10-Q

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, 2012

[ ] Transition report pursuant to Section 13 or 15(d) of the Securities Exchange Act of 1934

For the transition period from _______________ to _______________

Commission File No.	Name of Registrant, State of Incorporation, Address of Principal Executive Offices, and Telephone No.	IRS Employer Identification No.
000-49965	MGE Energy, Inc. (a Wisconsin Corporation) 133 South Blair Street Madison, Wisconsin 53703 (608) 252-7000 www.mgeenergy.com	39-2040501
000-1125	Madison Gas and Electric Company (a Wisconsin Corporation) 133 South Blair Street Madison, Wisconsin 53703 (608) 252-7000 www.mge.com	39-0444025

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 registrant was 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 sites, 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 registrant is a large accelerated filer, an accelerated filer, a non-accelerated filer, or a smaller reporting company. See 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
MGE Energy, Inc.	X
Madison Gas and Electric Company			X

Indicate by check mark whether the registrant is a shell company (as defined in Rule 12b-2 of the Exchange Act):

MGE Energy, Inc. and Madison Gas and Electric Company: Yes [ ] No [X]

Number of Shares Outstanding of Each Class of Common Stock as of April 30, 2012
MGE Energy, Inc.	Common stock, $1.00 par value, 23,113,638 shares outstanding.
Madison Gas and Electric Company	Common stock, $1.00 par value, 17,347,894 shares outstanding (all of which are owned beneficially and of record by MGE Energy, Inc.).

1

Table of Contents

2

PART I. FINANCIAL INFORMATION.

Filing Format

This combined Form 10-Q is being filed separately by MGE Energy, Inc. (MGE Energy) and Madison Gas and Electric Company (MGE). MGE is a wholly owned subsidiary of MGE Energy and represents a majority of its assets, liabilities, revenues, expenses, and operations. Thus, all information contained in this report relates to, and is filed by, MGE Energy. Information that is specifically identified in this report as relating solely to MGE Energy, such as its financial statements and information relating to its nonregulated business, does not relate to, and is not filed by, MGE. MGE makes no representation as to that information. The terms "we" and "our," as used in this report, refer to MGE Energy and its consolidated subsidiaries, unless otherwise indicated.

Forward-Looking Statements

This report, and other documents filed by MGE Energy and MGE with the Securities and Exchange Commission (SEC) from time to time, contain forward-looking statements that reflect management's current assumptions and estimates regarding future performance and economic conditions—especially as they relate to future load growth, revenues, expenses, capital expenditures, financial resources, regulatory matters, and the scope and expense associated with future environmental regulation. These forward-looking statements are made pursuant to the provisions of the Private Securities Litigation Reform Act of 1995. Words such as "believe," "expect," "anticipate," "estimate," "could," "should," "intend," and other similar words generally identify forward-looking statements. Both MGE Energy and MGE caution investors that these forward-looking statements are subject to known and unknown risks and uncertainties that may cause actual results to differ materially from those projected, expressed, or implied.

The factors that could cause actual results to differ materially from the forward-looking statements made by a registrant (a) include those factors discussed in the Registrants' 2011 Annual Report on Form 10-K: Item 1A. Risk Factors, as updated by Part II. Item 1A. Risk Factors, Item 7. Management's Discussion and Analysis of Financial Condition and Results of Operations, as updated by Part I, Item 2. Management's Discussion and Analysis of Financial Condition and Results of Operations in this report, and Item 8. Financial Statements and Supplementary Data – Note 18, as updated by Part I, Item 1. Financial Statements – Note 8 in this report, and (b) other factors discussed herein and in other filings made by that registrant with the SEC.

Readers are cautioned not to place undue reliance on these forward-looking statements, which apply only as of the date of this report. MGE Energy and MGE undertake no obligation to publicly release any revision to these forward-looking statements to reflect events or circumstances after the date of this report.

Where to Find More Information

The public may read and copy any reports or other information that MGE Energy and MGE file with the SEC at the SEC's public reference room at 100 F Street, NE, Washington, D.C. 20549. The public may obtain information on the operation of the Public Reference Room by calling the SEC at 1-800-SEC-0330. These documents also are available to the public from commercial document retrieval services, the website maintained by the SEC at http://www.sec.gov, MGE Energy's website at http://www.mgeenergy.com, and MGE's website at http://www.mge.com. Copies may be obtained from our websites free of charge. Information contained on MGE Energy's and MGE's websites shall not be deemed incorporated into, or to be a part of, this report.

3

Definitions, Abbreviations, and Acronyms Used in the Text and Notes of this Report

Abbreviations, acronyms, and definitions used in the text and notes of this report are defined below.
AFUDC	Allowance for Funds Used During Construction
ATC	American Transmission Company LLC
BART	Best Available Retrofit Technology
Blount	Blount Station
CAA	Clean Air Act
CAIR	Clean Air Interstate Rule
CAVR	Clean Air Visibility Rule
Codification	Financial Accounting Standards Board Accounting Standards Codification
Columbia	Columbia Energy Center
CSAPR	Cross-State Air Pollution Rule
CWA	Clean Water Act
CWDC	Central Wisconsin Development Corporation
DOE	U.S. Department of Energy
Dth	Dekatherms
Elm Road Units	Elm Road Generating Station
EPA	United States Environmental Protection Agency
ERISA	Employee Retirement Income Security Act
EGU	Electric Generating Unit
FASB	Financial Accounting Standards Board
FTR	Financial Transmission Rights
GHG	Greenhouse Gas
HAPs	Hazardous Air Pollutants
heating degree days (HDD)	Measure of the extent to which the average daily temperature is below 65 degrees Fahrenheit, which is considered an indicator of possible increased demand for energy to provide heating
IRS	Internal Revenue Service
kWh	Kilowatt-hour
MACT	Maximum Achievable Control Technology
MAGAEL	MAGAEL, LLC
MATS	Mercury and Air Toxics Standards
MGE	Madison Gas and Electric Company
MGE Construct	MGE Construct LLC
MGE Energy	MGE Energy, Inc.
MGE Power	MGE Power LLC
MGE Power Elm Road	MGE Power Elm Road, LLC
MGE Power West Campus	MGE Power West Campus, LLC
MGE Transco	MGE Transco Investment LLC
MISO	Midwest Independent System Operator (a regional transmission organization)
MW	Megawatt
MWh	Megawatt-hour
NAAQS	National Ambient Air Quality Standards
NGCC	Natural Gas Combined Cycle
NO2	Nitrogen Dioxide
NOV	Notice of Violation
NOx	Nitrogen Oxides
NSPS	New Source Performance Standards
OPRB	Other Postretirement Benefits
PGA	Purchased Gas Adjustment clause
PJM	PJM Interconnection, LLC (a regional transmission organization)
PM	Particulate Matter
PPA	Purchased power agreement
PSCW	Public Service Commission of Wisconsin
PSD	Prevention of Significant Deterioration
RICE	Reciprocating Internal Combustion Engine
SEC	Securities and Exchange Commission
SIP	State Implementation Plan
SO2	Sulfur Dioxide
Stock Plan	Direct Stock Purchase and Dividend Reinvestment Plan of MGE Energy
UW	University of Wisconsin at Madison
VIE	Variable Interest Entity
WCCF	West Campus Cogeneration Facility
WDNR	Wisconsin Department of Natural Resources
Working capital	Current assets less current liabilities
WPDES	Wisconsin Pollutant Discharge Elimination System
WPL	Wisconsin Power and Light Company
WPSC	Wisconsin Public Service Corporation

4

Item 1. Financial Statements.

MGE Energy, Inc.

Consolidated Statements of Income (unaudited)

(In thousands, except per-share amounts)

		Three Months Ended
		March 31,
		2012		2011
Operating Revenues:
Regulated electric revenues	$	89,936	$	86,007
Regulated gas revenues		57,019		77,437
Nonregulated revenues		2,304		1,161
Total Operating Revenues		149,259		164,605
Operating Expenses:
Fuel for electric generation		8,851		11,049
Purchased power		19,546		17,581
Cost of gas sold		34,845		50,947
Other operations and maintenance		42,949		39,413
Depreciation and amortization		9,624		10,016
Other general taxes		5,000		4,701
Total Operating Expenses		120,815		133,707
Operating Income		28,444		30,898
Other income, net		2,570		2,386
Interest expense, net		(5,104)		(4,850)
Income before income taxes		25,910		28,434
Income tax provision		(9,862)		(10,651)
Net Income	$	16,048	$	17,783
Earnings Per Share of Common Stock
(basic and diluted)	$	0.69	$	0.77
Dividends per share of common stock	$	0.383	$	0.375
Average Shares Outstanding
(basic and diluted)		23,114		23,114

MGE Energy, Inc.

Consolidated Statements of Comprehensive Income (unaudited)

(In thousands)

			Three Months Ended
			March 31,
			2012		2011
	Net Income	$	16,048	$	17,783
	Other comprehensive income, net of tax:
	Unrealized gain on available-for-sale securities, net of
	tax ($5 and $48)		7		72
	Comprehensive Income	$	16,055	$	17,855
The accompanying notes are an integral part of the above unaudited consolidated financial statements.

5

MGE Energy, Inc.

Consolidated Statements of Cash Flows (unaudited)

(In thousands)

		Three Months Ended
		March 31,
		2012		2011
Operating Activities:
Net income	$	16,048	$	17,783
Items not affecting cash:
Depreciation and amortization		9,624		10,016
Deferred income taxes		8,846		1,622
Provision for doubtful receivables		1,167		1,038
Employee benefit plan expenses		4,682		3,394
Equity earnings in ATC		(2,242)		(2,097)
Other items		660		178
Changes in working capital items:
Decrease in current assets		12,377		29,753
Decrease in current liabilities		(6,631)		(7,279)
Dividend income from ATC		1,740		1,682
Cash contributions to pension and other postretirement plans		(20,789)		(19,188)
Other noncurrent items, net		(746)		1,135
Cash Provided by Operating Activities		24,736		38,037
Investing Activities:
Capital expenditures		(15,467)		(9,843)
Capital contributions to investments		(355)		(425)
Purchase of investment - land		(3)		(1,794)
Other		109		(419)
Cash Used for Investing Activities		(15,716)		(12,481)
Financing Activities:
Cash dividends paid on common stock		(8,843)		(8,670)
Repayment of long-term debt		(667)		(500)
Issuance of long-term debt		-		30,000
Decrease in short-term debt		-		(22,500)
Other		(19)		(311)
Cash Used for Financing Activities		(9,529)		(1,981)
Change in Cash and Cash Equivalents:		(509)		23,575
Cash and cash equivalents at beginning of period		41,169		7,110
Cash and cash equivalents at end of period	$	40,660	$	30,685
Supplemental disclosures of cash flow information:
Significant noncash investing activities:
Accrued capital expenditures	$	4,674	$	1,146
The accompanying notes are an integral part of the unaudited consolidated financial statements.

6

MGE Energy, Inc.

Consolidated Balance Sheets (unaudited)

(In thousands)

		March 31,	December 31,
ASSETS		2012		2011
Current Assets:
Cash and cash equivalents	$	40,660	$	41,169
Receivable - margin account		2,500		2,477
Accounts receivable, less reserves of $3,775 and $3,662, respectively		38,090		36,744
Other accounts receivable, less reserves of $636 and $439, respectively		4,500		5,318
Unbilled revenues		20,706		25,754
Materials and supplies, at average cost		16,047		14,758
Fossil fuel		8,238		5,468
Stored natural gas, at average cost		10,385		19,575
Prepaid taxes		20,118		22,251
Regulatory assets - current		10,665		7,347
Other current assets		7,095		8,270
Total Current Assets		179,004		189,131
Regulatory assets		228,162		205,835
Other deferred assets and other		7,011		8,018
Property, Plant, and Equipment:
Property, plant, and equipment, net		966,069		961,511
Construction work in progress		40,854		34,055
Total Property, Plant, and Equipment		1,006,923		995,566
Investments		61,197		60,332
Total Assets	$	1,482,297	$	1,458,882
LIABILITIES AND CAPITALIZATION
Current Liabilities:
Long-term debt due within one year	$	2,667	$	2,667
Accounts payable		32,000		34,532
Accrued interest and taxes		4,542		4,085
Accrued payroll related items		7,895		9,987
Deferred income taxes		862		3,020
Derivative liabilities		8,198		4,568
Other current liabilities		6,047		4,215
Total Current Liabilities		62,211		63,074
Other Credits:
Deferred income taxes		210,999		199,850
Investment tax credit - deferred		1,715		1,780
Regulatory liabilities		18,387		20,463
Accrued pension and other postretirement benefits		165,304		183,622
Derivative liabilities		60,880		34,908
Other deferred liabilities and other		44,388		43,330
Total Other Credits		501,673		483,953
Capitalization:
Common shareholders' equity		558,164		550,952
Long-term debt		360,249		360,903
Total Capitalization		918,413		911,855
Commitments and contingencies (see Footnote 8)		-		-
Total Liabilities and Capitalization	$	1,482,297	$	1,458,882
The accompanying notes are an integral part of the above unaudited consolidated financial statements.

7

MGE Energy, Inc.

Consolidated Statements of Common Equity (unaudited)

(In thousands, except per-share amounts)

									Accumulated
					Additional				Other
	Common Stock				Paid-in		Retained		Comprehensive
	Shares		Value		Capital		Earnings		(Loss)/Income		Total
2011
Beginning balance - December 31, 2010	23,114	$	23,114	$	316,268	$	185,556	$	142	$	525,080
Net income							17,783				17,783
Other comprehensive income									72		72
Common stock dividends declared
($0.375 per share)							(8,670)				(8,670)
Ending balance - March 31, 2011	23,114	$	23,114	$	316,268	$	194,669	$	214	$	534,265
2012
Beginning balance - December 31, 2011	23,114	$	23,114	$	316,268	$	211,458	$	112	$	550,952
Net income							16,048				16,048
Other comprehensive income									7		7
Common stock dividends declared
($0.383 per share)							(8,843)				(8,843)
Ending balance - March 31, 2012	23,114	$	23,114	$	316,268	$	218,663	$	119	$	558,164
The accompanying notes are an integral part of the above unaudited consolidated financial statements.

8

Madison Gas and Electric Company

Consolidated Statements of Income (unaudited)

(In thousands)

		Three Months Ended
		March 31,
		2012		2011
Operating Revenues:
Regulated electric revenues	$	89,936	$	86,007
Regulated gas revenues		57,019		77,437
Nonregulated revenues		2,304		1,161
Total Operating Revenues		149,259		164,605
Operating Expenses:
Fuel for electric generation		8,851		11,049
Purchased power		19,546		17,581
Cost of gas sold		34,845		50,947
Other operations and maintenance		42,528		39,235
Depreciation and amortization		9,624		10,016
Other general taxes		5,000		4,701
Income tax provision		8,969		9,891
Total Operating Expenses		129,363		143,420
Operating Income		19,896		21,185
Other Income and Deductions:
AFUDC - equity funds		154		87
Equity in earnings in ATC		2,242		2,097
Income tax provision		(993)		(806)
Other income, net		56		113
Total Other Income and Deductions		1,459		1,491
Income before interest expense		21,355		22,676
Interest Expense:
Interest on long-term debt		5,197		4,991
Other interest, net		7		(147)
AFUDC - borrowed funds		(63)		(35)
Net Interest Expense		5,141		4,809
Net Income	$	16,214	$	17,867
Less Net Income Attributable to Noncontrolling Interest, net of tax		(6,072)		(5,933)
Net Income Attributable to MGE	$	10,142	$	11,934

Madison Gas and Electric Company

Consolidated Statements of Comprehensive Income (unaudited)

(In thousands)

			Three Months Ended
			March 31,
			2012		2011
	Net Income	$	16,214	$	17,867
	Other comprehensive income (loss), net of tax:
	Unrealized gain (loss) on available-for-sale securities, net of
	tax ($11 and $23)		(16)		35
	Comprehensive Income	$	16,198	$	17,902
	Less: Comprehensive income attributable to Noncontrolling
	Interest, net of tax		(6,072)		(5,933)
	Comprehensive Income attributable to MGE	$	10,126	$	11,969
The accompanying notes are an integral part of the above unaudited consolidated financial statements.

9

Madison Gas and Electric Company

Consolidated Statements of Cash Flows (unaudited)

(In thousands)

		Three Months Ended
		March 31,
		2012		2011
Operating Activities:
Net income	$	16,214	$	17,867
Items not affecting cash:
Depreciation and amortization		9,624		10,016
Deferred income taxes		8,768		1,412
Provision for doubtful receivables		1,005		1,038
Employee benefit plan expenses		4,682		3,394
Equity earnings in ATC		(2,242)		(2,097)
Other items		792		390
Changes in working capital items:
Decrease in current assets		11,542		28,893
Decrease in current liabilities		(6,991)		(7,441)
Dividend income from ATC		1,740		1,682
Cash contributions to pension and other postretirement plans		(20,789)		(19,188)
Other noncurrent items, net		(762)		1,110
Cash Provided by Operating Activities		23,583		37,076
Investing Activities:
Capital expenditures		(15,467)		(9,843)
Capital contributions to investments		(355)		(355)
Other		49		88
Cash Used for Investing Activities		(15,773)		(10,110)
Financing Activities:
Cash dividends paid to parent by MGE		(6,728)		(6,596)
Distributions to parent from noncontrolling interest		-		(33,000)
Equity contribution received by noncontrolling interest		355		356
Repayment of long-term debt		(667)		(500)
Issuance of long-term debt		-		30,000
Decrease in short-term debt		-		(3,500)
Other		(9)		(309)
Cash Used for Financing Activities		(7,049)		(13,549)
Change in Cash and Cash Equivalents:		761		13,417
Cash and cash equivalents at beginning of period		13,898		4,494
Cash and cash equivalents at end of period	$	14,659	$	17,911
Supplemental disclosures of cash flow information:
Significant noncash investing activities:
Accrued capital expenditures	$	4,674	$	1,146
The accompanying notes are an integral part of the unaudited consolidated financial statements.

10

Madison Gas and Electric Company

Consolidated Balance Sheets (unaudited)

(In thousands)

		March 31,	December 31,
ASSETS		2012		2011
Current Assets:
Cash and cash equivalents	$	14,659	$	13,898
Receivable - margin account		2,500		2,477
Accounts receivable, less reserves of $3,775 and $3,662, respectively		37,088		35,765
Affiliate receivables		609		605
Other accounts receivable, less reserves of $636 and $439, respectively		4,486		5,301
Unbilled revenues		20,706		25,754
Materials and supplies, at average cost		16,047		14,758
Fossil fuel		8,238		5,468
Stored natural gas, at average cost		10,385		19,575
Prepaid taxes		20,685		21,977
Regulatory assets - current		10,665		7,347
Other current assets		7,080		8,245
Total Current Assets		153,148		161,170
Affiliate receivable long-term		6,751		6,884
Regulatory assets		228,162		205,835
Other deferred assets and other		6,502		7,286
Property, Plant, and Equipment:
Property, plant, and equipment, net		965,565		961,007
Construction work in progress		40,854		34,055
Total Property, Plant, and Equipment		1,006,419		995,062
Investments		58,386		57,556
Total Assets	$	1,459,368	$	1,433,793
LIABILITIES AND CAPITALIZATION
Current Liabilities:
Long-term debt due within one year	$	2,667	$	2,667
Accounts payable		32,000		34,532
Affiliate payables		1,822		2,152
Accrued interest and taxes		4,495		4,037
Accrued payroll related items		7,895		9,987
Deferred income taxes		927		3,020
Derivative liabilities		8,198		4,568
Other current liabilities		5,798		3,997
Total Current Liabilities		63,802		64,960
Other Credits:
Deferred income taxes		207,541		196,550
Investment tax credit - deferred		1,715		1,780
Regulatory liabilities		18,387		20,463
Accrued pension and other postretirement benefits		165,304		183,622
Derivative liabilities		60,880		34,908
Other deferred liabilities and other		44,388		43,330
Total Other Credits		498,215		480,653
Capitalization:
Common shareholder's equity		416,324		412,926
Noncontrolling interest		120,778		114,351
Total Equity		537,102		527,277
Long-term debt		360,249		360,903
Total Capitalization		897,351		888,180
Commitments and contingencies (see Footnote 8)		-		-
Total Liabilities and Capitalization	$	1,459,368	$	1,433,793
The accompanying notes are an integral part of the above unaudited consolidated financial statements.

11

Madison Gas and Electric Company

Consolidated Statements of Common Equity (unaudited)

(In thousands)

								Accumulated
					Additional				Other		Non-
	Common Stock				Paid-in		Retained	Comprehensive			Controlling
	Shares		Value		Capital		Earnings	(Loss)/Income			Interest		Total
2011
Beginning balance - Dec. 31, 2010	17,348	$	17,348	$	192,417	$	192,480	$	71	$	141,993	$	544,309
Net income							11,934				5,933		17,867
Other comprehensive income									35				35
Cash dividends paid to parent
by MGE							(6,596)						(6,596)
Equity contribution received by
noncontrolling interest											356		356
Distributions to parent from
noncontrolling interest											(33,000)		(33,000)
Ending balance - March 31, 2011	17,348	$	17,348	$	192,417	$	197,818	$	106	$	115,282	$	522,971
2012
Beginning balance - Dec. 31, 2011	17,348	$	17,348	$	192,417	$	203,114	$	47	$	114,351	$	527,277
Net income							10,142				6,072		16,214
Other comprehensive loss									(16)				(16)
Cash dividends paid to parent
by MGE							(6,728)						(6,728)
Equity contribution received by
noncontrolling interest											355		355
Ending balance - March 31, 2012	17,348	$	17,348	$	192,417	$	206,528	$	31	$	120,778	$	537,102
The accompanying notes are an integral part of the above unaudited consolidated financial statements.

12

MGE Energy, Inc., and Madison Gas and Electric Company

Notes to Consolidated Financial Statements (unaudited)

March 31, 2012

1.

Basis of Presentation - MGE Energy and MGE.

This report is a combined report of MGE Energy and MGE. References in this report to "MGE Energy" are to MGE Energy, Inc., and its subsidiaries. References in this report to "MGE" are to Madison Gas and Electric Company.

MGE Power Elm Road and MGE Power West Campus own electric generating assets and lease those assets to MGE. Both entities are variable interest entities under applicable authoritative guidance. MGE is considered the primary beneficiary of these entities as a result of contractual agreements. As a result, MGE has consolidated MGE Power Elm Road and MGE Power West Campus.

The accompanying consolidated financial statements as of March 31, 2012, and for the three months ended, are unaudited, but include all adjustments that MGE Energy and MGE management consider necessary for a fair statement of their respective financial statements. All adjustments are of a normal, recurring nature except as otherwise disclosed. The year-end consolidated balance sheet information was derived from the audited balance sheet appearing in MGE Energy's and MGE's 2011 Annual Report on Form 10-K, but does not include all disclosures required by accounting principles in the United States of America. These notes should be read in conjunction with the financial statements and the notes on pages 54 through 107 of the 2011 Annual Report on Form 10-K.

2.

Equity and Financing Arrangements - MGE Energy.

a.

Common Stock.

MGE Energy purchases stock in the open market for issuance pursuant to its Stock Plan. All MGE Energy common stock issued under the Stock Plan is sold pursuant to a registration statement that has been filed with the SEC and is currently effective.

MGE Energy can issue new shares of its common stock through the Stock Plan. For both the three months ended March 31, 2012 and 2011, MGE Energy did not issue any new shares of common stock under the Stock Plan.

b.

Dilutive Shares Calculation.

MGE Energy does not hold any dilutive securities.

3.

Investment in ATC - MGE Energy and MGE.

ATC owns and operates electric transmission facilities primarily in Wisconsin. MGE received an interest in ATC when it, like other Wisconsin electric utilities, contributed its electric transmission facilities to ATC. That interest is presently held by MGE Transco, which is jointly owned by MGE Energy and MGE.

MGE Transco has accounted for its investment in ATC under the equity method of accounting. For the three months ended March 31, 2012 and 2011, MGE Transco recorded equity earnings from the investment in ATC of $2.2 million and $2.1 million, respectively. Dividend income received from ATC was $1.7 million for both the three months ended March 31, 2012 and 2011. In addition, during both the three months ended March 31, 2012 and 2011, MGE Transco made $0.4 million in capital contributions to ATC.

MGE Energy and MGE's investment in ATC as of March 31, 2012, and December 31, 2011, was $57.8 million and $57.0 million, respectively.

At March 31, 2012, MGE is the majority owner, and MGE Energy, the holding company, is the minority owner of MGE Transco. MGE Energy's proportionate share of the equity and net income of MGE Transco is classified within the MGE financial statements as noncontrolling interest.

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ATC's summarized financial data for the three months ended March 31, 2012 and 2011, is as follows:

		Three Months Ended
(In thousands)		March 31,
		2012		2011
Operating revenues	$	147,662	$	139,617
Operating expenses		(69,566)		(63,126)
Other expense, net		(500)		(358)
Interest expense, net		(19,501)		(21,897)
Earnings before members' income taxes	$	58,095	$	54,236

4.

Columbia Environmental Project Construction - MGE Energy and MGE.

MGE and two other utilities jointly own Columbia, a coal-fired generating facility. WPL is the plant operator and permit holder, and owns 46.2% of Columbia. WPSC owns a 31.8% interest, and MGE owns a 22% interest in Columbia. In early 2011, the PSCW issued a Certificate and Order authorizing the construction of scrubbers and bag houses and associated equipment on Columbia Units 1 and 2 to reduce SO₂ and mercury emissions. The scrubbers and bag houses are expected to support compliance obligations for current and anticipated air quality regulations, including CAIR or CSAPR, the Utility MACT Rule and the Wisconsin Mercury Rule. The operator's current estimate shows that MGE's share of the capital expenditures required for this project will be approximately $140 million. MGE expects to incur capital expenditures as follows: $43 million for the remainder of 2012, $68 million in 2013, and $14 million in 2014. These amounts may change as a result of modifications to the project estimate or timing difference.

As of March 31, 2012, MGE had incurred $10.5 million (excluding carrying costs) in construction expenditures at Columbia related to its share of the project and had accrued $4.0 million in incurred but unpaid capital expenditures. At March 31, 2012, $14.5 million (excluding carrying costs) related to this project is reflected in the Construction Work in Progress balance on MGE and MGE Energy's consolidated balance sheets.

MGE expects that the costs pertaining to this project will be fully recoverable through rates. Additionally, MGE is entitled to a carrying cost on the related construction costs at 100% of the determined AFUDC rate.

5.

Taxes - MGE Energy and MGE.

a.

Accounting for Uncertainty in Income Taxes.

MGE Energy and MGE account for the difference between the tax benefit amount taken on prior year tax returns, or expected to be taken on a current year tax return, and the tax benefit amount recognized in the financial statements as an unrecognized tax benefit.

MGE Energy has adopted a tax method of accounting to accelerate tax deductions for repairs in accordance with Treasury Regulations and case law, as compared to the prior method of claiming tax depreciation on project costs. The method change for electric generation and transmission and distribution repairs was included on the 2009 tax return while the change for gas distribution repairs was included on the 2010 return. During 2011, the IRS issued guidance on the treatment of electric transmission and distribution repairs. This guidance prompted the reversal of a portion of the unrecognized tax benefits for these repairs during 2011. MGE Energy and MGE have an unrecognized tax benefit at March 31, 2012, and December 31, 2011, in the amount of $2.7 million and $2.4 million, respectively, for the tax uncertainty primarily related to the change in tax method of accounting for electric generation and gas distribution repairs.

b.

Effective Tax Rate.

MGE Energy's and MGE's effective income tax rate for the three months ended March 31, 2012, is 38.1%, compared to 37.5% for the same period in 2011. The higher effective tax rate is, in part, attributable to a lower estimated domestic manufacturing deduction.

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6.

Pension and Other Postretirement Plans - MGE Energy and MGE.

MGE maintains qualified and nonqualified pension plans, health care, and life insurance benefits. Additionally, MGE has defined contribution 401(k) benefit plans.

The following table presents the components of MGE Energy's and MGE's net periodic benefit costs recognized for the three months ended March 31, 2012 and 2011. A portion of the net periodic benefit cost is capitalized within the consolidated balance sheets. The PSCW allowed MGE to defer the 2009 incremental pension and OPRB costs above the amounts recovered in rates. During the three months ended March 31, 2012 and 2011, $0.3 million and $0.7 million, respectively, has been recovered in rates.

		Three Months Ended
(In thousands)		March 31,
		2012		2011
Pension Benefits
Components of net periodic benefit cost:
Service cost	$	1,823	$	1,540
Interest cost		3,154		3,080
Expected return on assets		(3,818)		(3,531)
Amortization of:
Prior service cost		108		109
Actuarial loss		2,006		946
Net periodic benefit cost	$	3,273	$	2,144
Postretirement Benefits
Components of net periodic benefit cost:
Service cost	$	647	$	487
Interest cost		1,125		982
Expected return on assets		(435)		(396)
Amortization of:
Transition obligation		106		107
Prior service cost		28		27
Actuarial loss		621		111
Net periodic benefit cost	$	2,092	$	1,318

7.

Share-Based Compensation - MGE Energy and MGE.

Under MGE Energy's Performance Unit Plan, eligible participants may receive performance units that entitle the holder to receive a cash payment equal to the value of a designated number of shares of MGE Energy's common stock, plus dividend equivalent payments thereon, at the end of the set performance period.

In addition to units granted in 2008 through 2011, on February 17, 2012, 16,693 units were granted based on the MGE Energy closing stock price as of that date. These units are subject to a five-year graded vesting schedule. On the grant date, MGE Energy and MGE measure the cost of the employee services received in exchange for the award based on the current market value of MGE Energy common stock. The fair value of the awards has been subsequently re-measured at March 31, 2012, as required by applicable accounting standards. Changes in fair value have been recognized as compensation cost. Since this amount is re-measured quarterly throughout the vesting period, the compensation cost is subject to variability.

For nonretirement eligible employees, stock based compensation costs are accrued and recognized using the graded vesting method. Compensation cost for retirement eligible employees or employees that will become retirement eligible during the vesting schedule are recognized on an abridged horizon.

In April 2011, the MGE Energy Board approved an amendment to the outstanding awards under the Performance Unit Plan to provide for the continued vesting of those awards in the event of a bona fide retirement, provided the retired individual does not provide services to a competitor. The amendment did not change the number of performance units covered by any outstanding awards currently held by any of the participants.

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During the three months ended March 31, 2012 and 2011, MGE recorded $0.4 million and $0.1 million, respectively, in compensation expense as a result of the Performance Unit Plan. In January 2012, cash payments of $0.6 million were distributed relating to awards that were granted in 2007 and became payable under the Performance Unit Plan. No forfeitures occurred during the three months ended March 31, 2012 or 2011. At March 31, 2012, $2.6 million of outstanding awards are vested.

8.

Commitments and Contingencies.

a.

Environmental - MGE Energy and MGE.

Water quality

Water quality regulations promulgated by the EPA and WDNR in accordance with the Federal Water Pollution Control Act, or more commonly known as the Clean Water Act (CWA), impose restrictions on emissions of various pollutants into surface waters. The CWA also regulates surface water quality issues that affect aquatic life, such as water temperatures, intake structures, and wetlands filling. The CWA regulates discharges from "point sources" such as power plants by establishing discharge limits in water discharge permits. MGE's power plants operate under Wisconsin Pollution Discharge Elimination System (WPDES) permits to ensure compliance with these discharge limits.

EPA Cooling Water Intake Rules (Section 316(b))

In April 2011, the EPA proposed and asked for public comment on standards to reduce entrainment (drawing aquatic life into a plant's cooling system) and impingement (trapping aquatic life on screens) from existing structures designed to take in cooling water for plants such as power plants. This rule is commonly referred to as Phase II of Section 316(b) of the CWA. Both our Blount and Columbia generating plants are subject to the impingement and entrainment aspects of the current proposed rule. Our WCCF plant is subject to the impingement aspect only. Under the current proposed rule, equipment would need to be installed at Blount, WCCF and Columbia to meet these new standards. It is not presently possible to estimate the potential costs associated with the implementation of any of these initiatives because the rule has not been finalized.

WPDES Thermal Discharge Rule

WDNR rules to regulate thermal effluent discharges from point sources in Wisconsin became effective on October 1, 2010. We will need to meet the revised rule requirement as MGE's WPDES permits are issued or renewed. If we are unable to demonstrate that any of MGE's permitted plants (Blount, WCCF, Columbia, Elm Road) are able to comply with its associated WPDES permit requirements, then we may need operational controls and/or incur capital costs associated with plant modifications to meet discharge requirements. Those expenditures could be material.

WPDES Phosphorus Nutrient Standards

In December 2010, the WDNR established water quality standards for phosphorus and effluent limitations for permitted discharges into specific waterbodies. Phosphorus limitations will be added to water effluent discharge permits as they are issued or renewed. The WDNR will be developing site-specific phosphorus limits. MGE's facilities subject to these standards include Blount, Columbia, Elm Road and WCCF. MGE may incur additional capital or operational expenditures and/or need to install additional pollution controls to meet the new phosphorus limits. MGE has, however, identified potential compliance options and believes compliance can be managed without significant capital investments.

Air quality

Air quality regulations promulgated by the EPA and the WDNR in accordance with the Federal Clean Air Act and the Clean Air Act Amendments of 1990 impose restrictions on emission of particulates, sulfur dioxide (SO₂), nitrogen oxides (NO_x), and other pollutants and require permits for operation of emission sources. These permits have been obtained by MGE and must be renewed periodically.

Various initiatives, including the EPA's recently finalized Cross-State Air Pollution Rule (CSAPR), maximum achievable control technology (MACT) standards, new source performance standards (NSPS) and the Clean Air Visibility Rule (also known as the Regional Haze Rule), as well as state mercury emissions limits, are expected to result in additional operating and capital expenditure costs for electric generating units.

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Maximum Achievable Control Technology (MACT) for Utility Boilers (Also Referred to as the Mercury and Air Toxics Standards or MATS)

In December 2011, the EPA finalized its Mercury and Air Toxics Standards for coal and oil-burning electric generating unit (EGU) boilers. MATS will require emissions standards for mercury, non-mercury HAPs metals, and acid gases. MGE's Columbia and Elm Road Units are subject to MATS. The Elm Road Unit's current pollution controls and Columbia's planned mercury pollution controls will allow both facilities to comply with the MATS rule (see the discussion regarding Columbia below).

Reciprocating Internal Combustion Engine (RICE) MACT

In December 2011, the EPA finalized its RICE MACT standard. RICE MACT applies to combustion turbines that contain a reciprocating internal combustion engine. Under the current RICE MACT, MGE may have to adjust its dispatching of several small generation units used for emergency and backup generation or install pollution controls. In January 2012, the EPA published in the Federal Register an intention to propose a revised RICE MACT based on a settlement agreement with several power companies. MGE will review the revised proposal when it is finalized and continue to evaluate the impacts associated with complying with RICE MACT.

Stay of EPA's Cross State Air Pollution Rule (CSAPR) and Reinstatement of the Clean Air Interstate Rule (CAIR)

The CAIR, which became effective in 2009, generally requires NO_x and SO₂ emission reductions from fossil fuel-fired electric generating units (25 MW or greater) (EGUs) in the eastern half of the United States in two phases and includes a regional cap-and-trade system. The first phase (currently in place) requires annual regional emission reductions from 2003 levels of 55% for NO_x and 40% for SO₂. The second phase (beginning in 2015) reduces regional NO_x and SO₂ emissions further from 2003 levels to 65% and 70%, respectively. MGE owns or has partial ownership in several generation units currently subject to the CAIR: Blount, Columbia, Elm Road, and its combustion turbines located in West Marinette and Fitchburg.

In December 2008, the U.S. Court of Appeals for the D.C. Circuit remanded the CAIR to the EPA for further review. In August 2011, the EPA published the Cross-State Air Pollution Rule (CSAPR) to replace the CAIR. Similar to the CAIR, CSAPR requires NO_x and/or SO₂ air emissions reductions by fossil fuel-fired EGUs (25 MW or greater) in 28 states in the eastern half of the U.S. CSAPR established state emission restrictions, referred to as budgets, for SO₂ and NO_x beginning in 2012 (Phase I). Under CSAPR, SO₂ emission budgets in certain states, including Wisconsin, will be lowered further in 2014 (Phase II). CSAPR affects the same electric generation units at MGE as CAIR: Blount, Columbia, Elm Road, and the combustion turbines at West Marinette and Fitchburg. Plants in Wisconsin that are subject to CSAPR have been allocated CSAPR emission allowances and will need to hold sufficient allowances to cover emissions on an annual basis. If CSAPR allowances are not adequate for a given plant, emissions will need to be reduced at the plant level by fuel-switching, installation of controls, curtailment of operations or a combination thereof. MGE's Columbia plant, which is operated by WPL (MGE has a 22% ownership interest), has significantly fewer SO₂ allocations under CSAPR in 2012 and 2013 than recent actual emissions.

In December 2011, the U.S. Court of Appeals for the D.C. Circuit stayed the implementation of CSAPR pending judicial review. The ruling leaves the CAIR in place while the court considers the merits and challenges to CSAPR. MGE expects to hold sufficient emissions allowances under the CAIR for 2012.

If CSAPR is reinstated in 2012 or 2013, the Columbia co-owners will need to evaluate and implement interim strategies to address anticipated SO₂ allowance deficiencies under CSAPR. Current analysis shows that, if reinstated in 2013, additional allowances (if available) may need to be purchased, Columbia generation may need to be reduced to comply with CSAPR limits, or a combination of these two strategies may be employed. These interim measures may increase MGE's costs. MGE expects that the costs pertaining to meeting CSAPR requirements will be fully recoverable through rates. Planned new SO₂ controls at Columbia are expected to be completed by mid 2014 (see the discussion regarding the Columbia Environmental Project below). Once the new environmental control project is completed at Columbia, it is expected that the plant will emit below anticipated CSAPR allocation levels.

Clean Air Visibility Rule (CAVR)

Air modeling indicates that SO₂ and NO_x emissions (and to a lesser extent particulate matter, or PM) from Columbia may impair visibility at certain Class I Scenic Areas and may therefore be subject to the best available retrofit technology (BART) regulations, a subsection of the EPA's Clean Air Visibility Rule (CAVR), which requires pollution retrofits. The EPA has proposed that compliance with CAIR and with CSAPR emissions limitations could also serve as compliance with BART for SO₂ and NO_x emissions.

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However, with the uncertainty regarding the future of CAIR and CSAPR, the future of BART regulation and compliance strategies and costs are also uncertain.

Wisconsin State Mercury Rule

Beginning January 1, 2015, phase two of the Wisconsin mercury rule will require large coal-fired electric generating units (larger than 150 MW) to reduce mercury emissions by 90%, or choose a multi-pollutant reduction approach, which allows a stepped approach to mercury reduction while reducing NO_x and SO₂ emissions at prescribed rates. Elm Road currently meets this requirement. The Columbia co-owners plan to meet the 90% reduction option by installing pollution controls needed to meet this and other rules (see the discussion regarding the Columbia Environmental Project below).

National Ambient Air Quality Standards (NAAQS)

The EPA has developed National Ambient Air Quality Standards (NAAQS) for six compounds currently identified as criteria pollutants: nitrogen dioxide (NO₂), particulate matter (PM), ozone, SO₂, lead and carbon monoxide. The NAAQS for criteria pollutants establish acceptable ambient air levels based on effects to human health and the environment, and changes to those NAAQS can affect compliance requirements and associated capital and operating costs. The EPA is required to review NAAQS every five years. MGE is currently tracking two NAAQS developments: (1) EPA's five-year review of PM NAAQS that are scheduled to be released by June 2012, and (2) the WDNR' attainment/nonattainment designations associated with the EPA's June 2010 final revisions to its SO₂ NAAQS. These two NAAQS developments could have a potential material effect on capital and maintenance costs at our generating facilities. The magnitude will not be known until the rules are implemented.

EPA's Prevention of Significant Deterioration and Title V Greenhouse Gas Tailoring Rule

The EPA's Greenhouse Gas "Tailoring Rule" regulates stationary sources for GHG emissions by "phasing in" over time different types of facilities subject to Prevention of Significant Deterioration (PSD) pre-construction program or Title V permitting (i.e. new facilities and existing facilities with certain qualifying modifications). MGE facilities may become subject to this rule if modifications at any facilities trigger PSD or if MGE invests in new facilities that trigger PSD.

GHG New Source Performance Standards for Electric Generating Units (EGU GHG NSPS)

On March 27, 2012, the EPA proposed greenhouse gas (GHG) New Source Performance Standards (NSPS) for coal fired and natural gas combined cycle (NGCC) electric generation units (EGUs). The proposal applies to new EGUs only; the EPA has stated that it does not intend for these rules to apply to modified or existing units at this time. The proposed NSPS may be finalized within 2012 and is not anticipated to significantly affect MGE's existing generation units.

Columbia

MGE and two other utilities jointly own Columbia, a coal-fired generating facility, which accounts for 225 MW (29%) of MGE's net summer generating capability. WPL is the plant operator and permit holder, and owns 46.2% of Columbia. Wisconsin Public Service Corporation (WPSC) owns a 31.8% interest, and MGE owns a 22% interest in Columbia. Based upon current available information, compliance with various environmental requirements and initiatives is expected to result in significant additional operating and capital expenditures at Columbia.

Columbia Environmental Project

In early 2011, the PSCW issued a Certificate and Order authorizing the construction of scrubbers and bag houses and associated equipment on Columbia Units 1 and 2 to reduce SO₂ and mercury emissions. The scrubbers and bag houses are expected to support compliance obligations for current and anticipated air quality regulations, including CAIR or CSAPR, the Utility MACT Rule and the Wisconsin Mercury Rule. The operator's current estimate shows that MGE's share of the capital expenditures required for this project will be approximately $140 million.

As of March 31, 2012, Columbia has entered into various contractual commitments with vendors for a portion of the $140 million project. MGE is indirectly a party to these agreements as a result of its joint ownership of Columbia and is also contractually obligated, under the applicable ownership and operating agreements. MGE's share of these commitments is $109.7 million. These costs are expected to be capitalized and included in the consolidated balance sheets of MGE Energy and MGE. See Footnote 4 for further information regarding the Columbia Environmental construction project.

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Title V Operating Permit Petition

In September 2008, the WDNR issued a Title V renewal operating permit to WPL for Columbia. A citizen group petitioned the EPA to object to the issuance of the permit renewal. In October 2009, the EPA issued an order granting in part and denying in part the petition and sent the operating permit back to the WDNR for further review based on the EPA order. The WDNR took various preliminary actions and in February 2011, issued a letter stating its determination not to issue either the proposed construction permit or a revised operating permit for Columbia. In February 2011, the citizen group involved filed an action against the EPA in the U.S. District Court for the Western District of Wisconsin seeking to have the EPA take over the permit process. In May 2011, the WDNR proposed a revised operating permit for Columbia. The Columbia owners commented on the WDNR's draft permit and are awaiting the WDNR's response. MGE believes the permits currently in effect for Columbia remain in place at this time. MGE continues to follow these developments and is unable to predict the outcome of this matter and its impact on its financial or operational conditions.

Columbia Clean Air Act Litigation

In December 2009, the EPA sent a Notice of Violation (NOV) to MGE as one of the co-owners of Columbia. The NOV alleges that WPL, as operator, and the Columbia co-owners failed to comply with appropriate pre-construction review and permitting requirements and as a result violated the PSD program requirements, Title V Operating Permit requirements of the CAA and the Wisconsin SIP. The parties are exploring possible settlement.

In September 2010, Sierra Club filed a civil lawsuit against WPL alleging violations of the CAA at Columbia and other Wisconsin facilities operated by WPL. The Sierra Club and the co-owners are engaged in settlement discussions. The parties recently requested and received a temporary stay of proceedings to further explore settlement options. The trial date is scheduled for December 2012. During the February 15, 2012 status conference, the Court reaffirmed the December 2012 trial date, but set a pre-trial schedule that allows the parties to continue work toward settlement.

MGE and the other co-owners of Columbia are defending against these allegations while actively pursuing settlement options with the EPA and Sierra Club. WPL has informed MGE that WPL believes the projects at Columbia were routine or not projected to increase emissions and therefore did not violate the permitting requirements of the CAA.

In response to similar EPA CAA enforcement initiatives, certain utilities have elected to settle with the EPA, while others have elected to litigate. If the EPA and/or Sierra Club successfully prove their claims that projects completed in the past at Columbia required either state or federal CAA permits, MGE may, under the applicable statutes, be required to pay civil penalties in amounts of up to $37,500 per day for each violation and/or complete actions for injunctive relief. Payment of fines and/or injunctive relief could be included in a settlement outcome. Injunctive relief contained in settlements or court-ordered remedies for other utilities in similar matters required the installation of pollution control technology, changed operating conditions (including use of alternative fuels other than coal), surrender of excess emission trading allowances, caps for emissions and limitations on generation (including retirement of generating units) and other beneficial environmental projects. If similar remedies are required for final resolution of these matters at Columbia, MGE would likely incur additional capital and operating expenditures. At this time, MGE is unable to predict with certainty the impact of these claims on its financial condition or results of operations but believes that should there ultimately be an adverse outcome, it could have a significant effect.

b.

Chattel Paper Agreement and Other Guarantees - MGE Energy and MGE.

MGE makes available to qualifying customers a financing program for the purchase and installation of energy-related equipment that will provide more efficient use of utility service at the customer's property. MGE is party to a chattel paper purchase agreement with a financial institution under which it can sell or finance an undivided interest with recourse, in up to $10.0 million of the financing program receivables, until July 31, 2012. At March 31, 2012, MGE has outstanding a $4.2 million interest in these receivables. MGE retains the servicing responsibility for these receivables. As of March 31, 2012, the servicing asset recognized by MGE is $0.2 million.

MGE accounts for servicing rights under the amortization method. Initial determination of the servicing asset fair value is based on the present value of the estimated future cash flows. The discount rate is based on the PSCW authorized weighted cost of capital.

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MGE would be required to perform under its guarantee if a customer defaulted on its loan. The energy-related equipment installed at the customer sites is used to secure the customer loans. The loan balances outstanding at March 31, 2012, approximate the fair value of the energy-related equipment acting as collateral. The length of the MGE guarantee to the financial institution varies from one to ten years de pending on the term of the underlying customer loan. Principal payments for the remainder of 2012 and the next four years on the loans are:

(In thousands)		2012		2013		2014		2015		2016
Chattel Paper	$	422	$	646	$	461	$	772	$	695

c.

Other Legal Matters - MGE Energy and MGE.

MGE is involved in various other legal matters that are being defended and handled in the normal course of business. MGE maintains accruals for such costs that are probable of being incurred and subject to reasonable estimation. MGE has accrued for such matters in the financial statements. The ultimate outcomes of such matters are uncertain and may have an adverse effect on MGE Energy's and MGE's results of operations, financial position, or cash flows.

d.

Smart Grid Investment Grant - MGE Energy and MGE.

MGE was approved in 2010 by the U.S. Department of Energy (DOE) under the federal stimulus program for a $5.5 million grant for smart grid projects. The DOE grant requires MGE to match the grant funding, bringing the total cost of the projects to more than $11 million. The projects involve the installation of technologies to boost efficiency, enhance service and improve reliability for customers. The stimulus grant is being used to fund the following projects: advanced metering infrastructure, plug-in hybrid electric vehicles support, and distribution management. As of March 31, 2012, MGE has spent $6.8 million related to these projects and has outstanding agreements to purchase $0.8 million in smart grid related products for the remainder of 2012.

e.

Other Commitments - MGE Energy.

On January 31, 2012, MGE Energy entered a subscription agreement to invest in a nonpublic venture capital fund. From time to time, this entity will require capital infusions from its investors. MGE Energy has committed to contribute $2.0 million in capital for such infusions. The timing of these infusions is dependent on the needs of the investee and is therefore uncertain at this time.

9.

Derivative and Hedging Instruments - MGE Energy and MGE.

a.

Purpose.

As part of its regular operations, MGE enters into contracts, including options, swaps, futures, forwards, and other contractual commitments, to manage its exposure to commodity prices and gas revenues. To the extent that these contracts are derivatives, MGE assesses whether or not the normal purchases or normal sales exclusion applies. For contracts to which this exclusion cannot be applied, MGE Energy and MGE recognize such derivatives in the consolidated balance sheets at fair value. The majority of MGE's derivative activities are conducted in accordance with its electric and gas risk management program, which is approved by the PSCW and limits the volume MGE can hedge with specific risk management strategies. The maximum length of time over which cash flows related to energy commodities can be hedged is four years. If the derivative qualifies for regulatory deferral, the derivatives are marked to fair value and are offset with a corresponding regulatory asset or liability. The deferred gain or loss is recognized in earnings in the delivery month applicable to the instrument. Gains and losses related to hedges qualifying for regulatory treatment are recoverable in gas rates through the PGA or in electric rates as a component of the fuel rules mechanism.

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b.

Notional Amounts.

The gross notional volume of open derivatives is as follows:

	March 31, 2012	December 31, 2011
Commodity derivative contracts	451,750  MWh	482,545  MWh
Commodity derivative contracts	2,970,000  Dth	4,030,000  Dth
FTRs	962  MW	2,382  MW

c.

Financial Statement Presentation.

MGE Energy and MGE offset fair value amounts recognized for the right to reclaim collateral (a receivable) or the obligation to return collateral (a payable) against fair value amounts recognized for derivative instruments executed with the same counterparty under a master netting agreement. At March 31, 2012, and December 31, 2011, MGE Energy and MGE had $2.0 million and $3.0 million, respectively, in collateral that was netted against the net derivative positions with counterparties.

MGE purchases and sells exchange-traded and over-the-counter options, swaps, and future contracts. These arrangements are primarily entered into to help stabilize the price risk associated with gas or power purchases. These transactions are employed by both MGE's gas and electric segments. Additionally, as a result of the firm transmission agreements that MGE holds on transmission paths in the MISO and PJM markets, MGE holds FTRs. An FTR is a financial instrument that entitles the holder to a stream of revenues or charges based on the differences in hourly day-ahead energy prices between two points on the transmission grid. The fair values of these instruments are reflected as a regulatory asset/liability depending on whether they are in a net loss/gain position. Depending on the nature of the instrument, the gain or loss associated with these transactions will be reflected as cost of gas sold, fuel for electric generation, or purchased power expense in the delivery month applicable to the instrument. At March 31, 2012, and December 31, 2011, the cost basis of exchange traded derivatives and FTRs exceeded their fair value by $2.5 million and $2.8 million, respectively.

MGE has also entered into a ten-year purchased power agreement that provides MGE with firm capacity and energy during a base term from June 1, 2012, through May 31, 2022. The agreement also allows MGE an option to extend the contract after the base term. The agreement is accounted for as a derivative contract and is recognized at its fair value on the balance sheet. However, the derivative qualifies for regulatory deferral and is recognized with a corresponding regulatory asset or liability depending on whether the fair value is in a loss or gain position. The fair value of the contract at March 31, 2012, and December 31, 2011, reflects a loss position of $69.0 million and $39.5 million, respectively. The actual fuel cost will be recognized in purchased power expense in the month of purchase.

The following table summarizes the fair value of the derivative instruments on the balance sheet. All derivative instruments in this table are presented on a gross basis and are calculated prior to the netting of instruments with the same counterparty under a master netting agreement as well as the netting of collateral. For financial statement purposes, MGE Energy and MGE have netted instruments with the same counterparty under a master netting agreement as well as the netting of collateral.

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	Asset Derivatives			Liability Derivatives
(In thousands)	Balance Sheet Location		Fair Value	Balance Sheet Location		Fair Value
March 31, 2012
Commodity derivative contracts	Other current assets	$	266	Derivative liability (current)	$	2,723
Commodity derivative contracts	Other deferred charges		153	Derivative liability (long-term)		160
FTRs	Other current assets		-	Derivative liability (current)		40
Ten-year PPA	N/A		N/A	Derivative liability (current)		8,130
Ten-year PPA	N/A		N/A	Derivative liability (long-term)		60,880
December 31, 2011
Commodity derivative contracts	Other current assets	$	177	Derivative liability (current)	$	3,060
Commodity derivative contracts	Other deferred charges		92	Derivative liability (long-term)		231
FTRs	Other current assets		186	Derivative liability (current)		-
Ten-year PPA	N/A		N/A	Derivative liability (current)		4,600
Ten-year PPA	N/A		N/A	Derivative liability (long-term)		34,920

The following tables summarize the unrealized and realized gains (losses) related to the derivative instruments on the balance sheet at March 31, 2012 and 2011, and the income statement for the three months ended March 31, 2012 and 2011 (a).

		2012				2011
(In thousands)		Current and long-term regulatory asset		Other current assets		Current and long-term regulatory asset		Other current assets
Three Months Ended March 31:
Balance at January 1,	$	42,356	$	1,604	$	19,230	$	1,411
Change in unrealized loss		33,310		-		3,047		-
Realized loss reclassified to a deferred account		(2,658)		2,658		(663)		663
Realized gain (loss) reclassified to income
statement		(1,494)		(3,590)		63		(1,569)
Balance at March 31,	$	71,514	$	672	$	21,677	$	505

		Realized losses (gains)
				Fuel for electric
		Regulated		generation/		Cost of
(In thousands)		gas revenues		purchased power		gas sold
Three Months Ended March 31, 2012:
Commodity derivative contracts	$	-	$	1,928	$	3,090
FTRs		-		66		-
Ten-year PPA		-		-		-
Three Months Ended March 31, 2011:
Commodity derivative contracts	$	-	$	254	$	1,315
FTRs		-		(63)		-
Ten-year PPA		-		-		-

(a)

MGE's commodity derivative contracts, FTRs, and ten-year PPA are subject to regulatory deferral. These derivatives are marked to fair value and are offset with a corresponding regulatory asset or liability. Realized gains and losses are deferred on the balance sheet and are recognized in earnings in the delivery month applicable to the instrument. As a result of the above described treatment, there are no unrealized gains or losses that flow through earnings.

22

The ten-year PPA has a provision that may require MGE to post collateral if MGE's debt rating falls below investment grade (i.e., below BBB-) once MGE begins purchasing energy under the contract in 2012. The amount of collateral that it may be required to post varies from $20.0 million to $40.0 million, depending on MGE's nominated capacity amount. Certain counterparties extend MGE a credit limit. If MGE exceeds these limits, the counterparties may require collateral to be posted. As of March 31, 2012, certain counterparties were in a net liability position of $0.4 million. As of December 31, 2011, no counterparties were in a net liability position.

Nonperformance of counterparties to the non-exchange traded derivatives could expose MGE to credit loss. However, MGE enters into transactions only with companies that meet or exceed strict credit guidelines, and it monitors these counterparties on an ongoing basis to mitigate nonperformance risk in its portfolio. As of March 31, 2012, no counterparties have defaulted.

10.

Rate Matters - MGE Energy and MGE.

a.

Rate Proceedings.

On March 23, 2012, MGE filed an application with the PSCW requesting a 5.8% increase to electric rates and a 2.6% increase to gas rates. The proposed electric increase will cover costs for new environmental equipment at Columbia, final construction costs for the Elm Road Units, transmission reliability enhancements, and purchased power costs. MGE has requested that these rates become effective January 1, 2013.

On December 15, 2011, under a limited reopener of MGE's last rate order, the PSCW authorized MGE to increase 2012 rates for retail electric customers by 4.3% or $15.7 million and to increase gas rates by 0.3% or $0.6 million. The change in retail electric rates was driven by MGE's electric fuel and purchased power costs, increased transmission costs, an update to the Elm Road Units' costs, and an increase for energy efficiency programs. The PSCW also approved deferral of CSAPR costs.

On January 12, 2011, the PSCW authorized MGE to increase 2011 rates for retail electric customers by 2.3% or $8.0 million and to increase gas rates by 1.0% or $1.9 million. The increase in retail electric rates is driven by costs for MGE's share of the Elm Road Units. Pursuant to the provisions of this rate order, the fuel rules bandwidth effective January 1, 2011, will be plus or minus 2%. See below for further description of fuel rules. Authorized return on common stock equity was set at 10.3% based on a 58.1% utility common equity.

b.

Fuel Rules.

The PSCW approved new fuel rules that became effective January 1, 2011. The new rules require the PSCW and Wisconsin utilities to automatically defer electric fuel-related costs that fall outside a symmetrical cost tolerance band. Any over/under recovery of the deferred costs is determined on an annual basis and will be adjusted in future billings to electric retail customers. Under fuel rules, MGE would defer costs, less any excess revenues, if its actual electric fuel costs exceeded 102% of the electric fuel costs allowed in its latest rate order. Excess revenues are defined as revenues in the year in question that provide MGE with a greater return on common equity than authorized by the PSCW in MGE's latest rate order. Conversely, MGE is required to defer the benefit of lower costs if actual electric fuel costs were less than 98% of the electric fuel costs allowed in that order. As of March 31, 2012, MGE did not defer any electric fuel-related costs.

c.

Purchased Gas Adjustment Clause.

MGE's natural gas rates are subject to a fuel adjustment clause designed to recover or refund the difference between the actual cost of purchased gas and the amount included in rates. Differences between the amounts billed to customers and the actual costs recoverable are deferred and recovered or refunded in future periods by means of prospective monthly adjustments to rates. At March 31, 2012, and December 31, 2011, MGE had over collected $3.3 million and $0.9 million, respectively. These amounts were recorded in other current liabilities on the consolidated balance sheet.

23

11.

Fair Value of Financial Instruments - MGE Energy and MGE.

a.

Fair Value of Financial Assets and Liabilities Recorded at the Carrying Amount.

At March 31, 2012, and December 31, 2011, the carrying amount of cash, cash equivalents, and outstanding commercial paper approximates fair market value due to the short maturity of those investments and obligations. The estimated fair market value of MGE Energy's and MGE's long-term debt is based on quoted market prices for similar financial instruments at March 31, 2012, and December 31, 2011. The estimated fair market value of MGE Energy's and MGE's financial instruments are as follows:

		March 31, 2012				December 31, 2011
		Carrying		Fair		Carrying		Fair
(In thousands)		Amount		Value		Amount		Value
MGE Energy
Assets:
Cash and cash equivalents	$	40,660	$	40,660	$	41,169	$	41,169
Liabilities:
Long-term debt*		363,806		424,359		364,473		432,515
MGE
Assets:
Cash and cash equivalents		14,659		14,659		13,898		13,898
Liabilities:
Long-term debt*		363,806		424,359		364,473		432,515
*Includes long-term debt due within one year.

b.

Recurring Fair Value Measurements.

Fair value is defined as the price that would be received to sell an asset or would be paid to transfer a liability (an exit price) in the principal or most advantageous market for the asset or liability in an orderly transaction between market participants at the measurement date. The standard clarifies that fair value should be based on the assumptions market participants would use when pricing the asset or liability including assumptions about risk. The standard also establishes a three level fair value hierarchy based upon the observability of the assumptions used and requires the use of observable market data when available. The levels are:

Level 1 - Pricing inputs are quoted prices within active markets for identical assets or liabilities.

Level 2 - Pricing inputs are quoted prices within active markets for similar assets or liabilities; quoted prices for identical or similar instruments in markets that are not active; and model-derived valuations that are correlated with or otherwise verifiable by observable market data.

Level 3 - Pricing inputs are unobservable and reflect management's best estimate of what market participants would use in pricing the asset or liability.

24

The following table presents the balances of assets and liabilities measured at fair value on a recurring basis for MGE Energy and MGE.

	Fair Value as of March 31, 2012
(In thousands)		Total		Level 1		Level 2		Level 3
MGE Energy
Assets:
Exchange-traded investments	$	361	$	361	$	-	$	-
Total Assets	$	361	$	361	$	-	$	-
Liabilities:
Derivatives, net(a)	$	71,514	$	326	$	-	$	71,188
Deferred compensation		1,771		-		1,771		-
Total Liabilities	$	73,285	$	326	$	1,771	$	71,188
MGE
Assets:
Exchange-traded investments	$	162	$	162	$	-	$	-
Total Assets	$	162	$	162	$	-	$	-
Liabilities:
Derivatives, net(a)	$	71,514	$	326	$	-	$	71,188
Deferred compensation		1,771		-		1,771		-
Total Liabilities	$	73,285	$	326	$	1,771	$	71,188
(a)   These amounts are shown gross and exclude $2.0 million of collateral that was posted
against derivative positions with counterparties.
No transfers were made in or out of Level 1 or Level 2 for the three months ended March 31, 2012.
	Fair Value as of December 31, 2011
(In thousands)		Total		Level 1		Level 2		Level 3
MGE Energy
Assets:
Exchange-traded investments	$	350	$	350	$	-	$	-
Total Assets	$	350	$	350	$	-	$	-
Liabilities:
Derivatives, net(b)	$	42,356	$	1,695	$	-	$	40,661
Deferred compensation(c)		1,725		-		1,725		-
Total Liabilities	$	44,081	$	1,695	$	1,725	$	40,661
MGE
Assets:
Exchange-traded investments	$	188	$	188	$	-	$	-
Total Assets	$	188	$	188	$	-	$	-
Liabilities:
Derivatives, net(b)	$	42,356	$	1,695	$	-	$	40,661
Deferred compensation(c)		1,725		-		1,725		-
Total Liabilities	$	44,081	$	1,695	$	1,725	$	40,661
(b)   These amounts are shown gross and exclude $3.0 million of collateral that was posted
against derivative positions with counterparties.
(c)   The deferred compensation liability at December 31, 2011, was transferred from Level 1
to Level 2.

Investments include exchange-traded investment securities valued using quoted prices on active exchanges and are therefore classified as Level 1.

25

Derivatives include exchange-traded derivative contracts, over-the-counter party transactions, a ten-year purchased power agreement, and FTRs. Most exchange-traded derivative contracts are valued based on unadjusted quoted prices in active markets and are therefore classified as Level 1. A small number of exchange-traded derivative contracts are valued using quoted market pricing in markets with insufficient volumes and are therefore classified as Level 3. Transactions done with an over-the-counter party are on inactive markets and are therefore classified as Level 3. These transactions are valued based on quoted prices with markets with similar exchange traded transactions. FTRs are priced based upon monthly auction results for identical or similar instruments in a closed market with limited data available and are therefore classified as Level 3.

The ten-year purchased power agreement (see Footnote 9) was valued using an internally-developed pricing model and therefore is classified as Level 3. The model projects future market energy prices and compares those prices to the projected power costs to be incurred under the contract. Inputs to the model require significant management judgment and estimation. Future energy prices are based on a forward power pricing curve using exchange-traded contracts in the electric futures market, where such exchange-traded contracts exist, and upon calculations based on forward gas prices, where such exchange-traded contracts do not exist. A basis adjustment is applied to the market energy price to reflect the price differential between the market price delivery point and the counterparty delivery point. The historical relationship between the delivery points is reviewed and a discount (below 100%) or premium (above 100%) is derived. This comparison is done for both peak times when demand is high and off peak times when demand is low. If the basis adjustment is lowered, the fair value measurement will decrease and if the basis adjustment is increased, the fair value measurement will increase.

The projected power costs anticipated to be incurred under the purchased power agreement are determined using many factors, including historical generating costs, future prices, and expected fuel mix of the counterparty. An increase in the projected fuel costs would result in a decrease in the fair value measurement of the purchased power agreement. A significant input that MGE estimates is the counterparty's fuel mix in determining the projected power cost. MGE also considers the assumptions that market participants would use in valuing the asset or liability. This consideration includes assumptions about market risk such as liquidity, volatility and contract duration. The fair value model uses a discount rate that incorporates discounting, credit, and model risks.

This model is prepared by members of the Energy Supply group. It is reviewed on a quarterly basis by management in Energy Supply and Finance to review the assumptions, inputs and fair value measurements.

The following table presents the significant unobservable inputs used in the pricing model.

Significant Unobservable Inputs	Model Input
Basis adjustment
On peak	95.8 %
Off peak	95.4 %
Counterparty fuel mix:
Internal generation	49 % - 65 %
Purchased power	51 % - 35 %

The deferred compensation plan allows participants to defer certain cash compensation into a notional investment account. These amounts are included within other deferred liabilities in the balance sheets of MGE Energy and MGE. The notional investments earn interest based upon the semiannual rate of U.S. Treasury Bills having a 26 week maturity increased by 1% compounded monthly with a minimum annual rate of 7%, compounded monthly. The notional investments are based upon observable market data, however since the deferred compensation obligations themselves are not exchanged in an active market they are classified as Level 2.

26

The following table summarizes the changes in Level 3 assets and liabilities measured at fair value on a recurring basis for both MGE Energy and MGE.

		Three Months Ended
(In thousands)		March 31,
		2012		2011
Beginning balance,	$	(40,661)	$	(19,216)
Realized and unrealized gains (losses):
Included in regulatory liabilities (assets)		(30,527)		(2,932)
Included in other comprehensive income		-		-
Included in earnings		(1,502)		(8)
Included in current assets		(50)		-
Purchases		50		-
Sales		31		71
Issuances		-		-
Settlements		1,471		(63)
Transfers in and/or out of Level 3		-		-
Balance as of March 31,	$	(71,188)	$	(22,148)
Total gains (losses) included in earnings attributed to
the change in unrealized gains (losses) related to
assets and liabilities held at March 31,(d)	$	-	$	-

The following table presents total realized and unrealized gains (losses) included in income for Level 3 assets and liabilities measured at fair value on a recurring basis for both MGE Energy and MGE (d).

		Three Months Ended
(In thousands)		March 31,
		2012		2011
Purchased Power Expense	$	(1,502)	$	(8)
Cost of Gas Sold Expense		-		-
Regulated Gas Revenues		-		-
Total	$	(1,502)	$	(8)

(d)

MGE's exchange-traded derivative contracts, over-the-counter party transactions, ten-year purchased power agreement, and FTRs are subject to regulatory deferral. These derivatives are therefore marked to fair value and are offset with a corresponding regulatory asset or liability.

12.

New Accounting Pronouncements - MGE Energy and MGE.

a.

Fair Value Measurements and Disclosures.

In May 2011, the FASB issued authoritative guidance within the Codification's Fair Value Measurements and Disclosures topic that provides guidance on additional disclosures about fair value measurements, specifically related to Level 3 assets and liabilities. This authoritative guidance became effective January 1, 2012. The authoritative guidance did not have any financial impact, but required additional disclosures. See Footnote 11 for additional information.

b.

Presentation of Comprehensive Income.

In June 2011, the FASB issued authoritative guidance within the Codification's Comprehensive Income topic that provides guidance on presentation of comprehensive income. Comprehensive income will be presented either in a single continuous statement of comprehensive income or in two separate but consecutive statements. This authoritative guidance became effective January 1, 2012. The authoritative guidance had an effect on our financial statement presentation of comprehensive income. See the Statement of Comprehensive Income for additional information.

27

c.

Disclosures about Offsetting Assets and Liabilities.

In December 2011, the FASB issued authoritative guidance within the Codification's Balance Sheet topic that provides guidance on disclosures about offsetting assets and liabilities. The new disclosure requirements mandate that entities disclose both gross and net information for instruments and transactions eligible for offset in the balance sheet as well as instruments and transactions subject to a master netting arrangement. In addition, the standard requires disclosure of collateral received and posted in connections with a master netting arrangement. This authoritative guidance will become effective January 1, 2013. The authoritative guidance will not have a financial impact, but will require additional disclosures.

13.

Segment Information - MGE Energy and MGE.

MGE Energy operates in the following business segments: electric utility, gas utility, nonregulated energy, transmission investment, and all other. See MGE Energy's and MGE's 2011 Annual Report on Form 10-K for additional discussion of each of these segments.

The following tables show segment information for MGE Energy's operations for the indicated periods:

(In thousands)						Non-						Consolidation/
MGE Energy						Regulated		Transmission		All		Elimination		Consolidated
		Electric		Gas		Energy		Investment		Others		Entries		Total
Three Months Ended March 31, 2012
Operating revenues	$	89,936	$	57,019	$	2,304	$	-	$	-	$	-	$	149,259
Interdepartmental revenues		109		2,986		8,676		-		-		(11,771)		-
Total operating revenues		90,045		60,005		10,980		-		-		(11,771)		149,259
Depreciation and amortization		(6,478)		(1,370)		(1,776)		-		-		-		(9,624)
Other operating expenses		(72,788)		(49,741)		(12)		-		(421)		11,771		(111,191)
Operating income (loss)		10,779		8,894		9,192		-		(421)		-		28,444
Other income, net		164		46		-		2,242		118		-		2,570
Interest (expense) income, net		(2,727)		(769)		(1,645)		-		37		-		(5,104)
Income (loss) before taxes		8,216		8,171		7,547		2,242		(266)		-		25,910
Income tax (provision) benefit		(2,785)		(3,238)		(3,029)		(910)		100		-		(9,862)
Net income (loss)	$	5,431	$	4,933	$	4,518	$	1,332	$	(166)	$	-	$	16,048
Three Months Ended March 31, 2011
Operating revenues	$	86,007	$	77,437	$	1,161	$	-	$	-	$	-	$	164,605
Interdepartmental revenues		107		991		9,396		-		-		(10,494)		-
Total operating revenues		86,114		78,428		10,557		-		-		(10,494)		164,605
Depreciation and amortization		(6,977)		(1,337)		(1,702)		-		-		-		(10,016)
Other operating expenses		(70,916)		(63,053)		(39)		-		(177)		10,494		(123,691)
Operating income (loss)		8,221		14,038		8,816		-		(177)		-		30,898
Other income, net		157		44		-		2,097		88		-		2,386
Interest expense, net		(2,700)		(761)		(1,348)		-		(41)		-		(4,850)
Income (loss) before taxes		5,678		13,321		7,468		2,097		(130)		-		28,434
Income tax (provision) benefit		(1,601)		(5,248)		(2,997)		(852)		47		-		(10,651)
Net income (loss)	$	4,077	$	8,073	$	4,471	$	1,245	$	(83)	$	-	$	17,783

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The following tables show segment information for MGE's operations for the indicated periods:

(In thousands)						Non-				Consolidation/
MGE						Regulated		Transmission		Elimination		Consolidated
		Electric		Gas		Energy		Investment		Entries		Total
Three Months Ended March 31, 2012
Operating revenues	$	89,936	$	57,019	$	2,304	$	-	$	-	$	149,259
Interdepartmental revenues		109		2,986		8,676		-		(11,771)		-
Total operating revenues		90,045		60,005		10,980		-		(11,771)		149,259
Depreciation and amortization		(6,478)		(1,370)		(1,776)		-		-		(9,624)
Other operating expenses*		(75,508)		(52,961)		(3,041)		-		11,771		(119,739)
Operating income*		8,059		5,674		6,163		-		-		19,896
Other income, net*		99		28		-		1,332		-		1,459
Interest expense, net		(2,727)		(769)		(1,645)		-		-		(5,141)
Net income		5,431		4,933		4,518		1,332		-		16,214
Less: Net income attributable to
noncontrolling interest, net of tax		-		-		-		-		(6,072)		(6,072)
Net income attributable to MGE	$	5,431	$	4,933	$	4,518	$	1,332	$	(6,072)	$	10,142
Three Months Ended March 31, 2011
Operating revenues	$	86,007	$	77,437	$	1,161	$	-	$	-	$	164,605
Interdepartmental revenues		107		991		9,396		-		(10,494)		-
Total operating revenues		86,114		78,428		10,557		-		(10,494)		164,605
Depreciation and amortization		(6,977)		(1,337)		(1,702)		-		-		(10,016)
Other operating expenses*		(72,551)		(68,311)		(3,036)		-		10,494		(133,404)
Operating income*		6,586		8,780		5,819		-		-		21,185
Other income, net*		191		54		-		1,246		-		1,491
Interest expense, net		(2,700)		(761)		(1,348)		-		-		(4,809)
Net income		4,077		8,073		4,471		1,246		-		17,867
Less: net income attributable to
noncontrolling interest, net of tax		-		-		-		-		(5,933)		(5,933)
Net income attributable to MGE	$	4,077	$	8,073	$	4,471	$	1,246	$	(5,933)	$	11,934
*Amounts are shown net of the related tax expense, consistent with the presentation on the consolidated MGE Income Statement.

The following table shows segment information for MGE Energy's and MGE's assets and capital expenditures:
		Utility						Consolidated
(In thousands)						Assets							Consolidation/
MGE Energy						not	Nonregulated			Transmission		All		Elimination
		Electric		Gas		Allocated		Energy		Investment		Others		Entries		Total
Assets:
March 31, 2012	$	836,179	$	266,823	$	29,421	$	296,322	$	57,863	$	399,459	$	(403,770)	$	1,482,297
December 31, 2011		794,738		285,702		32,882		299,421		57,006		401,862		(412,729)		1,458,882
Capital Expenditures:
Three Months Ended March 31, 2012	$	13,987	$	1,151	$	-	$	329	$	-	$	-	$	-	$	15,467
Year ended Dec. 31, 2011		47,206		15,830		-		2,140		-		-		-		65,176

		Utility						Consolidated
(In thousands)						Assets
MGE						not	Nonregulated			Transmission		Elimination
		Electric		Gas		Allocated		Energy		Investment		Entries		Total
Assets:
March 31, 2012	$	836,179	$	266,823	$	29,421	$	296,072	$	57,863	$	(26,990)	$	1,459,368
December 31, 2011		794,738		285,702		32,882		299,171		57,006		(35,706)		1,433,793
Capital Expenditures:
Three Months Ended March 31, 2012	$	13,987	$	1,151	$	-	$	329	$	-	$	-	$	15,467
Year ended Dec. 31, 2011		47,206		15,830		-		2,140		-		-		65,176

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14.

Subsequent Events - MGE Energy and MGE.

a.

Long-term Debt.

On April 2, 2012, MGE issued $28 million in principal amount of its 4.38% senior notes, due April 1, 2042. The Notes were issued pursuant to a Note Purchase Agreement. The Notes are unsecured and are not issued under, or governed by, MGE's Indenture dated as of September 1, 1998, which governs MGE's Medium-Term Notes. MGE used the net proceeds from the sale of the Notes, together with other available corporate funds, to repay and retire on April 3, 2012, its obligations under a Loan Agreement dated as of April 1, 2002 with the City of Madison, Wisconsin, under which MGE received the net proceeds from the issuance of $28 million aggregate principal amount of 5.875% Series 2002A, Industrial Development Revenue Bonds that were issued by the City of Madison for MGE's benefit. The 5.875% Series 2002A Bonds were redeemed and retired on April 3, 2012, at 100% of their principal amount plus accrued interest with the proceeds of that loan repayment. Any interest savings in 2012 will be deferred.

b.

Remarketing of 4.875% Series 2002B, Industrial Development Revenue Bonds.

On April 2, 2012, $19.3 million of 4.875% Series 2002B, Industrial Development Revenue Bonds were remarketed at an interest rate of 3.45%. The net proceeds of the 4.875% Series 2002B Bonds were originally loaned to MGE pursuant to a Loan Agreement dated as of April 1, 2002 with the City of Madison, which issued the Series 2002B Bonds in 2002. MGE is responsible for the payment of principal, premium, if any, and interest on the Bonds. The 4.875% Series 2002B Bonds were originally issued bearing an interest rate of 4.875% per annum for a period that ended April 1, 2012, at which point the Bonds were subject to mandatory tender by their holders and remarketing. The Series 2002B Bonds were remarketed and will carry an interest rate of 3.45% per annum, which is payable semi-annually on April 1 and October 1, until their maturity on October 1, 2027. The Series 2002B Bonds are redeemable on or after April 1, 2017, at a redemption price equal to 100% of the principal amount of the Bonds to be redeemed, plus accrued interest to the redemption date.

c.

ATC Capital Contribution.

On April 30, 2012, MGE Transco made a voluntary $0.5 million capital contribution to ATC.

30

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

General

MGE Energy is an investor-owned public utility holding company operating through subsidiaries in five business segments:

·

Regulated electric utility operations, conducted through MGE,

·

Regulated gas utility operations, conducted through MGE,

·

Nonregulated energy operations, conducted through MGE Power and its subsidiaries,

·

Transmission investments, representing our equity investment in ATC, and

·

All other, which includes corporate operations and services.

Our principal subsidiary is MGE, which generates and distributes electric energy, distributes natural gas, and represents a majority portion of our assets, liabilities, revenues, and expenses. MGE generates and distributes electricity to approximately 139,000 customers in Dane County, Wisconsin, including the city of Madison, and purchases and distributes natural gas to approximately 144,000 customers in the Wisconsin counties of Columbia, Crawford, Dane, Iowa, Juneau, Monroe, and Vernon.

Our nonregulated energy operations own interests in electric generating capacity that is leased to MGE. The ownership/leasing structure was adopted under applicable state regulatory guidelines for MGE's participation in these generation facilities, consisting principally of a stable return on the equity investment in the new generation facilities over the term of the related leases. The nonregulated energy operations include an undivided 8.33% ownership interest in two 615 MW coal-fired generating units in Oak Creek, Wisconsin and a partial ownership of a cogeneration project on the UW-Madison campus. A third party operates the units in Oak Creek, and MGE operates the cogeneration project. Due to the nature of MGE's participation in these facilities, the results of our nonregulated operations are also consolidated into MGE's consolidated financial position and results of operations under applicable accounting standards.

Overview

Our primary focus today and for the foreseeable future is our core utility customers at MGE as well as creating long-term value for shareholders. MGE continues to face the challenge of providing its customers with reliable power at competitive prices. MGE meets this challenge by investing in more efficient generation projects, including renewable energy sources. In the future, MGE will continue to focus on growing earnings while controlling operating and fuel costs. MGE will continue to maintain safe and efficient operations in addition to providing customer value. We believe it is critical to maintain a strong credit standing consistent with financial strength in MGE as well as the parent company in order to accomplish these goals.

We earn our revenue and generate cash from operations by providing electric and natural gas utility services, including electric power generation and electric power and gas distribution. The earnings and cash flows from the utility business are sensitive to various external factors, including:

·

Weather, and its impact on customer sales of electricity and gas,

·

Economic conditions, including current business activity and employment and their impact on customer demand,

·

Regulation and regulatory issues, and their impact on the timing and recovery of costs,

·

Energy commodity prices,

·

Equity price risk pertaining to pension related assets,

·

Credit market conditions, including interest rates and our debt credit rating,

·

Environmental laws and regulations, including adopted and pending environmental rule changes,

·

Construction risk in connection with the Columbia environmental project,

and other factors listed in "Item 1A. Risk Factors."

For the three months ended March 31, 2012, MGE Energy's earnings were $16.0 million or $0.69 per share compared to $17.8 million or $0.77 per share for the same period in the prior year. MGE's earnings for the three months ended March 31, 2012, were $10.1 million compared to $11.9 million for the same period in the prior year.

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MGE Energy's income was derived from our business segments as follows:

		Three Months Ended
(In thousands)		March 31,
Business Segment:		2012		2011
Electric Utility	$	5,431	$	4,077
Gas Utility		4,933		8,073
Nonregulated Energy		4,518		4,471
Transmission Investments		1,332		1,245
All Other		(166)		(83)
Net Income	$	16,048	$	17,783

Our net income during the three months ended March 31, 2012, primarily reflects the effects of the following factors:

·

A 20.8% decrease in gas sales reflecting lower customer demand due to a milder winter. Heating degree days (a measure for determining the impact of weather during the heating season) decreased by 26.1% compared to the prior period.

During 2012, the following events occurred:

Columbia Environmental Project: In early 2011, the PSCW authorized the construction of air emission reduction systems and associated equipment on Columbia Units 1 and 2. MGE's estimated share of the capital expenditures required to complete this project will be approximately $140 million. MGE expects to incur capital expenditures as follows: $43 million for the remainder of 2012, $68 million in 2013, and $14 in 2014 million. As of March 31, 2012, MGE has incurred $10.5 million (excluding carrying costs) in construction expenditures at Columbia related to the project and has accrued $4.0 million in incurred, but unpaid capital expenditures.

Rate Filing: On March 23, 2012, MGE filed an application with the PSCW requesting a 5.8% increase to electric rates and a 2.6% increase to gas rates. The proposed electric increase will cover costs for new environmental equipment at Columbia, final construction costs for the Elm Road Units, transmission reliability enhancements, and purchased power costs. MGE has requested that these rates become effective January 1, 2013.

ATC: MGE Transco contributed $0.4 million for voluntary capital contributions to ATC for the three months ended March 31, 2012.

Smart Grid Investment Grant: MGE was approved in 2010 by the U.S. Department of Energy (DOE) under the federal stimulus program for a $5.5 million grant for smart grid projects. The DOE grant requires MGE to match the grant funding, bringing the total cost of the projects to more than $11 million. The projects involve the installation of technologies to boost efficiency, enhance service and improve reliability for customers. The stimulus grant is being used to fund the following projects: advanced metering infrastructure, plug-in hybrid electric vehicles support, and distribution management. As of March 31, 2012, MGE has spent $6.8 million related to these projects and has outstanding agreements to purchase $0.8 million in smart grid related products for the remainder of 2012.

In the near term, several items may affect us, including:

Environmental Initiatives: There are proposed legislation, rules and initiatives involving matters related to air emissions, water effluent, hazardous materials and greenhouse gases, all of which affect generation plant capital expenditures and operating costs as well as future operational planning. Such legislation and rulemaking could significantly affect the costs of owning and operating fossil-fueled generating plants, such as Columbia and Elm Road, from which we derive approximately 43% of our electric generating capacity. We would expect to seek and receive recovery of any such costs in rates; however, it is difficult to estimate the amount of such costs due to the uncertainty as to the timing and form of the legislation and rules, and the scope and time of the recovery of costs in rates. In addition, MGE is involved in claims surrounding the alleged failure, among other things, to obtain necessary air permits and implement necessary emission controls associated with past activities at Columbia. MGE and the other co-owners are defending against these claims. MGE is currently unable to predict the impact of these claims on its financial condition or results of operations at this time. However, should there ultimately be an adverse outcome, MGE believes it could have a significant effect.

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General economic conditions: Economic conditions both inside and outside our service area are expected to continue to affect the level of demand for our utility services and may affect the collection of our accounts receivable and the creditworthiness of counterparties with whom we do business. We have in place lines of credit aggregating $115 million for MGE Energy (including MGE) and $75 million for MGE to address our liquidity needs.

The following discussion is based on the business segments as discussed in Footnote 13.

Three Months Ended March 31, 2012 and 2011

Electric Utility Operations - MGE Energy and MGE

Electric sales and revenues

The following table compares MGE's electric revenues and electric kWh sales by customer class for each of the periods indicated:

		Revenues				Sales (kWh)
(in thousands)		Three Months Ended March 31,				Three Months Ended March 31,
		2012		2011	% Change	2012	2011	% Change
Residential	$	30,139	$	30,299	(0.5)%	196,163	206,861	(5.2)%
Commercial		47,196		44,691	5.6 %	431,755	434,789	(0.7)%
Industrial		4,526		4,333	4.5 %	59,848	61,881	(3.3)%
Other-retail/municipal		8,974		7,599	18.1 %	107,680	89,829	19.9 %
Total retail		90,835		86,922	4.5 %	795,446	793,360	0.3 %
Sales to the market		280		190	47.4 %	5,788	14,604	(60.4)%
Adjustments to revenues		(1,179)		(1,105)	(6.7)%	-	-	- %
Total	$	89,936	$	86,007	4.6 %	801,234	807,964	(0.8)%

Electric operating revenues increased $3.9 million or 4.6% for the three months ended March 31, 2012, due to the following:

(In millions)
Rate changes	$	3.7
Volume		0.2
Sales to the market		0.1
Adjustments to revenues		(0.1)
Total	$	3.9

·

Rate changes. Rates charged to retail customers for the three months ended March 31, 2012, were 4.2% or $3.7 million higher than those charged during the same period in the prior year.

In December 2011, the PSCW authorized MGE to increase 2012 rates for retail electric customers by 4.3% or $15.7 million. The increase in retail electric rates is driven by MGE's electric fuel and purchased power costs, increased transmission costs, an update to the Elm Road Units' costs, and an increase for energy efficiency programs.

·

Volume. During the three months ended March 31, 2012, there was a 0.3% increase in total retail sales volumes compared to the same period in the prior year.

·

Sales to the market. Sales to the market represent wholesale sales made to third parties who are not ultimate users of the electricity. These sales may include spot market transactions on the markets operated by MISO and PJM. These sales may also include bilateral sales to other utilities or power marketers. Generating units are dispatched by MISO based on cost considerations as well as reliability of the system. Sales to the market typically occur when MGE has more generation and purchases online than is needed for its own system demand. The excess electricity is then sold to others in the market. For the three months ended March 31, 2012, market volumes decreased compared to the same period in the prior year, reflecting decreased opportunities for sales; however, market settlement resulted in higher revenue per kWh for the three months ended March 31, 2012, reflecting higher market prices.

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·

Adjustments to revenues. The adjustments to revenues amount includes the elimination of carrying costs for WCCF and the Elm Road Units that were collected in electric rates, which are recognized as nonregulated energy operating revenues in our Nonregulated Energy Operations segment.

Electric fuel and purchased power

The expense for fuel for electric generation decreased $2.2 million or 19.9% during the three months ended March 31, 2012, compared to the same period in the prior year, reflecting lower generation at Columbia and Elm Road.

Purchased power expense increased $2.0 million or 11.2% during the three months ended March 31, 2012, compared to the same period in the prior year. This increase in expense reflects a $4.7 million increase due to a 26.8% increase in the volume of power purchased from third parties, partially offset by a $2.7 million decrease due to a 12.3% decrease in the per-unit cost of purchased power for the three months ended March 31, 2012, compared to the prior period.

Electric operating and maintenance expenses

Electric operating and maintenance expenses increased $2.4 million during the three months ended March 31, 2012, compared to the same period in 2011. The following changes contributed to the net change:

(In millions)
Increased administrative and general costs	$	1.9
Increased distribution costs		0.6
Increased transmission costs		0.3
Increased customer service costs		0.3
Decreased production costs		(0.7)
Total	$	2.4

For the three months ended March 31, 2012, increased administrative and general costs are primarily due to increased pension costs and increased distribution costs are due to increased overhead line expenses. Production costs decreased primarily due to decreased internal generation.

Gas Utility Operations - MGE Energy and MGE

Gas deliveries and revenues

The following table compares MGE's gas revenues and gas therms delivered by customer class during each of the periods indicated:

		Revenues				Therms Delivered
(In thousands, except HDD and average rate per therm of retail customer)		Three Months Ended March 31,				Three Months Ended March 31,
		2012		2011	% Change	2012	2011	% Change
Residential	$	33,381	$	44,316	(24.7)%	35,600	45,661	(22.0)%
Commercial/Industrial		22,771		32,095	(29.1)%	36,947	46,423	(20.4)%
Total retail		56,152		76,411	(26.5)%	72,547	92,084	(21.2)%
Gas Transportation		729		840	(13.2)%	10,117	12,315	(17.8)%
Other revenues		138		186	(25.8)%	-	-	- %
Total	$	57,019	$	77,437	(26.4)%	82,664	104,399	(20.8)%
Heating degree days (normal 3,554)						2,717	3,677	(26.1)%
Average Rate Per Therm of
Retail Customer	$	0.774	$	0.830	(6.7)%

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Gas revenues decreased $20.4 million or 26.4% for the three months ended March 31, 2012. These changes are related to the following factors:

(In millions)
Gas deliveries	$	(16.2)
Gas costs/rates		(4.0)
Transportation and other effects		(0.2)
Total	$	(20.4)

·

Retail gas deliveries. For the three months ended March 31, 2012, retail gas deliveries decreased 21.2% compared to the same period in 2011 as a result of milder weather during the winter months.

·

Gas costs/rates. The average retail rate per therm for the three months ended March 31, 2012, decreased 6.7% compared to the same period in 2011, reflecting lower natural gas commodity costs.

Cost of gas sold

For the three months ended March 31, 2012, cost of gas sold decreased by $16.1 million, compared to the same period in the prior year. The volume of gas purchased decreased 21.5%, which resulted in $10.9 million of decreased expense. In addition, the cost per therm of natural gas decreased 12.9%, which resulted in $5.2 million of decreased expense.  

Gas operating and maintenance expenses

Gas operating and maintenance expenses increased by $1.0 million for the three months ended March 31, 2012, compared to the same period in 2011. The following changes contributed to the net change:

(In millions)
Increased administrative and general costs	$	0.7
Increased distribution costs		0.3
Total	$	1.0

For the three months ended March 31, 2012, increased administrative general costs are primarily due to increased pension costs.

Nonregulated Energy Operations - MGE Energy and MGE

For both the three months ended March 31, 2012 and 2011, net income at the nonregulated energy operations segment was $4.5 million. The nonregulated energy operations are conducted through MGE Energy's subsidiaries: MGE Power, MGE Power Elm Road and MGE Power West Campus. These subsidiaries have been formed to construct, own and lease electric generating capacity to assist MGE.

Transmission Investment Operations - MGE Energy and MGE

Transmission investment other income

For the three months ended March 31, 2012 and 2011, other income at the transmission investment segment was $2.2 million and $2.1 million, respectively. The transmission investment segment holds our interest in ATC, and its income reflects our equity in the earnings of ATC. See Footnote 3 for additional information concerning ATC and summarized financial information regarding ATC.

Consolidated Income Taxes - MGE Energy and MGE

MGE Energy's and MGE's effective income tax rate for the three months ended March 31, 2012, is 38.1% compared to 37.5% for the same period in 2011. The higher effective tax rate is, in part, attributable to a lower estimated domestic manufacturing deduction.

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Noncontrolling Interest, Net of Tax - MGE

The noncontrolling interest, net of tax, reflects the accounting required for MGE Energy's interest in the Elm Road Units and WCCF. MGE Energy owns 100% of MGE Power Elm Road and MGE Power West Campus; however, due to the contractual agreements for these projects with MGE, the entities are considered VIEs and their results are consolidated with those of MGE, the primary beneficiary of the VIEs. Also included in noncontrolling interest, net of tax, is MGE Energy's interest in MGE Transco. The following table shows MGE Energy's noncontrolling interest, net of tax, reflected on MGE's consolidated statement of income:

		Three Months Ended
		March 31,
(in millions)		2012		2011
MGE Power Elm Road	$	3.7	$	3.6
MGE Power West Campus	$	1.9	$	1.9
MGE Transco	$	0.5	$	0.4

Contractual Obligations and Commercial Commitments - MGE Energy and MGE

There were no material changes, other than from the normal course of business, to MGE Energy's and MGE's contractual obligations (representing cash obligations that are considered to be firm commitments) and commercial commitments (representing commitments triggered by future events) during the three months ended March 31, 2012, except as noted below. Further discussion of the contractual obligations and commercial commitments is included in Footnote 8 of this filing and Footnote 18 and "Contractual Obligations and Commercial Commitments for MGE Energy and MGE" under "Management's Discussion and Analysis of Financial Condition and Results of Operations" in MGE Energy's and MGE's 2011 Annual Report on Form 10-K.

Smart Grid Investment Grant - MGE Energy and MGE

MGE was approved in 2010 by the U.S. Department of Energy (DOE) under the federal stimulus program for a $5.5 million grant for smart grid projects. The DOE grant requires MGE to match the grant funding, bringing the total cost of the projects to more than $11 million. The projects involve the installation of technologies to boost efficiency, enhance service and improve reliability for customers. The stimulus grant is being used to fund the following projects: advanced metering infrastructure, plug-in hybrid electric vehicles support, and distribution management. As of March 31, 2012, MGE has spent $6.8 million related to these projects and has outstanding agreements to purchase $0.8 million in smart grid related products for the remainder of 2012.

Other Commitments - MGE Energy

On January 31, 2012, MGE Energy entered a subscription agreement to invest in a nonpublic venture capital fund. From time to time, this entity will require capital infusions from its investors. MGE Energy has committed to contribute $2.0 million in capital for such infusions. The timing of these infusions is dependent on the needs of the investee and is therefore uncertain at this time.

Long-term Debt - MGE Energy and MGE

On April 2, 2012, MGE issued $28 million in principal amount of its 4.38% senior notes, due April 1, 2042. The Notes were issued pursuant to a Note Purchase Agreement. The Notes are unsecured and are not issued under, or governed by, MGE's Indenture dated as of September 1, 1998, which governs MGE's Medium-Term Notes. MGE used the net proceeds from the sale of the Notes, together with other available corporate funds, to repay and retire on April 3, 2012, its obligations under a Loan Agreement dated as of April 1, 2002 with the City of Madison, Wisconsin, under which MGE received the net proceeds from the issuance of $28 million aggregate principal amount of 5.875% Series 2002A, Industrial Development Revenue Bonds that were issued by the City of Madison for MGE's benefit. The 5.875% Series 2002A Bonds were redeemed and retired on April 3, 2012, at 100% of their principal amount plus accrued interest with the proceeds of that loan repayment. Any interest savings in 2012 will be deferred.

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Remarketing of 4.875% Series 2002B, Industrial Development Revenue Bonds - MGE Energy and MGE

On April 2, 2012, $19.3 million of 4.875% Series 2002B, Industrial Development Revenue Bonds were remarketed at an interest rate of 3.45%. The net proceeds of the 4.875% Series 2002B Bonds were originally loaned to MGE pursuant to a Loan Agreement dated as of April 1, 2002 with the City of Madison, which issued the Series 2002B Bonds in 2002. MGE is responsible for the payment of principal, premium, if any, and interest on the Bonds. The 4.875% Series 2002B Bonds were originally issued bearing an interest rate of 4.875% per annum for a period that ended April 1, 2012, at which point the Bonds were subject to mandatory tender by their holders and remarketing. The Series 2002B Bonds were remarketed and will carry an interest rate of 3.45% per annum, which is payable semi-annually on April 1 and October 1, until their maturity on October 1, 2027. The Series 2002B Bonds are redeemable on or after April 1, 2017, at a redemption price equal to 100% of the principal amount of the Bonds to be redeemed, plus accrued interest to the redemption date.

Liquidity and Capital Resources

Cash Flows

The following summarizes cash flows for MGE Energy and MGE during the three months ended March 31, 2012 and 2011:

		MGE Energy				MGE
(In thousands)		2012		2011		2012		2011
Cash provided by/(used for):
Operating activities	$	24,736	$	38,037	$	23,583	$	37,076
Investing activities		(15,716)		(12,481)		(15,773)		(10,110)
Financing activities		(9,529)		(1,981)		(7,049)		(13,549)

Cash Provided by Operating Activities

MGE Energy

MGE Energy's consolidated net cash provided by operating activities is derived mainly from the electric and gas operations of its principal subsidiary, MGE.

Cash provided by operating activities for the three months ended March 31, 2012, was $24.7 million, a decrease of $13.3 million when compared to the same period in the prior year, primarily due to working capital changes.

MGE Energy's net income decreased $1.7 million for the three months ended March 31, 2012, when compared to the same period in the prior year.

The cash flows for the three months ended March 31, 2012, reflect a $7.2 million benefit of lower taxes payable, compared to the same period in the prior year, primarily due to the additional benefit from the income tax method change in accounting for repairs and bonus depreciation.

Working capital accounts resulted in $5.7 million in cash provided by operating activities for the three months ended March 31, 2012, primarily due to decreased gas inventories and decreased unbilled receivables, partially offset by decreased accounts payable. Working capital accounts resulted in $22.5 million in cash provided by operating activities for the three months ended March 31, 2011, primarily due to decreased inventories, decreased prepaid taxes, and decreased unbilled revenues, partially offset by decreased accounts payable and increased accounts receivable.

An increase in pension contribution resulted in an additional $1.6 million in cash used by operating activities for the three months ended March 31, 2012, when compared to the same period in the prior year. These contributions were made to comply with the Employee Retirement Income Security Act (ERISA) and the Pension Protection Act of 2006, and additional contributions were at management's discretion.

MGE

Cash provided by operating activities for the three months ended March 31, 2012, was $23.6 million, a decrease of $13.5 million when compared to the same period in the prior year, primarily due to working capital changes.

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Net income decreased $1.7 million for the three months ended March 31, 2012, when compared to the same period in the prior year.

The cash flows for the three months ended March 31, 2012, reflect a $7.4 million benefit of lower taxes payable, compared to the same period in the prior year, primarily due to the additional benefit from the income tax method change in accounting for repairs and bonus depreciation.

Working capital accounts resulted in $4.6 million in cash provided by operating activities for the three months ended March 31, 2012, primarily due to decreased gas inventories and decreased unbilled receivables, partially offset by decreased accounts payable. Working capital accounts resulted in $21.5 million in cash provided by operating activities for the three months ended March 31, 2011, primarily due to decreased inventories, decreased prepaid taxes, and decreased unbilled receivables, partially offset by increased accounts receivable.

An increase in pension contribution resulted in an additional $1.6 million in cash used by operating activities for the three months ended March 31, 2012, when compared to the same period in the prior year. These contributions were made to comply with the ERISA and the Pension Protection Act of 2006, and additional contributions were at management's discretion.

Cash Used for Investing Activities

MGE Energy

MGE Energy's cash used for investing activities increased $3.2 million for the three months ended March 31, 2012, when compared to the same period in the prior year.

Capital expenditures for the three months ended March 31, 2012, were $15.5 million. This amount represents an increase of $5.6 million from the expenditures made in the same period in the prior year. This increase is due to increased expenditures on the Columbia environmental project of $6.2 million.

Cash used for investing activities for the three months ended March 31, 2011, also included land purchased for investing purposes of $1.8 million.

MGE

MGE's cash used for investing activities increased $5.7 million for the three months ended March 31, 2012, when compared to the same period in the prior year.

Capital expenditures for the three months ended March 31, 2012, were $15.5 million. This amount represents an increase of $5.6 million from the expenditures made in the same period in the prior year. This increase is due to increased expenditures on the Columbia environmental project of $6.2 million.

Cash Used for Financing Activities

MGE Energy

Cash used for MGE Energy's financing activities was $9.5 million for the three months ended March 31, 2012, compared to $2.0 million of cash used for the three months ended March 31, 2011.

For the three months ended March 31, 2012, dividends paid were $8.8 million compared to $8.7 million in the prior year. This increase was a result of a higher dividend per share ($0.383 vs. $0.375).

During the three months ended March 31, 2011, MGE Power Elm Road issued $30.0 million of long-term debt.

For the three months ended March 31, 2011, net short-term debt repayments were $22.5 million reflecting the use of proceeds from the MGE Power Elm Road long-term debt issues.

MGE

During the three months ended March 31, 2012, cash used for MGE's financing activities was $7.0 million compared to $13.5 million of cash used by MGE's financing activities in the prior year.

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Dividends paid from MGE to MGE Energy were $6.7 million for the three months ended March 31, 2012, compared to $6.6 million in the prior year.

During the three months ended March 31, 2011, MGE Power Elm Road issued $30.0 million of long-term debt.

As a result of the long-term debt financing by MGE Power Elm Road, distributions to parent from noncontrolling interest were $33.0 million for the three months ended March 31, 2011. The proceeds from the financing were used to repay MGE Energy, which had been using its short-term credit facilities to help finance the Elm Road Units.

In addition, for the three months ended March 31, 2011, net short-term debt repayments were $3.5 million.

Capitalization Ratios

MGE Energy's capitalization ratios were as follows:

	MGE Energy
	March 31, 2012	December 31, 2011
Common shareholders' equity	60.6 %	60.2 %
Long-term debt*	39.4 %	39.8 %
*Includes the current portion of long-term debt.

MGE Energy's and MGE's Capital Requirements

MGE Energy's and MGE's liquidity are primarily affected by their capital requirements. During the three months ended March 31, 2012, capital expenditures for MGE Energy and MGE totaled $15.5 million, which included $15.1 million of capital expenditures for utility operations.

In early 2011, the PSCW authorized the construction of air emission reduction systems and associated equipment on Columbia Units 1 and 2. MGE's estimated share of the capital expenditures required to complete this project will be approximately $140 million. MGE expects to incur capital expenditures as follows: $43 million for the remainder of 2012, $68 million in 2013, and $14 million in 2014. As of March 31, 2012, MGE had incurred $10.5 million (excluding carrying costs) in construction expenditures at Columbia related to the project and had accrued $4.0 million in incurred, but unpaid capital expenditures.

Credit Ratings

MGE Energy's and MGE's access to the capital markets, including, in the case of MGE, the commercial paper market, and their respective financing costs in those markets, may depend on the credit ratings of the entity that is accessing the capital markets.

None of MGE Energy's or MGE's borrowing is subject to default or prepayment as a result of a downgrading of credit ratings, although a downgrading of MGE's credit ratings could increase fees and interest charges under both MGE Energy's and MGE's credit agreements.

Environmental Matters

The following discussion is limited to updates or developments in environmental matters that occurred during the three months ended March 31, 2012. Further discussion of environmental matters is included in MGE Energy's and MGE's 2011 Annual Report on Form 10-K and Footnote 8.a. of Notes to Consolidated Financial Statements in this Report.

Global climate change

MGE is a producer of GHG emissions, primarily from the fossil fuel generating facilities it utilizes to meet customers' energy needs, as well as from its natural gas pipeline system and fleet vehicles. Climate change and the regulatory response to it could significantly affect our operations in a number of ways, including increased operating costs and capital expenditures, restrictions on energy supply options, permitting difficulties and more stringent emission limits. MGE management would expect to seek and receive rate recovery of such compliance costs, if and when required. MGE will continue to monitor proposed climate change legislation and regulation. MGE is currently complying with applicable greenhouse gas regulations and is actively monitoring current proposed and other potential greenhouse gas regulations from the EPA.

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GHG New Source Performance Standards for Electric Generating Units (EGU GHG NSPS)

On March 27, 2012, the EPA proposed greenhouse gas (GHG) New Source Performance Standards (NSPS) for coal fired and natural gas combined cycle (NGCC) electric generation units (EGUs). The proposal applies to new EGUs only; the EPA has stated that it does not intend for these rules to apply to modified or existing units at this time. The proposed NSPS may be finalized within 2012 and is not anticipated to significantly affect MGE's existing generation units.

New Accounting Principles

See Footnote 12 for discussion of new accounting pronouncements.

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Item 3. Quantitative and Qualitative Disclosures About Market Risk.

MGE Energy and MGE are potentially exposed to market risk associated with interest rates, commodity prices, and equity returns. MGE currently has no exposure to foreign currency risk. MGE manages some risk exposure through risk management policies and the use of derivative instruments. MGE's risk management policy prohibits speculative trading transactions.

Commodity Price Risk

MGE has commodity price risk exposure with respect to the price of natural gas, electricity, coal, emission credits, and oil. MGE employs established policies and procedures to reduce the market risks associated with changing commodity prices. MGE's commodity risks are somewhat mitigated by the current ratemaking process in place for recovering electric fuel cost, purchased energy costs, and the cost of natural gas. MGE's electric fuel costs are subject to fuel rules established by the PSCW.

MGE's electric operations burn natural gas in several of its peaking power plants and, in many cases, the cost of purchased power is tied to the cost of natural gas. MGE bears regulatory risk for the recovery of such fuel and purchased power costs when they are higher than the base rate established in its current rate structure.

The PSCW approved new fuel rules that became effective January 1, 2011. The new rules require the PSCW and Wisconsin utilities to automatically defer electric fuel-related costs that fall outside a symmetrical cost tolerance band. Any over/under recovery of the deferred costs is determined on an annual basis and will be adjusted in future billings to electric retail customers. Under the electric fuel rules, MGE is required to defer the benefit of lower costs if the actual fuel rules costs fall outside the lower end of the range and would defer costs, less any excess revenues, if the actual fuel rules costs exceeded the upper end of the range. Excess revenues are defined as revenues in the year in question that provide MGE with a greater return on common equity than authorized by the PSCW in MGE's latest rate order. The range is defined by the PSCW and has been modified throughout the years based on market conditions and other relevant factors. Currently, MGE is subject to a plus or minus 2% range. MGE assumes the risks and benefits of variances that are within the cost tolerance band. For 2012, fuel and purchased power costs included in MGE's base fuel rates are $100.7 million. See Footnote 10.b. for additional information.

MGE's gas segment is governed by the purchased gas adjustment clause (PGA). Under the PGA, MGE is able to pass through to customers the cost of gas.

MGE also reduces price risk caused by market fluctuations via physical contracts and financial derivative contracts, including futures, swaps, options, forwards, and other contractual commitments. The maximum length of time over which cash flows related to energy commodities can be hedged is four years.

MGE has financial gas and electric commodity contracts to hedge commodity price risk in the gas and electric segments. These contracts are primarily comprised of exchange-traded option and future contracts. MGE also holds FTRs, which are used to hedge the risk of increased congestion charges. At March 31, 2012, the cost basis of these instruments exceeded their fair value by $2.5 million. Under the PGA clause and electric fuel rules, MGE may include in the costs of fuel (natural gas or power) the costs and benefits of the aforementioned fuel price risk management tools. Because these costs/benefits are recoverable, the related unrealized loss/gain has been deferred on the balance sheet as a regulatory asset/liability.

MGE has also entered into a ten-year purchased power agreement that provides MGE with firm capacity and energy beginning June 1, 2012, and ending on May 31, 2022 (the "base term"). The agreement also allows MGE the option to extend the contract after the base term. The agreement is a derivative contract and is recognized at its fair value on the balance sheet. The fair value of the contract at March 31, 2012, reflects a loss position of $69.0 million.

Interest Rate Risk

Both MGE Energy and MGE may have short term borrowings at varying interest rates. MGE issues commercial paper for its short-term borrowings, while MGE Energy draws from its current credit facility to meet its short-term borrowing needs. Borrowing levels vary from period to period depending upon capital investments and other factors. Future short-term interest expense and payments will reflect both future short-term interest rates and borrowing levels. MGE Energy and MGE manage interest rate risk by limiting their variable rate exposure and continually monitoring the effects of market changes on interest rates. MGE is not exposed to changes in interest rates on a substantial portion of its long-term debt until that debt matures and is refinanced at market rates.

41

Equity Price Risk - Pension-Related Assets

MGE currently funds its liabilities related to employee benefits through trust funds. These funds, which include investments in debt and equity securities, are managed by various investment managers. Changes in market value of these investments can have an impact on the future expenses related to these liabilities.

Credit Risk - Counterparty

Credit risk is the loss that may result from counterparty nonperformance. MGE is exposed to credit risk primarily through its merchant energy business. MGE uses credit policies to manage its credit risk, which includes utilizing an established credit approval process, monitoring counterparty limits, employing credit mitigation measures such as collateral or prepayment arrangements, and using netting agreements.

Due to the possibility of extreme volatility in the prices of energy commodities and derivatives, the market value of contractual positions with individual counterparties could exceed established credit limits or collateral provided by those counterparties. If such a counterparty were then to fail to perform its obligations under its contract (for example, fail to deliver the electricity MGE originally contracted for), MGE could sustain a loss that could have a material impact on its financial results.

Additionally, if a counterparty were to default and MGE were to liquidate all contracts with that entity, MGE's credit loss would include the loss in value of mark-to-market contracts; the amount owed for settled transactions; and additional payments, if any, to settle unrealized losses on accrual contracts. As of March 31, 2012, no counterparties have defaulted.

MGE is obligated to provide service to all electric and gas customers within its respective franchised territories. MGE's franchised electric territory includes a 316 square-mile area in Dane County, Wisconsin, and MGE's franchised gas territory includes a service area covering 1,631 square miles in Wisconsin. Based on results for the year ended December 31, 2011, no one customer constituted more than 9% of total operating revenues for MGE Energy and MGE. Credit risk for electric and gas is managed by MGE's credit and collection policies, which are consistent with state regulatory requirements.

Cash, cash equivalents, and customer accounts receivable are the financial instruments that potentially subject MGE Energy and MGE to concentrations of credit risk. MGE Energy and MGE place their cash and cash equivalents with high credit-quality financial institutions. MGE has limited concentrations of credit risk from customer accounts receivable because of the large number of customers and relatively strong economy in its service territory.

42

Item 4. Controls and Procedures.

During the first quarter of 2012, each registrant's management, including the principal executive officer and principal financial officer, evaluated its disclosure controls and procedures related to the recording, processing, summarization, and reporting of information in its periodic reports that it files with the SEC. These disclosure controls and procedures have been designed to ensure that material information relating to that registrant, including its subsidiaries, is accumulated and made known to that registrant's management, including these officers, by other employees of that registrant and its subsidiaries as appropriate to allow timely decisions regarding required disclosure, and that this information is recorded, processed, summarized, evaluated, and reported, as applicable, within the time periods specified in the SEC's rules and forms. Due to the inherent limitations of control systems, not all misstatements may be detected. These inherent limitations include the realities that judgments in decision making can be faulty and breakdowns can occur because of simple error or mistake. Additionally, controls can be circumvented by the individual acts of some persons, by collusion of two or more people, or by management override of the control. Also, the registrants do not control or manage certain of their unconsolidated entities and thus, their access and ability to apply their procedures to those entities is more limited than is the case for their consolidated subsidiaries.

As of March 31, 2012, each registrant's principal executive officer and principal financial officer concluded that its disclosure controls and procedures were effective. Each registrant intends to strive continually to improve its disclosure controls and procedures to enhance the quality of its financial reporting.

During the quarter ended March 31, 2012, there were no changes in either registrant's internal controls over financial reporting that materially affected, or are reasonably likely to affect materially, that registrant's internal control over financial reporting.

43

PART II. OTHER INFORMATION.

Item 1. Legal Proceedings.

MGE Energy and MGE

MGE Energy and its subsidiaries, including MGE, from time to time are involved in various legal proceedings that are handled and defended in the ordinary course of business.

See Footnote 8.a. and 8.c. for a description of several proceedings involving MGE.

Item 1A. Risk Factors.

There were no material changes in the risk factors previously disclosed in Part I, Item 1A. of the 2011 Form 10-K, except as described below.

We face construction risk in connection with the completion of the Columbia environmental project.

The large-scale environmental project at the Columbia generating facility is subject to various risks that could cause costs to increase or delays in completion. These risks include shortages of, the inability to obtain, the cost of, and the consistency of, labor, materials and equipment; the inability of the general contractor or subcontractors to perform under their contracts; the inability to agree to terms of contracts or disputes in contract terms; work stoppages; adverse weather conditions; the inability to obtain necessary permits in a timely manner; changes in applicable laws or regulations; adverse interpretation or enforcement of permit conditions; governmental actions; legal action; and unforeseen engineering or technology issues. If the construction project is over budget, we may not be able to recover those excess costs. Inability to recover excess costs, or inability to complete the project in a timely manner, could adversely impact our financial condition and results of operations.

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

Issuer Purchases of Equity Securities

					Maximum number (or
					Approximate Dollar
	Total			Total Number	Value) of Shares That
	Number		Average	of Shares	May Yet Be
	of		Price	Purchased as Part of	Purchased
	Shares		Paid	Publicly Announced	Under the Plans or
Period	Purchased		per Share	Plans or Programs*	Programs*
January 1-31, 2012	24,830	$	45.20	-	-
February 1-29, 2012	39,810		46.07	-	-
March 1-31, 2012	78,100		45.06	-	-
Total	142,740	$	45.37	-	-

* Under the Stock Plan, common stock shares deliverable to plan participants may be either newly issued shares or shares purchased on the open market, as determined from time to time by MGE Energy. In June 2009, MGE Energy switched to using open market purchases to provide shares to meet obligations to participants in the Stock Plan. The shares are purchased on the open market through a securities broker-dealer and then are reissued under the Stock Plan as needed to meet share delivery requirements. The volume and timing of share repurchases in the open market depends upon the level of dividend reinvestment and optional share purchases being made from time to time by plan participants. As a result, there is no specified maximum number of shares to be repurchased and no specified termination date for the repurchases. All shares issued through the Stock Plan, whether newly issued or reissued following open market purchases, are issued and sold pursuant to a registration statement that was filed with the SEC and is currently effective.

44

Item 6. Exhibits.

12

Statement regarding computation of ratio of earnings to fixed charges for Madison Gas and Electric Company.

Certifications Pursuant to Rule 13a-14(a) and 15d-14(a) of the Securities and Exchange Act of 1934 as to the Quarterly Report on Form 10-Q for the quarter ended March 31, 2012, filed by the following officers for the following companies:

31.1

Filed by Gary J. Wolter for MGE Energy, Inc.

31.2

Filed by Jeffrey C. Newman for MGE Energy, Inc.

31.3

Filed by Gary J. Wolter for Madison Gas and Electric Company

31.4

Filed by Jeffrey C. Newman for Madison Gas and Electric Company

Certifications Pursuant to Section 1350 of Chapter 63 of Title 18 United States Code (Sarbanes-Oxley Act of 2002) as to the Quarterly Report on Form 10-Q for the quarter ended March 31, 2012, filed by the following officers for the following companies:

32.1

Filed by Gary J. Wolter for MGE Energy, Inc.

32.2

Filed by Jeffrey C. Newman for MGE Energy, Inc.

32.3

Filed by Gary J. Wolter for Madison Gas and Electric Company

32.4

Filed by Jeffrey C. Newman for Madison Gas and Electric Company

101*

Interactive Data Files:

101.INS - XBRL Instance

101.SCH - XBRL Taxonomy Extension Schema

101.CAL - XBRL Taxonomy Extension Calculation

101.DEF - XBRL Taxonomy Extension Definition

101.LAB - XBRL Taxonomy Extension Labels

101.PRE

 - XBRL Taxonomy Extension Presentation

*

XBRL information will be considered to be furnished, not filed for the first two years of a company's submission of XBRL information.

45

Signatures - MGE Energy, Inc.

Pursuant to the requirements of the Securities Exchange Act of 1934, the registrant has duly caused this report to be signed on its behalf by the undersigned hereunto duly authorized.

	MGE ENERGY, INC.
Date: May 7, 2012	/s/ Gary J. Wolter
	Gary J. Wolter Chairman, President and Chief Executive Officer (Duly Authorized Officer)
Date: May 7, 2012	/s/ Jeffrey C. Newman
	Jeffrey C. Newman Vice President, Chief Financial Officer, Secretary and Treasurer (Chief Financial and Accounting Officer)

46

Signatures - Madison Gas and Electric Company

Pursuant to the requirements of the Securities Exchange Act of 1934, the registrant has duly caused this report to be signed on its behalf by the undersigned hereunto duly authorized.

	MADISON GAS AND ELECTRIC COMPANY
Date: May 7, 2012	/s/ Gary J. Wolter
	Gary J. Wolter Chairman, President and Chief Executive Officer (Duly Authorized Officer)
Date: May 7, 2012	/s/ Jeffrey C. Newman
	Jeffrey C. Newman Vice President, Chief Financial Officer, Secretary and Treasurer (Chief Financial and Accounting Officer)

47

EX-12

EXHIBIT 12

Madison Gas and Electric Company

Ratio of Earnings to Fixed Charges

Three Months Ended March 31, 2012

(In thousands)

Earnings
Net income before minority interest	$16,214
Equity earnings	(2,242)
Income distribution from equity investees	1,740
Minority interest in pre-tax income	(848)
Amortization of capitalized interest	132
Federal and state income taxes	9,962
Fixed charges	5,474
Total Earnings as Defined	$30,432
Fixed Charges
Interest expense on long-term debt and other	$4,971
Interest on rentals*	270
Amortization of debt issuance costs	170
AFUDC - borrowed funds	63
Total Fixed Charges	$5,474
Ratio of Earnings to Fixed Charges	5.56X

*Management believes that using one-third of the total rental expense

gives a reasonable approximation for actual interest on rentals.

EX-31

EXHIBIT 31.1

Certification Pursuant to Rule 13a-14(a) and 15d-14(a) of the Securities Exchange Act of 1934

I, Gary J. Wolter, certify that:

1.

I have reviewed this quarterly report on Form 10-Q of MGE Energy, Inc.;

2.

Based on my knowledge, this report does not contain any untrue statement of a material fact or omit to state a material fact necessary to make the statements made, in light of the circumstances under which such statements were made, not misleading with respect to the period covered by this report;

3.

Based on my knowledge, the financial statements, and other financial information included in this report, fairly present in all material respects the financial condition, results of operations and cash flows of the registrant as of, and for, the periods presented in this report;

4.

The registrant's other certifying officer and I are responsible for establishing and maintaining disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) and internal control over financial reporting (as defined in Exchange Act Rules 13a-15(f) and 15d-15(f)) for the registrant and have:

(a)

Designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be designed under our supervision, to ensure that material information relating to the registrant, including its consolidated subsidiaries, is made known to us by others within those entities, particularly during the period in which this report is being prepared;

(b)

Designed such internal control over financial reporting, or caused such internal control over financial reporting to be designed under our supervision, to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles;

(c)

Evaluated the effectiveness of the registrant's disclosure controls and procedures and presented in this report our conclusions about the effectiveness of the disclosure controls and procedures, as of the end of the period covered by this report based on such evaluation; and

(d)

Disclosed in this report any change in the registrant's internal control over financial reporting that occurred during the registrant's most recent fiscal quarter (the registrant's fourth fiscal quarter in the case of an annual report) that has materially affected, or is reasonably likely to materially affect, the registrant's internal control over financial reporting; and

5.

The registrant's other certifying officer and I have disclosed, based on our most recent evaluation of internal control over financial reporting, to the registrant's auditors and the audit committee of the registrant's board of directors (or persons performing the equivalent functions):

(a)

All significant deficiencies and material weaknesses in the design or operation of internal control over financial reporting which are reasonably likely to adversely affect the registrant's ability to record, process, summarize and report financial information; and

(b)

Any fraud, whether or not material, that involves management or other employees who have a significant role in the registrant's internal control over financial reporting.

/s/ Gary J. Wolter

Gary J. Wolter

Chairman, President and Chief Executive Officer

Date: May 7, 2012

EX-31

EXHIBIT 31.2

Certification Pursuant to Rule 13a-14(a) and 15d-14(a) of the Securities Exchange Act of 1934

I, Jeffrey C. Newman, certify that:

1.

I have reviewed this quarterly report on Form 10-Q of MGE Energy, Inc.;

2.

Based on my knowledge, this report does not contain any untrue statement of a material fact or omit to state a material fact necessary to make the statements made, in light of the circumstances under which such statements were made, not misleading with respect to the period covered by this report;

3.

Based on my knowledge, the financial statements, and other financial information included in this report, fairly present in all material respects the financial condition, results of operations and cash flows of the registrant as of, and for, the periods presented in this report;

4.

The registrant's other certifying officer and I are responsible for establishing and maintaining disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) and internal control over financial reporting (as defined in Exchange Act Rules 13a-15(f) and 15d-15(f)) for the registrant and have:

(a)

Designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be designed under our supervision, to ensure that material information relating to the registrant, including its consolidated subsidiaries, is made known to us by others within those entities, particularly during the period in which this report is being prepared;

(b)

Designed such internal control over financial reporting, or caused such internal control over financial reporting to be designed under our supervision, to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles;

(c)

Evaluated the effectiveness of the registrant's disclosure controls and procedures and presented in this report our conclusions about the effectiveness of the disclosure controls and procedures, as of the end of the period covered by this report based on such evaluation; and

(d)

Disclosed in this report any change in the registrant's internal control over financial reporting that occurred during the registrant's most recent fiscal quarter (the registrant's fourth fiscal quarter in the case of an annual report) that has materially affected, or is reasonably likely to materially affect, the registrant's internal control over financial reporting; and

5.

The registrant's other certifying officer and I have disclosed, based on our most recent evaluation of internal control over financial reporting, to the registrant's auditors and the audit committee of the registrant's board of directors (or persons performing the equivalent functions):

(a)

All significant deficiencies and material weaknesses in the design or operation of internal control over financial reporting which are reasonably likely to adversely affect the registrant's ability to record, process, summarize and report financial information; and

(b)

Any fraud, whether or not material, that involves management or other employees who have a significant role in the registrant's internal control over financial reporting.

/s/ Jeffrey C. Newman

Jeffrey C. Newman

Vice President, Chief Financial Officer,

Secretary and Treasurer

Date: May 7, 2012

EX-31

EXHIBIT 31.3

Certification Pursuant to Rule 13a-14(a) and 15d-14(a) of the Securities Exchange Act of 1934

I, Gary J. Wolter, certify that:

1.

I have reviewed this quarterly report on Form 10-Q of Madison Gas and Electric Company;

2.

Based on my knowledge, this report does not contain any untrue statement of a material fact or omit to state a material fact necessary to make the statements made, in light of the circumstances under which such statements were made, not misleading with respect to the period covered by this report;

3.

Based on my knowledge, the financial statements, and other financial information included in this report, fairly present in all material respects the financial condition, results of operations and cash flows of the registrant as of, and for, the periods presented in this report;

4.

The registrant's other certifying officer and I are responsible for establishing and maintaining disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) and internal control over financial reporting (as defined in Exchange Act Rules 13a-15(f) and 15d-15(f)) for the registrant and have:

(a)

Designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be designed under our supervision, to ensure that material information relating to the registrant, including its consolidated subsidiaries, is made known to us by others within those entities, particularly during the period in which this report is being prepared;

(b)

Designed such internal control over financial reporting, or caused such internal control over financial reporting to be designed under our supervision, to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles;

(c)

Evaluated the effectiveness of the registrant's disclosure controls and procedures and presented in this report our conclusions about the effectiveness of the disclosure controls and procedures, as of the end of the period covered by this report based on such evaluation; and

(d)

Disclosed in this report any change in the registrant's internal control over financial reporting that occurred during the registrant's most recent fiscal quarter (the registrant's fourth fiscal quarter in the case of an annual report) that has materially affected, or is reasonably likely to materially affect, the registrant's internal control over financial reporting; and

5.

The registrant's other certifying officer and I have disclosed, based on our most recent evaluation of internal control over financial reporting, to the registrant's auditors and the audit committee of the registrant's board of directors (or persons performing the equivalent functions):

(a)

All significant deficiencies and material weaknesses in the design or operation of internal control over financial reporting which are reasonably likely to adversely affect the registrant's ability to record, process, summarize and report financial information; and

(b)

Any fraud, whether or not material, that involves management or other employees who have a significant role in the registrant's internal control over financial reporting.

/s/ Gary J. Wolter

Gary J. Wolter

Chairman, President and Chief Executive Officer

Date: May 7, 2012

EX-31

EXHIBIT 31.4

Certification Pursuant to Rule 13a-14(a) and 15d-14(a) of the Securities Exchange Act of 1934

I, Jeffrey C. Newman, certify that:

1.

I have reviewed this quarterly report on Form 10-Q of Madison Gas and Electric Company;

2.

Based on my knowledge, this report does not contain any untrue statement of a material fact or omit to state a material fact necessary to make the statements made, in light of the circumstances under which such statements were made, not misleading with respect to the period covered by this report;

3.

Based on my knowledge, the financial statements, and other financial information included in this report, fairly present in all material respects the financial condition, results of operations and cash flows of the registrant as of, and for, the periods presented in this report;

4.

The registrant's other certifying officer and I are responsible for establishing and maintaining disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) and internal control over financial reporting (as defined in Exchange Act Rules 13a-15(f) and 15d-15(f)) for the registrant and have:

(a)

Designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be designed under our supervision, to ensure that material information relating to the registrant, including its consolidated subsidiaries, is made known to us by others within those entities, particularly during the period in which this report is being prepared;

(b)

Designed such internal control over financial reporting, or caused such internal control over financial reporting to be designed under our supervision, to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles;

(c)

Evaluated the effectiveness of the registrant's disclosure controls and procedures and presented in this report our conclusions about the effectiveness of the disclosure controls and procedures, as of the end of the period covered by this report based on such evaluation; and

(d)

Disclosed in this report any change in the registrant's internal control over financial reporting that occurred during the registrant's most recent fiscal quarter (the registrant's fourth fiscal quarter in the case of an annual report) that has materially affected, or is reasonably likely to materially affect, the registrant's internal control over financial reporting; and

5.

The registrant's other certifying officer and I have disclosed, based on our most recent evaluation of internal control over financial reporting, to the registrant's auditors and the audit committee of the registrant's board of directors (or persons performing the equivalent functions):

(a)

All significant deficiencies and material weaknesses in the design or operation of internal control over financial reporting which are reasonably likely to adversely affect the registrant's ability to record, process, summarize and report financial information; and

(b)

Any fraud, whether or not material, that involves management or other employees who have a significant role in the registrant's internal control over financial reporting.

/s/ Jeffrey C. Newman

Jeffrey C. Newman

Vice President, Chief Financial Officer,

Secretary and Treasurer

Date: May 7, 2012

EX-32

EXHIBIT 32.1

Certification Pursuant to 18 U.S.C. Section 1350,

as Adopted Pursuant to Section 906 of the Sarbanes-Oxley Act of 2002

In connection with the quarterly report on Form 10-Q of MGE Energy, Inc. (the "Company"), for the period ended March 31, 2012, as filed with the Securities and Exchange Commission on the date hereof ("the Report"), I, Gary J. Wolter, Chief Executive Officer of the Company, certify, pursuant to 18 U.S.C. Section 1350, as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002, that:

1.

The Report fully complies with the requirements of Section 13(a) or 15(d) of the Securities Exchange Act of 1934, and

2.

The information contained in the Report fairly presents, in all material respects, the financial condition and results of operations of the Company.

/s/ Gary J. Wolter

Gary J. Wolter

Chairman, President and Chief Executive Officer

Date: May 7, 2012

EX-32

EXHIBIT 32.2

Certification Pursuant to 18 U.S.C. Section 1350,

as Adopted Pursuant to Section 906 of the Sarbanes-Oxley Act of 2002

In connection with the quarterly report on Form 10-Q of MGE Energy, Inc. (the "Company"), for the period ended March 31, 2012, as filed with the Securities and Exchange Commission on the date hereof ("the Report"), I, Jeffrey C. Newman, Chief Financial Officer of the Company, certify, pursuant to 18 U.S.C. Section 1350, as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002, that:

1.

The Report fully complies with the requirements of Section 13(a) or 15(d) of the Securities Exchange Act of 1934, and

2.

The information contained in the Report fairly presents, in all material respects, the financial condition and results of operations of the Company.

/s/ Jeffrey C. Newman

Jeffrey C. Newman

Vice President, Chief Financial Officer,

Secretary and Treasurer

Date: May 7, 2012

EX-32

EXHIBIT 32.3

Certification Pursuant to 18 U.S.C. Section 1350,

as Adopted Pursuant to Section 906 of the Sarbanes-Oxley Act of 2002

In connection with the quarterly report on Form 10-Q of Madison Gas and Electric Company (the "Company"), for the period ended March 31, 2012, as filed with the Securities and Exchange Commission on the date hereof ("the Report"), I, Gary J. Wolter, Chief Executive Officer of the Company, certify, pursuant to 18 U.S.C. Section 1350, as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002, that:

1.

The Report fully complies with the requirements of Section 13(a) or 15(d) of the Securities Exchange Act of 1934, and

2.

The information contained in the Report fairly presents, in all material respects, the financial condition and results of operations of the Company.

/s/ Gary J. Wolter

Gary J. Wolter

Chairman, President and Chief Executive Officer

Date: May 7, 2012

EX-32

EXHIBIT 32.4

Certification Pursuant to 18 U.S.C. Section 1350,

as Adopted Pursuant to Section 906 of the Sarbanes-Oxley Act of 2002

In connection with the quarterly report on Form 10-Q of Madison Gas and Electric Company (the "Company"), for the period ended March 31, 2012, as filed with the Securities and Exchange Commission on the date hereof ("the Report"), I, Jeffrey C. Newman, Chief Financial Officer of the Company, certify, pursuant to 18 U.S.C. Section 1350, as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002, that:

1.

The Report fully complies with the requirements of Section 13(a) or 15(d) of the Securities Exchange Act of 1934, and

2.

The information contained in the Report fairly presents, in all material respects, the financial condition and results of operations of the Company.

/s/ Jeffrey C. Newman

Jeffrey C. Newman

Vice President, Chief Financial Officer,

Secretary and Treasurer

Date: May 7, 2012

XML

Taxes (Details) (USD $) In Millions, unless otherwise specified	3 Months Ended
	Mar. 31, 2012	Mar. 31, 2011	Dec. 31, 2011
Unrecognized tax benefits that would impact effective tax rate [Abstract]
Total unrecognized tax benefit	$ 2.7		$ 2.4
Effective income tax rate [Line Items]
Effective income tax rate	38.10%	37.50%
MGE [Member]
Effective income tax rate [Line Items]
Effective income tax rate	38.10%	37.50%

XML

Fair Value of Financial Instruments (Details-1) (USD $) In Thousands, unless otherwise specified	3 Months Ended
	Mar. 31, 2012	Mar. 31, 2012 Maximum [Member]	Mar. 31, 2012 Minimum [Member]	Mar. 31, 2012 Carrying Amount [Member]	Dec. 31, 2011 Carrying Amount [Member]	Mar. 31, 2012 Fair Value [Member]	Dec. 31, 2011 Fair Value [Member]	Mar. 31, 2012 MGE [Member] Carrying Amount [Member]	Dec. 31, 2011 MGE [Member] Carrying Amount [Member]	Mar. 31, 2012 MGE [Member] Fair Value [Member]	Dec. 31, 2011 MGE [Member] Fair Value [Member]
Assets:
Cash and cash equivalents				$ 40,660	$ 41,169	$ 40,660	$ 41,169	$ 14,659	$ 13,898	$ 14,659	$ 13,898
Liabilities:
Long-term debt				$ 363,806	$ 364,473	$ 424,359	$ 432,515	$ 363,806	$ 364,473	$ 424,359	$ 432,515
Significant unobservable inputs [Line Items]
Basis adjustment - on peak	95.80%
Basis adjustment - off peak	95.40%
Counterparty fuel mix [Abstract]
Internal generation		65.00%	49.00%
Purchased power		51.00%	35.00%

XML

Derivative and Hedging Instruments (Details-3) (USD $)			3 Months Ended
	Mar. 31, 2012	Dec. 31, 2011	Mar. 31, 2012 Commodity Derivative Contracts [Member] Regulated Gas Revenues [Member]	Mar. 31, 2011 Commodity Derivative Contracts [Member] Regulated Gas Revenues [Member]	Mar. 31, 2012 Commodity Derivative Contracts [Member] Fuel For Electric Generation Purchased Power [Member]	Mar. 31, 2011 Commodity Derivative Contracts [Member] Fuel For Electric Generation Purchased Power [Member]	Mar. 31, 2012 Commodity Derivative Contracts [Member] Cost Of Gas Sold Expense [Member]	Mar. 31, 2011 Commodity Derivative Contracts [Member] Cost Of Gas Sold Expense [Member]	Mar. 31, 2012 Financial Transmission Rights [Member] Regulated Gas Revenues [Member]	Mar. 31, 2011 Financial Transmission Rights [Member] Regulated Gas Revenues [Member]	Mar. 31, 2012 Financial Transmission Rights [Member] Fuel For Electric Generation Purchased Power [Member]	Mar. 31, 2011 Financial Transmission Rights [Member] Fuel For Electric Generation Purchased Power [Member]	Mar. 31, 2012 Financial Transmission Rights [Member] Cost Of Gas Sold Expense [Member]	Mar. 31, 2011 Financial Transmission Rights [Member] Cost Of Gas Sold Expense [Member]	Mar. 31, 2012 Purchased Power Agreement [Member] Regulated Gas Revenues [Member]	Mar. 31, 2011 Purchased Power Agreement [Member] Regulated Gas Revenues [Member]	Mar. 31, 2012 Purchased Power Agreement [Member] Fuel For Electric Generation Purchased Power [Member]	Mar. 31, 2011 Purchased Power Agreement [Member] Fuel For Electric Generation Purchased Power [Member]	Mar. 31, 2012 Purchased Power Agreement [Member] Cost Of Gas Sold Expense [Member]	Mar. 31, 2011 Purchased Power Agreement [Member] Cost Of Gas Sold Expense [Member]
Realized losses (gains) on income statement [Line Items]
Realized losses (gains) on income statement			$ 0	$ 0	$ 1,928,000	$ 254,000	$ 3,090,000	$ 1,315,000	$ 0	$ 0	$ 66,000	$ (63,000)	$ 0	$ 0	$ 0	$ 0	$ 0	$ 0	$ 0	$ 0
Derivative collateral required to be posted for ten-year PPA [Abstract]
Minimum collateral required	20,000,000
Maximum collateral required	40,000,000
Counterparties in net liability position [Abstract]
Counterparties in net liability position	$ 400,000	$ 0

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Fair Value of Financial Instruments (Tables)

3 Months Ended

Mar. 31, 2012

Fair Value of Financial Instruments (Tables) [Abstract]

Estimated Fair Market Value of Financial Instruments

		March 31, 2012				December 31, 2011
		Carrying		Fair		Carrying		Fair
(In thousands)		Amount		Value		Amount		Value
MGE Energy
Assets:
Cash and cash equivalents	$	40,660	$	40,660	$	41,169	$	41,169
Liabilities:
Long-term debt*		363,806		424,359		364,473		432,515
MGE
Assets:
Cash and cash equivalents		14,659		14,659		13,898		13,898
Liabilities:
Long-term debt*		363,806		424,359		364,473		432,515
*Includes long-term debt due within one year.

Assets and Liabilities Measured at Fair Value on a Recurring Basis

	Fair Value as of March 31, 2012
(In thousands)		Total		Level 1		Level 2		Level 3
MGE Energy
Assets:
Exchange-traded investments	$	361	$	361	$	0	$	0
Total Assets	$	361	$	361	$	0	$	0
Liabilities:
Derivatives, net(a)	$	71,514	$	326	$	0	$	71,188
Deferred compensation		1,771		0		1,771		0
Total Liabilities	$	73,285	$	326	$	1,771	$	71,188
MGE
Assets:
Exchange-traded investments	$	162	$	162	$	0	$	0
Total Assets	$	162	$	162	$	0	$	0
Liabilities:
Derivatives, net(a)	$	71,514	$	326	$	0	$	71,188
Deferred compensation		1,771		0		1,771		0
Total Liabilities	$	73,285	$	326	$	1,771	$	71,188
(a)     These amounts are shown gross and exclude $2.0 million of collateral that was posted
against derivative positions with counterparties.
No transfers were made in or out of Level 1 or Level 2 for the three months ended March 31, 2012.
	Fair Value as of December 31, 2011
(In thousands)		Total		Level 1		Level 2		Level 3
MGE Energy
Assets:
Exchange-traded investments	$	350	$	350	$	0	$	0
Total Assets	$	350	$	350	$	0	$	0
Liabilities:
Derivatives, net(b)	$	42,356	$	1,695	$	0	$	40,661
Deferred compensation(c)		1,725		0		1,725		0
Total Liabilities	$	44,081	$	1,695	$	1,725	$	40,661
MGE
Assets:
Exchange-traded investments	$	188	$	188	$	0	$	0
Total Assets	$	188	$	188	$	0	$	0
Liabilities:
Derivatives, net(b)	$	42,356	$	1,695	$	0	$	40,661
Deferred compensation(c)		1,725		0		1,725		0
Total Liabilities	$	44,081	$	1,695	$	1,725	$	40,661
(b)     These amounts are shown gross and exclude $3.0 million of collateral that was posted
against derivative positions with counterparties.
(c)     The deferred compensation liability at December 31, 2011, was transferred from Level 1
to Level 2.

Significant Unobservable Inputs

Significant Unobservable Inputs	Model Input
Basis adjustment
On peak	95.8%
Off peak	95.4%
Counterparty fuel mix:
Internal generation	49 % - 65 %
Purchased power	51 % - 35 %

Changes in Level 3 Assets and Liabilities Measured at Fair Value on a Recurring Basis

		Three Months Ended
(In thousands)		March 31,
		2012		2011
Beginning balance,	$	(40,661)	$	(19,216)
Realized and unrealized gains (losses):
Included in regulatory liabilities (assets)		(30,527)		(2,932)
Included in other comprehensive income		0		0
Included in earnings		(1,502)		(8)
Included in current assets		(50)		0
Purchases		50		0
Sales		31		71
Issuances		0		0
Settlements		1,471		(63)
Transfers in and/or out of Level 3		0		0
Balance as of March 31,	$	(71,188)	$	(22,148)
Total gains (losses) included in earnings attributed to
the change in unrealized gains (losses) related to
assets and liabilities held at March 31,(d)	$	0	$	0

Gains and Losses Included in Income for Level 3 Assets and Liabilities Measured at Fair Value on a Recurring Basis

		Three Months Ended
(In thousands)		March 31,
		2012		2011
Purchased Power Expense	$	(1,502)	$	(8)
Cost of Gas Sold Expense		0		0
Regulated Gas Revenues		0		0
Total	$	(1,502)	$	(8)

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New Accounting Pronouncements

3 Months Ended

Mar. 31, 2012

New Accounting Pronouncements Disclosure [Abstract]

New Accounting Pronouncements

12.       New Accounting Pronouncements - MGE Energy and MGE.

a.       Fair Value Measurements and Disclosures.

In May 2011, the FASB issued authoritative guidance within the Codification's Fair Value Measurements and Disclosures topic that provides guidance on additional disclosures about fair value measurements, specifically related to Level 3 assets and liabilities. This authoritative guidance became effective January 1, 2012. The authoritative guidance did not have anyfinancial impact, but required additional disclosures. See Footnote 11 for additional information.

b.       Presentation of Comprehensive Income.

In June 2011, the FASB issued authoritative guidance within the Codification's Comprehensive Income topic that provides guidance on presentation of comprehensive income. Comprehensive income will be presented either in a single continuous statement of comprehensive income or in two separate but consecutive statements. This authoritative guidance became effective January 1, 2012.The authoritative guidance had an effect on our financial statement presentation of comprehensive income. See the Statement of Comprehensive Income for additional information.

c.       Disclosures about Offsetting Assets and Liabilities.

In December 2011, the FASB issued authoritative guidance within the Codification's Balance Sheet topic that provides guidance on disclosures about offsetting assets and liabilities. The new disclosure requirements mandate that entities disclose both gross and net information for instruments and transactions eligible for offset in the balance sheet as well as instruments and transactions subject to a master netting arrangement. In addition, the standard requires disclosure of collateral received and posted in connections with a master netting arrangement. This authoritative guidance will become effective January 1, 2013. The authoritative guidance will not have a financial impact, but will require additional disclosures.

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Fair Value of Financial Instruments (Details-3) (USD $) In Thousands, unless otherwise specified	3 Months Ended
	Mar. 31, 2012	Mar. 31, 2011
Changes in level 3 assets and liabilities measured at fair value on a recurring basis [Abstract]
Beginning balance,	$ (40,661)	$ (19,216)
Realized and unrealized gains (losses):
Included in regulatory liabilities (assets)	(30,527)	(2,932)
Included in other comprehensive income	0	0
Included in earnings	(1,502)	(8)
Included in current assets	(50)	0
Purchases	50	0
Sales	31	71
Issuances	0	0
Settlements	1,471	(63)
Transfers in or out of level 3	0	0
Ending balance,	(71,188)	(22,148)
Total gains (losses) included in earnings attributed to the change in unrealized gains (losses) related to assets and liabilities	0	0
Realized and unrealized gains (losses) included in income for level 3 instruments [Line Items]
Realized and unrealized gains (losses) included in income for level 3 instruments.	(1,502)	(8)
Regulated Gas Revenues [Member]
Realized and unrealized gains (losses) included in income for level 3 instruments [Line Items]
Realized and unrealized gains (losses) included in income for level 3 instruments.	0	0
Purchased Power Expense [Member]
Realized and unrealized gains (losses) included in income for level 3 instruments [Line Items]
Realized and unrealized gains (losses) included in income for level 3 instruments.	(1,502)	(8)
Cost Of Gas Sold Expense [Member]
Realized and unrealized gains (losses) included in income for level 3 instruments [Line Items]
Realized and unrealized gains (losses) included in income for level 3 instruments.	$ 0	$ 0

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Commitments and Contingencies (Details-1) (USD $)	3 Months Ended
	Mar. 31, 2012 MW
Air Quality Regulations [Abstract]
Minimum capacity to be regulated by CSAPR/CAIR - MW	25
CAIR phase one emission reductions for NOx	55.00%
CAIR phase one emission reductions for SO2	40.00%
CAIR phase two emission reductions for NOx	65.00%
CAIR phase two emission reductions for SO2	70.00%
Coal-fired electric generating units - MW requirement	150
Minimum amount of fleet-wide mercury reduction in Wisconsin - Phase two	90.00%
Columbia Clean Air Act Litigation [Abstract]
Columbia Clean Air Act litigation civil penalties	$ 37,500
Columbia Environmental Project [Member]
Expected Capital Expenditures [Line Items]
MGE's share of expected capital expenditures	140,000,000
Columbia Commitments [Abstract]
Columbia environmental project commitments	$ 109,700,000
Columbia Units [Member]
Columbia Units [Line Items]
Generating capability - MW	225
Columbia's share of MGE's net generating capability	29.00%
Ownership interest in jointly owned plant	22.00%
WPL ownership interest of Columbia	46.20%
WPSC ownership interest of Columbia	31.80%

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Investment in ATC (Details-2) (ATC [Member], USD $) In Thousands, unless otherwise specified	3 Months Ended
	Mar. 31, 2012	Mar. 31, 2011
ATC [Member]
Equity method investment summarized income statement [Line Items]
Operating revenues	$ 147,662	$ 139,617
Operating expenses	(69,566)	(63,126)
Other expense, net	(500)	(358)
Interest expense, net	(19,501)	(21,897)
Earnings before members' income taxes	$ 58,095	$ 54,236

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Subsequent Events (Details) (USD $)	3 Months Ended		4 Months Ended		3 Months Ended
	Mar. 31, 2012	Mar. 31, 2011	Apr. 30, 2012 ATC Capital Contribution [Member] Mge Transco [Member]	Apr. 02, 2012 Issuance of Debt [Member]	Apr. 03, 2012 Repayment of Debt [Member]	Apr. 02, 2012 Debt Conversion [Member]
ATC capital contribution [Abstract]
Subsequent Event, Description			On April 30, 2012, MGE Transco made a voluntary $0.5 million capital contribution to ATC.
Contributions to ATC	$ 355,000	$ 425,000	$ 500,000
Debt Instruments [Abstract]
Unsecured debt				28,000,000
Interest rate on secured long-term debt				4.38%	5.875%
Redeemed and retired debt					28,000,000
Extinguishment at percent of principal					100.00%	100.00%
Tax exempt debt						$ 19,300,000
Interest rate before remarketing						4.875%
Interest rate after remarketing						3.45%
Extinguishment at percent of principal					100.00%	100.00%

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Rate Matters (Details) (USD $) In Millions, unless otherwise specified	12 Months Ended
	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011	Mar. 31, 2012
Rate Proceedings [Abstract]
Authorized percentage increase (decrease) for electric		4.30%	2.30%
Authorized rate increase (decrease) for electric		$ 15.7	$ 8.0
Authorized percentage increase (decrease) for gas		0.30%	1.00%
Authorized rate increase (decrease) for gas		0.6	1.9
Fuel rules bandwidth			2.00%
Authorized return on common stock			10.30%
Utility common equity			58.10%
Proposed percent increase (decrease) for electric	5.80%
Proposed percent increase (decrease) for gas	2.60%
Fuel Rules [Abstract]
Electric fuel deferred costs upper threshold		102.00%
Electric fuel deferred costs lower threshold		98.00%
Increased electric fuel costs deferred				0
Purchased Gas Adjustment [Abstract]
Purchased gas adjustment over collected			$ 0.9	$ 3.3

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Consolidated Balance Sheets (Unaudited) (USD $) In Thousands, unless otherwise specified	Mar. 31, 2012		Dec. 31, 2011
Current Assets:
Cash and cash equivalents	$ 40,660		$ 41,169
Receivable - margin account	2,500		2,477
Accounts receivable, less reserves	38,090	[1]	36,744	[2]
Other accounts receivables, less reserves	4,500	[3]	5,318	[4]
Unbilled revenues	20,706		25,754
Materials and supplies, at average cost	16,047		14,758
Fossil fuel	8,238		5,468
Stored natural gas, at average cost	10,385		19,575
Prepaid taxes	20,118		22,251
Regulatory assets - current	10,665		7,347
Other current assets	7,095		8,270
Total Current Assets	179,004		189,131
Regulatory assets	228,162		205,835
Other deferred assets and other	7,011		8,018
Property, Plant, and Equipment:
Property, plant, and equipment, net	966,069		961,511
Construction work in progress	40,854		34,055
Total Property, Plant, and Equipment	1,006,923		995,566
Investments	61,197		60,332
Total Assets	1,482,297		1,458,882
Current Liabilities:
Long-term debt due within one year	2,667		2,667
Accounts payable	32,000		34,532
Accrued interest and taxes	4,542		4,085
Accrued payroll related items	7,895		9,987
Deferred income taxes	862		3,020
Derivative liabilities	8,198		4,568
Other current liabilities	6,047		4,215
Total Current Liabilities	62,211		63,074
Other Credits:
Deferred income taxes	210,999		199,850
Investment tax credit - deferred	1,715		1,780
Regulatory liabilities	18,387		20,463
Accrued pension and other postretirement benefits	165,304		183,622
Derivative liabilities	60,880		34,908
Other deferred liabilities and other	44,388		43,330
Total Other Credits	501,673		483,953
Capitalization:
Common shareholders equity	558,164		550,952
Long-term debt	360,249		360,903
Total Capitalization	918,413		911,855
Commitments and contingencies (see Footnote 8)	0		0
Total Liabilities and Capitalization	1,482,297		1,458,882
MGE [Member]
Current Assets:
Cash and cash equivalents	14,659		13,898
Receivable - margin account	2,500		2,477
Accounts receivable, less reserves	37,088	[1]	35,765	[2]
Affiliate receivables	609		605
Other accounts receivables, less reserves	4,486	[3]	5,301	[4]
Unbilled revenues	20,706		25,754
Materials and supplies, at average cost	16,047		14,758
Fossil fuel	8,238		5,468
Stored natural gas, at average cost	10,385		19,575
Prepaid taxes	20,685		21,977
Regulatory assets - current	10,665		7,347
Other current assets	7,080		8,245
Total Current Assets	153,148		161,170
Affiliate receivable long-term	6,751		6,884
Regulatory assets	228,162		205,835
Other deferred assets and other	6,502		7,286
Property, Plant, and Equipment:
Property, plant, and equipment, net	965,565		961,007
Construction work in progress	40,854		34,055
Total Property, Plant, and Equipment	1,006,419		995,062
Investments	58,386		57,556
Total Assets	1,459,368		1,433,793
Current Liabilities:
Long-term debt due within one year	2,667		2,667
Accounts payable	32,000		34,532
Affiliate payables	1,822		2,152
Accrued interest and taxes	4,495		4,037
Accrued payroll related items	7,895		9,987
Deferred income taxes	927		3,020
Derivative liabilities	8,198		4,568
Other current liabilities	5,798		3,997
Total Current Liabilities	63,802		64,960
Other Credits:
Deferred income taxes	207,541		196,550
Investment tax credit - deferred	1,715		1,780
Regulatory liabilities	18,387		20,463
Accrued pension and other postretirement benefits	165,304		183,622
Derivative liabilities	60,880		34,908
Other deferred liabilities and other	44,388		43,330
Total Other Credits	498,215		480,653
Capitalization:
Common shareholders equity	416,324		412,926
Noncontrolling interest	120,778		114,351
Total Equity	537,102		527,277
Long-term debt	360,249		360,903
Total Capitalization	897,351		888,180
Commitments and contingencies (see Footnote 8)	0		0
Total Liabilities and Capitalization	$ 1,459,368		$ 1,433,793

[1] less reserves of $3,775

[2] less reserves of $3,662

[3] less reserves of $636

[4] less reserves of $439

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Commitments and Contingencies (Details-2) (USD $)	3 Months Ended
	Mar. 31, 2012
Chattel Paper Purchase Agreement [Abstract]
Chattel paper purchase agreement maximum interest	$ 10,000,000
Outstanding interest in chattel paper receivables	4,200,000
Servicing asset recognized	200,000
Smart Grid Investment Grant [Abstract]
Smart Grid grant approval amount	5,500,000
Total cost of proposed projects	11,000,000
Smart grid expenditures to date	6,800,000
Investment Capital Contribution Commitment [Abstract]
Capital contribution commitment	2,000,000
One Year From Balance Sheet Date [Member]
Chattel Paper Agreement Principal Payments [Abstract]
Chattel paper agreement principal payments commitments	422,000
Smart Grid Investment Grant [Abstract]
Smart grid commitments to date	800,000
More Than One And Within Two Years From Balance Sheet Date [Member]
Chattel Paper Agreement Principal Payments [Abstract]
Chattel paper agreement principal payments commitments	646,000
More Than Two And Within Three Years From Balance Sheet Date [Member]
Chattel Paper Agreement Principal Payments [Abstract]
Chattel paper agreement principal payments commitments	461,000
More Than Three And Within Four Years From Balance Sheet Date [Member]
Chattel Paper Agreement Principal Payments [Abstract]
Chattel paper agreement principal payments commitments	772,000
More Than Four And Within Five Years From Balance Sheet Date [Member]
Chattel Paper Agreement Principal Payments [Abstract]
Chattel paper agreement principal payments commitments	$ 695,000

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Investment in ATC (Tables)

3 Months Ended

Mar. 31, 2012

Investment in ATC (Tables) [Abstract]

ATC's Summarized Financial Data

		Three Months Ended
(In thousands)		March 31,
		2012		2011
Operating revenues	$	147,662	$	139,617
Operating expenses		(69,566)		(63,126)
Other expense, net		(500)		(358)
Interest expense, net		(19,501)		(21,897)
Earnings before members' income taxes	$	58,095	$	54,236

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Significant Accounting Policies (Policies)

3 Months Ended

Mar. 31, 2012

Significant Accounting Policies [Abstract]

Basis of Presentation

MGE Power Elm Road and MGE Power West Campus own electric generating assets and lease those assets to MGE. Both entities are variable interest entities under applicable authoritative guidance. MGE is considered the primary beneficiary of these entities as a result of contractual agreements. As a result, MGE has consolidated MGE Power Elm Road and MGE Power West Campus.

Share-based Compensation

In addition to units granted in 2008 through 2011, on February 17, 2012, 16,693 units were granted based on the MGE Energy closing stock price as of that date. These units are subject to a five-year graded vesting schedule. On the grant date, MGE Energy and MGE measure the cost of the employee services received in exchange for the award based on the current market value of MGE Energy common stock. The fair value of the awards has been subsequently re-measured at March 31, 2012, as required by applicable accounting standards. Changes in fair value have been recognized as compensation cost. Since this amount is re-measured quarterly throughout the vesting period, the compensation cost is subject to variability.

For nonretirement eligible employees, stock based compensation costs are accrued and recognized using the graded vesting method. Compensation cost for retirement eligible employees or employees that will become retirement eligible during the vesting schedule are recognized on an abridged horizon.

Derivative Hedging

As part of its regular operations, MGE enters into contracts, including options, swaps, futures, forwards, and other contractual commitments, to manage its exposure to commodity prices and gas revenues. To the extent that these contracts are derivatives, MGE assesses whether or not the normal purchases or normal sales exclusion applies. For contracts to which this exclusion cannot be applied, MGE Energy and MGE recognize such derivatives in the consolidated balance sheets at fair value. The majority of MGE's derivative activities are conducted in accordance with its electric and gas risk management program, which is approved by the PSCW and limits the volume MGE can hedge with specific risk management strategies. The maximum length of time over which cash flows related to energy commodities can be hedged is four years. If the derivative qualifies for regulatory deferral, the derivatives are marked to fair value and are offset with a corresponding regulatory asset or liability. The deferred gain or loss is recognized in earnings in the delivery month applicable to the instrument. Gains and losses related to hedges qualifying for regulatory treatment are recoverable in gas rates through the PGA or in electric rates as a component of the fuel rules mechanism.

Derivative Netting

All derivative instruments in this table are presented on a gross basis and are calculated prior to the netting of instruments with the same counterparty under a master netting agreement as well as the netting of collateral. For financial statement purposes, MGE Energy and MGE have netted instruments with the same counterparty under a master netting agreement as well as the netting of collateral.

Wisconsin Fuel Rules

The PSCW approved new fuel rules that became effective January 1, 2011. The new rules require the PSCW and Wisconsin utilities to automatically defer electric fuel-related costs that fall outside a symmetrical cost tolerance band. Any over/under recovery of the deferred costs is determined on an annual basis and will be adjusted in future billings to electric retail customers. Under fuel rules, MGE would defer costs, less any excess revenues, if its actual electric fuel costs exceeded 102% of the electric fuel costs allowed in its latest rate order. Excess revenues are defined as revenues in the year in question that provide MGE with a greater return on common equity than authorized by the PSCW in MGE's latest rate order. Conversely, MGE is required to defer the benefit of lower costs if actual electric fuel costs were less than 98% of the electric fuel costs allowed in that order.

Recurring Fair Value Measurements

Investments include exchange-traded investment securities valued using quoted prices on active exchanges and are therefore classified as Level 1.

Derivatives include exchange-traded derivative contracts, over-the-counter party transactions, a ten-year purchased power agreement, and FTRs. Most exchange-traded derivative contracts are valued based on unadjusted quoted prices in active markets and are therefore classified as Level 1. A small number of exchange-traded derivative contracts are valued using quoted market pricing in markets with insufficient volumes and are therefore classified as Level 3. Transactions done with an over-the-counter party are on inactive markets and are therefore classified as Level 3. These transactions are valued based on quoted prices with markets with similar exchange traded transactions. FTRs are priced based upon monthly auction results for identical or similar instruments in a closed market with limited data available and are therefore classified as Level 3.

The ten-year purchased power agreement (see Footnote 9) was valued using an internally-developed pricing model and therefore is classified as Level 3. The model projects future market energy prices and compares those prices to the projected power costs to be incurred under the contract. Inputs to the model require significant management judgment and estimation. Future energy prices are based on a forward power pricing curve using exchange-traded contracts in the electric futures market, where such exchange-traded contracts exist, and upon calculations based on forward gas prices, where such exchange-traded contracts do not exist. A basis adjustment is applied to the market energy price to reflect the price differential between the market price delivery point and the counterparty delivery point. The historical relationship between the delivery points is reviewed and a discount (below 100%) or premium (above 100%) is derived. This comparison is done for both peak times when demand is high and off peak times when demand is low. If the basis adjustment is lowered, the fair value measurement will decrease and if the basis adjustment is increased, the fair value measurement will increase.

The projected power costs anticipated to be incurred under the purchased power agreement are determined using many factors, including historical generating costs, future prices, and expected fuel mix of the counterparty. An increase in the projected fuel costs would result in a decrease in the fair value measurement of the purchased power agreement. A significant input that MGE estimates is the counterparty's fuel mix in determining the projected power cost. MGE also considers the assumptions that market participants would use in valuing the asset or liability. This consideration includes assumptions about market risk such as liquidity, volatility and contract duration. The fair value model uses a discount rate that incorporates discounting, credit, and model risks.

This model is prepared by members of the Energy Supply group. It is reviewed on a quarterly basis by management in Energy Supply and Finance to review the assumptions, inputs and fair value measurements.

The following table presents the significant unobservable inputs used in the pricing model.

Significant Unobservable Inputs	Model Input
Basis adjustment
On peak	95.8%
Off peak	95.4%
Counterparty fuel mix:
Internal generation	49 % - 65 %
Purchased power	51 % - 35 %

The deferred compensation plan allows participants to defer certain cash compensation into a notional investment account. These amounts are included within other deferred liabilities in the balance sheets of MGE Energy and MGE. The notional investments earn interest based upon the semiannual rate of U.S. Treasury Bills having a 26 week maturity increased by 1% compounded monthly with a minimum annual rate of 7%, compounded monthly. The notional investments are based upon observable market data, however since the deferred compensation obligations themselves are not exchanged in an active market they are classified as Level 2.

New Accounting Pronouncements

12.       New Accounting Pronouncements - MGE Energy and MGE.

a.       Fair Value Measurements and Disclosures.

In May 2011, the FASB issued authoritative guidance within the Codification's Fair Value Measurements and Disclosures topic that provides guidance on additional disclosures about fair value measurements, specifically related to Level 3 assets and liabilities. This authoritative guidance became effective January 1, 2012. The authoritative guidance did not have anyfinancial impact, but required additional disclosures. See Footnote 11 for additional information.

b.       Presentation of Comprehensive Income.

In June 2011, the FASB issued authoritative guidance within the Codification's Comprehensive Income topic that provides guidance on presentation of comprehensive income. Comprehensive income will be presented either in a single continuous statement of comprehensive income or in two separate but consecutive statements. This authoritative guidance became effective January 1, 2012.The authoritative guidance had an effect on our financial statement presentation of comprehensive income. See the Statement of Comprehensive Income for additional information.

c.       Disclosures about Offsetting Assets and Liabilities.

In December 2011, the FASB issued authoritative guidance within the Codification's Balance Sheet topic that provides guidance on disclosures about offsetting assets and liabilities. The new disclosure requirements mandate that entities disclose both gross and net information for instruments and transactions eligible for offset in the balance sheet as well as instruments and transactions subject to a master netting arrangement. In addition, the standard requires disclosure of collateral received and posted in connections with a master netting arrangement. This authoritative guidance will become effective January 1, 2013. The authoritative guidance will not have a financial impact, but will require additional disclosures.

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Derivative and Hedging Instruments (Details-1) (USD $)	Mar. 31, 2012 MW MWh Dth	Dec. 31, 2011 MWh Dth MW
Gross notional volume of open derivatives [Abstract]
Commodity derivative contracts - MWh	451,750	482,545
Commodity derivative contracts - Dth	2,970,000	4,030,000
Financial transmission rights - MW	962	2,382
Derivative collateral [Abstract]
Derivative collateral	$ 2,000,000	$ 3,000,000
Derivative fair values [Abstract]
Exchange traded and financial transmission rights	(2,500,000)	(2,800,000)
Purchased power agreement	(69,000,000)	(39,500,000)
Derivative instruments at fair value on the balance sheet [Line Items]
Derivative liability (current)	8,198,000	4,568,000
Derivative liability (long-term)	60,880,000	34,908,000
Commodity Derivative Contracts [Member]
Derivative instruments at fair value on the balance sheet [Line Items]
Other current assets	266,000	177,000
Other defered charges	153,000	92,000
Derivative liability (current)	2,723,000	3,060,000
Derivative liability (long-term)	160,000	231,000
Financial Transmission Rights [Member]
Derivative instruments at fair value on the balance sheet [Line Items]
Other current assets	0	186,000
Derivative liability (current)	40,000	0
Purchased Power Agreement [Member]
Derivative instruments at fair value on the balance sheet [Line Items]
Derivative liability (current)	8,130,000	4,600,000
Derivative liability (long-term)	$ 60,880,000	$ 34,920,000

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Pension and Other Postretirement Plans (Tables)

3 Months Ended

Mar. 31, 2012

Pension and Other Postretirement Plans (Tables) [Abstract]

Net Periodic Benefit Cost

		Three Months Ended
(In thousands)		March 31,
		2012		2011
Pension Benefits
Components of net periodic benefit cost:
Service cost	$	1,823	$	1,540
Interest cost		3,154		3,080
Expected return on assets		(3,818)		(3,531)
Amortization of:
Prior service cost		108		109
Actuarial loss		2,006		946
Net periodic benefit cost	$	3,273	$	2,144
Postretirement Benefits
Components of net periodic benefit cost:
Service cost	$	647	$	487
Interest cost		1,125		982
Expected return on assets		(435)		(396)
Amortization of:
Transition obligation		106		107
Prior service cost		28		27
Actuarial loss		621		111
Net periodic benefit cost	$	2,092	$	1,318

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Commitments and Contingencies (Tables)

3 Months Ended

Mar. 31, 2012

Commitments and Contingencies (Tables) [Abstract]

Chattel Paper Principal Payments

(In thousands)		2012		2013		2014		2015		2016
Chattel Paper	$	422	$	646	$	461	$	772	$	695

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Madison Gas and Electric Company Consolidated Statements of Cash Flows (Unaudited) (USD $) In Thousands, unless otherwise specified	3 Months Ended
	Mar. 31, 2012	Mar. 31, 2011
Items not affecting cash:
Depreciation and amortization	$ 9,624	$ 10,016
Deferred income taxes	8,846	1,622
Provision for doubtful receivables	1,167	1,038
Employee benefit plan expenses	4,682	3,394
Equity earnings in ATC	(2,242)	(2,097)
Other items	660	178
Changes in working capital items:
Decrease in current assets	12,377	29,753
Decrease in current liabilities	(6,631)	(7,279)
Dividend income from ATC	1,740	1,682
Cash contributions to pension and other postretirement plans	(20,789)	(19,188)
Other noncurrent items, net	(746)	1,135
Cash Provided by Operating Activities	24,736	38,037
Investing Activities:
Capital expenditures	(15,467)	(9,843)
Capital contributions to investments	(355)	(425)
Purchase of investment - land	(3)	(1,794)
Other	109	(419)
Cash Used for Investing Activities	(15,716)	(12,481)
Financing Activities:
Cash dividends paid on common stock	(8,843)	(8,670)
Repayment of long-term debt	(667)	(500)
Issuance of long-term debt	0	30,000
Decrease in short-term debt	0	(22,500)
Other	(19)	(311)
Cash Used for Financing Activities	(9,529)	(1,981)
Change in Cash and Cash Equivalents:	(509)	23,575
Cash and cash equivalents at beginning of period	41,169	7,110
Cash and cash equivalents at end of period	40,660	30,685
Significant noncash investing activities [Abstract]
Accrued capital expenditures	4,674	1,146
MGE [Member]
Operating Activities:
Net Income	16,214	17,867
Items not affecting cash:
Depreciation and amortization	9,624	10,016
Deferred income taxes	8,768	1,412
Provision for doubtful receivables	1,005	1,038
Employee benefit plan expenses	4,682	3,394
Equity earnings in ATC	(2,242)	(2,097)
Other items	792	390
Changes in working capital items:
Decrease in current assets	11,542	28,893
Decrease in current liabilities	(6,991)	(7,441)
Dividend income from ATC	1,740	1,682
Cash contributions to pension and other postretirement plans	(20,789)	(19,188)
Other noncurrent items, net	(762)	1,110
Cash Provided by Operating Activities	23,583	37,076
Investing Activities:
Capital expenditures	(15,467)	(9,843)
Capital contributions to investments	(355)	(355)
Other	49	88
Cash Used for Investing Activities	(15,773)	(10,110)
Financing Activities:
Cash dividends paid to parent by MGE	(6,728)	(6,596)
Distributions to parent from noncontrolling interest	0	(33,000)
Equity contribution received by noncontrolling interest	355	356
Repayment of long-term debt	(667)	(500)
Issuance of long-term debt	0	30,000
Decrease in short-term debt	0	(3,500)
Other	(9)	(309)
Cash Used for Financing Activities	(7,049)	(13,549)
Change in Cash and Cash Equivalents:	761	13,417
Cash and cash equivalents at beginning of period	13,898	4,494
Cash and cash equivalents at end of period	14,659	17,911
Significant noncash investing activities [Abstract]
Accrued capital expenditures	$ 4,674	$ 1,146

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Derivative and Hedging Instruments (Tables)

3 Months Ended

Mar. 31, 2012

Derivative and Hedging Instruments (Tables) [Abstract]

Gross Notional Volume of Open Derivatives

	March 31, 2012	December 31, 2011
Commodity derivative contracts	451,750 MWh	482,545 MWh
Commodity derivative contracts	2,970,000 Dth	4,030,000 Dth
FTRs	962 MW	2,382 MW

Fair Value of Derivative Instruments on the Balance Sheet

	Asset Derivatives			Liability Derivatives
(In thousands)	Balance Sheet Location		Fair Value	Balance Sheet Location		Fair Value
March 31, 2012
Commodity derivative contracts	Other current assets	$	266	Derivative liability (current)	$	2,723
Commodity derivative contracts	Other deferred charges		153	Derivative liability (long-term)		160
FTRs	Other current assets		0	Derivative liability (current)		40
Ten-year PPA	N/A		N/A	Derivative liability (current)		8,130
Ten-year PPA	N/A		N/A	Derivative liability (long-term)		60,880
December 31, 2011
Commodity derivative contracts	Other current assets	$	177	Derivative liability (current)	$	3,060
Commodity derivative contracts	Other deferred charges		92	Derivative liability (long-term)		231
FTRs	Other current assets		186	Derivative liability (current)		0
Ten-year PPA	N/A		N/A	Derivative liability (current)		4,600
Ten-year PPA	N/A		N/A	Derivative liability (long-term)		34,920

Derivative Gains and Losses in Balance Sheet

		2012				2011
(In thousands)		Current and long-term regulatory asset		Other current assets		Current and long-term regulatory asset		Other current assets
Three Months Ended March 31:
Balance at January 1,	$	42,356	$	1,604	$	19,230	$	1,411
Change in unrealized loss		33,310		0		3,047		0
Realized loss reclassified to a deferred account		(2,658)		2,658		(663)		663
Realized gain (loss) reclassified to income
statement		(1,494)		(3,590)		63		(1,569)
Balance at March 31,	$	71,514	$	672	$	21,677	$	505

Derivative Gains and Losses in Income Statement

		Realized losses (gains)
				Fuel for electric
		Regulated		generation/		Cost of
(In thousands)		gas revenues		purchased power		gas sold
Three Months Ended March 31, 2012:
Commodity derivative contracts	$	0	$	1,928	$	3,090
FTRs		0		66		0
Ten-year PPA		0		0		0
Three Months Ended March 31, 2011:
Commodity derivative contracts	$	0	$	254	$	1,315
FTRs		0		(63)		0
Ten-year PPA		0		0		0

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Pension and Other Postretirement Plans (Details) (USD $)	3 Months Ended
	Mar. 31, 2012	Mar. 31, 2011
Deferred pension and OPRB costs recovered [Abstract]
Deferred pension and OPRB costs recovered	$ 300,000	$ 700,000
Pension Benefits [Member]
Components of net periodic benefit cost [Line Items]
Service cost	1,823,000	1,540,000
Interest cost	3,154,000	3,080,000
Expected return on assets	(3,818,000)	(3,531,000)
Amortization of:
Prior service cost	108,000	109,000
Actuarial loss	2,006,000	946,000
Net periodic benefit cost	3,273,000	2,144,000
Postretirement Benefits [Member]
Components of net periodic benefit cost [Line Items]
Service cost	647,000	487,000
Interest cost	1,125,000	982,000
Expected return on assets	(435,000)	(396,000)
Amortization of:
Transition obligation	106,000	107,000
Prior service cost	28,000	27,000
Actuarial loss	621,000	111,000
Net periodic benefit cost	$ 2,092,000	$ 1,318,000

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MGE Energy Inc Consolidated Statements of Income (Unaudited) (USD $) In Thousands, except Per Share data, unless otherwise specified	3 Months Ended
	Mar. 31, 2012	Mar. 31, 2011
Operating Revenues:
Regulated electric revenues	$ 89,936	$ 86,007
Regulated gas revenues	57,019	77,437
Nonregulated revenues	2,304	1,161
Total Operating Revenues	149,259	164,605
Operating Expenses:
Fuel for electric generation	8,851	11,049
Purchased power	19,546	17,581
Cost of gas sold	34,845	50,947
Other operations and maintenance	42,949	39,413
Depreciation and amortization	9,624	10,016
Other general taxes	5,000	4,701
Total Operating Expenses	120,815	133,707
Operating Income	28,444	30,898
Other income, net	2,570	2,386
Interest expense, net	(5,104)	(4,850)
Income before income taxes	25,910	28,434
Income tax provision	(9,862)	(10,651)
Net Income	$ 16,048	$ 17,783
Earnings Per Share of Common Stock (basic and diluted)	$ 0.69	$ 0.77
Dividends per share of common stock	$ 0.383	$ 0.375
Average Shares Outstanding (basic and diluted)	23,114	23,114

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Derivative and Hedging Instruments (Details-2) (USD $) In Thousands, unless otherwise specified	3 Months Ended
	Mar. 31, 2012	Mar. 31, 2011
Regulatory Asset [Member]
Unrealized and realized gains (losses) on balance sheet [Line Items]
Beginning balance,	$ 42,356	$ 19,230
Change in unrealized loss (gain)	33,310	3,047
Realized loss reclassified to a deferred account	(2,658)	(663)
Realized gain (loss) reclassified to income statement	(1,494)	63
Ending balance,	71,514	21,677
Other Current Assets [Member]
Unrealized and realized gains (losses) on balance sheet [Line Items]
Beginning balance,	1,604	1,411
Change in unrealized loss (gain)	0	0
Realized loss reclassified to a deferred account	2,658	663
Realized gain (loss) reclassified to income statement	(3,590)	(1,569)
Ending balance,	$ 672	$ 505

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Consolidated Statements of Comprehensive Income (Unaudited) (Parantheticals) (USD $) In Thousands, unless otherwise specified	3 Months Ended
	Mar. 31, 2012	Mar. 31, 2011
Comprehensive Income [Abstract]
Unrealized gain (loss) on available-for-sale securities, taxes	$ 5	$ 48
MGE [Member]
Comprehensive Income [Abstract]
Unrealized gain (loss) on available-for-sale securities, taxes	$ (11)	$ 23

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Equity and Financing Arrangements (Details) (USD $) In Millions, except Share data, unless otherwise specified	3 Months Ended
	Mar. 31, 2012	Mar. 31, 2011
Common Stock Disclosures [Abstract]
Common stock issued during period	0	0
Dilutive Securities [Abstract]
Dilutive Securities	$ 0

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Derivative and Hedging Instruments

3 Months Ended

Mar. 31, 2012

Derivative and Hedging Instruments Disclosure [Abstract]

Derivative and Hedging Instruments

9.       Derivative and Hedging Instruments - MGE Energy and MGE.

a.       Purpose.

As part of its regular operations, MGE enters into contracts, including options, swaps, futures, forwards, and other contractual commitments, to manage its exposure to commodity prices and gas revenues. To the extent that these contracts are derivatives, MGE assesses whether or not the normal purchases or normal sales exclusion applies. For contracts to which this exclusion cannot be applied, MGE Energy and MGE recognize such derivatives in the consolidated balance sheets at fair value. The majority of MGE's derivative activities are conducted in accordance with its electric and gas risk management program, which is approved by the PSCW and limits the volume MGE can hedge with specific risk management strategies. The maximum length of time over which cash flows related to energy commodities can be hedged is four years. If the derivative qualifies for regulatory deferral, the derivatives are marked to fair value and are offset with a corresponding regulatory asset or liability. The deferred gain or loss is recognized in earnings in the delivery month applicable to the instrument. Gains and losses related to hedges qualifying for regulatory treatment are recoverable in gas rates through the PGA or in electric rates as a component of the fuel rules mechanism.

b.       Notional Amounts.

The gross notional volume of open derivatives is as follows:

	March 31, 2012	December 31, 2011
Commodity derivative contracts	451,750 MWh	482,545 MWh
Commodity derivative contracts	2,970,000 Dth	4,030,000 Dth
FTRs	962 MW	2,382 MW

c.       Financial Statement Presentation.

MGE Energy and MGE offset fair value amounts recognized for the right to reclaim collateral (a receivable) or the obligation to return collateral (a payable) against fair value amounts recognized for derivative instruments executed with the same counterparty under a master netting agreement.At March 31, 2012 and December 31, 2011,MGE Energy and MGE had $2.0 million and $3.0 million, respectively,in collateral that was netted against the net derivative positions with counterparties.

MGE purchases and sells exchange-traded and over-the-counter options, swaps, and future contracts. These arrangements are primarily entered into to help stabilize the price risk associated with gas or power purchases. These transactions are employed by both MGE's gas and electric segments. Additionally, as a result of the firm transmission agreements that MGE holds on transmission paths in the MISO and PJM markets,MGE holdsFTRs. An FTR is a financial instrument that entitles the holder to a stream of revenues or charges based on the differences in hourly day-ahead energy prices between two points on the transmission grid. The fair values of these instruments are reflected as a regulatory asset/liability depending on whether they are in a net loss/gain position. Depending on the nature of the instrument, the gain or loss associated with these transactions will be reflected as cost of gas sold, fuel for electric generation, or purchased power expense in the delivery month applicable to the instrument. At March 31, 2012 and December 31,2011, the cost basis of exchange traded derivatives and FTRs exceeded their fair value by $2.5 million and $2.8 million, respectively.

MGE has also entered into a ten-year purchased power agreement that provides MGE with firm capacity and energy during a base term from June 1, 2012, through May 31, 2022. The agreement also allows MGE an option to extend the contract after the base term. The agreement is accounted for as a derivative contract and is recognized at its fair value on the balance sheet. However, the derivative qualifies for regulatory deferral and is recognized with a corresponding regulatory asset or liability depending on whether the fair value is in a loss or gain position. The fair value of the contract at March 31, 2012 and December 31, 2011, reflects a loss position of $69.0 million and $39.5 million, respectively. The actual fuel cost will be recognized in purchased power expense in the month of purchase.

The following table summarizes the fair value of the derivative instruments on the balance sheet. All derivative instruments in this table are presented on a gross basis and are calculated prior to the netting of instruments with the same counterparty under a master netting agreement as well as the netting of collateral. For financial statement purposes, MGE Energy and MGE have netted instruments with the same counterparty under a master netting agreement as well as the netting of collateral.

	Asset Derivatives			Liability Derivatives
(In thousands)	Balance Sheet Location		Fair Value	Balance Sheet Location		Fair Value
March 31, 2012
Commodity derivative contracts	Other current assets	$	266	Derivative liability (current)	$	2,723
Commodity derivative contracts	Other deferred charges		153	Derivative liability (long-term)		160
FTRs	Other current assets		0	Derivative liability (current)		40
Ten-year PPA	N/A		N/A	Derivative liability (current)		8,130
Ten-year PPA	N/A		N/A	Derivative liability (long-term)		60,880
December 31, 2011
Commodity derivative contracts	Other current assets	$	177	Derivative liability (current)	$	3,060
Commodity derivative contracts	Other deferred charges		92	Derivative liability (long-term)		231
FTRs	Other current assets		186	Derivative liability (current)		0
Ten-year PPA	N/A		N/A	Derivative liability (current)		4,600
Ten-year PPA	N/A		N/A	Derivative liability (long-term)		34,920

The following tables summarize the unrealized and realized gains (losses) related to the derivative instruments on the balance sheet at March 31, 2012 and 2011, and the income statement for the three months endedMarch 31, 2012 and 2011(a).

		2012				2011
(In thousands)		Current and long-term regulatory asset		Other current assets		Current and long-term regulatory asset		Other current assets
Three Months Ended March 31:
Balance at January 1,	$	42,356	$	1,604	$	19,230	$	1,411
Change in unrealized loss		33,310		0		3,047		0
Realized loss reclassified to a deferred account		(2,658)		2,658		(663)		663
Realized gain (loss) reclassified to income
statement		(1,494)		(3,590)		63		(1,569)
Balance at March 31,	$	71,514	$	672	$	21,677	$	505

		Realized losses (gains)
				Fuel for electric
		Regulated		generation/		Cost of
(In thousands)		gas revenues		purchased power		gas sold
Three Months Ended March 31, 2012:
Commodity derivative contracts	$	0	$	1,928	$	3,090
FTRs		0		66		0
Ten-year PPA		0		0		0
Three Months Ended March 31, 2011:
Commodity derivative contracts	$	0	$	254	$	1,315
FTRs		0		(63)		0
Ten-year PPA		0		0		0

(a)       MGE's commodity derivative contracts, FTRs, and ten-year PPA are subject to regulatory deferral. These derivatives are marked to fair value and are offset with a corresponding regulatory asset or liability. Realized gains and losses are deferred on the balance sheet and are recognized in earnings in the delivery month applicable to the instrument. As a result of the above described treatment, there are no unrealized gains or losses that flow through earnings.

The ten-year PPA has a provision that may require MGE to post collateral if MGE's debt rating falls below investment grade (i.e., below BBB-) once MGE begins purchasing energy under the contract in 2012. The amount of collateral that it may be required to post varies from $20.0 million to $40.0 million, depending on MGE's nominated capacity amount. Certain counterparties extend MGE a credit limit. If MGE exceeds these limits, the counterparties may require collateral to be posted.As ofMarch 31, 2012, certain counterparties were in a net liability position of $0.4 million. As of December 31,2011,no counterparties were in a net liability position.

Nonperformance of counterparties to the non-exchange traded derivatives could expose MGE to credit loss. However, MGE enters into transactions only with companies that meet or exceed strict credit guidelines, and it monitors these counterparties on an ongoing basis to mitigate nonperformance risk in its portfolio. As of March 31, 2012,no counterparties have defaulted.

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Investment in ATC (Details-1) (USD $)	3 Months Ended				3 Months Ended
	Mar. 31, 2012	Mar. 31, 2011	Mar. 31, 2012 ATC [Member]	Dec. 31, 2011 ATC [Member]	Mar. 31, 2012 ATC [Member] Mge Transco [Member]	Mar. 31, 2011 ATC [Member] Mge Transco [Member]
Equity method investments [Line Items]
Equity earnings from investment in ATC	$ 2,242,000	$ 2,097,000			$ 2,200,000	$ 2,100,000
Dividend income from ATC	1,740,000	1,682,000			1,700,000	1,700,000
Contributions to ATC					400,000	400,000
Investment in ATC			$ 57,800,000	$ 57,000,000

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Fair Value of Financial Instruments

3 Months Ended

Mar. 31, 2012

Fair Value of Financial Instruments Disclosure [Abstract]

Fair Value of Financial Instruments

11.       Fair Value of Financial Instruments - MGE Energy and MGE.

a.       Fair Value of Financial Assets and Liabilities Recorded at the Carrying Amount.

At March 31,2012 and December 31, 2011, the carrying amount of cash, cash equivalents, and outstanding commercial paper approximates fair market value due to the short maturity of those investments and obligations. The estimated fair market value of MGE Energy's and MGE's long-term debt is based on quoted market prices for similar financial instruments at March 31,2012 and December 31, 2011. The estimated fair market value of MGE Energy's and MGE's financial instruments are as follows:

		March 31, 2012				December 31, 2011
		Carrying		Fair		Carrying		Fair
(In thousands)		Amount		Value		Amount		Value
MGE Energy
Assets:
Cash and cash equivalents	$	40,660	$	40,660	$	41,169	$	41,169
Liabilities:
Long-term debt*		363,806		424,359		364,473		432,515
MGE
Assets:
Cash and cash equivalents		14,659		14,659		13,898		13,898
Liabilities:
Long-term debt*		363,806		424,359		364,473		432,515
*Includes long-term debt due within one year.

b.       Recurring Fair Value Measurements.

Fair value is defined as the price that would be received to sell an asset or would be paid to transfer a liability (an exit price) in the principal or most advantageous market for the asset or liability in an orderly transaction between market participants at the measurement date. The standard clarifies that fair value should be based on the assumptions market participants would use when pricing the asset or liability including assumptions about risk. The standard also establishes a three level fair value hierarchy based upon the observability of the assumptions used and requires the use of observable market data when available. The levels are:

Level 1 - Pricing inputs are quoted prices within active markets for identical assets or liabilities.

Level 2 - Pricing inputs are quoted prices within active markets for similar assets or liabilities; quoted prices for identical or similar instruments in markets that are not active; and model-derived valuations that are correlated with or otherwise verifiable by observable market data.

Level 3 - Pricing inputs are unobservable and reflect management's best estimate of what market participants would use in pricing the asset or liability.

The following table presents the balances of assets and liabilities measured at fair value on a recurring basis for MGE Energy and MGE.

	Fair Value as of March 31, 2012
(In thousands)		Total		Level 1		Level 2		Level 3
MGE Energy
Assets:
Exchange-traded investments	$	361	$	361	$	0	$	0
Total Assets	$	361	$	361	$	0	$	0
Liabilities:
Derivatives, net(a)	$	71,514	$	326	$	0	$	71,188
Deferred compensation		1,771		0		1,771		0
Total Liabilities	$	73,285	$	326	$	1,771	$	71,188
MGE
Assets:
Exchange-traded investments	$	162	$	162	$	0	$	0
Total Assets	$	162	$	162	$	0	$	0
Liabilities:
Derivatives, net(a)	$	71,514	$	326	$	0	$	71,188
Deferred compensation		1,771		0		1,771		0
Total Liabilities	$	73,285	$	326	$	1,771	$	71,188
(a)     These amounts are shown gross and exclude $2.0 million of collateral that was posted
against derivative positions with counterparties.
No transfers were made in or out of Level 1 or Level 2 for the three months ended March 31, 2012.
	Fair Value as of December 31, 2011
(In thousands)		Total		Level 1		Level 2		Level 3
MGE Energy
Assets:
Exchange-traded investments	$	350	$	350	$	0	$	0
Total Assets	$	350	$	350	$	0	$	0
Liabilities:
Derivatives, net(b)	$	42,356	$	1,695	$	0	$	40,661
Deferred compensation(c)		1,725		0		1,725		0
Total Liabilities	$	44,081	$	1,695	$	1,725	$	40,661
MGE
Assets:
Exchange-traded investments	$	188	$	188	$	0	$	0
Total Assets	$	188	$	188	$	0	$	0
Liabilities:
Derivatives, net(b)	$	42,356	$	1,695	$	0	$	40,661
Deferred compensation(c)		1,725		0		1,725		0
Total Liabilities	$	44,081	$	1,695	$	1,725	$	40,661
(b)     These amounts are shown gross and exclude $3.0 million of collateral that was posted
against derivative positions with counterparties.
(c)     The deferred compensation liability at December 31, 2011, was transferred from Level 1
to Level 2.

Investments include exchange-traded investment securities valued using quoted prices on active exchanges and are therefore classified as Level 1.

Derivatives include exchange-traded derivative contracts, over-the-counter party transactions, a ten-year purchased power agreement, and FTRs. Most exchange-traded derivative contracts are valued based on unadjusted quoted prices in active markets and are therefore classified as Level 1. A small number of exchange-traded derivative contracts are valued using quoted market pricing in markets with insufficient volumes and are therefore classified as Level 3. Transactions done with an over-the-counter party are on inactive markets and are therefore classified as Level 3. These transactions are valued based on quoted prices with markets with similar exchange traded transactions. FTRs are priced based upon monthly auction results for identical or similar instruments in a closed market with limited data available and are therefore classified as Level 3.

The ten-year purchased power agreement (see Footnote 9) was valued using an internally-developed pricing model and therefore is classified as Level 3. The model projects future market energy prices and compares those prices to the projected power costs to be incurred under the contract. Inputs to the model require significant management judgment and estimation. Future energy prices are based on a forward power pricing curve using exchange-traded contracts in the electric futures market, where such exchange-traded contracts exist, and upon calculations based on forward gas prices, where such exchange-traded contracts do not exist. A basis adjustment is applied to the market energy price to reflect the price differential between the market price delivery point and the counterparty delivery point. The historical relationship between the delivery points is reviewed and a discount (below 100%) or premium (above 100%) is derived. This comparison is done for both peak times when demand is high and off peak times when demand is low. If the basis adjustment is lowered, the fair value measurement will decrease and if the basis adjustment is increased, the fair value measurement will increase.

The projected power costs anticipated to be incurred under the purchased power agreement are determined using many factors, including historical generating costs, future prices, and expected fuel mix of the counterparty. An increase in the projected fuel costs would result in a decrease in the fair value measurement of the purchased power agreement. A significant input that MGE estimates is the counterparty's fuel mix in determining the projected power cost. MGE also considers the assumptions that market participants would use in valuing the asset or liability. This consideration includes assumptions about market risk such as liquidity, volatility and contract duration. The fair value model uses a discount rate that incorporates discounting, credit, and model risks.

This model is prepared by members of the Energy Supply group. It is reviewed on a quarterly basis by management in Energy Supply and Finance to review the assumptions, inputs and fair value measurements.

The following table presents the significant unobservable inputs used in the pricing model.

Significant Unobservable Inputs	Model Input
Basis adjustment
On peak	95.8%
Off peak	95.4%
Counterparty fuel mix:
Internal generation	49 % - 65 %
Purchased power	51 % - 35 %

The deferred compensation plan allows participants to defer certain cash compensation into a notional investment account. These amounts are included within other deferred liabilities in the balance sheets of MGE Energy and MGE. The notional investments earn interest based upon the semiannual rate of U.S. Treasury Bills having a 26 week maturity increased by 1% compounded monthly with a minimum annual rate of 7%, compounded monthly. The notional investments are based upon observable market data, however since the deferred compensation obligations themselves are not exchanged in an active market they are classified as Level 2.

The following table summarizes the changes in Level 3 assets and liabilities measured at fair value on a recurring basis for both MGE Energy and MGE.

		Three Months Ended
(In thousands)		March 31,
		2012		2011
Beginning balance,	$	(40,661)	$	(19,216)
Realized and unrealized gains (losses):
Included in regulatory liabilities (assets)		(30,527)		(2,932)
Included in other comprehensive income		0		0
Included in earnings		(1,502)		(8)
Included in current assets		(50)		0
Purchases		50		0
Sales		31		71
Issuances		0		0
Settlements		1,471		(63)
Transfers in and/or out of Level 3		0		0
Balance as of March 31,	$	(71,188)	$	(22,148)
Total gains (losses) included in earnings attributed to
the change in unrealized gains (losses) related to
assets and liabilities held at March 31,(d)	$	0	$	0

The following table presents total realized and unrealized gains (losses) included in income for Level 3 assets and liabilities measured at fair value on a recurring basis for both MGE Energy and MGE(d).

		Three Months Ended
(In thousands)		March 31,
		2012		2011
Purchased Power Expense	$	(1,502)	$	(8)
Cost of Gas Sold Expense		0		0
Regulated Gas Revenues		0		0
Total	$	(1,502)	$	(8)

(d)MGE's exchange-traded derivative contracts, over-the-counter party transactions, ten-year purchased power agreement, and FTRs are subject to regulatory deferral. These derivatives are therefore marked to fair value and are offset with a corresponding regulatory asset or liability.

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MGE Energy Inc Consolidated Statements of Cash Flows (Unaudited) (USD $) In Thousands, unless otherwise specified	3 Months Ended
	Mar. 31, 2012	Mar. 31, 2011
Operating Activities:
Net Income	$ 16,048	$ 17,783
Items not affecting cash:
Depreciation and amortization	9,624	10,016
Deferred income taxes	8,846	1,622
Provision for doubtful receivables	1,167	1,038
Employee benefit plan expenses	4,682	3,394
Equity earnings in ATC	(2,242)	(2,097)
Other items	660	178
Changes in working capital items:
Decrease in current assets	12,377	29,753
Decrease in current liabilities	(6,631)	(7,279)
Dividend income from ATC	1,740	1,682
Cash contributions to pension and other postretirement plans	(20,789)	(19,188)
Other noncurrent items, net	(746)	1,135
Cash Provided by Operating Activities	24,736	38,037
Investing Activities:
Capital expenditures	(15,467)	(9,843)
Capital contributions to investments	(355)	(425)
Purchase of investment - land	(3)	(1,794)
Other	109	(419)
Cash Used for Investing Activities	(15,716)	(12,481)
Financing Activities:
Cash dividends paid on common stock	(8,843)	(8,670)
Repayment of long-term debt	(667)	(500)
Issuance of long-term debt	0	30,000
Decrease in short-term debt	0	(22,500)
Other	(19)	(311)
Cash Used for Financing Activities	(9,529)	(1,981)
Change in Cash and Cash Equivalents:	(509)	23,575
Cash and cash equivalents at beginning of period	41,169	7,110
Cash and cash equivalents at end of period	40,660	30,685
Significant noncash investing activities [Abstract]
Accrued capital expenditures	$ 4,674	$ 1,146

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Madison Gas and Electric Company Consolidated Statements of Income (Unaudited) (USD $) In Thousands, unless otherwise specified	3 Months Ended
	Mar. 31, 2012	Mar. 31, 2011
Operating Revenues:
Regulated electric revenues	$ 89,936	$ 86,007
Regulated gas revenues	57,019	77,437
Nonregulated revenues	2,304	1,161
Total Operating Revenues	149,259	164,605
Operating Expenses:
Fuel for electric generation	8,851	11,049
Purchased power	19,546	17,581
Cost of gas sold	34,845	50,947
Other operations and maintenance	42,949	39,413
Depreciation and amortization	9,624	10,016
Other general taxes	5,000	4,701
Income tax provision	9,862	10,651
Total Operating Expenses	120,815	133,707
Operating Income	28,444	30,898
Other Income and Deductions:
Equity in earnings in ATC	2,242	2,097
Total Other Income and Deductions	2,570	2,386
Interest Expense:
Net Interest Expense	5,104	4,850
Net Income	16,048	17,783
MGE [Member]
Operating Revenues:
Regulated electric revenues	89,936	86,007
Regulated gas revenues	57,019	77,437
Nonregulated revenues	2,304	1,161
Total Operating Revenues	149,259	164,605
Operating Expenses:
Fuel for electric generation	8,851	11,049
Purchased power	19,546	17,581
Cost of gas sold	34,845	50,947
Other operations and maintenance	42,528	39,235
Depreciation and amortization	9,624	10,016
Other general taxes	5,000	4,701
Income tax provision	8,969	9,891
Total Operating Expenses	129,363	143,420
Operating Income	19,896	21,185
Other Income and Deductions:
AFUDC - equity funds	154	87
Equity in earnings in ATC	2,242	2,097
Income tax provision	(993)	(806)
Other income, net	56	113
Total Other Income and Deductions	1,459	1,491
Income before interest expense	21,355	22,676
Interest Expense:
Interest on long-term debt	5,197	4,991
Other interest, net	7	(147)
AFUDC - borrowed funds	(63)	(35)
Net Interest Expense	5,141	4,809
Net Income Including Noncontrolling Interest	16,214	17,867
Less Net Income Attributable to Noncontrolling Interest, net of tax	(6,072)	(5,933)
Net Income	$ 10,142	$ 11,934

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Columbia Environmental Project Construction

3 Months Ended

Mar. 31, 2012

Columbia Environmental Project Construction Disclosure [Abstract]

Columbia Environmental Project Construction

4.       Columbia Environmental Project Construction - MGE Energy and MGE.

MGE and two other utilities jointly own Columbia, a coal-fired generating facility. WPL is the plant operator and permit holder, and owns 46.2% of Columbia. WPSC owns a 31.8% interest, and MGE owns a 22% interest in Columbia. In early 2011, the PSCW issued a Certificate and Order authorizing the construction of scrubbers and bag houses and associated equipment on Columbia Units 1 and 2 to reduce SO2 and mercury emissions. The scrubbers and bag houses are expected to support compliance obligations for current and anticipated air quality regulations, including CAIR or CSAPR, the Utility MACT Rule and the Wisconsin Mercury Rule. The operator's current estimate shows that MGE's share of the capital expenditures required for this project will be approximately $140 million. MGE expects to incur capital expenditures as follows: $43 million for the remainder of 2012, $68 million in 2013, and $14 million in 2014. These amounts may change as a result of modifications to the project estimate or timing difference.

As of March 31, 2012, MGE had incurred $10.5 million (excluding carrying costs) in construction expenditures at Columbia related to its share of the project and had accrued $4.0 million in incurred but unpaid capital expenditures. At March 31, 2012, $14.5 million (excluding carrying costs) related to this project is reflected in the Construction Work in Progress balance on MGE and MGE Energy's consolidated balance sheets.

MGE expects that the costs pertaining to this project will be fully recoverable through rates. Additionally, MGE is entitled to a carrying cost on the related construction costs at 100% of the determined AFUDC rate.

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Document and Entity Information	3 Months Ended
	Mar. 31, 2012
Document And Entity Information [Line Items]
Entity Registrant Name	MGE Energy Inc
Entity Central Index Key	0001161728
Document Type	10-Q
Document Period End Date	Mar. 31, 2012
Amendment Flag	false
Document Fiscal Year Focus	2012
Document Fiscal Period Focus	Q1
Current Fiscal Year End Date	--12-31
Entity Well known Seasoned Issuer	Yes
Entity Voluntary Filers	No
Entity Current Reporting Status	Yes
Entity Filer Category	Large Accelerated Filer
Entity Common Stock Shares Outstanding	23,113,638
MGE [Member]
Document And Entity Information [Line Items]
Entity Registrant Name	Madison Gas and Electric Company
Entity Central Index Key	0000061339
Entity Current Reporting Status	Yes
Entity Filer Category	Non-accelerated Filer
Entity Common Stock Shares Outstanding	17,347,894

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Taxes

3 Months Ended

Mar. 31, 2012

Taxes Disclosure [Abstract]

Taxes

5.       Taxes - MGE Energy and MGE.

a.       Accounting for Uncertainty in Income Taxes.

MGE Energy and MGE account for the difference between the tax benefit amount taken on prior year tax returns, or expected to be taken on a current year tax return, and the tax benefit amount recognized in the financial statements as an unrecognized tax benefit.

MGE Energy hasadopted a tax method of accounting to accelerate tax deductions for repairs in accordance with Treasury Regulations and case law, as compared to the prior method of claiming tax depreciation on project costs.The method change for electric generation and transmission and distribution repairs was included on the 2009 tax return while the change for gas distribution repairs was included on the 2010 return. During 2011, the IRS issued guidance on the treatment of electric transmission and distribution repairs. This guidance prompted the reversal of a portion of the unrecognized tax benefits for these repairs during 2011. MGE Energy and MGE have an unrecognized tax benefit at March 31, 2012 and December 31, 2011, in the amount of $2.7 million and $2.4million, respectively, for the tax uncertainty primarily related to the change in tax method of accounting forelectric generation and gas distribution repairs.

b.       Effective Tax Rate.

MGE Energy's and MGE's effective income tax rate for the three months endedMarch 31, 2012, is38.1%, compared to 37.5%for the same period in 2011. The higher effective tax rate is, in part, attributable to a lowerestimated domestic manufacturing deduction.

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MGE Energy Inc Consolidated Statements of Comprehensive Income (Unaudited) (USD $) In Thousands, unless otherwise specified	3 Months Ended
	Mar. 31, 2012		Mar. 31, 2011
Comprehensive Income [Abstract]
Net Income	$ 16,048		$ 17,783
Other comprehensive income (loss), net of tax:
Unrealized gain (loss) on available-for-sale securities, net of tax	7	[1]	72	[2]
Comprehensive Income	$ 16,055		$ 17,855

[1] Net of $5 tax

[2] Net of $48 tax

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Madison Gas and Electric Company Consolidated Statements of Common Equity (Unaudited) (USD $) In Thousands	Total USD ($)	MGE [Member] USD ($)	Common Stock [Member]	Common Stock [Member] MGE [Member] USD ($)	Additional Paid-In Capital [Member] MGE [Member] USD ($)	Retained Earnings [Member] MGE [Member] USD ($)	Accumulated Other Comprehensive (Loss)/ Income [Member] USD ($)	Accumulated Other Comprehensive (Loss)/ Income [Member] MGE [Member] USD ($)	Noncontrolling Interest [Member] MGE [Member] USD ($)
Beginning balance, value at Dec. 31, 2010		$ 544,309		$ 17,348	$ 192,417	$ 192,480		$ 71	$ 141,993
Beginning balance, shares at Dec. 31, 2010			23,114	17,348
Net Income		17,867				11,934			5,933
Other comprehensive income (loss)	72	35					72	35
Cash dividends paid to parent by MGE		(6,596)				(6,596)
Equity contribution received by noncontrolling interest		356							356
Distributions to parent from noncontrolling interest		(33,000)							(33,000)
Ending balance, value at Mar. 31, 2011		522,971		17,348	192,417	197,818		106	115,282
Ending balance, shares at Mar. 31, 2011			23,114	17,348
Beginning balance, value at Dec. 31, 2011		527,277		17,348	192,417	203,114		47	114,351
Beginning balance, shares at Dec. 31, 2011			23,114	17,348
Net Income		16,214				10,142			6,072
Other comprehensive income (loss)	7	(16)					7	(16)
Cash dividends paid to parent by MGE		(6,728)				(6,728)
Equity contribution received by noncontrolling interest		355							355
Distributions to parent from noncontrolling interest		0
Ending balance, value at Mar. 31, 2012		$ 537,102		$ 17,348	$ 192,417	$ 206,528		$ 31	$ 120,778
Ending balance, shares at Mar. 31, 2012			23,114	17,348

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MGE Energy Inc Consolidated Statements of Common Equity (Unaudited) (USD $) In Thousands, except Share data		Total	Common Stock [Member]	Additional Paid-In Capital [Member]	Retained Earnings [Member]	Accumulated Other Comprehensive (Loss)/ Income [Member]
Beginning balance, value at Dec. 31, 2010		$ 525,080	$ 23,114	$ 316,268	$ 185,556	$ 142
Beginning balance, shares at Dec. 31, 2010			23,114,000
Net Income		17,783			17,783
Other comprehensive income (loss)		72				72
Common stock dividends declared	[1]	(8,670)			(8,670)
Common stock issued during period		0
Ending balance, value at Mar. 31, 2011		534,265	23,114	316,268	194,669	214
Ending balance, shares at Mar. 31, 2011			23,114,000
Beginning balance, value at Dec. 31, 2011		550,952	23,114	316,268	211,458	112
Beginning balance, shares at Dec. 31, 2011			23,114,000
Net Income		16,048			16,048
Other comprehensive income (loss)		7				7
Common stock dividends declared	[2]	(8,843)			(8,843)
Common stock issued during period		0
Ending balance, value at Mar. 31, 2012		$ 558,164	$ 23,114	$ 316,268	$ 218,663	$ 119
Ending balance, shares at Mar. 31, 2012			23,114,000

[1] $0.375 per share

[2] $0.383 per share

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Rate Matters

3 Months Ended

Mar. 31, 2012

Rate Matters Disclosure [Abstract]

Rate Matters

10.       Rate Matters - MGE Energy and MGE.

a.       Rate Proceedings.

On March 23, 2012, MGE filed an application with the PSCW requesting a 5.8% increase to electric rates and a 2.6% increase to gas rates. The proposed electric increase will cover costs for new environmental equipment at Columbia, final construction costs for the Elm Road Units, transmission reliability enhancements, and purchased power costs. MGE has requested that these rates become effective January 1, 2013.

On December 15, 2011, under a limited reopener of MGE'slast rate order, the PSCW authorized MGE to increase 2012 rates for retail electric customers by 4.3% or $15.7 million and to increase gas rates by 0.3% or $0.6 million.The change in retail electric rates was driven by MGE's electric fuel and purchased power costs, increased transmission costs, an update to the Elm Road Units' costs, and an increase for energy efficiency programs. The PSCW also approved deferral of CSAPR costs.

On January 12, 2011, the PSCW authorized MGE to increase 2011 rates for retail electric customers by 2.3% or $8.0 million and to increase gas rates by 1.0% or $1.9 million. The increase in retail electric rates is driven by costs for MGE's share of the Elm Road Units. Pursuant to the provisions of this rate order, the fuel rules bandwidth effective January 1, 2011, will be plus or minus 2%. See below for further description of fuel rules. Authorized return on common stock equity was set at 10.3% based on a 58.1% utility common equity.

b.       Fuel Rules.

The PSCW approved new fuel rules that became effective January 1, 2011. The new rules require the PSCW and Wisconsin utilities to automatically defer electric fuel-related costs that fall outside a symmetrical cost tolerance band. Any over/under recovery of the deferred costs is determined on an annual basis and will be adjusted in future billings to electric retail customers. Under fuel rules, MGE would defer costs, less any excess revenues, if its actual electric fuel costs exceeded 102% of the electric fuel costs allowed in its latest rate order. Excess revenues are defined as revenues in the year in question that provide MGE with a greater return on common equity than authorized by the PSCW in MGE's latest rate order. Conversely, MGE is required to defer the benefit of lower costs if actual electric fuel costs were less than 98% of the electric fuel costs allowed in that order.As of March 31, 2012, MGE did not defer any electric fuel-related costs.

c.       Purchased Gas Adjustment Clause.

MGE's natural gas rates are subject to a fuel adjustment clause designed to recover or refund the difference between the actual cost of purchased gas and the amount included in rates. Differences between the amounts billed to customers and the actual costs recoverable are deferred and recovered or refunded in future periods by means of prospective monthly adjustments to rates. At March 31, 2012and December 31, 2011, MGE had over collected $3.3 million and $0.9 million, respectively. These amounts were recorded in other current liabilities on the consolidated balance sheet.

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Pension and Other Postretirement Plans

3 Months Ended

Mar. 31, 2012

Pension and Other Postretirement Plans Disclosure [Abstract]

Pension and Other Postretirement Plans

6.       Pension and Other Postretirement Plans - MGE Energy and MGE.

MGE maintains qualified and nonqualified pension plans, health care, and life insurance benefits. Additionally, MGE has defined contribution 401(k) benefit plans.

The following table presents the components of MGE Energy's and MGE's net periodic benefit costs recognized for the three months ended March 31, 2012 and 2011. A portion of the net periodic benefit cost is capitalized within the consolidated balance sheets. The PSCW allowed MGE to defer the 2009 incremental pension and OPRB costs above the amounts recovered in rates. During the three months endedMarch 31,2012 and 2011, $0.3 million and $0.7 million, respectively, has been recovered in rates.

		Three Months Ended
(In thousands)		March 31,
		2012		2011
Pension Benefits
Components of net periodic benefit cost:
Service cost	$	1,823	$	1,540
Interest cost		3,154		3,080
Expected return on assets		(3,818)		(3,531)
Amortization of:
Prior service cost		108		109
Actuarial loss		2,006		946
Net periodic benefit cost	$	3,273	$	2,144
Postretirement Benefits
Components of net periodic benefit cost:
Service cost	$	647	$	487
Interest cost		1,125		982
Expected return on assets		(435)		(396)
Amortization of:
Transition obligation		106		107
Prior service cost		28		27
Actuarial loss		621		111
Net periodic benefit cost	$	2,092	$	1,318

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Equity and Financing Arrangements

3 Months Ended

Mar. 31, 2012

Equity and Financing Arrangements Disclosure [Abstract]

Equity and Financing Arrangements

2.       Equity and Financing Arrangements - MGE Energy.

a.       Common Stock.

MGE Energy purchases stock in the open market for issuance pursuant to its Stock Plan. All MGE Energy common stock issued under the Stock Plan is sold pursuant to a registration statement that has been filed with the SEC and is currently effective.

MGE Energy can issue new shares of its common stock through the Stock Plan. For both the three months ended March 31, 2012 and 2011, MGE Energy did not issue any new shares of common stock under the Stock Plan.

b.       Dilutive Shares Calculation.

MGE Energy does not hold any dilutive securities.