct the EGU and a pipeline to supply natural gas to the EGU and exclude transmission network upgrades and AFUDC. Upon exercise of their options, the current wholesale power supply agreements with the various electric cooperatives will be extended by at least four years until 2026 with automatic continuation of such agreements unless terminated by either party, with a five-year notice requirement.

Pursuant to agreements WPL entered into with Wisconsin Public Service Corporation (WPSC) and Madison Gas and Electric Company (MGE) related to the Riverside expansion, WPL, WPSC and MGE filed a request with the PSCW seeking approval of amendments to the Columbia joint operating agreement. In October 2016, WPL received a decision from the PSCW approving such amendments, which allow WPSC and MGE to forgo certain capital expenditures at Columbia, resulting in WPL incurring these additional capital expenditures in exchange for a proportional increase in its ownership share of Columbia. Based upon the additional capital expenditures WPL currently expects to incur through June 1, 2020, WPL’s ownership interest in Columbia is expected to increase from 46.2% to 53.4%. WPL currently expects to file a request with FERC in the fourth quarter of 2016 for approval of these amendments to the Columbia joint operating agreement.

IPL’s Construction of Marshalltown - IPL began constructing Marshalltown in the second quarter of 2014 after receiving the final necessary regulatory approvals and permits. IPL executed an engineering, procurement and construction contract for Marshalltown after a competitive bidding process. In September 2016, Marshalltown’s engineering, procurement and construction contractor announced that costs to construct Marshalltown will exceed its expectations and that it expects to



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seek compensation from vendors performing work on Marshalltown. IPL does not currently anticipate it will be responsible for these increased costs. Capital expenditures are currently estimated to be approximately $700 million to construct the EGU and a pipeline to supply natural gas to the EGU. The estimated capital expenditures exclude transmission network upgrades and AFUDC. IPL expects to place Marshalltown in service by the second quarter of 2017.

Wind Generation - The strategic plan includes the planned and potential addition of wind generation of up to 1,000 MW to Alliant Energy’s resources portfolio as follows. Estimated capital expenditures for the planned and potential wind generation projects for 2016 through 2020 are included in the “Renewable projects” line in the construction and acquisition expenditures table in “Liquidity and Capital Resources.”

Up to 500 MW of additional wind generation that qualifies for the full level of production tax credits, regardless of the location in Iowa, with a cost cap of $1,830/kilowatt, including AFUDC and transmission costs. Any costs incurred in excess of this $1,830/kilowatt cost cap are expected to be incorporated into rates if determined to be reasonable and prudent.

A depreciable life of the wind generation of 40 years, unless changed as a result of a contested case before the IUB.

An 11.0% return on common equity, with the exception of certain transmission facilities classified as intangible assets, which would earn the rate of return on common equity the IUB finds reasonable during a future rate case.

A return on common equity for the calculation of AFUDC during the construction period that is the greater of 10.0% or the percentage the IUB finds reasonable during IPL’s next rate case.

The application of double leverage is deferred until IPL’s next retail electric base rate case or other future proceeding.

Amortization over a 10-year period of IPL’s prudently incurred and unreimbursed costs, effective with IPL’s next retail electric base rate case, if IPL cancels the construction of the wind generation.

Withdrawal of IPL’s proposed renewable energy rider, which would have allowed IPL to commence recovery of the wind projects from its retail electric customers at the time the additional wind generation was placed in service.

IPL currently expects to add wind generation near its Whispering Willow - East wind farm, and is evaluating other siting options to build and operate the 500 MW of additional wind. IPL plans to commence the construction process in 2016, and as a result, be eligible for the full level of production tax credits from the electricity generated during the first 10 years of operation. IPL anticipates placing the 500 MW of additional wind generation in service in 2019 and 2020.

Franklin County Wind Farm - In addition to IPL’s expansion of wind generation discussed above, refer to Note 3 for discussion of IPL’s anticipated filing with FERC in the fourth quarter of 2016 requesting approval to transfer the 99 MW Franklin County wind farm assets from AEF to IPL in 2017.

IPL’s and WPL’s Potential Expansion of Wind Generation - In addition to IPL’s 500 MW expansion of wind generation and planned transfer of the 99 MW Franklin County wind farm to IPL in 2017 discussed above, IPL and WPL are exploring options to own and operate up to 400 MW of additional new wind generation in aggregate. The estimated capital expenditures included in “Liquidity and Capital Resources” assume this 400 MW of additional new wind generation will be equally allocated between IPL and WPL. The final amount and allocation of this potential expansion of wind generation for IPL and WPL is subject to change pending further evaluation.

Coal-Fired Generation -

Environmental Controls Projects - Refer to Note 3 for further discussion of a scrubber and baghouse project at Edgewater Unit 5, which was completed in July 2016.

RATE MATTERS

The rate matters summary included in the ~~receipt~~2015 Form 10-K has not changed materially, except as described below.



	46

Table of ~~various other approvals~~Contents

implement a $13 million, or approximately 1%, increase in annual rates for WPL’s retail electric customers. The net requested increase for 2017 compared to WPL’s retail electric rate case for the 2015/2016 Test Period reflects a $65 million increase in base rates, partially offset by a $52 million reduction in fuel-related costs, using a preliminary estimate for 2017 fuel-related costs. Based on updated fuel-related cost information at the time of rate case hearings in September 2016, the current estimate of the net increase in annual rates for WPL’s retail electric customers is $17 million, consisting of the original $65 million increase in base rates, partially offset by a $48 million reduction in fuel-related costs. The filing also requested approval for WPL to implement a $9 million, or approximately 13%, increase in annual base rates for WPL’s retail gas customers. Any rate changes granted from this request are expected to be effective January 1, 2017 and ~~permits necessary~~extend through the end of 2018. The key drivers for the electric and gas base rate increases are recovery of the costs for environmental controls projects at Edgewater and Columbia, and investments in electric and gas distribution systems, including expansion of natural gas pipeline infrastructure. The filing also included utilization of amounts that WPL previously over-recovered from its customers for energy efficiency cost recovery and electric transmission cost recovery, as well as amounts deferred under the return on common equity sharing mechanism for the 2013/2014 Test Period to ~~construct and operate~~reduce the ~~EGU and connect such EGU to the transmission system. Subject to such approvals, construction~~requested base rate increases. The fuel-related cost component of WPL’s retail electric rates for 2018 will be addressed in a separate filing, which is currently expected to ~~begin~~be filed in the second or third quarter of 2017.

WPL’s May 2016 retail base rate filing included a return on common equity of 10.0% and becontinues a regulatory return on common equity sharing mechanism, whereby WPL must defer a portion of its earnings if its annual regulatory return on common equity exceeds 10.25% during the 2017 and 2018 Test Period. WPL must defer 50% of its excess earnings between 10.25% and 11.00%, and 100% of any excess earnings above 11.00%. The May 2016 filing also included the following key assumptions (Common Equity (CE); Long-term Debt (LD); Short-term Debt (SD); Weighted-average Cost of Capital (WACC)):



Utility	Test	Regulatory Capital Structure			After-tax	Average Retail Rate
Type	Period	CE	LD	SD	WACC	Base (in millions) (a)
Electric	2017	52.23%	43.92%	3.85%	7.57%		$2,699
Electric	2018	52.20%	45.16%	2.64%	7.59%	2,851
Gas	2017	52.23%	43.92%	3.85%	7.57%	259
Gas	2018	52.20%	45.16%	2.64%	7.59%	284


(a)	Average rate base is calculated using a 13-month average.

The May 2016 retail base rate filing also reflected the impact of the anticipated transfer of ATC from WPL to Alliant Energy or one of its subsidiaries by December 31, 2016 as discussed in “Other Future Considerations,” approved changes to depreciation rates pursuant to a September 2016 PSCW order, continued escrow treatment of transmission charges and application of AFUDC rates to 100% of the retail portion of the CWIP balances for the Riverside expansion. If WPL does not complete the anticipated transfer of ATC to Alliant Energy or one of its subsidiaries by December 31, 2016, WPL would expect to defer the revenue requirement impacts until such time the transfer occurs or until WPL’s next base rate case filing. The filing also assumed deferral of any potential changes in revenue requirement due to anticipated increases in WPL’s ownership share of Columbia resulting from the Riverside expansion agreements WPL previously entered into with neighboring utilities.

WPL currently expects a decision from the PSCW regarding this base rate filing in the fourth quarter of 2016.

WPL’s Retail Fuel-related Rate Filings - Refer to Note 2 for discussion of WPL’s retail fuel-related rate filings for the 2015 and 2016 Test Years.

WPL’s Depreciation Study - Refer to Note 1(c) for discussion of a September 2016 PSCW order approving updated depreciation rates for WPL effective January 1, 2017 as a result of a recently completed ~~by early 2020.~~depreciation study. The September 2016 PSCW order also authorized WPL to recover the remaining net book value of Edgewater Unit 4 over a 10-year period beginning the later of the retirement date of the EGU or January 1, 2019.

IPL’s Tax Benefit Riders - Pursuant to a 2015 IUB order, IPL established tax benefit riders regulatory liabilities in 2014 to record additional tax savings related to repair expenditures and cost of removal expenditures on partial dispositions that were previously capitalized to help offset the impact of future rate increases on IPL’s retail electric and gas customers. In November 2016, IPL filed a tariff with the IUB to facilitate refunds of approximately $75 million of the related tax benefits to IPL’s retail electric and gas customers in 2017. IPL currently expects a decision from the IUB in December 2016.



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~~RATE~~ENVIRONMENTAL MATTERS

~~A rate~~The environmental matters summary is included in the 2015 Form 10-K ~~and~~ has not changed materially, ~~from the items reported in the~~ ~~2015~~ ~~Form 10-K,~~ except as described below.

~~WPL’s Retail Fuel-related Rate Filing (2015 Test Year) -~~ Pursuant to a 2014 PSCW order, WPL’s 2015 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, 2015 were lower than fuel-related costs used to determine rates for such period resulting in an over-collection of fuel-related costs. In March 2016, WPL filed a fuel reconciliation application with the PSCW for approval to refund $10 million of over-collections, including interest, to its retail electric customers. WPL anticipates a decision from the PSCW regarding its application in the third quarter of 2016.

~~ENVIRONMENTAL MATTERS~~

~~An environmental matters summary is included in the~~ ~~2015~~ ~~Form 10-K and has not changed materially from the items reported in the~~ ~~2015~~ ~~Form 10-K, except as described below.~~

Air Quality -

Ozone NAAQS Rule - The 2008 Ozone NAAQS Rule may require a reduction of NOx emissions in certain non-attainment areas designated by the EPA. Sheboygan County in Wisconsin is currently the only non-attainment area for the 2008 Ozone NAAQS Rule in Alliant Energy’s service territory. WPL operates Edgewater and the Sheboygan Falls Energy Center in Sheboygan County, Wisconsin. ~~In response to Wisconsin’s request for a one-year extension, in April 2016, the EPA changed the~~The compliance deadline ~~to July 2016~~ for Sheboygan County to meet the 2008 Ozone NAAQS ~~Rule.~~Rule was July 2016. Alliant Energy and WPL are currently in compliance with applicable requirements resulting from the 2008 Ozone NAAQS rule.

LEGISLATIVE MATTERS

AThe legislative matters summary is included in the 2015 Form 10-K ~~and~~ has not changed ~~materially from the items reported in the~~ ~~2015~~ ~~Form 10-K.~~materially.

LIQUIDITY AND CAPITAL RESOURCES

AThe liquidity and capital resources matters summary is included in the 2015 Form 10-K ~~and~~ has not changed materially, ~~from the items reported in the~~ ~~2015~~ ~~Form 10-K,~~ except as described below.

Liquidity Position - At ~~March 31,~~September 30, 2016, Alliant Energy had $5$85 million of cash and cash equivalents, ~~$787~~$762 million ($~~112~~74 million at the parent company, $300 million at IPL and ~~$375~~$388 million at WPL) of available capacity under the revolving credit facilities and ~~$118~~$179 million of available capacity at IPL under its sales of accounts receivable program.

Capital Structures - Capital structures at ~~March 31,~~September 30, 2016 were as follows (dollars in millions):

Alliant Energy
(Consolidated)
IPL WPL
Common equity
$3,764.6
47 %
$2,042.9
50 %
$1,769.1
53 %
Preferred stock of IPL 200.0
2 % 200.0
5 % —
— %
Noncontrolling interest —
— % —
— % 14.0
— %
Long-term debt (incl. current maturities) 3,836.1
48 % 1,857.4
45 % 1,534.2
46 %
Short-term debt 213.4
3 % —
— % 25.5
1 %

$8,014.1
100 %
$4,100.3
100 %
$3,342.8
100 %

~~Table of Contents~~



	Alliant Energy (Consolidated)				IPL				WPL
Common equity		$3,859.1	46	%		$2,137.9	48	%		$1,813.8	54	%
Preferred stock of IPL	200.0		2	%	200.0		4	%	—		—	%
Noncontrolling interest	—		—	%	—		—	%	18.5		1	%
Long-term debt (incl. current maturities)	4,130.9		49	%	2,153.1		48	%	1,534.9		45	%
Short-term debt	238.3		3	%	—		—	%	11.8		—	%
		$8,428.3	100	%		$4,491.0	100	%		$3,379.0	100	%

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


	Alliant Energy						IPL						WPL						Alliant Energy						IPL						WPL
	2016			2015			2016			2015			2016			2015			2016			2015			2016			2015			2016			2015
Cash and cash equivalents, January 1		$5.8			$56.9			$4.5			$5.3			$0.4			$46.7			$5.8			$56.9			$4.5			$5.3			$0.4			$46.7
Cash flows from (used for):
Operating activities	228.3			314.7			116.4			170.1			123.6			157.8			654.0			695.3			256.5			318.0			439.3			375.9
Investing activities	(220.0		)	(250.9		)	(123.2		)	(156.3		)	(91.4		)	(78.4		)	(771.8		)	(613.0		)	(435.4		)	(319.4		)	(326.7		)	(259.6		)
Financing activities	(9.3		)	(23.1		)	5.3			(16.5		)	(31.3		)	(35.2		)	196.7			—			252.1			95.5			(107.4		)	(127.3		)
Net increase (decrease)	(1.0		)	40.7			(1.5		)	(2.7		)	0.9			44.2			78.9			82.3			73.2			94.1			5.2			(11.0		)
Cash and cash equivalents, March 31		$4.8			$97.6			$3.0			$2.6			$1.3			$90.9
Cash and cash equivalents, September 30																				$84.7			$139.2			$77.7			$99.4			$5.6			$35.7



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Operating Activities -

~~Three~~Nine Months Ended ~~March 31,~~September 30, 2016 vs. ~~Three~~Nine Months Ended ~~March 31,~~September 30, 2015 - The following items contributed to increased (decreased) operating activity cash flows for the ~~three~~nine months ended ~~March 31,~~September 30, 2016 compared to the same period in 2015 (in millions):


	Alliant Energy			IPL			WPL			Alliant Energy			IPL			WPL
Changes in levels of gas stored underground		($22	)		($11	)		($11	)
Changes in cash collateral balances	(19		)	—			(5		)		($29	)		$—			$—
Decreased collections from IPL’s and WPL’s retail customers caused by temperature impacts on electric and gas sales	(17		)	(9		)	(8		)
Changes in levels of gas stored underground and prepaid gas costs										(20		)	(10		)	(10		)
Changes in income taxes paid/refunded										(8		)	(30		)	30
Timing of WPL’s fuel-related cost recoveries from customers										25			—			25
Changes in levels of production fuel	(15		)	(17		)	2			10			(12		)	22
Changes in income taxes paid/refunded at IPL and WPL	—			(5		)	(17		)
Other	(13		)	(12		)	5			(19		)	(10		)	(4		)
		($86	)		($54	)		($34	)		($41	)		($62	)		$63

Investing Activities -

~~Three~~Nine Months Ended ~~March 31,~~September 30, 2016 vs. ~~Three~~Nine Months Ended ~~March 31,~~September 30, 2015 - The following items contributed to increased (decreased) investing activity cash flows for the ~~three~~nine months ended ~~March 31,~~September 30, 2016 compared to the same period in 2015 (in millions):


	Alliant Energy			IPL		WPL			Alliant Energy			IPL			WPL
Proceeds from IPL’s Minnesota distribution asset sales in 2015										($138	)		($138	)		$—
Higher utility construction expenditures									(65		)	(4		)	(61		)
Proceeds from the liquidation of company-owned life insurance policies		$26			$18		$—		31			19			—
Lower (higher) utility construction expenditures	6			15		(10		)
Other	(1		)	—		(3		)	13			7			(6		)
		$31			$33		($13	)		($159	)		($116	)		($67	)

Construction and Acquisition Expenditures - Construction and acquisition expenditures for 2016 through 2020 are currently anticipated as follows (in millions). Cost estimates represent Alliant Energy’s, IPL’s and WPL’s estimated portion of total escalated construction expenditures and exclude AFUDC and capitalized interest, if applicable. Such estimates reflect impacts to Alliant Energy’s and WPL’s capital expenditures resulting from the intent to exercise purchase options by certain electric cooperatives for a partial ownership interest in the Riverside expansion, as well as additional capital expenditures related to Columbia that WPL is expected to incur related to agreements entered into with Wisconsin Public Service Corporation and Madison Gas and Electric Company. Refer to “Strategic Overview” for further discussion of certain key projects impacting construction and acquisition plans related to the utility business.



	Alliant Energy										IPL										WPL
	2016		2017		2018		2019		2020		2016		2017		2018		2019		2020		2016		2017		2018		2019		2020
Generation:
Renewable projects		$100		$140		$345		$340		$325		$70		$175		$325		$270		$115		$30		$—		$20		$70		$210
Riverside expansion	75		295		180		85		5		—		—		—		—		—		75		295		180		85		5
Marshalltown	185		20		—		—		—		185		20		—		—		—		—		—		—		—		—
Other	270		235		185		180		160		90		115		105		105		80		180		120		80		75		80
Distribution:
Electric systems	305		425		440		475		475		175		230		255		285		295		130		195		185		190		180
Gas systems	170		110		145		100		220		120		70		75		60		160		50		40		70		40		60
Other	105		155		120		100		100		35		40		35		25		25		20		15		10		10		10
		$1,210		$1,380		$1,415		$1,280		$1,285		$675		$650		$795		$745		$675		$485		$665		$545		$470		$545



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Financing Activities -

~~Three~~Nine Months Ended ~~March 31,~~September 30, 2016 vs. ~~Three~~Nine Months Ended ~~March 31,~~September 30, 2015 - The following items contributed to increased (decreased) financing activity cash flows for the ~~three~~nine months ended ~~March 31,~~September 30, 2016 compared to the same period in 2015 (in millions):


	Alliant Energy			IPL			WPL			Alliant Energy			IPL			WPL
Proceeds from the issuance of IPL’s 3.7% senior debentures in September 2016											$300			$300			$—
Payments to retire IPL’s 3.3% senior debentures in June 2015										150			150			—
Net changes in the amount of commercial paper outstanding		$153			$—			$6		111			—			(8		)
Lower net proceeds from common stock issuances	(116		)	—			—
Capital contributions from IPL’s parent company, Alliant Energy, in 2016	—			40			—
Payments to retire WPL’s pollution control revenue bonds in the third quarter of 2015										31			—			31
Proceeds from the issuance of IPL’s 3.4% senior debentures in August 2015										(250		)	(250		)	—
Proceeds from Alliant Energy’s at-the-market offering program in 2015										(133		)	—			—
Lower capital contributions from IPL’s parent company, Alliant Energy										—			(35		)	—
Other	(23		)	(18		)	(2		)	(12		)	(8		)	(3		)
		$14			$22			$4			$197			$157			$20

FERC Financing Authorization - After issuing $300 million of long-term debt securities in September 2016, IPL currently has remaining authority to issue up to $250 million of long-term debt securities in aggregate through December 31, 2017 pursuant to a December 2015 FERC order.

State Regulatory Financing Authorizations - In September 2016, WPL received authorization from the PSCW to have up to $400 million of short-term borrowings and/or letters of credit outstanding at any time through the earlier of the expiration date of WPL’s credit facility agreement (including extensions) or December 2024.

WPL previously had remaining authority to issue up to $300 million of long-term debt securities in aggregate in 2016 pursuant to a November 2014 PSCW order. As a result of the Moody’s Investors Service’s credit ratings changes in July 2016 discussed below, WPL no longer has authority to issue long-term debt securities in 2016. WPL currently has no plans to issue long-term debt securities in 2016.

Common Stock Dividends and Common Stock Split - As discussed in Note 6, Alliant Energy’s Board of Directors approved a two-for-one common stock split, which ~~is expected to be effective on or about~~was distributed in May ~~19,~~ 2016. The next quarterly dividends are payable on May 13, 2016 to shareowners of record on April 29, 2016. This dividend payment will be made before the stock split, resulting in a $0.5875 per share dividend rate. After the two-for-one common stock split, the targeted 2016 quarterly common stock dividend payment ~~will be~~is $0.29375 per share. Refer to “



	39

~~Table~~Executive Summary” for discussion of ~~Contents~~

expected common stock dividends in 2017.

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 ~~three~~nine months ended ~~March 31,~~September 30, 2016. Refer to “Executive Summary” for discussion of expected common stock issuances and capital contributions in 2017.

Long-term Debt - Refer to Note ~~9(b)~~7(b) for discussion of various long-term debt issuances and retirements. Refer to “Executive Summary” for discussion of expected issuances of long-term debt in 2017.

Impact of Credit Ratings on Liquidity and Collateral Obligations -

Ratings Triggers - In July 2016, Moody’s Investors Service changed Alliant Energy’s ~~common~~and IPL’s corporate/issuer and senior unsecured long-term debt credit ratings from A3 to Baa1. IPL’s preferred stock ~~issuances during the three months ended March 31, 2016 under its equity-based compensation plans for employees.~~credit rating also changed from Baa2 to Baa3. In addition, WPL’s corporate/issuer and senior unsecured long-term debt credit ratings changed from A1 to A2. Alliant Energy’s, IPL’s and WPL’s outlooks also changed from negative to stable. Alliant Energy’s, IPL’s and WPL’s commercial paper ratings remained unchanged. These credit ratings changes are not expected to have a material impact on Alliant Energy’s, IPL’s, and WPL’s liquidity or collateral obligations.

Off-Balance Sheet Arrangements - A summary of Alliant Energy’s off-balance sheet arrangements is included in the 2015 Form 10-K and has not changed materially from the items reported in the 2015 Form 10-K, except as described below. Refer to Note 4 for information regarding IPL’s sales of accounts receivable program. In March 2016, IPL extended through March 2018 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.



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Certain Financial Commitments -

Contractual Obligations - A summary of Alliant Energy’s, IPL’s and WPL’s contractual obligations is included in the 2015 Form 10-K and has not changed materially from the items reported in the 2015 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~~The market risks issummary included in the 2015 Form 10-K ~~and such market risks have~~has not changed materially, ~~from those reported in the~~ ~~2015~~ ~~Form 10-K,~~ except as described below.

Commodity Price - Refer to “~~Rate Matters~~Note 2” for discussion of WPL’s retail fuel-related rate ~~filing~~filings for the 2015 and 2016 Test ~~Year 2015.~~Years.

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

Critical Accounting Policies and Estimates - AThe summary of critical accounting policies and estimates is included in the 2015 Form 10-K ~~and such policies and estimates have~~has not changed materially, ~~from those reported~~except as described below.

Long-Lived Assets -

Non-regulated Operations -

Franklin County Wind Farm - On a quarterly basis, Alliant Energy evaluates if there are any impairment indicators present related to the Franklin County wind farm. Based on an evaluation of the strategic options for the Franklin County wind farm performed in the third quarter of 2016, Alliant Energy concluded, as of September 30, 2016, it was probable the Franklin County wind farm will be transferred to IPL. As a result, Alliant Energy performed an impairment analysis of such assets in the third quarter of 2016. Refer to ~~2015~~Note 3 ~~Form 10-K.~~for discussion of the impairment analysis, which resulted in non-cash, pre-tax asset valuation charges of $86 million recorded by Alliant Energy in the third quarter of 2016.

Other Future Considerations - AThe summary of other future considerations is included in the 2015 Form 10-K ~~and~~ has not changed materially, ~~from the items reported in the~~ ~~2015~~ ~~Form 10-K~~ except as described below, and as discussed earlier in MDA and the Notes in Item 1.

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 future changes to their electric transmission service expense as follows:

2017 Electric Transmission Service Expense - Alliant Energy, IPL and WPL currently estimate their total electric transmission service expense in 2017 will be lower than the comparable expense in 2016 by approximately $20 million, $15 million and $5 million, respectively. Such decreases are primarily due to expected lower return on equity resulting from the MISO transmission owner return on equity complaints. Alliant Energy’s, IPL’s and WPL’s estimated 2017 electric transmission service expense remains subject to change pending the IUB’s approval of IPL’s 2017 transmission rates and the PSCW’s final decision in WPL’s retail electric rate case for the 2017/2018 Test Period.

In June 2016, a FERC administrative law judge issued an initial decision regarding the second complaint and recommended a base return on equity of 9.70%, excluding any incentive adders granted by FERC, for the refund period from February 12, 2015 through May 11, 2016. A final decision from FERC on the second complaint is currently expected in the first half of 2017.



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Alliant Energy and WPL have realized a cumulative $24 million of reductions in the amount of equity income from ATC as a result of the two complaints through September 30, 2016, including $9 million during the nine months ended September 30, 2016. These reductions are based upon a 10.32% base return on equity for the first complaint period and assume a 10.2% return on equity (9.70% base return on equity plus 50 basis point incentive adder approved in a previous FERC order) for the second complaint period and thereafter.

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.

2017 Rates Charged by ATC to WPL - In October 2016, ATC shared with its customers the Attachment “O” rate it proposes to charge them in 2017 for electric transmission services. The proposed rate was based on ATC’s estimated net revenue requirement for 2017 as well as a true-up adjustment credit related to amounts that ATC over-recovered from its customers in 2015 and expects to over-recover from its customers in 2016. Amounts billed under the 2017 Attachment “O” rate are currently expected to be approximately 5% lower than the amounts ATC is charging its customers in 2016. The proposed rate for 2017 reflects a 10.82% return on equity for the impact of FERC’s September 2016 order to lower the base return on equity for MISO transmission owners to 10.32% discussed above, plus a 50 basis point incentive return on equity adder based on ATC’s participation in MISO.

2017 Rates Charged by ITC to IPL - In October 2016, ITC filed with MISO the Attachment “O” rate it proposes to charge its customers in 2017 for electric transmission services. The proposed rate was based on ITC’s estimated net revenue requirement for 2017 as well as a true-up adjustment related to amounts that ITC under-recovered from its customers in 2015. Amounts billed under the 2017 Attachment “O” rate are currently expected to be approximately 4% higher than the amounts ITC is charging its customers in 2016. The proposed rate for 2017 reflects an 11.32% return on equity for the impact of FERC’s September 2016 order to lower the base return on equity for MISO transmission owners to 10.32% discussed above, plus a 50 basis point incentive return on equity adder based on ITC’s participation in MISO, as well as a 50 basis point incentive return on equity adder for ITC being an independent transmission company. The proposed rate for 2017 also reflects the impacts of bonus tax depreciation deductions for 2015, 2016 and 2017 in response to FERC’s March 2016 order discussed below.

ITC Bonus Tax Depreciation Deductions - In December 2015, IPL filed a complaint with FERC regarding ITC’s Attachment “O” rate pursuant to FERC-approved Attachment “O” ~~audit~~ protocols. IPL’s complaint alleged that ITC acted imprudently by failing to take advantage of tax savings benefits available through bonus tax depreciation deductions, which results in higher Attachment “O” rates being billed by ITC to IPL. In March 2016, FERC issued an order concluding that ITC acted imprudently by failing to take advantage of tax savings benefits available through bonus tax depreciation deductions. The FERC order requires ITC to recalculate its Attachment “O” rate effective January 1, 2015 to simulate taking bonus tax depreciation deductions ~~beginning January 1,~~for 2015. In April 2016, ITC filed a request for rehearing of FERC’s March 2016 order. IPL subsequently filed a response to ITC’s request for rehearing, requesting that FERC require ITC to also take bonus tax depreciation deductions for 2012 through 2014. In June 2016, FERC issued an order rejecting ITC’s and IPL’s requests. If ITC does not take advantage of bonus tax depreciation deductions in 2016 or in future years, IPL retains the right under Attachment “O” protocols to challenge ITC’s decision if IPL deems that decision to be imprudent. Alliant Energy and IPL are ~~unable to determine~~currently reviewing ITC’s estimated impacts through the ~~magnitude of resulting~~FERC-approved Attachment “O” protocols.

Electric Transmission Cost Recovery - Any changes ~~to future~~in IPL’s electric transmission service ~~charges from this proceeding, but do expect such charges~~costs billed by ITC to IPL are expected to be ~~lower as a result of FERC’s March 2016 order. Alliant Energy and IPL currently expect any changes~~passed on to ~~future~~IPL’s Iowa retail electric customers through the transmission cost recovery rider. The difference between WPL’s actual electric transmission service expense ~~will~~incurred and amounts collected from customers as electric revenues in 2017 is expected to be ~~offset~~recorded as electric transmission service expense with an offsetting amount recorded to a regulatory asset or regulatory liability due to the escrow treatment proposed by WPL in its 2017/2018 Test Period retail electric rate case. Based on IPL’s and WPL’s electric transmission cost recovery mechanisms, IPL and WPL currently do not expect that any changes to electric ~~revenues.~~transmission service costs billed by ITC and ATC will have a material impact on their financial condition and results of operations. IPL and WPL could have a material impact on their cash flows depending on the final timing of refunds resulting from the MISO return on equity complaints, and the subsequent timing of the refunds being credited to their customers.



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WPL’s Future Transfer of Investment in ATC - In June 2016, WPL received an order from the PSCW requiring WPL to transfer its investment in ATC to Alliant Energy or an Alliant Energy subsidiary by December 31, 2022. In addition, WPL is required to obtain PSCW approval prior to transferring any additional capital or assets to ATC. WPL is currently evaluating the impacts of the June 2016 PSCW order on its results of operations and financial condition. Subsequent to WPL transferring its investment in ATC, future contributions to, and equity earnings and dividends from, the investment in ATC would occur at the entity to which the investment in ATC was transferred and would not be reflected in WPL’s consolidated financial statements. As a result, WPL’s earnings and cash flows from operations are expected to decrease subsequent to the transfer. This transfer is not expected to impact Alliant Energy’s consolidated financial statements.

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.



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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 ~~March 31,~~September 30, 2016 pursuant to the requirements of the Securities Exchange Act of 1934, as amended. 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 the quarter ended ~~March 31,~~September 30, 2016.

During the first quarter of 2016, IPL implemented a new customer billing and information system, which houses all customer records, and processes metering, billing and payment transactions. The new system more fully automates and improves the efficiency of IPL’s financial reporting process, and resulted in a material change in Alliant Energy’s and IPL’s internal control over financial reporting. Other than IPL’s new customer billing and information system, thereThere was no change in Alliant Energy’s, IPL’s and ~~IPL’s~~WPL’s internal control over financial reporting that occurred during the quarter ended ~~March 31,~~September 30, 2016 that has materially affected, or is reasonably likely to materially affect, Alliant Energy’s, ~~and~~ IPL’s ~~internal control over financial reporting. There was no change in WPL’s internal control over financial reporting that occurred during the quarter ended~~ ~~March 31, 2016~~ ~~that has materially affected,~~ or ~~is reasonably likely to materially affect,~~ WPL’s internal control over financial reporting.

PART II. OTHER INFORMATION

ITEM 1A. RISK FACTORS

A summary of risk factors is included in Item 1A in the 2015 Form 10-K and such risk factors have not changed materially from the items reported in the 2015 Form 10-K.

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

A summary of Alliant Energy common stock repurchases for the quarter ended ~~March 31,~~September 30, 2016 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) (b) Share (b) Publicly Announced Plan Be Purchased Under the Plan (a)
January 1 through January 31 2,333

$62.66
— N/A
February 1 through February 29 1,925
66.98
— N/A
March 1 through March 31 397
71.00
— N/A
4,655
65.16
—



	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	3,751		$39.36	—	N/A
August 1 through August 31	3,372	38.93		—	N/A
September 1 through September 30	92	38.57		—	N/A
	7,215	39.15		—


(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.


~~(b)~~	~~Share and per share amounts do not reflect the effects of a two-for-one common stock split approved by Alliant Energy’s Board of Directors on April 20, 2016. Refer to~~ ~~Note 6~~ ~~for additional details.~~

Refer to Note 6 for discussion of IPL’s and WPL’s dividend restrictions and limitations on distributions to their parent company, Alliant Energy.

~~ITEM 5. OTHER INFORMATION~~

Alliant Energy filed with the Wisconsin Department of Financial Institutions an amendment (the Amendment) to Alliant Energy’s Restated Articles of Incorporation, as amended (the Articles) that, effective at the close of business on May 4, 2016 (the Record Date), (i) changed each share of common stock, $.01 par value, of Alliant Energy (the Common Stock) outstanding into two shares of Common Stock to effect a two-for-one split of the Common Stock, without a change in the par value, and (ii) increased Alliant Energy’s authorized shares of Common Stock from 240,000,000 to 480,000,000.

In connection with the two-for-one stock split, on the Record Date, each share of Common Stock outstanding immediately prior to the Record Date was changed into two shares of Common Stock. Stock certificates evidencing shares of Common Stock outstanding on the Record Date will continue to evidence the same number of shares that such certificates evidenced prior to the Record Date, and the additional shares will be issued in book-entry form only, without certificates, on or about May 19, 2016 to persons who were at the Record Date the holders of the Common Stock.



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~~Table of Contents~~

~~The Amendment is included in the Articles filed as Exhibit 3.1 to this Report on Form 10-Q and is incorporated by reference herein.~~

ITEM 6. EXHIBITS

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



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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 ~~5th~~4th day of ~~May~~November 2016.



ALLIANT ENERGY CORPORATION
Registrant

By: /s/ Robert J. Durian	Vice President, Chief Accounting Officer and ~~Controller~~Treasurer
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~~Treasurer
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~~Treasurer
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.~~herewith or incorporated herein by reference.



Exhibit Number		Description
~~3.1~~4.1		~~Articles~~Officer’s Certificate, dated as of ~~Amendment~~September 15, 2016, creating IPL’s 3.70% Senior Debentures due September 15, 2046 (incorporated by reference to ~~Restated Articles~~Exhibit 4.1 to IPL’s Form 8-K, filed September 15, 2016 (File No. 1-4117))
10.1		Term Loan Credit Agreement, dated as of ~~Incorporation, as amended, effective May 4,~~October 7, 2016, among AEF, Alliant Energy, JPMorgan Chase Bank, N.A. and the lender parties set forth therein (incorporated by reference to Exhibit 10.1 to Alliant Energy’s Form 8-K, filed October 7, 2016 (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 nine months ended ~~March 31,~~September 30, 2016 and 2015 ~~and 2015;~~; (ii) Alliant Energy’s, IPL’s and WPL’s Condensed Consolidated Balance Sheets as of ~~March 31,~~September 30, 2016 and December 31, ~~2015~~;2015; (iii) Alliant Energy’s, IPL’s and WPL’s Condensed Consolidated Statements of Cash Flows for the ~~three~~nine months ended ~~March 31,~~September 30, 2016 and 2015; and (iv) the Combined Notes to Condensed Consolidated Financial Statements.



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	2016		2015
Basic and diluted EPS:
As reported		$0.85		$0.87
Pro forma	0.43		0.43



	Alliant Energy			IPL			WPL
Estimated decrease from changes in sales caused by temperatures		($6	)		($3	)		($3	)
Lower revenues at IPL related to changes in recovery amounts for energy efficiency costs through the energy efficiency rider (a)	(3		)	(3		)	—
Other	(2		)	(2		)	1
		($11	)		($8	)		($2	)



	Alliant Energy (Consolidated)				IPL				WPL
Common equity		$3,764.6	47	%		$2,042.9	50	%		$1,769.1	53	%
Preferred stock of IPL	200.0		2	%	200.0		5	%	—		—	%
Noncontrolling interest	—		—	%	—		—	%	14.0		—	%
Long-term debt (incl. current maturities)	3,836.1		48	%	1,857.4		45	%	1,534.2		46	%
Short-term debt	213.4		3	%	—		—	%	25.5		1	%
		$8,014.1	100	%		$4,100.3	100	%		$3,342.8	100	%