Edgar Filing: WISCONSIN ENERGY CORP

WEC 03.31.2013 10Q

UNITED STATES

SECURITIES AND EXCHANGE COMMISSION

WASHINGTON, DC 20549

FORM 10-Q

QUARTERLY REPORT PURSUANT TO SECTION 13 OR 15(d)

OF THE SECURITIES EXCHANGE ACT OF 1934

For the Quarterly Period Ended March 31, 2013



Commission	Registrant; State of Incorporation	IRS Employer
File Number	Address; and Telephone Number	Identification No.



001-09057	WISCONSIN ENERGY CORPORATION	39-1391525
	(A Wisconsin Corporation)
	231 West Michigan Street
	P.O. Box 1331
	Milwaukee, WI 53201
	(414) 221-2345

Indicate by check mark whether the registrant (1) has 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 registrant was required to file such reports), and (2) has been subject to such filing requirements for the past 90 days.

Yes [X] No [ ]

Indicate by check mark whether the registrant has submitted electronically and posted on its 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 registrant was required to submit and post such files). Yes [X] No [ ]

Indicate by check mark whether the registrant is a large accelerated filer, an accelerated filer, a non-accelerated filer, or a smaller reporting company. See the definitions of "large accelerated filer", "accelerated filer" and "smaller reporting company" in Rule 12b-2 of the Exchange Act.



	Large accelerated filer [X]		Accelerated filer [ ]
	Non-accelerated filer [ ] (Do not		Smaller reporting company [ ]
	check if a smaller reporting company)

Indicate by check mark whether the registrant is a shell company (as defined in Rule 12b-2 of the Exchange Act). Yes [ ] No [X]

Indicate the number of shares outstanding of each of the issuer's classes of common stock, as of the latest practicable date (March 31, 2013):



Common Stock, $.01 Par Value,	228,723,020 shares outstanding.

Form 10-Q

WISCONSIN ENERGY CORPORATION

_______________________

FORM 10-Q REPORT FOR THE QUARTER ENDED MARCH 31, 2013



	TABLE OF CONTENTS
Item		Page

	Introduction	7

	Part I -- Financial Information

1.	Financial Statements

	Consolidated Condensed Income Statements	8

	Consolidated Condensed Balance Sheets	9

	Consolidated Condensed Statements of Cash Flows	10

	Notes to Consolidated Condensed Financial Statements	11

2.	Management's Discussion and Analysis of Financial Condition and Results of Operations	21

3.	Quantitative and Qualitative Disclosures About Market Risk	32

4.	Controls and Procedures	32

	Part II -- Other Information

1.	Legal Proceedings	32

1A.	Risk Factors	33

2.	Unregistered Sales of Equity Securities and Use of Proceeds	33

5.	Other Information	34

6.	Exhibits	34

	Signatures	35



March 2013	2	Wisconsin Energy Corporation

Form 10-Q



DEFINITION OF ABBREVIATIONS AND INDUSTRY TERMS

The abbreviations and terms set forth below are used throughout this report and have the meanings assigned to them below:

Primary Subsidiaries
We Power		W.E. Power, LLC
Wisconsin Electric		Wisconsin Electric Power Company
Wisconsin Gas		Wisconsin Gas LLC

Significant Assets
OC 1		Oak Creek expansion Unit 1
OC 2		Oak Creek expansion Unit 2
PIPP		Presque Isle Power Plant
PSGS		Paris Generating Station
PWGS 1		Port Washington Generating Station Unit 1
PWGS 2		Port Washington Generating Station Unit 2
VAPP		Valley Power Plant

Other Subsidiaries and Affiliates
ATC		American Transmission Company LLC

Federal and State Regulatory Agencies
DOE		United States Department of Energy
EPA		United States Environmental Protection Agency
FERC		Federal Energy Regulatory Commission
MPSC		Michigan Public Service Commission
PSCW		Public Service Commission of Wisconsin
SEC		Securities and Exchange Commission
WDNR		Wisconsin Department of Natural Resources

Environmental Terms
CAIR		Clean Air Interstate Rule
CSAPR		Cross-State Air Pollution Rule
NOV		Notice of Violation
SO₂		Sulfur Dioxide

Other Terms and Abbreviations
AQCS		Air Quality Control System
Compensation Committee		Compensation Committee of the Board of Directors
Exchange Act		Securities Exchange Act of 1934, as amended
FTRs		Financial Transmission Rights
Junior Notes		Wisconsin Energy's 2007 Series A Junior Subordinated Notes due 2067
MISO		Midwest Independent Transmission System Operator, Inc.
NDAA		National Defense Authorization Act
OTC		Over-the-Counter
PTF		Power the Future
WPL		Wisconsin Power and Light Company, a subsidiary of Alliant Energy Corp.



March 2013	3	Wisconsin Energy Corporation

Form 10-Q



DEFINITION OF ABBREVIATIONS AND INDUSTRY TERMS

The abbreviations and terms set forth below are used throughout this report and have the meanings assigned to them below:

Measurements
Btu		British Thermal Unit(s)
Dth		Dekatherm(s) (One Dth equals one million Btu)
MW		Megawatt(s) (One MW equals one million Watts)
MWh		Megawatt-hour(s)
Watt		A measure of power production or usage

Accounting Terms
AFUDC		Allowance for Funds Used During Construction
ASU		Accounting Standards Update
GAAP		Generally Accepted Accounting Principles
OPEB		Other Post-Retirement Employee Benefits



March 2013	4	Wisconsin Energy Corporation

Form 10-Q

CAUTIONARY STATEMENT REGARDING FORWARD-LOOKING INFORMATION

Certain statements contained in this report are "forward-looking statements" within the meaning of Section 27A of the Securities Act of 1933 and Section 21E of the Securities Exchange Act of 1934, as amended (Exchange Act). These statements are based upon management's current expectations and are subject to risks and uncertainties that could cause our actual results to differ materially from those contemplated in the statements. Readers are cautioned not to place undue reliance on these forward-looking statements. Forward-looking statements include, among other things, statements concerning management's expectations and projections regarding earnings, completion of construction projects, regulatory matters, on-going legal proceedings, fuel costs, sources of electric energy supply, coal and gas deliveries, remediation costs, environmental and other capital expenditures, liquidity and capital resources and other matters. In some cases, forward-looking statements may be identified by reference to a future period or periods or by the use of forward-looking terminology such as "anticipates," "believes," "estimates," "expects," "forecasts," "goals," "guidance," "intends," "may," "objectives," "plans," "possible," "potential," "projects," "seeks," "should," "targets" or similar terms or variations of these terms.

Actual results may differ materially from those set forth in forward-looking statements. In addition to the assumptions and other factors referred to specifically in connection with these statements, factors that could cause our actual results to differ materially from those contemplated in any forward-looking statements or otherwise affect our future results of operations and financial condition include, among others, the following:

•

Factors affecting utility operations such as catastrophic weather-related or terrorism-related damage; cyber-security threats and disruptions to our technology network; availability of electric generating facilities; unscheduled generation outages, or unplanned maintenance or repairs; unanticipated events causing scheduled generation outages to last longer than expected; unanticipated changes in fossil fuel, purchased power, coal supply, gas supply or water supply costs or availability due to higher demand, shortages, transportation problems or other developments; unanticipated changes in the cost or availability of materials needed to operate new environmental controls at our electric generating facilities or replace and/or repair our electric and gas distribution systems; nonperformance by electric energy or natural gas suppliers under existing power purchase or gas supply contracts; environmental incidents; electric transmission or gas pipeline system constraints; unanticipated organizational structure or key personnel changes; or collective bargaining agreements with union employees or work stoppages.


•	Factors affecting the demand for electricity and natural gas, including weather and other natural phenomena; general economic conditions and, in particular, the economic climate in our service territories; customer growth and declines; customer business conditions, including demand for their products and services; energy conservation efforts; and customers moving to self-generation.


•	Timing, resolution and impact of future rate cases and negotiations, including recovery of costs associated with environmental compliance, renewable generation, transmission service, distribution system upgrades, fuel and the Midwest Independent Transmission System Operator, Inc. (MISO) Energy Markets.


•	Increased competition in our electric and gas markets, including retail choice and alternative electric suppliers, and continued industry consolidation.


•	The ability to control costs and avoid construction delays during the development and construction of new environmental controls and renewable generation, as well as upgrades to our electric and natural gas distribution systems.

•

The impact of recent and future federal, state and local legislative and regulatory changes, including any changes in rate-setting policies or procedures; cuts in funding of the U.S. Treasury Department's 1603 grant program for renewable energy projects under the National Defense Authorization Act (NDAA); electric and gas industry restructuring initiatives; transmission or distribution system operation and/or administration initiatives; any required changes in facilities or operations to reduce the risks or impacts of potential terrorist activities or cybersecurity threats; required approvals for new construction, and the siting approval process for new generation and transmission facilities and new pipeline construction; changes to the Federal Power Act and related regulations and enforcement thereof by the Federal Energy Regulatory Commission (FERC) and other regulatory agencies; changes in allocation of energy assistance, including state public benefits funds; changes in environmental, tax and other laws and regulations to which we are subject; changes in the application of



March 2013	5	Wisconsin Energy Corporation

CAUTIONARY STATEMENT REGARDING FORWARD-LOOKING INFORMATION -- (CONT'D) Form 10-Q

existing laws and regulations; and changes in the interpretation or enforcement of permit conditions by the permitting agencies.


•	Restrictions imposed by various financing arrangements and regulatory requirements on the ability of our subsidiaries to transfer funds to us in the form of cash dividends, loans or advances.


•	Current and future litigation, regulatory investigations, proceedings or inquiries, including FERC matters and Internal Revenue Service audits and other tax matters.


•	Events in the global credit markets that may affect the availability and cost of capital.


•	Other factors affecting our ability to access the capital markets, including general capital market conditions; our capitalization structure; market perceptions of the utility industry, us or any of our subsidiaries; and our credit ratings.


•	Inflation rates.


•	The investment performance of our pension and other post-retirement benefit trusts.


•	The financial performance of American Transmission Company LLC (ATC) and its corresponding contribution to our earnings.


•	The impact of the Dodd-Frank Wall Street Reform and Consumer Protection Act and any regulations promulgated thereunder.


•	The impact of the Patient Protection and Affordable Care Act and the Health Care and Education Reconciliation Act of 2010 and any related regulations.


•	The effect of accounting pronouncements issued periodically by standard setting bodies, including any changes in regulatory accounting policies and practices and any requirement for U.S. registrants to follow International Financial Reporting Standards instead of Generally Accepted Accounting Principles (GAAP).


•	Unanticipated technological developments that result in competitive disadvantages and create the potential for impairment of existing assets.


•	Changes in the creditworthiness of the counterparties with whom we have contractual arrangements, including participants in the energy trading markets and fuel suppliers and transporters.


•	The ability to obtain and retain short- and long-term contracts with wholesale customers.


•	Potential strategic business opportunities, including acquisitions and/or dispositions of assets or businesses, which we cannot ensure will be beneficial for us.


•	Incidents affecting the U.S. electric grid or operation of generating facilities.


•	The cyclical nature of property values that could affect our real estate investments.


•	Changes to the legislative or regulatory restrictions or caps on non-utility acquisitions, investments or projects, including the State of Wisconsin's public utility holding company law.


•	Foreign governmental, economic, political and currency risks.


•	Other business or investment considerations that may be disclosed from time to time in our Securities and Exchange Commission (SEC) filings or in other publicly disseminated written documents, including the risk factors set forth in our Annual Report on Form 10-K for the year ended December 31, 2012.

We expressly disclaim any obligation to publicly update or revise any forward-looking statements, whether as a result of new information, future events or otherwise.



March 2013	6	Wisconsin Energy Corporation

Form 10-Q

INTRODUCTION

Wisconsin Energy Corporation is a diversified holding company which conducts its operations primarily in two reportable segments: a utility energy segment and a non-utility energy segment. Unless qualified by their context when used in this document, the terms Wisconsin Energy, the Company, our, us or we refer to the holding company and all of its subsidiaries. Our primary subsidiaries are Wisconsin Electric Power Company (Wisconsin Electric), Wisconsin Gas LLC (Wisconsin Gas) and W.E. Power, LLC (We Power).

Utility Energy Segment: Our utility energy segment consists of: Wisconsin Electric, which serves electric customers in Wisconsin and the Upper Peninsula of Michigan, gas customers in Wisconsin and steam customers in metropolitan Milwaukee, Wisconsin; and Wisconsin Gas, which serves gas customers in Wisconsin. Wisconsin Electric and Wisconsin Gas operate under the trade name of "We Energies."

Non-Utility Energy Segment: Our non-utility energy segment consists primarily of We Power. We Power was formed in 2001 to design, construct, own and lease to Wisconsin Electric the new generating capacity included in our Power the Future (PTF) strategy. See Item 1. Business and Item 7. Management's Discussion and Analysis of Financial Condition and Results of Operations in our 2012 Annual Report on Form 10-K for more information on PTF.

We have prepared the unaudited interim financial statements presented in this Form 10-Q pursuant to the rules and regulations of the SEC. We have condensed or omitted some information and note disclosures normally included in financial statements prepared in accordance with GAAP pursuant to these rules and regulations. This Form 10-Q, including the financial statements contained herein, should be read in conjunction with our 2012 Annual Report on Form 10-K, including the financial statements and notes therein.



March 2013	7	Wisconsin Energy Corporation

Form 10-Q

PART I -- FINANCIAL INFORMATION

ITEM 1. FINANCIAL STATEMENTS



WISCONSIN ENERGY CORPORATION
CONSOLIDATED CONDENSED INCOME STATEMENTS
(Unaudited)

	Three Months Ended March 31
	2013		2012
	(Millions of Dollars, Except Per Share Amounts)

Operating Revenues	$	1,275.2	$	1,191.2

Operating Expenses
Fuel and purchased power	271.0		253.8
Cost of gas sold	270.1		237.5
Other operation and maintenance	288.1		286.3
Depreciation and amortization	95.5		87.6
Property and revenue taxes	29.5		30.3
Total Operating Expenses	954.2		895.5

Operating Income	321.0		295.7

Equity in Earnings of Transmission Affiliate	16.6		15.6
Other Income, net	4.4		16.0
Interest Expense, net	65.0		58.9

Income Before Income Taxes	277.0		268.4

Income Tax Expense	100.4		96.3

Net Income	$	176.6	$	172.1

Earnings Per Share
Basic	$	0.77	$	0.75
Diluted	$	0.76	$	0.74

Weighted Average Common Shares Outstanding (Millions)
Basic	228.9		230.5
Diluted	231.2		233.2

Dividends Per Share of Common Stock	$	0.34	$	0.30

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



March 2013	8	Wisconsin Energy Corporation

Form 10-Q



WISCONSIN ENERGY CORPORATION
CONSOLIDATED CONDENSED BALANCE SHEETS
(Unaudited)

	March 31, 2013			December 31, 2012
	(Millions of Dollars)
Assets
Property, Plant and Equipment
In service	$	14,325.3		$	14,238.8
Accumulated depreciation	(4,098.4		)	(4,036.0		)
	10,226.9			10,202.8
Construction work in progress	337.1			315.9
Leased facilities, net	52.1			53.5
Net Property, Plant and Equipment	10,616.1			10,572.2
Investments
Equity investment in transmission affiliate	383.0			378.3
Other	36.8			35.5
Total Investments	419.8			413.8
Current Assets
Cash and cash equivalents	24.7			35.6
Restricted cash	—			2.7
Accounts receivable, net	389.0			285.3
Accrued revenues	246.3			278.1
Materials, supplies and inventories	266.8			360.7
Prepayments and other	387.0			351.5
Total Current Assets	1,313.8			1,313.9
Deferred Charges and Other Assets
Regulatory assets	1,323.9			1,339.0
Goodwill	441.9			441.9
Other	179.8			204.2
Total Deferred Charges and Other Assets	1,945.6			1,985.1
Total Assets	$	14,295.3		$	14,285.0

Capitalization and Liabilities
Capitalization
Common equity	$	4,203.6		$	4,135.1
Preferred stock of subsidiary	30.4			30.4
Long-term debt	4,441.0			4,453.8
Total Capitalization	8,675.0			8,619.3
Current Liabilities
Long-term debt due currently	413.5			412.1
Short-term debt	316.7			394.6
Accounts payable	257.1			368.4
Accrued payroll and benefits	71.7			100.9
Other	219.1			167.3
Total Current Liabilities	1,278.1			1,443.3
Deferred Credits and Other Liabilities
Regulatory liabilities	853.7			866.5
Deferred income taxes - long-term	2,275.6			2,117.0
Deferred revenue, net	702.6			709.7
Pension and other benefit obligations	233.9			244.0
Other	276.4			285.2
Total Deferred Credits and Other Liabilities	4,342.2			4,222.4
Total Capitalization and Liabilities	$	14,295.3		$	14,285.0

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



March 2013	9	Wisconsin Energy Corporation

Form 10-Q



WISCONSIN ENERGY CORPORATION
CONSOLIDATED CONDENSED STATEMENTS OF CASH FLOWS
(Unaudited)

	Three Months Ended March 31
	2013			2012
	(Millions of Dollars)
Operating Activities
Net income	$	176.6		$	172.1
Reconciliation to cash
Depreciation and amortization	98.2			90.6
Deferred income taxes and investment tax credits, net	42.8			67.9
Change in - Accounts receivable and accrued revenues	(84.3		)	11.5
Inventories	93.9			70.4
Other current assets	28.2			29.8
Accounts payable	(104.5		)	(82.3		)
Accrued income taxes, net	46.2			15.5
Other current liabilities	35.6			15.2
Other, net	(2.4		)	(50.2		)
Cash Provided by Operating Activities	330.3			340.5

Investing Activities
Capital expenditures	(133.6		)	(142.3		)
Investment in transmission affiliate	(1.3		)	(2.6		)
Change in restricted cash	2.7			20.8
Other, net	(13.1		)	(6.3		)
Cash Used in Investing Activities	(145.3		)	(130.4		)

Financing Activities
Exercise of stock options	27.3			12.9
Purchase of common stock	(66.5		)	(29.2		)
Dividends paid on common stock	(77.8		)	(69.1		)
Retirement of long-term debt	(8.5		)	(8.0		)
Change in short-term debt	(77.9		)	(112.6		)
Other, net	7.5			(0.1		)
Cash Used in Financing Activities	(195.9		)	(206.1		)

Change in Cash and Cash Equivalents	(10.9		)	4.0

Cash and Cash Equivalents at Beginning of Period	35.6			14.1

Cash and Cash Equivalents at End of Period	$	24.7		$	18.1

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



March 2013	10	Wisconsin Energy Corporation

Form 10-Q

WISCONSIN ENERGY CORPORATION

NOTES TO CONSOLIDATED CONDENSED FINANCIAL STATEMENTS

(Unaudited)

1 -- GENERAL INFORMATION

Our accompanying unaudited consolidated condensed financial statements should be read in conjunction with Item 8, Financial Statements and Supplementary Data, in our 2012 Annual Report on Form 10-K. In the opinion of management, we have included all adjustments, normal and recurring in nature, necessary for a fair presentation of the results of operations, cash flows and financial position in the accompanying income statements, statements of cash flows and balance sheets. The results of operations for the three months ended March 31, 2013 are not necessarily indicative of the results which may be expected for the entire fiscal year 2013 because of seasonal and other factors.

2 -- NEW ACCOUNTING PRONOUNCEMENTS

Offsetting Assets and Liabilities: In December 2011, The Financial Accounting Standards Board issued Accounting Standards Update (ASU) 2011-11, Disclosures about Offsetting Assets and Liabilities. The guidance requires enhanced disclosures about derivatives. Both gross and net information related to eligible transactions is required under the guidance. This guidance is effective for fiscal years and interim periods beginning on or after January 1, 2013, and must be applied retrospectively. We adopted this guidance on January 1, 2013, and applied it retrospectively. See Note 5 -- Derivative Instruments for the enhanced disclosures.

3 -- COMMON EQUITY

Stock Option Activity: During the first three months of 2013, the Compensation Committee of the Board of Directors (Compensation Committee) granted 1,418,560 non-qualified stock options that had an estimated fair value of $3.45 per share. During the first three months of 2012, the Compensation Committee granted 938,770 non-qualified stock options that had an estimated fair value of $3.34 per share. The following assumptions were used to value the options using a binomial option pricing model:



	2013		2012

Risk-free interest rate	0.1% - 1.9%		0.1% - 2.0%
Dividend yield	3.7	%	3.9	%
Expected volatility	18.0	%	19.0	%
Expected forfeiture rate	2.0	%	2.0	%
Expected life (years)	5.9		5.9

The risk-free interest rate is based on the U.S. Treasury interest rate whose term is consistent with the expected life of the stock options. Dividend yield, expected volatility, expected forfeiture rate and expected life assumptions are based on our historical experience.



March 2013	11	Wisconsin Energy Corporation

Form 10-Q

The following is a summary of our stock option activity for the three months ended March 31, 2013:



					Weighted-
					Average
			Weighted-		Remaining	Aggregate
	Number of		Average		Contractual Life	Intrinsic Value
Stock Options	Options		Exercise Price		(Years)	(Millions)
Outstanding as of January 1, 2013	8,919,669		$	23.86
Granted	1,418,560		$	37.46
Exercised	(1,274,206	)	$	21.40
Forfeited	—		$	—
Outstanding as of March 31, 2013	9,064,023		$	26.34	5.9	$	150.0

Exercisable as of March 31, 2013	6,633,593		$	22.92	4.7	$	132.5

The intrinsic value of options exercised was $24.4 million and $12.0 million for the three months ended March 31, 2013 and 2012, respectively. Cash received from options exercised was $27.3 million and $12.9 million for the three months ended March 31, 2013 and 2012, respectively. The actual tax benefit realized for the tax deductions from option exercises for the same periods was $9.7 million and zero, respectively.

All outstanding stock options to purchase shares of common stock were included in the computation of diluted earnings per share during the first quarter of 2013.

The following table summarizes information about stock options outstanding as of March 31, 2013:



	Options Outstanding				Options Exercisable
		Weighted-Average				Weighted-Average
				Remaining				Remaining
	Number of	Exercise		Contractual	Number of	Exercise		Contractual
Range of Exercise Prices	Options	Price		Life (Years)	Options	Price		Life (Years)
$16.72 to $21.11	2,733,433	$	20.10	4.2	2,733,433	$	20.10	4.2
$23.88 to $29.35	3,976,660	$	24.65	5.0	3,661,370	$	24.24	4.7
$34.87 to $37.46	2,353,930	$	36.43	9.4	238,790	$	34.90	8.8
	9,064,023	$	26.34	5.9	6,633,593	$	22.92	4.7

The following table summarizes information about our non-vested options during the three months ended March 31, 2013:



			Weighted-Average
Non-Vested Stock Options	Number of Options		Fair Value
Non-vested as of January 1, 2013	1,702,275		$	3.31
Granted	1,418,560		$	3.45
Vested	(690,405	)	$	3.33
Forfeited	—		$	—
Non-vested as of March 31, 2013	2,430,430		$	3.38

As of March 31, 2013, total compensation costs related to non-vested stock options not yet recognized was approximately $4.9 million, which is expected to be recognized over the next 22 months on a weighted-average basis.

Restricted Shares: During the first three months of 2013, the Compensation Committee granted 74,290 restricted shares to directors, officers and other key employees. These awards have a three-year vesting period, and generally, one-third of the award vests on each anniversary of the grant date. During the vesting period, restricted share recipients have voting rights and are entitled to dividends in the same manner as other shareholders.



March 2013	12	Wisconsin Energy Corporation

Form 10-Q

The following restricted stock activity occurred during the three months ended March 31, 2013:



			Weighted-Average
Restricted Shares	Number of Shares		Grant Date Fair Value
Outstanding as of January 1, 2013	188,222
Granted	74,290		$	37.65
Released	(83,085	)	$	27.68
Forfeited	(11,698	)	$	33.01
Outstanding as of March 31, 2013	167,729

We record the market value of the restricted stock awards on the date of grant, and then we charge their value to expense over the vesting period of the awards. The intrinsic value of restricted stock vesting was $3.2 million and $2.6 million for the three months ended March 31, 2013 and 2012, respectively. The actual tax benefit realized for the tax deductions from released restricted shares was $1.1 million and zero for the three months ended March 31, 2013, and 2012, respectively.

As of March 31, 2013, total compensation cost related to restricted stock not yet recognized was approximately $4.4 million, which is expected to be recognized over the next 27 months on a weighted-average basis.

Performance Units: In January 2013 and 2012, the Compensation Committee granted 239,120 and 346,570 performance units, respectively, to officers and other key employees under the Wisconsin Energy Performance Unit Plan. Under the grants, the ultimate number of units that will be awarded is dependent upon the achievement of certain financial performance of our stock over a three-year period. Under the terms of the award, participants may earn between 0% and 175% of the base performance unit award. All grants are settled in cash. We are accruing compensation costs over the three-year period based on our estimate of the final expected value of the awards. Performance units earned as of December 31, 2012 and 2011 vested and were settled during the first quarter of 2013 and 2012, and had a total intrinsic value of $19.3 million and $26.7 million, respectively. The actual tax benefit realized for the tax deductions from the settlement of performance units was approximately $7.0 million and $9.7 million, respectively. As of March 31, 2013, total compensation cost related to performance units not yet recognized was approximately $22.0 million, which is expected to be recognized over the next 23 months on a weighted-average basis.

Restrictions: Wisconsin Energy's ability as a holding company to pay common dividends primarily depends on the availability of funds received from its non-utility subsidiary, We Power, and its utility subsidiaries. Various financing arrangements and regulatory requirements impose certain restrictions on the ability of our subsidiaries to transfer funds to us in the form of cash dividends, loans or advances. In addition, under Wisconsin law, Wisconsin Electric and Wisconsin Gas are prohibited from loaning funds, either directly or indirectly, to Wisconsin Energy. See Note H -- Common Equity in our 2012 Annual Report on Form 10-K for additional information on these and other restrictions.

We do not believe that these restrictions will materially affect our operations or limit any dividend payments in the foreseeable future.

Share Repurchase Program: In May 2011, our Board of Directors authorized a share repurchase program that allows us to repurchase up to $300 million of our common stock through the end of 2013. Through March 31, 2013, we have repurchased $162.9 million of our common stock pursuant to this program at an average cost of $33.03 per share. The share repurchase program does not obligate Wisconsin Energy to acquire any specific number of shares and may be suspended or terminated by the Board of Directors at any time. In addition, through our independent agents, we purchase shares on the open market to fulfill exercised stock options and restricted stock awards. The following table identifies the shares purchased by the Company in the following periods:



March 2013	13	Wisconsin Energy Corporation

Form 10-Q



	Three Months Ended March 31
	2013			2012
	Shares	Cost		Shares	Cost
	(In Millions)

Under May 2011 share repurchase program	0.3	$	11.1	—	$	—
To fulfill exercised stock options and restricted stock awards	1.4	55.4		0.8	28.3
Total	1.7	$	66.5	0.8	$	28.3

4 -- FAIR VALUE MEASUREMENTS

Fair value measurements require enhanced disclosures about assets and liabilities that are measured and reported at fair value and establish a hierarchal disclosure framework which prioritizes and ranks the level of observable inputs used in measuring fair value.

Fair value is the price that would be received upon the sale of an asset or paid to transfer a liability in an orderly transaction between market participants at the measurement date (exit price). We primarily apply the market approach for recurring fair value measurements and attempt to utilize the best available information. Accordingly, we also utilize valuation techniques that maximize the use of observable inputs and minimize the use of unobservable inputs. We are able to classify fair value balances based on the observability of those inputs. The hierarchy gives the highest priority to unadjusted quoted prices in active markets for identical assets or liabilities (Level 1) and the lowest priority to unobservable inputs (Level 3).

Assets and liabilities measured and reported at fair value are classified and disclosed in one of the following categories:

Level 1 -- Pricing inputs are unadjusted quoted prices available in active markets for identical assets or liabilities as of the reporting date. Active markets are those in which transactions for the asset or liability occur in sufficient frequency and volume to provide pricing information on an ongoing basis. Instruments in this category consist of financial instruments such as exchange-traded derivatives, cash equivalents and restricted cash investments.

Level 2 -- Pricing inputs are other than quoted prices in active markets, which are either directly or indirectly observable as of the reporting date, and fair value is determined through the use of models or other valuation methodologies. Instruments in this category include non-exchange-traded derivatives such as Over-the-Counter (OTC) forwards and options.

Level 3 -- Pricing inputs include significant inputs that are generally less observable from objective sources. The inputs in the determination of fair value require significant management judgment or estimation. At each balance sheet date, we perform an analysis of all instruments subject to fair value reporting and include in Level 3 all instruments whose fair value is based on significant unobservable inputs.

In certain cases, the inputs used to measure fair value may fall into different levels of the fair value hierarchy. In such cases, an instrument's level within the fair value hierarchy is based on the lowest level of input that is significant to the fair value measurement. Our assessment of the significance of a particular input to the fair value measurement in its entirety requires judgment and considers factors specific to the instrument.



March 2013	14	Wisconsin Energy Corporation

Form 10-Q

The following tables summarize our financial assets and liabilities by level within the fair value hierarchy:



Recurring Fair Value Measures	As of March 31, 2013
	Level 1		Level 2		Level 3		Total
	(Millions of Dollars)
Assets:
Restricted Cash	$	—	$	—	$	—	$	—
Derivatives	7.0		3.3		1.6		11.9
Total	$	7.0	$	3.3	$	1.6	$	11.9
Liabilities:
Derivatives	$	—	$	0.3	$	—	$	0.3
Total	$	—	$	0.3	$	—	$	0.3



Recurring Fair Value Measures	As of December 31, 2012
	Level 1		Level 2		Level 3		Total
	(Millions of Dollars)
Assets:
Restricted Cash	$	2.7	$	—	$	—	$	2.7
Derivatives	2.2		12.3		4.7		19.2
Total	$	4.9	$	12.3	$	4.7	$	21.9
Liabilities:
Derivatives	$	1.9	$	—	$	—	$	1.9
Total	$	1.9	$	—	$	—	$	1.9

We adopted ASU 2011-11, Disclosures about Offsetting Assets and Liabilities, on a retrospective basis. For additional information, see Note 2 -- New Accounting Pronouncements and Note 5 -- Derivative Instruments.

Restricted cash consists of certificates of deposit and government backed interest bearing securities and represents the settlement we received from the United States Department of Energy (DOE) during the first quarter of 2011, which was returned, net of costs incurred, to customers. Derivatives reflect positions we hold in exchange-traded derivative contracts and OTC derivative contracts. Exchange-traded derivative contracts, which include futures and exchange-traded options, are generally based on unadjusted quoted prices in active markets and are classified within Level 1. Some OTC derivative contracts are valued using broker or dealer quotations, or market transactions in either the listed or OTC markets utilizing a mid-market pricing convention (the mid-point between bid and ask prices), as appropriate. In such cases, these derivatives are classified within Level 2. Certain OTC derivatives may utilize models to measure fair value. Generally, we use a similar model to value similar instruments. Valuation models utilize various inputs which include quoted prices for similar assets or liabilities in active markets, quoted prices for identical or similar assets or liabilities in markets that are not active, other observable inputs for the asset or liability, and market-corroborated inputs (i.e., inputs derived principally from or corroborated by observable market data by correlation or other means). Where observable inputs are available for substantially the full term of the asset or liability, the instrument is categorized in Level 2. Certain OTC derivatives are in less active markets with a lower availability of pricing information which might not be observable in or corroborated by the market. When such inputs have a significant impact on the measurement of fair value, the instrument is categorized in Level 3.



March 2013	15	Wisconsin Energy Corporation

Form 10-Q

The following table summarizes the changes to derivatives classified as Level 3 in the fair value hierarchy:



	2013			2012
	(Millions of Dollars)

Balance as of January 1	$	4.7		$	5.7
Realized and unrealized gains (losses)	—			—
Purchases	—			—
Issuances	—			—
Settlements	(3.1		)	(3.5		)
Transfers in and/or out of Level 3	—			—
Balance as of March 31	$	1.6		$	2.2

Change in unrealized gains (losses) relating to instruments still held as of March 31	$	—		$	—

Derivative instruments reflected in Level 3 of the hierarchy include MISO Financial Transmission Rights (FTRs) that are measured at fair value each reporting period using monthly or annual auction shadow prices from relevant auctions. Changes in fair value for Level 3 recurring items are recorded on our balance sheet. See Note 5 -- Derivative Instruments for further information on the offset to regulatory assets and liabilities.

The carrying amount and estimated fair value of certain of our recorded financial instruments are as follows:



	March 31, 2013				December 31, 2012
Financial Instruments	Carrying Amount		Fair Value		Carrying Amount		Fair Value
	(Millions of Dollars)

Preferred stock, no redemption required	$	30.4	$	27.6	$	30.4	$	26.0
Long-term debt, including current portion	$	4,764.5	$	5,407.1	$	4,772.9	$	5,447.3

The carrying value of net accounts receivable, accounts payable and short-term borrowings approximates fair value due to the short-term nature of these instruments. The fair value of our preferred stock is estimated based upon the quoted market value for the same or similar issues. The fair value of our long-term debt, including the current portion of long-term debt, but excluding capitalized leases and unamortized discount on debt, is estimated based upon quoted market value for the same or similar issues or upon the quoted market prices of U.S. Treasury issues having a similar term to maturity, adjusted for the issuing company's bond rating and the present value of future cash flows.

5 -- DERIVATIVE INSTRUMENTS

We utilize derivatives as part of our risk management program to manage the volatility and costs of purchased power, generation and natural gas purchases for the benefit of our customers and shareholders. Our approach is non-speculative and designed to mitigate risk and protect against price volatility. Regulated hedging programs require prior approval by the Public Service Commission of Wisconsin (PSCW).

We record derivative instruments on the balance sheet as an asset or liability measured at its fair value, and changes in the derivative's fair value are recognized currently in earnings unless specific hedge accounting criteria are met or we receive regulatory treatment for the derivative. For most energy related physical and financial contracts in our regulated operations that qualify as derivatives, the PSCW allows the effects of the fair market value accounting to be offset to regulatory assets and liabilities. As of March 31, 2013, we recognized $0.2 million in regulatory assets and $9.9 million in regulatory liabilities related to derivatives in comparison to $7.6 million in regulatory assets and $17.5 million in regulatory liabilities as of December 31, 2012.



March 2013	16	Wisconsin Energy Corporation

Form 10-Q

We record our current derivative assets on the balance sheet in prepayments and other current assets and the current portion of the liabilities in other current liabilities. The long-term portion of our derivative assets of $0.1 million is recorded in other deferred charges and other assets as of March 31, 2013, and the long-term portion of our derivative liabilities of $0.3 million is recorded in other deferred credits and other liabilities as of March 31, 2013. Our Consolidated Condensed Balance Sheets as of March 31, 2013 and December 31, 2012 include:



	March 31, 2013				December 31, 2012
	Derivative Asset		Derivative Liability		Derivative Asset		Derivative Liability
	(Millions of Dollars)

Natural Gas	$	6.7	$	—	$	3.0	$	1.9
Fuel Oil	0.5		—		0.4		—
FTRs	1.5		—		4.7		—
Coal	3.2		0.3		11.1		—
Total	$	11.9	$	0.3	$	19.2	$	1.9

Our Consolidated Condensed Income Statements include gains (losses) on derivative instruments used in our risk management strategies under fuel and purchased power for those commodities supporting our electric operations and under cost of gas sold for the natural gas sold to our customers. Our estimated notional volumes and gains (losses) were as follows:



	Three Months Ended March 31, 2013				Three Months Ended March 31, 2012
	Volume	Gains (Losses)			Volume	Gains (Losses)
		(Millions of Dollars)				(Millions of Dollars)

Natural Gas	18.8 million Dth	$	(6.5	)	20.4 million Dth	$	(16.2	)
Fuel Oil	1.6 million gallons	0.1			1.7 million gallons	0.6
FTRs	5,343 MW	0.9			5,358 MW	0.6
Total		$	(5.5	)		$	(15.0	)

As of March 31, 2013 and December 31, 2012, we posted collateral of $0.2 million and $2.9 million, respectively, in our margin accounts. These amounts are recorded on the balance sheets in other current assets.

The fair value amounts recognized for the right to reclaim cash collateral or the obligation to return cash collateral are not offset against the fair value amounts recognized for derivative instruments executed with the same counterparty under the same master netting arrangement. The table below shows derivative assets and derivative liabilities if derivative instruments by counterparty were presented net on the balance sheet as of March 31, 2013 and December 31, 2012.



	March 31, 2013						December 31, 2012
	Derivative			Derivative			Derivative			Derivative
	Asset			Liability			Asset			Liability
	(Millions of Dollars)

Gross Amount Recognized on the Balance Sheet	$	11.9		$	0.3		$	19.2		$	1.9
Gross Amount Not Offset on Balance Sheet (a)	(0.1		)	(0.1		)	(0.5		)	(1.8		)
Net Amount	$	11.8		$	0.2		$	18.7		$	0.1


(a)	Gross Amount Not Offset on Balance Sheet includes cash collateral posted of zero and $1.3 million as of March 31, 2013 and December 31, 2012, respectively.



March 2013	17	Wisconsin Energy Corporation

Form 10-Q

6 -- BENEFITS

The components of our net periodic pension and Other Post-Retirement Employee Benefits (OPEB) costs for the three months ended March 31 were as follows:



	Pension Costs						OPEB Costs
	2013			2012			2013			2012
	(Millions of Dollars)
Net Periodic Benefit Cost
Service cost	$	4.2		$	5.4		$	2.7		$	2.8
Interest cost	15.1			16.4			3.9			5.1
Expected return on plan assets	(24.0		)	(22.6		)	(5.3		)	(4.8		)
Amortization of:
Transition obligation	—			—			—			0.1
Prior service (credit)	0.6			0.6			(0.5		)	(0.5		)
Actuarial loss	13.6			9.9			0.9			1.8
Net Periodic Benefit Cost	$	9.5		$	9.7		$	1.7		$	4.5

During the first three months of 2013 and 2012, we made no contributions to our qualified benefit plans. Future contributions to the plans will be dependent upon many factors, including the performance of existing plan assets and long-term discount rates.

Postemployment Benefits: Postemployment benefits provided to former or inactive employees are recognized when an event occurs. The estimated liability for such benefits was $4.0 million as of March 31, 2013 and December 31, 2012.



March 2013	18	Wisconsin Energy Corporation

Form 10-Q

7 -- SEGMENT INFORMATION

Summarized financial information concerning our reportable segments for the three months ended March 31, 2013 and 2012 is shown in the following table:



	Reportable Segments							Eliminations
	Energy				Corporate &			& Reconciling			Total
Three Months Ended	Utility		Non-Utility		Other (a)			Items			Consolidated
	(Millions of Dollars)
March 31, 2013
Operating Revenues (b)	$	1,261.5	$	109.8	$	0.3		$	(96.4	)	$	1,275.2
Other Operation and Maintenance	$	380.6	$	1.5	$	1.0		$	(95.0	)	$	288.1
Depreciation and Amortization	$	78.6	$	16.7	$	0.2		$	—		$	95.5
Operating Income (Loss)	$	230.6	$	91.6	$	(1.2	)	$	—		$	321.0
Equity in Earnings of Unconsolidated Affiliates	$	16.6	$	—	$	0.1		$	—		$	16.7
Interest Expense, Net	$	35.9	$	16.5	$	12.8		$	(0.2	)	$	65.0
Income Tax Expense (Benefit)	$	77.4	$	30.5	$	(7.5	)	$	—		$	100.4
Net Income (Loss)	$	138.0	$	44.6	$	176.6		$	(182.6	)	$	176.6
Capital Expenditures	$	130.9	$	2.1	$	0.6		$	—		$	133.6

March 31, 2012
Operating Revenues (b)	$	1,178.4	$	107.3	$	0.3		$	(94.8	)	$	1,191.2
Other Operation and Maintenance	$	376.4	$	2.1	$	1.3		$	(93.5	)	$	286.3
Depreciation and Amortization	$	70.7	$	16.8	$	0.1		$	—		$	87.6
Operating Income (Loss)	$	208.6	$	88.4	$	(1.3	)	$	—		$	295.7
Equity in Earnings of Unconsolidated Affiliates	$	15.6	$	—	$	—		$	—		$	15.6
Interest Expense, Net	$	29.2	$	16.8	$	13.1		$	(0.2	)	$	58.9
Income Tax Expense (Benefit)	$	74.0	$	28.8	$	(6.5	)	$	—		$	96.3
Net Income (Loss)	$	136.2	$	43.0	$	172.6		$	(179.7	)	$	172.1
Capital Expenditures	$	137.6	$	1.9	$	2.8		$	—		$	142.3


(a)	Corporate & Other includes all other non-utility activities, primarily non-utility real estate investment and development by Wispark LLC, as well as interest on corporate debt.


(b)	An elimination for intersegment revenues is included in Operating Revenues. This elimination is primarily between We Power and Wisconsin Electric.

8 -- VARIABLE INTEREST ENTITIES

The primary beneficiary of a variable interest entity must consolidate the related assets and liabilities. Certain disclosures are required by sponsors, significant interest holders in variable interest entities and potential variable interest entities.

We assess our relationships with potential variable interest entities such as our coal suppliers, natural gas suppliers, coal and gas transporters, and other counterparties in power purchase agreements and joint ventures. In making this assessment, we consider the potential that our contracts or other arrangements provide subordinated financial support, the potential for us to absorb losses or rights to residual returns of the entity, the ability to directly or indirectly make decisions about the entities' activities and other factors.

We have identified a purchased power agreement which represents a variable interest. This agreement is for 236 MW of firm capacity from a gas-fired cogeneration facility and we account for it as a capital lease. The agreement includes no minimum energy requirements over the remaining term of approximately nine years. We have examined the risks of the entity including operations and maintenance, dispatch, financing, fuel costs and other



March 2013	19	Wisconsin Energy Corporation

Form 10-Q

factors, and have determined that we are not the primary beneficiary of the entity. We do not hold an equity or debt interest in the entity and there is no residual guarantee associated with the purchased power agreement.

We have approximately $246.2 million of required payments over the remaining term of this agreement. We believe that the required lease payments under this contract will continue to be recoverable in rates. Total capacity and lease payments under contracts considered variable interests for the three months ended March 31, 2013 and 2012 were $12.5 million and $14.7 million, respectively. Our maximum exposure to loss is limited to the capacity payments under the contracts.

9 -- COMMITMENTS AND CONTINGENCIES

Environmental Matters: We periodically review our exposure for environmental remediation costs as evidence becomes available indicating that our liability has changed. Given current information, including the following, we believe that future costs in excess of the amounts accrued and/or disclosed on all presently known and quantifiable environmental contingencies will not be material to our financial position or results of operations.

We have a program of comprehensive environmental remediation planning for former manufactured gas plant sites and coal combustion product disposal sites. We perform ongoing assessments of manufactured gas plant sites and related disposal sites used by Wisconsin Electric and Wisconsin Gas, and coal combustion product disposal/landfill sites used by Wisconsin Electric, as discussed below. We are working with the Wisconsin Department of Natural Resources (WDNR) in our investigation and remediation planning. At this time, we cannot estimate future remediation costs associated with these sites beyond those described below.

Manufactured Gas Plant Sites: We have identified several sites at which Wisconsin Electric, Wisconsin Gas, or a predecessor company historically owned or operated a manufactured gas plant. These sites have been substantially remediated or are at various stages of investigation, monitoring and remediation. We have also identified other sites that may have been impacted by historical manufactured gas plant activities. Based upon on-going analysis, we estimate that the future costs for detailed site investigation and future remediation costs may range from $16 million to $62 million over the next ten years. This estimate is dependent upon several variables including, among other things, the extent of remediation, changes in technology and changes in regulation. As of March 31, 2013, we have established reserves of $38.2 million related to future remediation costs.

Historically, the PSCW has allowed Wisconsin utilities, including Wisconsin Electric and Wisconsin Gas, to defer the costs spent on the remediation of manufactured gas plant sites, and has allowed for these costs to be recovered in rates over five years. Accordingly, we have recorded a regulatory asset for remediation costs.

Divested Assets: Pursuant to the sale of the Point Beach Nuclear Power Plant, we agreed to indemnification provisions customary to transactions involving the sale of nuclear assets. We also provided customary indemnifications to Wisconsin Power and Light Company, a subsidiary of Alliant Energy Corp. (WPL) in connection with the sale of our interest in Edgewater Generating Unit 5.

10 -- SUPPLEMENTAL CASH FLOW INFORMATION

During the three months ended March 31, 2013, we paid $21.7 million in interest, net of amounts capitalized, and paid $2.0 million in income taxes, net of refunds. During the three months ended March 31, 2012, we paid $26.5 million in interest, net of amounts capitalized, and paid $15.3 million in income taxes, net of refunds.

As of March 31, 2013 and 2012, the amount of accounts payable related to capital expenditures was $8.9 million and $12.6 million, respectively.

During the three months ended March 31, 2013 and 2012, total amortization of deferred revenue was $14.9 million and $13.7 million, respectively.

During the three months ended March 31, 2013 and 2012, our equity in earnings from ATC was $16.6 million and $15.6 million, respectively. During the three months ended March 31, 2013 and 2012, distributions received from ATC were $13.3 million and $12.9 million, respectively.



March 2013	20	Wisconsin Energy Corporation

Form 10-Q


ITEM 2.	MANAGEMENT'S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION

AND RESULTS OF OPERATIONS

RESULTS OF OPERATIONS -- THREE MONTHS ENDED MARCH 31, 2013

CONSOLIDATED EARNINGS

The following table compares our operating income by business segment and our net income during the first quarter of 2013 with the first quarter of 2012, including favorable (better (B)) or unfavorable (worse (W)) variances:



	Three Months Ended March 31
	2013			B (W)			2012
	(Millions of Dollars)

Utility Energy Segment	$	230.6		$	22.0		$	208.6
Non-Utility Energy Segment	91.6			3.2			88.4
Corporate and Other	(1.2		)	0.1			(1.3		)
Total Operating Income	321.0			25.3			295.7
Equity in Earnings of Transmission Affiliate	16.6			1.0			15.6
Other Income, net	4.4			(11.6		)	16.0
Interest Expense, net	65.0			(6.1		)	58.9
Income Before Income Taxes	277.0			8.6			268.4
Income Tax Expense	100.4			(4.1		)	96.3
Net Income	$	176.6		$	4.5		$	172.1
Diluted Earnings Per Share	$	0.76		$	0.02		$	0.74

UTILITY ENERGY SEGMENT CONTRIBUTION TO OPERATING INCOME

Our utility energy segment contributed $230.6 million of operating income during the first quarter of 2013, an increase of $22.0 million, or 10.5%, compared with the first quarter of 2012. The following table summarizes the operating income of this segment between the comparative quarters:



	Three Months Ended March 31
Utility Energy Segment	2013		B (W)			2012
	(Millions of Dollars)
Operating Revenues
Electric	$	812.3	$	35.0		$	777.3
Gas	434.0		45.5			388.5
Other	15.2		2.6			12.6
Total Operating Revenues	1,261.5		83.1			1,178.4
Operating Expenses
Fuel and Purchased Power	272.3		(17.2		)	255.1
Cost of Gas Sold	270.1		(32.6		)	237.5
Other Operation and Maintenance	380.6		(4.2		)	376.4
Depreciation and Amortization	78.6		(7.9		)	70.7
Property and Revenue Taxes	29.3		0.8			30.1
Total Operating Expenses	1,030.9		(61.1		)	969.8
Operating Income	$	230.6	$	22.0		$	208.6



March 2013	21	Wisconsin Energy Corporation

Form 10-Q

Electric Utility Revenues and Sales

The following table compares electric utility operating revenues and MWh sales by customer class during the first quarter of 2013 with the first quarter of 2012:



	Electric Revenues							MWh Sales
Electric Utility Operations	2013		B (W)			2012		2013	B (W)		2012
	(Millions of Dollars)							(Thousands)
Customer Class
Residential	$	303.2	$	28.6		$	274.6	2,044.5	101.6		1,942.9
Small Commercial/Industrial	253.9		8.7			245.2		2,179.0	27.4		2,151.6
Large Commercial/Industrial	186.3		1.9			184.4		2,347.8	(96.5	)	2,444.3
Other - Retail	6.2		0.2			6.0		39.5	(0.9	)	40.4
Total Retail	749.6		39.4			710.2		6,610.8	31.6		6,579.2
Wholesale - Other	39.5		2.8			36.7		517.0	184.3		332.7
Resale - Utilities	17.3		0.3			17.0		559.9	(37.2	)	597.1
Other Operating Revenues	5.9		(7.5		)	13.4		—	—		—
Total	$	812.3	$	35.0		$	777.3	7,687.7	178.7		7,509.0

Weather -- Degree Days (a)
Heating (3,252 Normal)								3,471	861		2,610

(a) As measured at Mitchell International Airport in Milwaukee, Wisconsin. Normal degree days are based upon a 20-year
moving average.

Our electric utility operating revenues increased by $35.0 million, or 4.5%, when compared to the first quarter of 2012. The most significant factors that caused a change in revenues were:

•

Net retail pricing increases of $28.6 million ($43.8 million less $15.2 million related to Section 1603 bill credits), which is primarily related to our 2013 Wisconsin Rate Case. For information on the Section 1603 bill credits and the rate order in the 2013 rate case, see Results of Operations -- March 31, 2013 -- Section 1603 Renewable Energy Treasury Grant and Factors Affecting Results, Liquidity and Capital Resources -- Utility Rates and Regulatory Matters, respectively.


•	Favorable weather that increased electric revenues by an estimated $21.5 million as compared to the first quarter of 2012.


•	A $7.5 million decrease in other operating revenues, primarily driven by the amortization of $6.7 million in 2012 related to the settlement with the DOE. See Factors Affecting Results, Liquidity and Capital Resources -- Utility Rates and Regulatory Matters -- 2012 Fuel Recovery Request.

As measured by heating degree days, the first quarter of 2013 was 33.0% colder than the same period in 2012 and 6.7% colder than normal. We believe the colder winter weather was the primary reason for the 5.2% increase in residential sales. Sales to large commercial/industrial customers decreased by 3.9%, primarily because of the leap year in 2012 and a decrease in sales to the two iron ore mines in Michigan. Wholesale - Other sales increased by 55.4%; however, our related revenues increased by only $2.8 million, or 7.6%, due to a large increase in off-peak sales which are at significantly lower prices than on-peak sales.

Fuel and Purchased Power

Our fuel and purchased power costs increased by $17.2 million, or 6.7%, when compared to the first quarter of 2012. This increase was primarily caused by a 2.4% increase in total MWh sales and higher generating costs driven by an increase in natural gas prices as compared to the first quarter of 2012.



March 2013	22	Wisconsin Energy Corporation

Form 10-Q

Gas Utility Revenues, Gross Margin and Therm Deliveries

A comparison follows of gas utility operating revenues, gross margin and gas deliveries during the first quarter of 2013 with the first quarter of 2012. We believe gross margin is a better performance indicator than revenues because changes in the cost of gas sold flow through to revenue under gas cost recovery mechanisms. Between the comparative periods, total gas operating revenues increased by $45.5 million, or 11.7%, and cost of gas sold increased by $32.6 million, or 13.7%, due to the colder winter weather.



	Three Months Ended March 31
	2013		B (W)			2012
	(Millions of Dollars)

Gas Operating Revenues	$	434.0	$	45.5		$	388.5
Cost of Gas Sold	270.1		(32.6		)	237.5
Gross Margin	$	163.9	$	12.9		$	151.0

The following table compares gas utility gross margin and natural gas therm deliveries by customer class during the first quarter of 2013 with the first quarter of 2012:



	Gross Margin							Therm Deliveries
Gas Utility Operations	2013		B (W)			2012		2013	B (W)		2012
	(Millions of Dollars)							(Millions)
Customer Class
Residential	$	107.6	$	9.7		$	97.9	402.3	104.1		298.2
Commercial/Industrial	39.5		3.7			35.8		219.4	48.8		170.6
Interruptible	0.6		—			0.6		6.5	1.5		5.0
Total Retail	147.7		13.4			134.3		628.2	154.4		473.8
Transported Gas	14.9		0.2			14.7		316.6	(7.5	)	324.1
Other	1.3		(0.7		)	2.0		—	—		—
Total	$	163.9	$	12.9		$	151.0	944.8	146.9		797.9

Weather -- Degree Days (a)
Heating (3,252 Normal)								3,471	861		2,610

(a) As measured at Mitchell International Airport in Milwaukee, Wisconsin. Normal degree days are based upon a 20-year
moving average.

Our gas margin increased by $12.9 million, or approximately 8.5%, when compared to the first quarter of 2012. We estimate that weather increased gas margins by approximately $33.9 million. As measured by heating degree days, the first quarter of 2013 was 33.0% colder than the same period in 2012 and 6.7% colder than normal. The first quarter of 2012 was significantly warmer than normal. Gas margins were reduced by approximately $20.5 million because of lower gas rates that became effective January 1, 2013. For information on this rate order, see Factors Affecting Results, Liquidity and Capital Resources -- Utility Rates and Regulatory Matters.

Other Operation and Maintenance Expense

Our other operation and maintenance expense increased by $4.2 million, or approximately 1.1%, when compared to the first quarter of 2012. This increase was primarily driven by the reinstatement of $37.5 million of regulatory amortizations, offset in part by a $17.2 million reduction in bad debt expense related to our natural gas customers, continued cost control efforts across the utility and some timing impacts associated with the variation in weather between quarters.



March 2013	23	Wisconsin Energy Corporation

Form 10-Q

Depreciation and Amortization Expense

Our depreciation and amortization expense increased by $7.9 million, or approximately 11.2%, when compared to the first quarter of 2012 primarily because of an overall increase in utility plant in service. The emission control equipment for units 5 and 6 of the Oak Creek Air Quality Control System (AQCS) project went into service in March 2012, and for units 7 and 8 in September 2012. For additional information, see Factors Affecting Results, Liquidity and Capital Resources -- Utility Rates and Regulatory Matters -- Oak Creek Air Quality Control System.

Section 1603 Renewable Energy Treasury Grant

We expect to receive a treasury grant of approximately $72 million related to the construction of our biomass facility in Rothschild, Wisconsin. The PSCW took this grant into consideration when it set rates for our electric customers for the two years ending December 31, 2014. These rates became effective on January 1, 2013 and are reflected in the form of bill credits that reduce our revenues. We expect to recognize the treasury grant as income in the fourth quarter of 2013 when the plant is expected to be placed into service. At that time, we will also defer as a regulatory liability, the portion of the grant income that will be used to reduce rates in 2014. For the first three quarters of 2013, we will experience a mismatch between bill credits (lower revenues) and grant income. However, when the plant is placed into service in the fourth quarter, we will make an entry to record grant income to match the bill credits that have been provided to customers during 2013. If we recorded grant income to match the credits provided to customers, we estimate that the earnings in the first, second and third quarters would be approximately $0.03 per share higher in each quarter.

In addition, the PSCW approved escrow accounting treatment for the treasury grant. As a result, we expect to true-up any difference between the actual grant proceeds we receive and the estimated grant proceeds the PSCW used to set electric retail rates for 2013 and 2014.

NON-UTILITY ENERGY SEGMENT CONTRIBUTION TO OPERATING INCOME

Our non-utility energy segment consists primarily of our PTF units (Port Washington Generating Station Unit 1 (PWGS 1), Port Washington Generating Station Unit 2 (PWGS 2), Oak Creek expansion Unit 1 (OC 1) and Oak Creek expansion Unit 2 (OC 2)).

This segment reflects the lease revenues on the new units as well as the depreciation expense. Operating and maintenance costs associated with the plants are the responsibility of Wisconsin Electric and are recorded in the utility segment.



	Three Months Ended March 31
	2013		B (W)		2012
	(Millions of Dollars)

Operating Revenues	$	109.8	$	2.5	$	107.3
Operation and Maintenance Expense	1.5		0.6		2.1
Depreciation Expense	16.7		0.1		16.8
Operating Income	$	91.6	$	3.2	$	88.4

Non-utility energy segment operating income increased by $3.2 million, or approximately 3.6%, when compared to the first quarter of 2012. The increase in operating revenues is primarily related to the final approved construction costs for the Oak Creek expansion as part of the 2013 Wisconsin Rate Case.



March 2013	24	Wisconsin Energy Corporation

Form 10-Q

CONSOLIDATED OTHER INCOME, NET



	Three Months Ended March 31
	2013		B (W)			2012
	(Millions of Dollars)

AFUDC - Equity	$	4.3	$	(10.5	)	$	14.8
Other, net	0.1		(1.1		)	1.2
Other Income, net	$	4.4	$	(11.6	)	$	16.0

Other income, net decreased by $11.6 million, or approximately 72.5%, when compared to the first quarter of 2012. The decrease in AFUDC - Equity is primarily related to the Oak Creek AQCS project which emission control equipment went into service in March 2012 for units 5 and 6 and September 2012 for units 7 and 8.

CONSOLIDATED INTEREST EXPENSE, NET



	Three Months Ended March 31
	2013		B (W)			2012
	(Millions of Dollars)

Gross Interest Costs	$	67.2	$	(1.9	)	$	65.3
Less: Capitalized Interest	2.2		(4.2		)	6.4
Interest Expense, net	$	65.0	$	(6.1	)	$	58.9

Our gross interest costs increased by $1.9 million, or approximately 2.9%, when compared to the first quarter of 2012 primarily because of the issuance of $250 million of long-term debt by Wisconsin Electric in December 2012. Our capitalized interest decreased by $4.2 million primarily because of lower construction work in progress. As a result, our net interest expense increased by $6.1 million, or 10.4%, as compared to the first quarter of 2012.

CONSOLIDATED INCOME TAX EXPENSE

For the first quarter of 2013, our effective tax rate applicable to continuing operations was 36.2% compared to 35.9% for the first quarter of 2012. For additional information, see Note G -- Income Taxes in our 2012 Annual Report on Form 10-K. We expect our 2013 annual effective tax rate to be between 37% and 38%.

LIQUIDITY AND CAPITAL RESOURCES

CASH FLOWS

The following summarizes our cash flows from continuing operations during the three months ended March 31:



	2013			2012
	(Millions of Dollars)
Cash Provided by (Used in)
Operating Activities	$	330.3		$	340.5
Investing Activities	$	(145.3	)	$	(130.4	)
Financing Activities	$	(195.9	)	$	(206.1	)



March 2013	25	Wisconsin Energy Corporation

Form 10-Q

Operating Activities

Cash provided by operating activities decreased by $10.2 million during the first three months of 2013 as compared to the same period in 2012. The decrease is primarily because of higher working capital requirements. We experienced significantly colder weather when compared to the same period in 2012, resulting in higher accounts receivable and accrued revenues. Partially offsetting this decrease is higher net income, higher depreciation expense and the end of the one year suspension of amortization expense authorized by the 2012 Wisconsin Rate Case.

Investing Activities

Cash used in investing activities increased by $14.9 million during the first three months of 2013 as compared to the same period in 2012. Our change in restricted cash decreased by $18.1 million which is related to the 2012 release of restricted cash through bill credits and reimbursements of costs associated with the DOE settlement. Our capital expenditures decreased by $8.7 million during the first three months of 2013 as compared to the same period in 2012, primarily because of the completion of the Oak Creek AQCS project, partially offset by the increased spending at the biomass plant.

Financing Activities

Cash used in financing activities decreased by $10.2 million during the first three months of 2013 as compared to the same period in 2012. Repayment of short-term debt was $34.7 million lower in 2013 as compared to the same period in 2012, primarily because of lower cash flows from operations and higher cash flows used in investing. In addition, proceeds received from the exercise of stock options totaled $27.3 million during the first three months of 2013 as compared to $12.9 million during the same period in 2012. These factors were partially offset by increased share repurchases and dividends paid on common stock. During the first three months of 2013, we repurchased $11.1 million of common stock under our May 2011 share repurchase program and another $55.4 million of common stock to fulfill exercised stock options and restricted stock awards. During the same period in 2012, we repurchased $29.2 million to fulfill stock options and awards, but had no repurchases under the share repurchase program. Our dividends paid on common stock increased by $8.7 million in the first quarter of 2013 as a result of a 13.3% increase in the quarterly common stock dividend.

CAPITAL RESOURCES AND REQUIREMENTS

Liquidity

We anticipate meeting our capital requirements during the remainder of 2013 and beyond primarily through internally generated funds and short-term borrowings, supplemented by the issuance of intermediate or long-term debt securities, depending on market conditions and other factors.

We currently have access to the capital markets and have been able to generate funds internally and externally to meet our capital requirements. Our ability to attract the necessary financial capital at reasonable terms is critical to our overall strategic plan. We currently believe that we have adequate capacity to fund our operations for the foreseeable future through our existing borrowing arrangements, access to capital markets and internally generated cash.

Wisconsin Energy, Wisconsin Electric and Wisconsin Gas maintain bank back-up credit facilities, which provide liquidity support for each company's obligations with respect to commercial paper and for general corporate purposes.

As of March 31, 2013, we had approximately $1.2 billion of available, undrawn lines under our bank back-up credit facilities, and approximately $316.7 million of commercial paper outstanding on a consolidated basis that was supported by the available lines of credit. During the first three months of 2013, our maximum commercial paper outstanding was $431.3 million with a weighted-average interest rate of 0.29%.



March 2013	26	Wisconsin Energy Corporation

Form 10-Q

We review our bank back-up credit facility needs on an ongoing basis and expect to be able to maintain adequate credit facilities to support our operations. The following table summarizes such facilities as of March 31, 2013:



Company	Total Facility		Letters of Credit		Credit Available		Facility Expiration
	(Millions of Dollars)

Wisconsin Energy	$	400.0	$	0.4	$	399.6	December 2017
Wisconsin Electric	$	500.0	$	6.1	$	493.9	December 2017
Wisconsin Gas	$	350.0	$	—	$	350.0	December 2017