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, 2013

[ ] 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, 2013
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 include (a) those factors discussed in the Registrants' 2012 Annual Report on Form 10-K: 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.

MGE Energy and Subsidiaries:
CWDC	Central Wisconsin Development Corporation
MAGAEL	MAGAEL, LLC
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
Other Defined Terms:
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
DNR	Department of Natural Resources
DOE	United States Department of Energy
Dth	Dekatherms, a quantity measure used in respect of natural gas
EGUs	Electric Generating Units
Elm Road Units	Elm Road Generating Station
EPA	United States Environmental Protection Agency
ERISA	Employee Retirement Income Security Act
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, a measure of electric energy produced
MACT	Maximum Achievable Control Technology
MAP-21	Moving Ahead for Progress in the 21st Century Act
MATs	Mercury and Air Toxics Standards
MISO	Midwest Independent System Operator (a regional transmission organization)
MW	Megawatt, a measure of electric energy generating capacity
MWh	Megawatt-hour, a measure of electric energy produced
NAAQS	National Ambient Air Quality Standards
NGCC	Natural Gas Combined Cycle
NO2	Nitrogen Dioxide
NODA	Notices of Data Availability
NOV	Notice of Violation
NOx	Nitrogen Oxides
NSPS	New Source Performance Standards
OPRB	Other Postretirement Benefits

4

PGA	Purchased Gas Adjustment clause, a regulatory mechanism used to reconcile natural gas costs recovered in rates to actual costs
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
SCR	Selective Catalytic Reduction
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

5

Item 1. Financial Statements.

MGE Energy, Inc.

Consolidated Statements of Income (unaudited)

(In thousands, except per-share amounts)

		Three Months Ended
		March 31,
		2013		2012
Operating Revenues:
Regulated electric revenues	$	93,494	$	89,936
Regulated gas revenues		72,467		57,019
Nonregulated revenues		1,276		2,304
Total Operating Revenues		167,237		149,259
Operating Expenses:
Fuel for electric generation		10,760		8,851
Purchased power		18,205		19,546
Cost of gas sold		44,692		34,845
Other operations and maintenance		41,649		42,949
Depreciation and amortization		9,624		9,624
Other general taxes		4,679		5,000
Total Operating Expenses		129,609		120,815
Operating Income		37,628		28,444
Other income, net		3,309		2,570
Interest expense, net		(4,675)		(5,104)
Income before income taxes		36,262		25,910
Income tax provision		(13,678)		(9,862)
Net Income	$	22,584	$	16,048
Earnings Per Share of Common Stock
(basic and diluted)	$	0.98	$	0.69
Dividends per share of common stock	$	0.395	$	0.383
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,
		2013		2012
Net Income	$	22,584	$	16,048
Other comprehensive income, net of tax:
Unrealized gain on available-for-sale securities, net of
tax ($43 and $5)		65		7
Comprehensive Income	$	22,649	$	16,055

The accompanying notes are an integral part of the above unaudited consolidated financial statements.

6

MGE Energy, Inc.

Consolidated Statements of Cash Flows (unaudited)

(In thousands)

		Three Months Ended
		March 31,
		2013		2012
Operating Activities:
Net income	$	22,584	$	16,048
Items not affecting cash:
Depreciation and amortization		9,624		9,624
Deferred income taxes		11,294		8,846
Provision for doubtful receivables		743		1,167
Employee benefit plan expenses		3,336		4,682
Equity earnings in ATC		(2,396)		(2,242)
Other items		750		660
Changes in working capital items:
Decrease in current assets		17,341		12,377
Decrease in current liabilities		(4,590)		(6,631)
Dividend income from ATC		1,807		1,740
Cash contributions to pension and other postretirement plans		(30,764)		(20,789)
Other noncurrent items, net		(1,077)		(746)
Cash Provided by Operating Activities		28,652		24,736
Investing Activities:
Capital expenditures		(29,164)		(15,467)
Capital contributions to investments		(373)		(355)
Other		(279)		106
Cash Used for Investing Activities		(29,816)		(15,716)
Financing Activities:
Cash dividends paid on common stock		(9,132)		(8,843)
Repayment of long-term debt		(667)		(667)
Increase in short-term debt		10,500		-
Other		-		(19)
Cash Provided by (Used for) Financing Activities		701		(9,529)
Change in cash and cash equivalents		(463)		(509)
Cash and cash equivalents at beginning of period		46,357		41,169
Cash and Cash Equivalents at End of Period	$	45,894	$	40,660
Supplemental disclosures of cash flow information:
Significant noncash investing activities:
Accrued capital expenditures	$	12,699	$	4,674

The accompanying notes are an integral part of the unaudited consolidated financial statements.

7

MGE Energy, Inc.

Consolidated Balance Sheets (unaudited)

(In thousands)

		March 31,	December 31,
ASSETS		2013		2012
Current Assets:
Cash and cash equivalents	$	45,894	$	46,357
Receivable - margin account		766		1,818
Accounts receivable, less reserves of $3,914 and $3,885, respectively		46,864		41,386
Other accounts receivable, less reserves of $931 and $931, respectively		5,125		6,746
Unbilled revenues		26,761		28,262
Materials and supplies, at average cost		16,933		16,997
Fossil fuel		7,375		6,367
Stored natural gas, at average cost		2,195		14,980
Prepaid taxes		13,868		19,520
Regulatory assets - current		8,471		10,327
Deferred income taxes - current		14,260		23,483
Other current assets		7,431		6,694
Total Current Assets		195,943		222,937
Regulatory assets		214,496		218,853
Other deferred assets and other		7,222		7,075
Property, Plant, and Equipment:
Property, plant, and equipment, net		981,325		975,053
Construction work in progress		115,803		98,411
Total Property, Plant, and Equipment		1,097,128		1,073,464
Investments		65,651		64,595
Total Assets	$	1,580,440	$	1,586,924
LIABILITIES AND CAPITALIZATION
Current Liabilities:
Long-term debt due within one year	$	3,365	$	3,013
Short-term debt		10,500		-
Accounts payable		39,586		43,518
Accrued interest and taxes		4,099		4,296
Accrued payroll related items		7,711		10,063
Derivative liabilities		8,880		9,270
Other current liabilities		10,605		5,637
Total Current Liabilities		84,746		75,797
Other Credits:
Deferred income taxes		272,511		270,410
Investment tax credit - deferred		1,466		1,520
Regulatory liabilities		22,598		24,538
Accrued pension and other postretirement benefits		133,380		162,835
Derivative liabilities		61,810		63,320
Other deferred liabilities and other		53,505		50,584
Total Other Credits		545,270		573,207
Capitalization:
Common shareholders' equity		592,946		579,429
Long-term debt		357,478		358,491
Total Capitalization		950,424		937,920
Commitments and contingencies (see Footnote 8)		-		-
Total Liabilities and Capitalization	$	1,580,440	$	1,586,924

The accompanying notes are an integral part of the above unaudited consolidated financial statements.

8

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
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
2013
Beginning balance - December 31, 2012	23,114	$	23,114	$	316,268	$	239,953	$	94	$	579,429
Net income							22,584				22,584
Other comprehensive income									65		65
Common stock dividends declared
($0.395 per share)							(9,132)				(9,132)
Ending balance - March 31, 2013	23,114	$	23,114	$	316,268	$	253,405	$	159	$	592,946

The accompanying notes are an integral part of the above unaudited consolidated financial statements.

9

Madison Gas and Electric Company

Consolidated Statements of Income (unaudited)

(In thousands)

		Three Months Ended
		March 31,
		2013		2012
Operating Revenues:
Regulated electric revenues	$	93,494	$	89,936
Regulated gas revenues		72,467		57,019
Nonregulated revenues		1,276		2,304
Total Operating Revenues		167,237		149,259
Operating Expenses:
Fuel for electric generation		10,760		8,851
Purchased power		18,205		19,546
Cost of gas sold		44,692		34,845
Other operations and maintenance		41,504		42,528
Depreciation and amortization		9,624		9,624
Other general taxes		4,679		5,000
Income tax provision		12,870		8,969
Total Operating Expenses		142,334		129,363
Operating Income		24,903		19,896
Other Income and Deductions:
AFUDC - equity funds		596		154
Equity in earnings in ATC		2,396		2,242
Income tax provision		(781)		(993)
Other income, net		141		56
Total Other Income and Deductions		2,352		1,459
Income before interest expense		27,255		21,355
Interest Expense:
Interest on long-term debt		4,928		5,197
Other interest, net		(37)		7
AFUDC - borrowed funds		(196)		(63)
Net Interest Expense		4,695		5,141
Net Income	$	22,560	$	16,214
Less Net Income Attributable to Noncontrolling Interest, net of tax		(6,826)		(6,072)
Net Income Attributable to MGE	$	15,734	$	10,142

Madison Gas and Electric Company

Consolidated Statements of Comprehensive Income (unaudited)

(In thousands)

		Three Months Ended
		March 31,
		2013		2012
Net Income	$	22,560	$	16,214
Other comprehensive income (loss), net of tax:
Unrealized gain (loss) on available-for-sale securities, net of
tax ($18 and $11)		27		(16)
Comprehensive Income	$	22,587	$	16,198
Less: Comprehensive income attributable to Noncontrolling
Interest, net of tax		(6,826)		(6,072)
Comprehensive Income attributable to MGE	$	15,761	$	10,126

The accompanying notes are an integral part of the above unaudited consolidated financial statements.

10

Madison Gas and Electric Company

Consolidated Statements of Cash Flows (unaudited)

(In thousands)

		Three Months Ended
		March 31,
		2013		2012
Operating Activities:
Net income	$	22,560	$	16,214
Items not affecting cash:
Depreciation and amortization		9,624		9,624
Deferred income taxes		11,016		8,768
Provision for doubtful receivables		743		1,005
Employee benefit plan expenses		3,336		4,682
Equity earnings in ATC		(2,396)		(2,242)
Other items		882		792
Changes in working capital items:
Decrease in current assets		17,135		11,542
Decrease in current liabilities		(4,326)		(6,991)
Dividend income from ATC		1,807		1,740
Cash contributions to pension and other postretirement plans		(30,764)		(20,789)
Other noncurrent items, net		(1,096)		(762)
Cash Provided by Operating Activities		28,521		23,583
Investing Activities:
Capital expenditures		(29,164)		(15,467)
Capital contributions to investments		(178)		(355)
Other		(184)		49
Cash Used for Investing Activities		(29,526)		(15,773)
Financing Activities:
Cash dividends paid to parent by MGE		-		(6,728)
Distributions to parent from noncontrolling interest		(5,500)		-
Equity contribution received by noncontrolling interest		178		355
Repayment of long-term debt		(667)		(667)
Increase in short-term debt		10,500		-
Other		-		(9)
Cash Provided by (Used for) Financing Activities		4,511		(7,049)
Change in cash and cash equivalents		3,506		761
Cash and cash equivalents at beginning of period		6,350		13,898
Cash and Cash Equivalents at End of Period	$	9,856	$	14,659
Supplemental disclosures of cash flow information:
Significant noncash investing activities:
Accrued capital expenditures	$	12,699	$	4,674

The accompanying notes are an integral part of the unaudited consolidated financial statements.

11

Madison Gas and Electric Company

Consolidated Balance Sheets (unaudited)

(In thousands)

		March 31,	December 31,
ASSETS		2013		2012
Current Assets:
Cash and cash equivalents	$	9,856	$	6,350
Receivable - margin account		766		1,818
Accounts receivable, less reserves of $3,914 and $3,885, respectively		46,864		41,386
Affiliate receivables		619		634
Other accounts receivable, less reserves of $931 and $931, respectively		5,124		6,732
Unbilled revenues		26,761		28,262
Materials and supplies, at average cost		16,933		16,997
Fossil fuel		7,375		6,367
Stored natural gas, at average cost		2,195		14,980
Prepaid taxes		18,108		23,561
Regulatory assets - current		8,471		10,327
Deferred income taxes - current		13,808		23,305
Other current assets		7,416		6,670
Total Current Assets		164,296		187,389
Affiliate receivable long-term		6,222		6,354
Regulatory assets		214,496		218,853
Other deferred assets and other		6,602		6,540
Property, Plant, and Equipment:
Property, plant, and equipment, net		980,820		974,549
Construction work in progress		115,803		98,411
Total Property, Plant, and Equipment		1,096,623		1,072,960
Investments		62,366		61,555
Total Assets	$	1,550,605	$	1,553,651
LIABILITIES AND CAPITALIZATION
Current Liabilities:
Long-term debt due within one year	$	3,365	$	3,013
Short-term debt		10,500		-
Accounts payable		39,586		43,517
Affiliate payables		405		767
Accrued interest and taxes		3,699		4,248
Accrued payroll related items		7,711		10,063
Derivative liabilities		8,880		9,270
Other current liabilities		10,163		4,491
Total Current Liabilities		84,309		75,369
Other Credits:
Deferred income taxes		268,028		266,231
Investment tax credit - deferred		1,466		1,520
Regulatory liabilities		22,598		24,538
Accrued pension and other postretirement benefits		133,380		162,835
Derivative liabilities		61,810		63,320
Other deferred liabilities and other		53,505		50,581
Total Other Credits		540,787		569,025
Capitalization:
Common shareholder's equity		449,057		433,296
Noncontrolling interest		118,974		117,470
Total Equity		568,031		550,766
Long-term debt		357,478		358,491
Total Capitalization		925,509		909,257
Commitments and contingencies (see Footnote 8)		-		-
Total Liabilities and Capitalization	$	1,550,605	$	1,553,651

The accompanying notes are an integral part of the above unaudited consolidated financial statements.

12

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
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
2013
Beginning balance - Dec. 31, 2012	17,348	$	17,348	$	192,417	$	223,527	$	4	$	117,470	$	550,766
Net income							15,734				6,826		22,560
Other comprehensive loss									27				27
Equity contribution received by
noncontrolling interest											178		178
Distributions to parent from
noncontrolling interest											(5,500)		(5,500)
Ending balance - March 31, 2013	17,348	$	17,348	$	192,417	$	239,261	$	31	$	118,974	$	568,031

The accompanying notes are an integral part of the above unaudited consolidated financial statements.

13

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

Notes to Consolidated Financial Statements (unaudited)

March 31, 2013

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. See Footnote 2 of Notes to Consolidated Financial Statements under Item 8, Financial Statements and Supplementary Data, of MGE Energy's and MGE's 2012 Annual Report on Form 10-K.

The accompanying consolidated financial statements as of March 31, 2013, 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 2012 Annual Report on Form 10-K, but does not include all disclosures required by accounting principles generally accepted in the United States of America. These notes should be read in conjunction with the financial statements and the notes on pages 51 through 104 of the 2012 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, 2013 and 2012, 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, 2013 and 2012, MGE Transco recorded equity earnings from the investment in ATC of $2.4 million and $2.2 million, respectively. Dividend income received from ATC was $1.8 million and $1.7 million for the three months ended March 31, 2013 and 2012, respectively. In addition, during the three months ended March 31, 2013 and 2012, MGE Transco made $0.2 million and $0.4 million in capital contributions to ATC, respectively. On April 30, 2013, MGE Transco made a $0.5 million capital contribution to ATC.

MGE Energy and MGE's investment in ATC as of March 31, 2013, and December 31, 2012, was $61.8 million and $61.0 million, respectively.

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At March 31, 2013, 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.

ATC's summarized financial data for the three months ended March 31, 2013 and 2012, is as follows:

		Three Months Ended March 31,
(In thousands)		2013		2012
Operating revenues	$	151,737	$	147,662
Operating expenses		(69,770)		(69,566)
Other expense, net		(448)		(500)
Interest expense, net		(21,044)		(19,501)
Earnings before members' income taxes	$	60,475	$	58,095

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, CAIR's eventual replacement, the Mercury and Air Toxics Standards (MATS), and the Wisconsin Mercury Rule. The operator's current estimate shows that MGE's share of the capital expenditures required for this project is approximately $140 million. As of March 31, 2013, MGE had accumulated $78.8 million (excluding carrying costs) related to its share of the project, which is reflected in the Construction Work in Progress balance on MGE Energy's and MGE's consolidated balance sheets. MGE's share of the capital expenditures associated with the Columbia environmental project will be approximately $49 million for the remainder of 2013 and $12 million in 2014. These amounts may change as a result of modifications to the project estimate or timing differences. For the three months ended March 31, 2013 and 2012, MGE has recognized after tax $0.5 million and $0.1 million, respectively, in AFUDC equity related to this project.

MGE expects that the costs pertaining to this project will be fully recoverable through rates. In 2012, the PSCW authorized MGE 100% AFUDC on this project during construction. Beginning in 2013, similar to MGE's other utility construction projects, the PSCW authorized MGE a 50% current return (included in customer rates) and the remaining 50% as AFUDC.

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. MGE Energy and MGE have an unrecognized tax benefit at March 31, 2013, and December 31, 2012, in the amount of $3.4 million and $3.2 million, respectively, for the tax uncertainty related to the change in tax method of accounting for repairs.

On April 18, 2013, MGE Energy received notification from the Internal Revenue Service that the examination of tax periods 2007-2009 has been completed. Unrecognized tax benefits of $1.5 million related to those years will be reversed (in the second quarter) due to those positions not being adversely adjusted in the examination.

b.

Effective Tax Rate.

MGE Energy's and MGE's effective income tax rate for the three months ended March 31, 2013, was 37.7%, compared to 38.1% for the same period in 2012.

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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, 2013 and 2012. A portion of the net periodic benefit cost is capitalized within the consolidated balance sheets.

		Three Months Ended March 31,
(In thousands)		2013		2012
Pension Benefits
Components of net periodic benefit cost:
Service cost	$	1,929	$	1,823
Interest cost		3,186		3,154
Expected return on assets		(4,776)		(3,818)
Amortization of:
Prior service cost		79		108
Actuarial loss		2,015		2,006
Net periodic benefit cost	$	2,433	$	3,273
Postretirement Benefits
Components of net periodic benefit cost:
Service cost	$	596	$	647
Interest cost		970		1,125
Expected return on assets		(544)		(435)
Amortization of:
Transition obligation		1		106
Prior service cost		28		28
Actuarial loss		311		621
Net periodic benefit cost	$	1,362	$	2,092

The PSCW allowed MGE to defer the 2009 incremental pension and OPRB costs above the amounts recovered in rates. During both the three months ended March 31, 2013 and 2012, $0.3 million has been recovered in rates. These costs are not reflected in the table above.

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 2009 through 2012, on February 15, 2013, 15,256 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 a performance unit 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, 2013, 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 the event of a bona fide retirement, not followed by work for a competitor, the executive will receive full vesting credit for each outstanding award.

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During the three months ended March 31, 2013 and 2012, MGE recorded $0.9 million and $0.4 million, respectively, in compensation expense as a result of the Performance Unit Plan. In January 2013, cash payments of $1.0 million were distributed relating to awards that were granted in 2008 and became payable under the Performance Unit Plan. No forfeitures occurred during the three months ended March 31, 2013 or 2012. At March 31, 2013, $3.7 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 discharges 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 also includes discharge standards, which require the use of effluent-treatment processes equivalent to categorical "best practicable" or "best available" technologies. The CWA regulates discharges from "point sources" such as power plants through 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))

Section 316(b) of the Clean Water Act requires that the cooling water intake structures at electric power plants meet best available technology standards so that mortality from entrainment (drawing aquatic life into a plant's cooling system) and impingement (trapping aquatic life on screens) are reduced. Section 316(b) has been introduced in two phases. Phase I, which has been finalized, covered new facilities at the time that the rule was introduced. Phase II, which has not been finalized, is designed to cover what is defined as existing facilities. The EPA issued a proposed Phase II rule and alternative compliance strategies for existing facilities in April 2011 and has until June 27, 2013, to issue a final rule, pursuant to a settlement agreement.

The currently proposed Phase II rule and potential alternatives allow for a state permitting agency's discretion in determining best technology available at plants that are under their permitting authority and is not requiring cooling towers in all instances. The WDNR holds permitting authority for Wisconsin and implementation of the rule will be through modification of the plants' WPDES permits. Blount and Columbia generating plants are subject to both the impingement and entrainment aspects of the current proposed rule. WCCF is subject to the impingement aspect only. The Elm Road Units are covered under Phase I of the rule and meets those requirements. We anticipate that under the current proposed rule, equipment would need to be installed at Blount, WCCF, and Columbia to meet these new standards. However it is not presently possible to estimate the potential costs associated with this rule because the rule has not been finalized.

Air Quality

Federal and state air quality regulations impose restrictions on emission of particulate matter (PM), 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 interstate pollution transport rules, maximum achievable control technology (MACT) standards, new source performance standards (NSPS), the Clean Air Visibility Rule (also known as the Regional Haze Rule), and mercury emissions limits are expected to result in additional operating and capital expenditure costs for electric generating units.

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

In 2005, EPA promulgated the Clean Air Interstate Rule (CAIR) to reduce ozone and fine particulate matter emissions by reducing NO_x and SO₂ emissions. NO_x and SO₂ interact in the atmosphere to form ambient ozone from NO_x and fine particulate matter pollution from NO_x and SO₂. The CAIR generally requires NO_x and SO₂ emission reductions from fossil fuel-fired EGUs (25 MW or greater) 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)

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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 Units, 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 with directions to revise or replace the rule. The Court's remand order directed that the CAIR remain in effect until the EPA promulgated a replacement rule. The Court's order did not include a deadline for the EPA to act.

In August 2011, the EPA responded to the remand of the CAIR by promulgating the Cross State Air Pollution Rule (CSAPR). However, in August 2012, the U.S. Court of Appeals for the D.C. Circuit vacated CSAPR and instructed the EPA to continue administering the CAIR pending finalizing a valid alternative program to control interstate pollution. In January 2013, the U.S. Court of Appeals for the D.C. Circuit denied the EPA's petition for reconsideration en banc. The EPA and several environmental groups have appealed the D.C. Circuit Court's August 2012 decision to the Supreme Court in separate filings. At this time, the CAIR remains effective.

MGE is currently in compliance with the CAIR Phase I requirements. MGE will be able to meet Phase II NO_x emissions reductions through using our NO_x allowances provided through the rule, and we will meet Phase II SO₂ emissions reductions through installation of pollution controls. New SO₂ controls at Columbia are already underway and are planned to be completed by mid 2014 (see the discussion regarding the Columbia environmental project below). MGE expects that any costs incurred to meet Phase II of the CAIR will be fully recoverable through rates. MGE will monitor the Supreme Court's response to the CSAPR appeals and any subsequent actions by the EPA to continue to evaluate potential impacts to our operations.

Clean Air Visibility Rule (CAVR)

Air modeling indicates that SO₂ and NO_x emissions (and to a lesser extent particulate matter) 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 may require pollution retrofits. The EPA had proposed that a power plant's compliance with emissions limitations in the CAIR and later under CSAPR could also serve as compliance with the BART regulations for SO₂ and NO_x emissions. However, this proposal is now uncertain because of the D.C. Circuit decisions to remand the CAIR and vacate CSAPR and the EPA's decision to pursue Supreme Court review of the CSAPR vacature. See CAIR and CSAPR discussion above for additional information on these proceedings. Capital expenditures at Columbia under BART still remain a possibility however at this time, the BART regulatory obligations, compliance strategies and costs remain uncertain until the Supreme Court makes a decision regarding CSAPR.

Wisconsin State Mercury Rule

Beginning January 1, 2015, phase two of the Wisconsin mercury rule will require large coal-fired EGUs (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. The Elm Road Units currently meet this requirement. The Columbia co-owners expect to meet the 90% reduction option by installing baghouses and scrubbers by mid 2014 (see the discussion regarding the Columbia environmental project below). With the finalization of the EPA's Mercury and Air Toxics Standard, or MATs, the WDNR is currently evaluating how the state mercury rule should be supplanted by the EPA's rule (see discussion on MATs below).

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

In December 2011, the EPA finalized its Mercury and Air Toxics Standards for coal and oil-burning EGU boilers. MATs will require emissions standards for mercury, non-mercury HAPs metals, and acid gases. Compliance with MATs is generally required three years from the rule issuance, but permitting authorities can grant an additional year for compliance to facilities. 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 (baghouse and scrubbers) to be installed by mid 2014, are expected to allow both facilities to comply with the MATs rule without extensions (see the discussion regarding Columbia environmental project below).

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National Ambient Air Quality Standards

The EPA has developed National Ambient Air Quality Standards (NAAQS) for six compounds currently identified as criteria pollutants: nitrogen dioxide, particulate matter, ozone, sulfur dioxide, lead, and carbon monoxide. The NAAQS for criteria pollutants establish acceptable ambient air levels of each pollutant based on a review of their 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.

Certain stationary sources, such as MGE's generation facilities, must meet NAAQS standards for emissions that travel offsite. Stationary source air quality modeling is used to determine whether emissions from permitted sources meet these NAAQS. Failure to meet NAAQS may require a permit applicant to incur capital or operational costs to bring a source into compliance. We cannot predict if MGE's permitted stationary sources will have difficulty meeting new standards not previously modeled. Modeling performed by the WDNR for MGE's permitted facilities has demonstrated compliance with current NAAQS. Additional modeling may be required in future permitting actions.

MGE tracks NAAQS developments to determine if new standards may affect us. MGE is currently tracking two NAAQS developments: (1) determination and placement of monitoring networks in Wisconsin for the 2010 nitrogen dioxide (NO₂) NAAQS (Wisconsin is currently considered in attainment with NO₂ NAAQS, however stationary source modeling may be required for NO₂ in the future) and (2) implementation requirements under the 2010 sulfur dioxide (SO₂) NAAQS. The EPA has issued draft guidance that indicates larger sources, such as Columbia, may be required to install ambient air monitors and/or perform dispersion modeling to demonstrate attainment. A concern has been raised regarding the current EPA-preferred dispersion model. The model may not be accurate for estimating SO₂ stationary source impacts and may overestimate off-site concentrations of SO₂ from stationary sources. The EPA is working to resolve issues with the model.

Reciprocating Internal Combustion Engine (RICE) MACT Standard

In January 2013, the EPA finalized amendments to its RICE MACT standard. RICE MACT applies to industrial or electrical engines that are classified as reciprocating internal combustion engines. Engines owned by MGE that would fall under the RICE MACT rule include backup generators and small engines at various locations, including our fleet of distributed generators that serve as electric system backup and emergency dispatch. The distributed generators in particular will either require additional pollution controls or a change in how they are dispatched. MGE is continuing to evaluate the impacts to our engines based on this new standard, including evaluating the costs associated with adding pollution controls on some or all our aforementioned distributed generators.

Greenhouse Gas Regulation

On March 27, 2012, the EPA proposed GHG New Source Performance Standards (NSPS) for coal fired and natural gas combined cycle (NGCC) EGUs. The proposal applies to new EGUs only.

However, the EPA plans to propose NSPS for existing units some time in 2013 as part of a 2010 settlement agreement. There is a great deal of uncertainty as to what the EPA will include in their NSPS for existing units and thus we are unable to comment on potential impacts to MGE at this time.

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, CAIR's eventual replacement, the Mercury and Air Toxics Standards

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(MATs), and the Wisconsin Mercury Rule. WPL, the plant operator, currently estimates that MGE's share of the capital expenditures required for this project is approximately $140 million. The project is underway and estimated to be completed by mid 2014.

MGE's share of various contractual commitments entered for the project as of March 31, 2013, is $56.7 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.

Title V Operating Permit Petition

In September 2008, the WDNR issued a Title V renewal operating permit to WPL for Columbia. However, a citizen group petitioned the EPA to object to 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. 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 June 2012, the EPA notified the plant operator of its intent to assume responsibility for issuing the renewed operating permit for Columbia, but agreed to provide the plant operator with more time to potentially resolve the issues raised in the EPA's order. On February 4, 2013, the parties involved dismissed the litigation without prejudice. The matter is still pending at the EPA but has been postponed pending possible resolution of the Clean Air Act litigation discussed below. 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 operations or financial condition.

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 co-owners (WPL, WPS, and MGE) failed to comply with appropriate pre-construction review and permitting requirements and, as a result, violated the PSD program requirements, the Title V operating permit requirements of the CAA and the Wisconsin State Implementation Plan (SIP). In September 2010, Sierra Club filed a lawsuit against WPL alleging violations of the CAA at Columbia and other WPL-operated Wisconsin facilities. WPL responded that the projects at Columbia were routine, or not projected to increase emissions, and therefore did not violate the permitting requirements of the CAA.

In April 2013, WPL, as operator, along with the other owners of Columbia (MGE and WPS), entered into a consent decree with the EPA and the Sierra Club to resolve these claims, while admitting no liability. The consent decree has been lodged with, and is subject to approval by, the Court, which could occur in the second quarter of 2013. The consent decree, requires installation of the following emission controls at Columbia; scrubbers and baghouses at Columbia Units 1 and 2 by December 31, 2014 and an SCR system at Columbia Unit 2 by December 31, 2018. In addition, the consent decree establishes emission rate limits for SO₂, nitrogen oxide (NO_x) and particulate matter for Columbia Units 1 and 2. The consent decree also includes annual plant-wide emission caps for SO₂ and NO_x for Columbia. MGE will also pay approximately $0.2 million as its share of a civil penalty and complete approximately $0.6 million in environmental mitigation projects. MGE currently expects to recover any material costs that could be incurred by MGE related to the terms of the final consent decree from MGE's electric customers, except for costs related to the civil penalty. In accordance with applicable accounting standards, MGE has accrued an amount for this matter representing its best estimate of its probable liability, based upon its assessment of the settlement. That accrued amount is not material to the financial statements. MGE believes the likelihood of a materially greater liability than the accrued amount is remote based upon the current status.

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, 2013. At March 31, 2013, MGE has outstanding a $4.3 million interest in these receivables. MGE retains the servicing responsibility for these receivables. As of March 31, 2013, the servicing asset recognized by MGE is $0.2 million.

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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.

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, 2013, 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 depending on the term of the underlying customer loan. Principal payments for the remainder of 2013 and the next four years on the loans are:

(In thousands)		2013		2014		2015		2016		2017
Chattel Paper	$	531	$	554	$	867	$	791	$	382

c.

Legal Matters - MGE Energy and MGE.

MGE is involved in various legal matters that are being defended and handled in the normal course of business, including the Columbia matters discussed above. MGE maintains accruals for such costs that are probable of being incurred and subject to reasonable estimation. The accrued amount for these matters is not material to the financial statements.

d.

Purchase Contracts - MGE Energy and MGE.

MGE Energy and MGE have entered into various commodity supply, transportation and storage contracts to meet their obligations to deliver electricity and natural gas to customers. As of March 31, 2013, the future commitments related to these purchase contracts were as follows:

(In thousands)		2013		2014		2015		2016		2017
Coal(a)	$	16,922	$	9,933	$	9,252	$	1,623	$	1,040
Purchase power(b)		49,182		48,425		47,293		48,121		49,242
Other		1,939		-		-		-		-
	$	68,043	$	58,358	$	56,545	$	49,744	$	50,282

(a)

Total coal commitments for the Columbia and Elm Road Units, including transportation.  Fuel procurement for MGE's jointly owned Columbia and Elm Road Units are handled by WPL and WEPCO, respectively, who are the operators of those facilities.  If any minimum purchase obligations must be paid under these contracts, management believes these obligations would be considered costs of service and recoverable in rates.

(b)

MGE has several purchase power agreements to help meet future electric supply requirements. Management expects to recover these costs in future customer rates.

e.

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, 2013, MGE has spent $9.6 million related to these projects and has outstanding agreements to purchase $0.9 million in smart grid related products for the remainder of 2013.

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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, 2013	December 31, 2012
Commodity derivative contracts	331,315  MWh	444,650  MWh
Commodity derivative contracts	1,360,000  Dth	1,980,000  Dth
FTRs	1,085  MW	2,670  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.

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 market, 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, 2013, and December 31, 2012, the fair value of exchange traded derivatives and FTRs exceeded their cost basis by $1.5 million and $0.3 million, respectively.

MGE is a party to 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 consolidated 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, 2013, and December 31, 2012, reflects a loss position of $70.7 million and $72.6 million, respectively. The actual fuel cost will be recognized in purchased power expense in the month of purchase.

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The following table summarizes the fair value of the derivative instruments on the consolidated 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, 2013
Commodity derivative contracts	Other current assets	$	1,343	Derivative liability (current)	$	30
Commodity derivative contracts	Other deferred charges		158	Derivative liability (long-term)		-
FTRs	Other current assets		22	Derivative liability (current)		-
Ten-year PPA	N/A		N/A	Derivative liability (current)		8,880
Ten-year PPA	N/A		N/A	Derivative liability (long-term)		61,810
December 31, 2012
Commodity derivative contracts	Other current assets	$	365	Derivative liability (current)	$	394
Commodity derivative contracts	Other deferred charges		95	Derivative liability (long-term)		11
FTRs	Other current assets		206	Derivative liability (current)		-
Ten-year PPA	N/A		N/A	Derivative liability (current)		9,270
Ten-year PPA	N/A		N/A	Derivative liability (long-term)		63,320

The following tables show the effect of netting arrangements for recognized derivative assets and liabilities that are subject to a master netting arrangement or similar arrangement on the balance sheet.

Offsetting of Derivative Assets
		Gross amounts		Gross amounts offset in balance sheet		Collateral posted against derivative positions		Net amount presented in balance sheet
(In thousands)
March 31, 2013
Commodity derivative contracts	$	1,502	$	(30)	$	(465)	$	1,007
FTRs		22		-		-		22
December 31, 2012
Commodity derivative contracts	$	460	$	(405)	$	-	$	55
FTRs		206		-		-		206

Offsetting of Derivative Liabilities
		Gross amounts		Gross amounts offset in balance sheet		Collateral posted against derivative positions		Net amount presented in balance sheet
(In thousands)
March 31, 2013
Commodity derivative contracts	$	30	$	(30)	$	-	$	-
Ten-year PPA		70,690		-		-		70,690
December 31, 2012
Commodity derivative contracts	$	405	$	(405)	$	-	$	-
Ten-year PPA		72,590		-		-		72,590

23

The following tables summarize the unrealized and realized gains (losses) related to the derivative instruments on the consolidated balance sheet at March 31, 2013 and 2012, and the consolidated income statement for the three months ended March 31, 2013 and 2012.

		2013				2012
(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,	$	72,329	$	574	$	42,356	$	1,604
Change in unrealized (gain) loss		(1,697)		-		33,310		-
Realized loss reclassified to a deferred account		(290)		290		(2,658)		2,658
Realized loss reclassified to income
statement		(1,145)		(605)		(1,494)		(3,590)
Balance at March 31,	$	69,197	$	259	$	71,514	$	672

		Realized losses (gains)
		Regulated gas revenues		Fuel for electric generation/ purchased power		Cost of gas sold
(In thousands)
Three Months Ended March 31, 2013:
Commodity derivative contracts	$	-	$	22	$	608
FTRs		-		(158)		-
Ten-year PPA		-		1,278		-
Three Months Ended March 31, 2012:
Commodity derivative contracts	$	-	$	1,928	$	3,090
FTRs		-		66		-
Ten-year PPA		-		-		-

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 consolidated 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-). 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. As of March 31, 2013, no collateral has been posted. Certain counterparties extend MGE a credit limit. If MGE exceeds these limits, the counterparties may require collateral to be posted. As of March 31, 2013, and December 31, 2012, 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, 2013, no counterparties have defaulted.

10.

Rate Matters - MGE Energy and MGE.

a.

Rate Proceedings.

On April 15, 2013, MGE applied with the PSCW for authority to freeze electric and natural gas rates at 2013 levels for 2014. The application includes a request for categorizing 100% of the cost of the Columbia scrubber construction project as AFUDC. The plan includes a request for deferral of increases in ATC and MISO Schedule 26 fees. In addition, MGE is requesting that approximately $6.2 million pertaining to a fuel rule surplus credit be offset against MGE's increased costs. The fuel credit will accrue interest at MGE's weighted cost of capital during 2013, and the requested treatment of the credit will contribute to the overall rate freeze for 2014.

24

On December 14, 2012, the PSCW authorized MGE to increase 2013 rates for retail electric customers by 3.8% or $14.9 million and to increase gas rates by 1.0% or $1.6 million. The change in retail electric rates was driven by costs for new environmental equipment at Columbia, final construction costs for the Elm Road Units, transmission reliability enhancements, and purchased power costs. The authorized return on common stock equity remains unchanged at 10.3%.

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.

b.

Fuel Rules.

Fuel rules require the PSCW and Wisconsin utilities to defer electric fuel-related costs that fall outside a symmetrical cost tolerance band around the amount approved for a utility in its most recent base rate proceedings. Any over/under recovery of the actual costs is determined on an annual basis and will be adjusted in future billings to electric retail customers. The fuel rules bandwidth is currently set at plus or minus 2%. 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, 2013, MGE did not defer any electric fuel-related savings/costs that are outside the range authorized by the PSCW.

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, 2013, MGE had over collected $5.3 million, recorded in other current liabilities on the consolidated balance sheet. At December 31, 2012, MGE had under collected $0.1 million, recorded in other current assets on the consolidated balance sheet.

11.

Fair Value of Financial Instruments - MGE Energy and MGE.

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.

25

a.

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

At March 31, 2013, and December 31, 2012, the carrying amount of cash and cash equivalents 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, 2013, and December 31, 2012. Since the long-term debt is not traded in an active market, it is classified as Level 2. The estimated fair market value of MGE Energy's and MGE's financial instruments are as follows:

		March 31, 2013				December 31, 2012
		Carrying		Fair		Carrying		Fair
(In thousands)		Amount		Value		Amount		Value
MGE Energy
Assets:
Cash and cash equivalents	$	45,894	$	45,894	$	46,357	$	46,357
Liabilities:
Short-term debt - commercial paper		10,500		10,500		-		-
Long-term debt*		361,138		432,430		361,805		427,456
MGE
Assets:
Cash and cash equivalents		9,856		9,856		6,350		6,350
Liabilities:
Short-term debt - commercial paper		10,500		10,500		-		-
Long-term debt*		361,138		432,430		361,805		427,456
*Includes long-term debt due within one year.

b.

Recurring Fair Value Measurements.

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, 2013
(In thousands)		Total		Level 1		Level 2		Level 3
MGE Energy
Assets:
Exchange-traded investments	$	428	$	428	$	-	$	-
Total Assets	$	428	$	428	$	-	$	-
Liabilities:
Derivatives, net(a)	$	69,197	$	(401)	$	-	$	69,598
Deferred compensation		2,085		-		2,085		-
Total Liabilities	$	71,282	$	(401)	$	2,085	$	69,598
MGE
Assets:
Exchange-traded investments	$	161	$	161	$	-	$	-
Total Assets	$	161	$	161	$	-	$	-
Liabilities:
Derivatives, net(a)	$	69,197	$	(401)	$	-	$	69,598
Deferred compensation		2,085		-		2,085		-
Total Liabilities	$	71,282	$	(401)	$	2,085	$	69,598
(a)     These amounts are shown gross and exclude $0.5 million of collateral that was posted                   against derivative positions with counterparties.

26

	Fair Value as of December 31, 2012
(In thousands)		Total		Level 1		Level 2		Level 3
MGE Energy
Assets:
Exchange-traded investments	$	320	$	320	$	-	$	-
Total Assets	$	320	$	320	$	-	$	-
Liabilities:
Derivatives, net	$	72,329	$	(17)	$	-	$	72,346
Deferred compensation		2,010		-		2,010		-
Total Liabilities	$	74,339	$	(17)	$	2,010	$	72,346
MGE
Assets:
Exchange-traded investments	$	117	$	117	$	-	$	-
Total Assets	$	117	$	117	$	-	$	-
Liabilities:
Derivatives, net	$	72,329	$	(17)	$	-	$	72,346
Deferred compensation		2,010		-		2,010		-
Total Liabilities	$	74,339	$	(17)	$	2,010	$	72,346

No transfers were made in or out of Level 1 or Level 2 for the three months ended March 31, 2013.

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 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 from 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.

27

This model is prepared by members of MGE's 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	97.1 %
Off peak	96.0 %
Counterparty fuel mix:
Internal generation	50 % - 70 %
Purchased power	50 % - 30 %

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 consolidated 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
		March 31,
(In thousands)		2013		2012
Beginning balance,	$	(72,346)	$	(40,661)
Realized and unrealized gains (losses):
Included in regulatory liabilities (assets)		2,748		(30,527)
Included in other comprehensive income		-		-
Included in earnings		(1,148)		(1,502)
Included in current assets		-		(50)
Purchases		5,562		50
Sales		(3)		31
Issuances		-		-
Settlements		(4,411)		1,471
Transfers in and/or out of Level 3		-		-
Balance as of March 31,	$	(69,598)	$	(71,188)
Total gains (losses) included in earnings attributed to
the change in unrealized gains (losses) related to
assets and liabilities held at March 31,(b)	$	-	$	-

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 (b).

		Three Months Ended
		March 31,
(In thousands)		2013		2012
Purchased Power Expense	$	(1,148)	$	(1,502)
Cost of Gas Sold Expense		-		-
Regulated Gas Revenues		-		-
Total	$	(1,148)	$	(1,502)

(b) 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.

28

12.

New Accounting Pronouncements - MGE Energy and MGE.

a.

Presentation of Comprehensive Income.

In February 2013, the FASB issued authoritative guidance within the Codification's Comprehensive Income topic that provides guidance on the reporting of amounts reclassified out of accumulated other comprehensive income. Reclassification adjustments will be presented either on the financial statement where income is presented or as a separate disclosure in the notes to the financial statements. This authoritative guidance became effective January 1, 2013. The authoritative guidance had no effect on our financial statement presentation or notes to the financial statements.

b.

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. On January 31, 2013, the FASB issued additional authoritative guidance which clarified the scope of disclosures about offsetting assets and liabilities. The revised guidance limits the scope of the new balance sheet offsetting disclosures to derivatives, repurchase agreements, and securities lending transactions to the extent that they are (1) offset in the financial statements or (2) subject to an enforceable master netting arrangement or similar agreement. This authoritative guidance became effective January 1, 2013. The authoritative guidance did not have a financial impact, but required additional disclosures. See Footnote 9 for additional information.

c.

Obligations Resulting from Joint and Several Liability Arrangements for Which the Total Amount of the Obligation Is Fixed at the Reporting Date.

In February 2013, the FASB issued authoritative guidance within the Codification's Balance Sheet topic that provides guidance on the recognition, measurement, and disclosure of obligations resulting from joint and several liability arrangements for which the total amount of the obligation is fixed at the reporting date. This authoritative guidance will become effective January 1, 2014. The authoritative guidance will not have a financial or disclosure impact.

29

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 2012 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) MGE Energy		Electric		Gas		Non- Regulated Energy		Transmission Investment		All Others		Consolidation/ Elimination Entries		Consolidated Total
Three Months Ended March 31, 2013
Operating revenues	$	93,494	$	72,467	$	1,276	$	-	$	-	$	-	$	167,237
Interdepartmental revenues		109		4,876		10,573		-		-		(15,558)		-
Total operating revenues		93,603		77,343		11,849		-		-		(15,558)		167,237
Depreciation and amortization		(6,400)		(1,425)		(1,799)		-		-		-		(9,624)
Other operating expenses		(74,925)		(60,437)		(37)		-		(144)		15,558		(119,985)
Operating income (loss)		12,278		15,481		10,013		-		(144)		-		37,628
Other income, net		575		162		-		2,396		176		-		3,309
Interest (expense) income, net		(2,404)		(678)		(1,613)		-		20		-		(4,675)
Income before taxes		10,449		14,965		8,400		2,396		52		-		36,262
Income tax provision		(3,433)		(5,989)		(3,257)		(971)		(28)		-		(13,678)
Net income	$	7,016	$	8,976	$	5,143	$	1,425	$	24	$	-	$	22,584
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

30

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

(In thousands) MGE		Electric		Gas		Non- Regulated Energy		Transmission Investment		Consolidation/ Elimination Entries		Consolidated Total
Three Months Ended March 31, 2013
Operating revenues	$	93,494	$	72,467	$	1,276	$	-	$	-	$	167,237
Interdepartmental revenues		109		4,876		10,573		-		(15,558)		-
Total operating revenues		93,603		77,343		11,849		-		(15,558)		167,237
Depreciation and amortization		(6,400)		(1,425)		(1,799)		-		-		(9,624)
Other operating expenses*		(78,506)		(66,468)		(3,294)		-		15,558		(132,710)
Operating income*		8,697		9,450		6,756		-		-		24,903
Other income, net*		723		204		-		1,425		-		2,352
Interest expense, net		(2,404)		(678)		(1,613)		-		-		(4,695)
Net income		7,016		8,976		5,143		1,425		-		22,560
Less: Net income attributable to
noncontrolling interest, net of tax		-		-		-		-		(6,826)		(6,826)
Net income attributable to MGE	$	7,016	$	8,976	$	5,143	$	1,425	$	(6,826)	$	15,734
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
*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) MGE Energy		Electric		Gas		Assets not Allocated	Nonregulated Energy			Transmission Investment		All Others	Consolidation/ Elimination Entries			Total
Assets:
March 31, 2013	$	904,578	$	275,815	$	11,900	$	324,894	$	61,826	$	409,602	$	(408,175)	$	1,580,440
December 31, 2012		888,444		285,468		18,559		323,216		61,064		413,291		(403,118)		1,586,924
Capital Expenditures:
Three Months Ended March 31, 2013	$	27,007	$	1,689	$	-	$	468	$	-	$	-	$	-	$	29,164
Year ended Dec. 31, 2012		81,965		13,812		-		2,658		-		-		-		98,435

		Utility						Consolidated
(In thousands) MGE		Electric		Gas		Assets not Allocated	Nonregulated Energy			Transmission Investment		Elimination Entries		Total
Assets:
March 31, 2013	$	904,578	$	275,815	$	11,900	$	324,844	$	61,826	$	(28,358)	$	1,550,605
December 31, 2012		888,444		285,468		18,559		323,166		61,064		(23,050)		1,553,651
Capital Expenditures:
Three Months Ended March 31, 2013	$	27,007	$	1,689	$	-	$	468	$	-	$	-	$	29,164
Year ended Dec. 31, 2012		81,965		13,812		-		2,658		-		-		98,435

31

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 140,000 customers in Dane County, Wisconsin, including the city of Madison, and purchases and distributes natural gas to approximately 145,000 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 ownership interest in two 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 our 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" in our 2012 Annual Report on Form 10-K.

For the three months ended March 31, 2013, MGE Energy's earnings were $22.6 million or $0.98 per share compared to $16.0 million or $0.69 per share for the same period in the prior year. MGE's earnings for the three months ended March 31, 2013, were $15.7 million compared to $10.1 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 March 31,
(In thousands)
Business Segment:		2013		2012
Electric Utility	$	7,016	$	5,431
Gas Utility		8,976		4,933
Nonregulated Energy		5,143		4,518
Transmission Investments		1,425		1,332
All Other		24		(166)
Net Income	$	22,584	$	16,048

Our net income during the three months ended March 31, 2013, primarily reflects the effects of the following factors:

·

A 4.5% increase in retail electric revenues, driven by a 6.9% increase in residential customer demand.

·

A 31.8% increase in gas sales reflecting higher customer demand due to a colder winter compared to the same period in the prior year. Heating degree days (a measure for determining the impact of weather during the heating season) increased by 38% compared to the prior period.

During the first three months of 2013, 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. As of March 31, 2013, MGE has accumulated $78.8 million (excluding carrying costs) related to its share of the project, which is reflected in the Construction Work in Progress balance on MGE Energy's and MGE's consolidated balance sheets. Of this amount, MGE has accumulated $18.8 million in 2013. MGE has recognized $0.5 million (after tax) in AFUDC equity related to this project for the three months ended March 31, 2013.

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, 2013, MGE has spent $9.6 million related to these projects. Of this amount, $1.2 million was incurred during the three months ended March 31, 2013. MGE also has outstanding agreements to purchase $0.9 million in smart grid related products for the remainder of 2013.

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

Rate Filing: On April 15, 2013, MGE applied with the PSCW for authority to freeze electric and natural gas rates at 2013 levels for 2014. The application includes a request for categorizing 100% of the cost of the Columbia scrubber construction project as AFUDC. The plan includes a request for deferral of increases in ATC and MISO Schedule 26 fees. In addition, MGE is requesting that approximately $6.2 million pertaining to a fuel rule surplus credit be offset against MGE's increased costs. The fuel credit will accrue interest at MGE's weighted cost of capital during 2013, and the requested treatment of the credit will contribute to the overall rate freeze for 2014.

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. See Columbia discussion in Footnote 8.a. in Notes to Consolidated Financial Statements.

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Columbia Environmental Project: MGE's share of the capital expenditures associated with the Columbia environmental project will be approximately $49 million for the remainder of 2013 million and $12 million in 2014. We intend to fund any remaining capital commitments with funds generated from normal operations and the issuance of long-term and short-term debt.

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 $104.5 million for MGE Energy (including MGE) and $64.5 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, 2013 and 2012

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 Three Months Ended March 31,				Sales (kWh) Three Months Ended March 31,
(in thousands)
		2013		2012	% Change	2013	2012	% Change
Residential	$	33,574	$	30,139	11.4 %	209,782	196,163	6.9 %
Commercial		48,147		47,196	2.0 %	429,359	431,755	(0.6)%
Industrial		4,531		4,526	0.1 %	59,187	59,848	(1.1)%
Other-retail/municipal		8,639		8,974	(3.7)%	97,538	107,680	(9.4)%
Total retail		94,891		90,835	4.5 %	795,866	795,446	0.1 %
Sales to the market		19		280	(93.2)%	10,146	5,788	75.3 %
Adjustments to revenues		(1,416)		(1,179)	(20.1)%	-	-	- %
Total	$	93,494	$	89,936	4.0 %	806,012	801,234	0.6 %

Electric operating revenues increased $3.6 million or 4.0% for the three months ended March 31, 2013, due to the following:

(In millions)
Rate changes	$	4.0
Sales to the market		(0.2)
Adjustments to revenues		(0.2)
Total	$	3.6

·

Rate changes. Rates charged to retail customers for the three months ended March 31, 2013, were 4.4% or $4.0 million higher than those charged during the same period in the prior year.

In December 2012, the PSCW authorized MGE to increase 2013 rates for retail electric customers by 3.8% or $14.9 million. The increase in retail electric rates is driven by costs for new environmental equipment at Columbia, final construction costs for the Elm Road Units, transmission reliability enhancements, and purchased power costs.

·

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, 2013, market volumes increased compared to the same period in the prior year, reflecting increased opportunities for sales; however, market settlement resulted in lower revenue per kWh for the three months ended March 31, 2013, reflecting lower market prices.

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·

Adjustments to revenues. The adjustments to revenues amount includes the elimination of carrying costs for the Elm Road Units and WCCF 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 increased $1.9 million or 21.6% during the three months ended March 31, 2013, compared to the same period in the prior year. Internal electric generated volume delivered to the system increased 35.4% which resulted in $2.8 million of increased expense, reflecting higher generation at Columbia. This increase was offset by a decrease in internal electric generation costs of $0.9 million as a result of a 10.2% decrease in the per-unit cost (largely due to lower natural gas prices).

Purchased power expense decreased $1.3 million during the three months ended March 31, 2013, compared to the same period in the prior year. A 29.4% decrease in the volume of purchased power from third parties lowered expense by $5.7 million, which was offset by a $4.4 million or 31.9% increase in the per-unit cost of purchased power.

Electric operating and maintenance expenses

Electric operating and maintenance expenses decreased $0.4 million during the three months ended March 31, 2013, compared to the same period in 2012. The following changes contributed to the net change:

(In millions)
Decreased administrative and general costs	$	(0.7)
Decreased customer service costs		(0.3)
Decreased other costs		(0.1)
Increased transmission costs		0.7
Total	$	(0.4)

For the three months ended March 31, 2013, decreased administrative and general costs are primarily due to decreased pension costs and increased transmission costs are primarily due to an increase in transmission reliability enhancements.

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 Three Months Ended March 31,				Therms Delivered Three Months Ended March 31,
(In thousands, except HDD and average rate per therm of retail customer)
		2013		2012	% Change	2013	2012	% Change
Residential	$	41,611	$	33,381	24.7 %	47,454	35,600	33.3 %
Commercial/Industrial		29,771		22,771	30.7 %	49,211	36,947	33.2 %
Total retail		71,382		56,152	27.1 %	96,665	72,547	33.2 %
Gas transportation		943		729	29.4 %	12,327	10,117	21.8 %
Other revenues		142		138	2.9 %	-	-	- %
Total	$	72,467	$	57,019	27.1 %	108,992	82,664	31.8 %
Heating degree days (normal 3,488)						3,745	2,717	37.8 %
Average rate per therm of
retail customer	$	0.738	$	0.774	(4.7)%

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Gas revenues increased $15.4 million or 27.1% for the three months ended March 31, 2013. These changes are related to the following factors:

(In millions)
Gas deliveries	$	18.7
Transportation and other effects		0.1
Gas costs/rates		(3.4)
Total	$	15.4

·

Retail gas deliveries. For the three months ended March 31, 2013, retail gas deliveries increased 33.2% compared to the same period in 2012 as a result of colder weather during the winter months compared to milder weather in the prior year.

·

Gas costs/rates. The average retail rate per therm for the three months ended March 31, 2013, decreased 4.7% compared to the same period in 2012, reflecting lower natural gas commodity costs.

Cost of gas sold

For the three months ended March 31, 2013, cost of gas sold increased by $9.8 million, compared to the same period in the prior year. The volume of gas purchased increased 33.0%, which resulted in $11.4 million of increased expense. However, the cost per therm of natural gas decreased 3.5%, which resulted in $1.6 million of decreased expense.

Gas operating and maintenance expenses

Gas operating and maintenance expenses decreased by $0.7 million for the three months ended March 31, 2013, compared to the same period in 2012. The following changes contributed to the net change:

(In millions)
Decreased administrative and general costs	$	(0.3)
Decreased customer service costs		(0.3)
Decreased customer accounts costs		(0.1)
Total	$	(0.7)

Nonregulated Energy Operations - MGE Energy and MGE

For the three months ended March 31, 2013 and 2012, net income at the nonregulated energy operations segment was $5.1 million and $4.5 million, respectively. The nonregulated energy operations are conducted through MGE Energy's subsidiaries: 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, 2013, other income at the transmission investment segment was $2.4 million compared to $2.2 million for the same period in 2012. 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, 2013, was 37.7% compared to 38.1% for the same period in 2012.

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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 MGE Power Elm Road (the Elm Road Units) and MGE Power West Campus (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)		2013		2012
MGE Power Elm Road	$	4.3	$	3.7
MGE Power West Campus	$	1.9	$	1.9
MGE Transco	$	0.6	$	0.5

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, 2013, except as noted below. Further discussion of the contractual obligations and commercial commitments is included in Footnote 8 of this Report 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 2012 Annual Report on Form 10-K.

Purchase Contracts - MGE Energy and MGE

See Footnote 8.d. for a description of commitments at March 31, 2013, that MGE Energy and MGE have entered with respect to various commodity supply, transportation and storage contracts to meet their obligations to deliver electricity and natural gas to customers.

Smart Grid Investment Grant - MGE Energy and MGE

See Footnote 8.e. for a description of MGE's commitments and expenditures related to a grant received from the U.S. Department of Energy (DOE) under the federal stimulus program for smart grid projects.

Liquidity and Capital Resources

Cash Flows

The following summarizes cash flows for MGE Energy and MGE during the three months ended March 31, 2013 and 2012:

		MGE Energy				MGE
(In thousands)		2013		2012		2013		2012
Cash provided by/(used for):
Operating activities	$	28,652	$	24,736	$	28,521	$	23,583
Investing activities		(29,816)		(15,716)		(29,526)		(15,773)
Financing activities		701		(9,529)		4,511		(7,049)

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.

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Cash provided by operating activities for the three months ended March 31, 2013, was $28.7 million, an increase of $3.9 million when compared to the same period in the prior year primarily related to working capital changes.

MGE Energy's net income increased $6.5 million for the three months ended March 31, 2013, when compared to the same period in the prior year.

The cash flows for the three months ended March 31, 2013, reflect a $2.4 million benefit of lower taxes payable, compared to the same period in the prior year, primarily due to bonus depreciation and repairs deduction.

Working capital accounts resulted in $12.8 million in cash provided by operating activities for the three months ended March 31, 2013, primarily due to decreased gas inventories, decreased prepaid taxes, and decreased unbilled revenues, partially offset by increased accounts receivable and decreased accounts payable. 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.

An increase in pension contribution resulted in an additional $10.0 million in cash used for operating activities for the three months ended March 31, 2013, when compared to the same period in the prior year. These contributions reflect amounts required by law and discretionary amounts.

MGE

Cash provided by operating activities for the three months ended March 31, 2013, was $28.5 million, an increase of $4.9 million when compared to the same period in the prior year primarily related to working capital changes.

Net income increased $6.3 million for the three months ended March 31, 2013, when compared to the same period in the prior year.

The cash flows for the three months ended March 31, 2013, reflect a $2.2 million benefit of lower taxes payable, compared to the same period in the prior year, primarily due to bonus depreciation and repairs deduction.

Working capital accounts resulted in $12.8 million in cash provided by operating activities for the three months ended March 31, 2013, primarily due to decreased gas inventories, decreased prepaid taxes, and decreased unbilled revenues, partially offset by increased accounts receivable and decreased accounts payable. 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.

An increase in pension contribution resulted in an additional $10.0 million in cash used for operating activities for the three months ended March 31, 2013, when compared to the same period in the prior year. These contributions reflect amounts required by law and discretionary amounts.

Cash Used for Investing Activities

MGE Energy

MGE Energy's cash used for investing activities increased $14.1 million for the three months ended March 31, 2013, when compared to the same period in the prior year.

Capital expenditures for the three months ended March 31, 2013, were $29.2 million. This amount represents an increase of $13.7 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 $10.8 million.

MGE

MGE's cash used for investing activities increased $13.8 million for the three months ended March 31, 2013, when compared to the same period in the prior year.

Capital expenditures for the three months ended March 31, 2013, were $29.2 million. This amount represents an increase of $13.7 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 $10.8 million.

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Cash Provided by (Used for) Financing Activities

MGE Energy

Cash provided by MGE Energy's financing activities was $0.7 million for the three months ended March 31, 2013, compared to $9.5 million of cash used for the three months ended March 31, 2012.

For the three months ended March 31, 2013, dividends paid were $9.1 million compared to $8.8 million in the prior year. This increase was a result of a higher dividend per share ($0.395 vs. $0.383).

During the three months ended March 31, 2013, net short-term debt borrowings were $10.5 million.

MGE

During the three months ended March 31, 2013, cash provided by MGE's financing activities was $4.5 million compared to $7.0 million of cash used for MGE's financing activities in the prior year.

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

During the three months ended March 31, 2013, net short-term debt borrowings were $10.5 million.

Distributions to parent from noncontrolling interest were $5.5 million for the three months ended March 31, 2013.

Capitalization Ratios

MGE Energy's capitalization ratios were as follows:

	MGE Energy
	March 31, 2013	December 31, 2012
Common shareholders' equity	61.5 %	61.6 %
Long-term debt*	37.4 %	38.4 %
Short-term debt	1.1 %	- %
*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, 2013, capital expenditures for MGE Energy and MGE totaled $29.2 million, which included $28.7 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's share of the capital expenditures associated with the Columbia environmental project will be approximately $49 million for the remainder of 2013 and $12 million in 2014. During the three months ended March 31, 2013, MGE had incurred $18.8 million (excluding carrying costs) in construction expenditures at Columbia related to the project. MGE has recognized $0.5 million (after tax) in AFUDC equity related to this project for the three months ended March 31, 2013.

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.

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Environmental Matters

The following discussion is limited to updates or developments in environmental matters that occurred during the three months ended March 31, 2013. Further discussion of environmental matters is included in MGE Energy's and MGE's 2012 Annual Report on Form 10-K and Footnote 8.a. of Notes to Consolidated Financial Statements in this Report.

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

In 2005, EPA promulgated the Clean Air Interstate Rule (CAIR) to reduce ozone and fine particulate matter emissions by reducing nitrogen oxide (NO_x) and sulfur dioxide (SO₂) emissions. NO_x and SO₂ interact in the atmosphere to form ambient ozone from NO_x and fine particulate matter pollution from NO_x and SO₂. The CAIR generally requires NO_x and SO₂ emission reductions from fossil fuel-fired EGUs (25 MW or greater) 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 Units, 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 with directions to revise or replace the rule. The Court's remand order directed that the CAIR remain in effect until the EPA promulgated a replacement rule. The Court's order did not include a deadline for the EPA to act.

In August 2011, the EPA responded to the remand of the CAIR by promulgating the Cross State Air Pollution Rule (CSAPR). However, in August 2012, the U.S. Court of Appeals for the D.C. Circuit vacated CSAPR and instructed the EPA to continue administering the CAIR pending finalizing a valid alternative program to control interstate pollution. In January 2013, the U.S. Court of Appeals for the D.C. Circuit denied the EPA's petition for reconsideration en banc. The EPA and several environmental groups have appealed the D.C. Circuit Court's August 2012 decision to the Supreme Court in separate filings. At this time, the CAIR remains effective.

MGE is currently in compliance with the CAIR Phase I requirements. MGE will be able to meet Phase II NO_x emissions reductions through using our NO_x allowances provided through the rule, and we will meet Phase II SO₂ emissions reductions through installation of pollution controls. New SO₂ controls at Columbia are already underway and are planned to be completed by mid 2014. MGE expects that any costs incurred to meet Phase II of the CAIR will be fully recoverable through rates. MGE will monitor the Supreme Court's response to the CSAPR appeals and any subsequent actions by the EPA to continue to evaluate potential impacts to our operations.

Columbia

Columbia is a coal-fired generating station operated by WPL in which WPL, WPSC, and MGE have ownership interests. 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 and the Columbia co-owners failed to comply with appropriate pre-construction review and permitting requirements and, as a result, violated the Prevention of Significant Deterioration program requirements, Title V Operating Permit requirements of the CAA, and the Wisconsin SIP. In September 2010, the Sierra Club filed a civil lawsuit against WPL alleging violations of the CAA at Columbia and other Wisconsin facilities operated by WPL. In April 2013, WPL, as operator, along with the other owners of Columbia (MGE and WPS), entered into a consent decree with the EPA and the Sierra Club to resolve these claims, while admitting no liability. One of the requirements of the consent decree requires installation of a SCR system at Columbia Unit 2 by December 31, 2018. Based on a preliminary estimate received by WPL, MGE’s share of the projected cost for construction of the SCR system at Columbia is approximately $50-$60 million. The consent decree has been lodged with, and is subject to approval by, the Court, which could occur in the second quarter of 2013. See Footnote 8.a. for additional information regarding these matters.

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 fuel rules require the PSCW and Wisconsin utilities to defer electric fuel-related costs that fall outside a symmetrical cost tolerance band. Any over/under recovery of the actual 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 electric fuel rules costs fall outside the lower end of the range and would defer costs, less any excess revenues, if the actual electric 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 2013, fuel and purchased power costs included in MGE's base fuel rates are $106.1 million. See Footnote 10.b. for additional information.

MGE recovers the cost of natural gas in its gas segment through the purchased gas adjustment clause (PGA). Under the PGA, MGE is able to pass through to its gas 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 under applicable PSCW approvals 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 transmission congestion charges. At March 31, 2013, the fair value of these instruments exceeded their cost basis by $1.5 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 consolidated 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 that began on June 1, 2012, and ends 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 consolidated 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, 2013, reflects a loss position of $70.7 million.

41

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.

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 include 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, 2013, 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, 2012, no one customer constituted more than 10% 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 2013, 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, 2013, 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, 2013, 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 more information.

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

Issuer Purchases of Equity Securities

Period	Total Number of Shares Purchased		Average Price Paid per Share	Total Number of Shares Purchased as Part of Publicly Announced Plans or Programs*	Maximum number (or Approximate Dollar Value) of Shares That May Yet Be Purchased Under the Plans or Programs*
January 1-31, 2013	22,070	$	52.03	-	-
February 1-28, 2013	22,995		53.14	-	-
March 1-31, 2013	55,875		55.02	-	-
Total	100,940	$	53.94	-	-

* 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.

Item 4. Mine Safety Disclosures.

Not applicable to MGE Energy and MGE.

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, 2013, 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

44

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, 2013, 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

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 3, 2013	/s/ Gary J. Wolter
	Gary J. Wolter Chairman, President and Chief Executive Officer (Duly Authorized Officer)
Date: May 3, 2013	/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 3, 2013	/s/ Gary J. Wolter
	Gary J. Wolter Chairman, President and Chief Executive Officer (Duly Authorized Officer)
Date: May 3, 2013	/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, 2013

(In thousands)

Earnings
Net income before minority interest	$22,560
Equity earnings	(2,396)
Income distribution from equity investees	1,807
Minority interest in pretax income	(998)
Amortization of capitalized interest	132
Federal and state income taxes	13,651
Fixed charges	5,107
Total Earnings as Defined	$39,863
Fixed Charges
Interest expense on long-term debt and other	$4,529
Interest on rentals*	216
Amortization of debt issuance costs	166
AFUDC - borrowed funds	196
Total Fixed Charges	$5,107
Ratio of Earnings to Fixed Charges	7.81X

*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 3, 2013

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 3, 2013

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 3, 2013

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 3, 2013

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, 2013, 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 3, 2013

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, 2013, 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 3, 2013

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, 2013, 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 3, 2013

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, 2013, 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 3, 2013

XML

Pension and Other Postretirement Plans (Details) (USD $)	3 Months Ended
	Mar. 31, 2013	Mar. 31, 2012
Deferred pension and OPRB costs recovered [Abstract]
Deferred pension and OPRB costs recovered	$ 300,000	$ 300,000
Pension Benefits [Member]
Components of net periodic benefit cost [Line Items]
Service cost	1,929,000	1,823,000
Interest cost	3,186,000	3,154,000
Expected return on assets	(4,776,000)	(3,818,000)
Amortization of:
Prior service cost	79,000	108,000
Actuarial loss	2,015,000	2,006,000
Net periodic benefit cost	2,433,000	3,273,000
Postretirement Benefits [Member]
Components of net periodic benefit cost [Line Items]
Service cost	596,000	647,000
Interest cost	970,000	1,125,000
Expected return on assets	(544,000)	(435,000)
Amortization of:
Transition obligation	1,000	106,000
Prior service cost	28,000	28,000
Actuarial loss	311,000	621,000
Net periodic benefit cost	$ 1,362,000	$ 2,092,000

XML

Fair Value of Financial Instruments (Details-1) (USD $) In Thousands, unless otherwise specified	3 Months Ended
	Mar. 31, 2013	Mar. 31, 2013 Maximum [Member]	Mar. 31, 2013 Minimum [Member]	Mar. 31, 2013 Carrying Amount [Member]	Dec. 31, 2012 Carrying Amount [Member]	Mar. 31, 2013 Fair Value [Member]	Dec. 31, 2012 Fair Value [Member]	Mar. 31, 2013 MGE [Member] Carrying Amount [Member]	Dec. 31, 2012 MGE [Member] Carrying Amount [Member]	Mar. 31, 2013 MGE [Member] Fair Value [Member]	Dec. 31, 2012 MGE [Member] Fair Value [Member]
Assets:
Cash and cash equivalents				$ 45,894	$ 46,357	$ 45,894	$ 46,357	$ 9,856	$ 6,350	$ 9,856	$ 6,350
Liabilities:
Short-term debt - commercial paper				10,500	0	10,500	0	10,500	0	10,500	0
Long-term debt				$ 361,138	$ 361,805	$ 432,430	$ 427,456	$ 361,138	$ 361,805	$ 432,430	$ 427,456
Significant unobservable inputs [Line Items]
Basis adjustment - on peak	97.10%
Basis adjustment - off peak	96.00%
Counterparty fuel mix [Abstract]
Internal generation		70.00%	50.00%
Purchased power		50.00%	30.00%

XML

Derivative and Hedging Instruments (Details-4) (USD $)			3 Months Ended
	Mar. 31, 2013	Dec. 31, 2012	Mar. 31, 2013 Commodity Derivative Contracts [Member] Regulated Gas Revenues [Member]	Mar. 31, 2012 Commodity Derivative Contracts [Member] Regulated Gas Revenues [Member]	Mar. 31, 2013 Commodity Derivative Contracts [Member] Fuel For Electric Generation Purchased Power [Member]	Mar. 31, 2012 Commodity Derivative Contracts [Member] Fuel For Electric Generation Purchased Power [Member]	Mar. 31, 2013 Commodity Derivative Contracts [Member] Cost Of Gas Sold Expense [Member]	Mar. 31, 2012 Commodity Derivative Contracts [Member] Cost Of Gas Sold Expense [Member]	Mar. 31, 2013 Financial Transmission Rights [Member] Regulated Gas Revenues [Member]	Mar. 31, 2012 Financial Transmission Rights [Member] Regulated Gas Revenues [Member]	Mar. 31, 2013 Financial Transmission Rights [Member] Fuel For Electric Generation Purchased Power [Member]	Mar. 31, 2012 Financial Transmission Rights [Member] Fuel For Electric Generation Purchased Power [Member]	Mar. 31, 2013 Financial Transmission Rights [Member] Cost Of Gas Sold Expense [Member]	Mar. 31, 2012 Financial Transmission Rights [Member] Cost Of Gas Sold Expense [Member]	Mar. 31, 2013 Purchased Power Agreement [Member] Regulated Gas Revenues [Member]	Mar. 31, 2012 Purchased Power Agreement [Member] Regulated Gas Revenues [Member]	Mar. 31, 2013 Purchased Power Agreement [Member] Fuel For Electric Generation Purchased Power [Member]	Mar. 31, 2012 Purchased Power Agreement [Member] Fuel For Electric Generation Purchased Power [Member]	Mar. 31, 2013 Purchased Power Agreement [Member] Cost Of Gas Sold Expense [Member]	Mar. 31, 2012 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	$ 22,000	$ 1,928,000	$ 608,000	$ 3,090,000	$ 0	$ 0	$ (158,000)	$ 66,000	$ 0	$ 0	$ 0	$ 0	$ 1,278,000	$ 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
Required collateral posted	0
Counterparties in net liability position [Abstract]
Counterparties in net liability position	$ 0	$ 0

XML

Segment Information (Tables)

3 Months Ended

Mar. 31, 2013

Segment Information (Tables) [Line Items]

Segment Information

(In thousands)						Non-						Consolidation/
MGE Energy						Regulated		Transmission		All		Elimination		Consolidated
		Electric		Gas		Energy		Investment		Others		Entries		Total
Three Months Ended March 31, 2013
Operating revenues	$	93,494	$	72,467	$	1,276	$	0	$	0	$	0	$	167,237
Interdepartmental revenues		109		4,876		10,573		0		0		(15,558)		0
Total operating revenues		93,603		77,343		11,849		0		0		(15,558)		167,237
Depreciation and amortization		(6,400)		(1,425)		(1,799)		0		0		0		(9,624)
Other operating expenses		(74,925)		(60,437)		(37)		0		(144)		15,558		(119,985)
Operating income (loss)		12,278		15,481		10,013		0		(144)		0		37,628
Other income, net		575		162		0		2,396		176		0		3,309
Interest (expense) income, net		(2,404)		(678)		(1,613)		0		20		0		(4,675)
Income before taxes		10,449		14,965		8,400		2,396		52		0		36,262
Income tax provision		(3,433)		(5,989)		(3,257)		(971)		(28)		0		(13,678)
Net income	$	7,016	$	8,976	$	5,143	$	1,425	$	24	$	0	$	22,584
Three Months Ended March 31, 2012
Operating revenues	$	89,936	$	57,019	$	2,304	$	0	$	0	$	0	$	149,259
Interdepartmental revenues		109		2,986		8,676		0		0		(11,771)		0
Total operating revenues		90,045		60,005		10,980		0		0		(11,771)		149,259
Depreciation and amortization		(6,478)		(1,370)		(1,776)		0		0		0		(9,624)
Other operating expenses		(72,788)		(49,741)		(12)		0		(421)		11,771		(111,191)
Operating income (loss)		10,779		8,894		9,192		0		(421)		0		28,444
Other income, net		164		46		0		2,242		118		0		2,570
Interest (expense) income, net		(2,727)		(769)		(1,645)		0		37		0		(5,104)
Income (loss) before taxes		8,216		8,171		7,547		2,242		(266)		0		25,910
Income tax (provision) benefit		(2,785)		(3,238)		(3,029)		(910)		100		0		(9,862)
Net income (loss)	$	5,431	$	4,933	$	4,518	$	1,332	$	(166)	$	0	$	16,048

(In thousands)						Non-				Consolidation/
MGE						Regulated		Transmission		Elimination		Consolidated
		Electric		Gas		Energy		Investment		Entries		Total
Three Months Ended March 31, 2013
Operating revenues	$	93,494	$	72,467	$	1,276	$	0	$	0	$	167,237
Interdepartmental revenues		109		4,876		10,573		0		(15,558)		0
Total operating revenues		93,603		77,343		11,849		0		(15,558)		167,237
Depreciation and amortization		(6,400)		(1,425)		(1,799)		0		0		(9,624)
Other operating expenses*		(78,506)		(66,468)		(3,294)		0		15,558		(132,710)
Operating income*		8,697		9,450		6,756		0		0		24,903
Other income, net*		723		204		0		1,425		0		2,352
Interest expense, net		(2,404)		(678)		(1,613)		0		0		(4,695)
Net income		7,016		8,976		5,143		1,425		0		22,560
Less: Net income attributable to
noncontrolling interest, net of tax		0		0		0		0		(6,826)		(6,826)
Net income attributable to MGE	$	7,016	$	8,976	$	5,143	$	1,425	$	(6,826)	$	15,734
Three Months Ended March 31, 2012
Operating revenues	$	89,936	$	57,019	$	2,304	$	0	$	0	$	149,259
Interdepartmental revenues		109		2,986		8,676		0		(11,771)		0
Total operating revenues		90,045		60,005		10,980		0		(11,771)		149,259
Depreciation and amortization		(6,478)		(1,370)		(1,776)		0		0		(9,624)
Other operating expenses*		(75,508)		(52,961)		(3,041)		0		11,771		(119,739)
Operating income*		8,059		5,674		6,163		0		0		19,896
Other income, net*		99		28		0		1,332		0		1,459
Interest expense, net		(2,727)		(769)		(1,645)		0		0		(5,141)
Net income		5,431		4,933		4,518		1,332		0		16,214
Less: net income attributable to
noncontrolling interest, net of tax		0		0		0		0		(6,072)		(6,072)
Net income attributable to MGE	$	5,431	$	4,933	$	4,518	$	1,332	$	(6,072)	$	10,142
*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, 2013	$	904,578	$	275,815	$	11,900	$	324,894	$	61,826	$	409,602	$	(408,175)	$	1,580,440
December 31, 2012		888,444		285,468		18,559		323,216		61,064		413,291		(403,118)		1,586,924
Capital Expenditures:
Three Months Ended March 31, 2013	$	27,007	$	1,689	$	0	$	468	$	0	$	0	$	0	$	29,164
Year ended Dec. 31, 2012		81,965		13,812		0		2,658		0		0		0		98,435

		Utility						Consolidated
(In thousands)						Assets
MGE						not	Nonregulated			Transmission		Elimination
		Electric		Gas		Allocated		Energy		Investment		Entries		Total
Assets:
March 31, 2013	$	904,578	$	275,815	$	11,900	$	324,844	$	61,826	$	(28,358)	$	1,550,605
December 31, 2012		888,444		285,468		18,559		323,166		61,064		(23,050)		1,553,651
Capital Expenditures:
Three Months Ended March 31, 2013	$	27,007	$	1,689	$	0	$	468	$	0	$	0	$	29,164
Year ended Dec. 31, 2012		81,965		13,812		0		2,658		0		0		98,435

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New Accounting Pronouncements

3 Months Ended

Mar. 31, 2013

New Accounting Pronouncements Disclosure [Abstract]

New Accounting Pronouncements

12.       New Accounting Pronouncements - MGE Energy and MGE.

a.       Presentation of Comprehensive Income.

In February 2013, the FASB issued authoritative guidance within the Codification's Comprehensive Income topic that provides guidance on the reporting of amounts reclassified out of accumulated other comprehensive income. Reclassification adjustments will be presented either on the financial statement where income is presented or as a separate disclosure in the notes to the financial statements. This authoritative guidance became effective January 1, 2013.The authoritative guidance hadno effect on our financial statement presentation or notes to the financial statements.

b.       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. On January 31, 2013, the FASB issued additional authoritative guidance which clarified the scope of disclosures about offsetting assets and liabilities. The revised guidance limits the scope of the new balance sheet offsetting disclosures to derivatives, repurchase agreements, and securities lending transactions to the extent that they are (1) offset in the financial statements or (2) subject to an enforceable master netting arrangement or similar agreement. This authoritative guidance became effective January 1, 2013. The authoritative guidance did not have a financial impact, but required additional disclosures. See Footnote 9 for additional information.

c.       Obligations Resulting from Joint and Several Liability Arrangements for Which the Total Amount of the Obligation Is Fixed at the Reporting Date.

In February 2013, the FASB issued authoritative guidance within the Codification's Balance Sheet topic that provides guidance on the recognition, measurement, and disclosure of obligations resulting from joint and several liability arrangements for which the total amount of the obligation is fixed at the reporting date. This authoritative guidance will become effective January 1, 2014. The authoritative guidance will not have a financial or disclosure impact.

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Fair Value of Financial Instruments (Details-3) (USD $) In Thousands, unless otherwise specified	3 Months Ended
	Mar. 31, 2013	Mar. 31, 2012
Changes in level 3 assets and liabilities measured at fair value on a recurring basis [Abstract]
Beginning balance,	$ (72,346)	$ (40,661)
Realized and unrealized gains (losses):
Included in regulatory liabilities (assets)	2,748	(30,527)
Included in other comprehensive income	0	0
Included in earnings	(1,148)	(1,502)
Included in current assets	0	(50)
Purchases	5,562	50
Sales	(3)	31
Issuances	0	0
Settlements	(4,411)	1,471
Transfers in or out of level 3	0	0
Ending balance,	(69,598)	(71,188)
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.	(1,148)	(1,502)
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.	(1,148)	(1,502)
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-2) (USD $)	3 Months Ended
	Mar. 31, 2013
Chattel Paper Purchase Agreement [Abstract]
Chattel paper purchase agreement maximum interest	$ 10,000,000
Outstanding interest in chattel paper receivables	4,300,000
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	9,600,000
One Year From Balance Sheet Date [Member]
Chattel Paper Agreement Principal Payments [Abstract]
Chattel paper agreement principal payments commitments	531,000
Operating expense purchase contracts [Abstract]
Coal commitments	16,922,000
Purchase power commitments	49,182,000
Other commitments	1,939,000
Total purchase contracts	68,043,000
Smart Grid Investment Grant [Abstract]
Smart grid commitments to date	900,000
More Than One And Within Two Years From Balance Sheet Date [Member]
Chattel Paper Agreement Principal Payments [Abstract]
Chattel paper agreement principal payments commitments	554,000
Operating expense purchase contracts [Abstract]
Coal commitments	9,933,000
Purchase power commitments	48,425,000
Other commitments	0
Total purchase contracts	58,358,000
More Than Two And Within Three Years From Balance Sheet Date [Member]
Chattel Paper Agreement Principal Payments [Abstract]
Chattel paper agreement principal payments commitments	867,000
Operating expense purchase contracts [Abstract]
Coal commitments	9,252,000
Purchase power commitments	47,293,000
Other commitments	0
Total purchase contracts	56,545,000
More Than Three And Within Four Years From Balance Sheet Date [Member]
Chattel Paper Agreement Principal Payments [Abstract]
Chattel paper agreement principal payments commitments	791,000
Operating expense purchase contracts [Abstract]
Coal commitments	1,623,000
Purchase power commitments	48,121,000
Other commitments	0
Total purchase contracts	49,744,000
More Than Four And Within Five Years From Balance Sheet Date [Member]
Chattel Paper Agreement Principal Payments [Abstract]
Chattel paper agreement principal payments commitments	382,000
Operating expense purchase contracts [Abstract]
Coal commitments	1,040,000
Purchase power commitments	49,242,000
Other commitments	0
Total purchase contracts	$ 50,282,000

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Columbia Environmental Project Construction (Details) (USD $)	3 Months Ended
	Mar. 31, 2013	Mar. 31, 2012	Dec. 31, 2012
Expected Capital Expenditures [Line Items]
Total incurred costs to date	$ 115,803,000		98,411,000
MGE rate of return	50.00%
Columbia Environmental Project [Member]
Expected Capital Expenditures [Line Items]
MGE's share of expected capital expenditures	140,000,000
Total incurred costs to date	78,800,000
Carrying cost on pre-construction costs - AFUDC rate	50.00%		100.00%
AFUDC - equity funds	500,000	100,000
Columbia Environmental Project [Member] | One Year From Balance Sheet Date [Member]
Expected Capital Expenditures [Line Items]
MGE's share of expected capital expenditures	49,000,000
Columbia Environmental Project [Member] | More Than One And Within Two Years From Balance Sheet Date [Member]
Expected Capital Expenditures [Line Items]
MGE's share of expected capital expenditures	$ 12,000,000
Columbia Units [Member]
Columbia Units [Line Items]
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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Rate Matters (Details) (USD $) In Millions, unless otherwise specified	12 Months Ended
	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012	Mar. 31, 2013
Rate Proceedings [Abstract]
Authorized percentage increase (decrease) for electric		3.80%	4.30%
Authorized rate increase (decrease) for electric		$ 14.9	$ 15.7
Authorized percentage increase (decrease) for gas		1.00%	0.30%
Authorized rate increase (decrease) for gas		1.6	0.6
Fuel rules bandwidth		2.00%
Authorized return on common stock		10.30%
Proposed percent increase (decrease) for electric	0.00%
Proposed percent increase (decrease) for gas	0.00%
Proposed carrying cost on pre-construction costs - AFUDC rate	100.00%
Proposed return of electric fuel credit	6.2
Fuel Rules [Abstract]
Electric fuel deferred costs upper threshold		102.00%
Electric fuel deferred costs lower threshold		98.00%
Increased (decreased) electric fuel costs deferred				0
Purchased Gas Adjustment [Abstract]
Purchased gas adjustment over(under) collected			$ (0.1)	$ 5.3

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Consolidated Balance Sheets (Unaudited) (USD $) In Thousands, unless otherwise specified	Mar. 31, 2013		Dec. 31, 2012
Current Assets:
Cash and cash equivalents	$ 45,894		$ 46,357
Receivable - margin account	766		1,818
Accounts receivable, less reserves	46,864	[1]	41,386	[2]
Other accounts receivables, less reserves	5,125	[3]	6,746	[3]
Unbilled revenues	26,761		28,262
Materials and supplies, at average cost	16,933		16,997
Fossil fuel	7,375		6,367
Stored natural gas, at average cost	2,195		14,980
Prepaid taxes	13,868		19,520
Regulatory assets - current	8,471		10,327
Deferred income taxes	14,260		23,483
Other current assets	7,431		6,694
Total Current Assets	195,943		222,937
Regulatory assets	214,496		218,853
Other deferred assets and other	7,222		7,075
Property, Plant, and Equipment:
Property, plant, and equipment, net	981,325		975,053
Construction work in progress	115,803		98,411
Total Property, Plant, and Equipment	1,097,128		1,073,464
Investments	65,651		64,595
Total Assets	1,580,440		1,586,924
Current Liabilities:
Long-term debt due within one year	3,365		3,013
Short-term debt	10,500		0
Accounts payable	39,586		43,518
Accrued interest and taxes	4,099		4,296
Accrued payroll related items	7,711		10,063
Derivative liabilities	8,880		9,270
Other current liabilities	10,605		5,637
Total Current Liabilities	84,746		75,797
Other Credits:
Deferred income taxes	272,511		270,410
Investment tax credit - deferred	1,466		1,520
Regulatory liabilities	22,598		24,538
Accrued pension and other postretirement benefits	133,380		162,835
Derivative liabilities	61,810		63,320
Other deferred liabilities and other	53,505		50,584
Total Other Credits	545,270		573,207
Capitalization:
Common shareholders equity	592,946		579,429
Long-term debt	357,478		358,491
Total Capitalization	950,424		937,920
Commitments and contingencies (see Footnote 8)	0		0
Total Liabilities and Capitalization	1,580,440		1,586,924
MGE [Member]
Current Assets:
Cash and cash equivalents	9,856		6,350
Receivable - margin account	766		1,818
Accounts receivable, less reserves	46,864	[1]	41,386	[2]
Affiliate receivables	619		634
Other accounts receivables, less reserves	5,124	[3]	6,732	[3]
Unbilled revenues	26,761		28,262
Materials and supplies, at average cost	16,933		16,997
Fossil fuel	7,375		6,367
Stored natural gas, at average cost	2,195		14,980
Prepaid taxes	18,108		23,561
Regulatory assets - current	8,471		10,327
Deferred income taxes	13,808		23,305
Other current assets	7,416		6,670
Total Current Assets	164,296		187,389
Affiliate receivable long-term	6,222		6,354
Regulatory assets	214,496		218,853
Other deferred assets and other	6,602		6,540
Property, Plant, and Equipment:
Property, plant, and equipment, net	980,820		974,549
Construction work in progress	115,803		98,411
Total Property, Plant, and Equipment	1,096,623		1,072,960
Investments	62,366		61,555
Total Assets	1,550,605		1,553,651
Current Liabilities:
Long-term debt due within one year	3,365		3,013
Short-term debt	10,500		0
Accounts payable	39,586		43,517
Affiliate payables	405		767
Accrued interest and taxes	3,699		4,248
Accrued payroll related items	7,711		10,063
Derivative liabilities	8,880		9,270
Other current liabilities	10,163		4,491
Total Current Liabilities	84,309		75,369
Other Credits:
Deferred income taxes	268,028		266,231
Investment tax credit - deferred	1,466		1,520
Regulatory liabilities	22,598		24,538
Accrued pension and other postretirement benefits	133,380		162,835
Derivative liabilities	61,810		63,320
Other deferred liabilities and other	53,505		50,581
Total Other Credits	540,787		569,025
Capitalization:
Common shareholders equity	449,057		433,296
Noncontrolling interest	118,974		117,470
Total Equity	568,031		550,766
Long-term debt	357,478		358,491
Total Capitalization	925,509		909,257
Commitments and contingencies (see Footnote 8)	0		0
Total Liabilities and Capitalization	$ 1,550,605		$ 1,553,651

[1] less reserves of $3,914

[2] less reserves of $3,885

[3] less reserves of $931

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Derivative and Hedging Instruments (Details-1) (USD $)	Mar. 31, 2013 MW MWh Dth	Dec. 31, 2012 MWh Dth MW
Gross notional volume of open derivatives [Abstract]
Commodity derivative contracts - MWh	331,315	444,650
Commodity derivative contracts - Dth	1,360,000	1,980,000
Financial transmission rights - MW	1,085	2,670
Derivative fair values [Abstract]
Exchange traded and financial transmission rights	$ 1,500,000	$ 300,000
Purchased power agreement	(70,700,000)	(72,600,000)
Derivative instruments at fair value on the balance sheet [Line Items]
Derivative liability (current)	8,880,000	9,270,000
Derivative liability (long-term)	61,810,000	63,320,000
Commodity Derivative Contracts [Member]
Derivative instruments at fair value on the balance sheet [Line Items]
Other current assets	1,343,000	365,000
Other defered charges	158,000	95,000
Derivative liability (current)	30,000	394,000
Derivative liability (long-term)	0	11,000
Offsetting Assets [Line Items]
Gross amounts	1,502,000	460,000
Gross amounts offset in balance sheet	(30,000)	(405,000)
Collateral posted against derivative positions	(465,000)	0
Net amount presented in balance sheet	1,007,000	55,000
Financial Transmission Rights [Member]
Derivative instruments at fair value on the balance sheet [Line Items]
Other current assets	22,000	206,000
Derivative liability (current)	0	0
Offsetting Assets [Line Items]
Gross amounts	22,000	206,000
Gross amounts offset in balance sheet	0	0
Collateral posted against derivative positions	0	0
Net amount presented in balance sheet	22,000	206,000
Purchased Power Agreement [Member]
Derivative instruments at fair value on the balance sheet [Line Items]
Derivative liability (current)	8,880,000	9,270,000
Derivative liability (long-term)	$ 61,810,000	$ 63,320,000

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Pension and Other Postretirement Plans (Tables)

3 Months Ended

Mar. 31, 2013

Pension and Other Postretirement Plans (Tables) [Abstract]

Net Periodic Benefit Cost

		Three Months Ended
		March 31,
(In thousands)		2013		2012
Pension Benefits
Components of net periodic benefit cost:
Service cost	$	1,929	$	1,823
Interest cost		3,186		3,154
Expected return on assets		(4,776)		(3,818)
Amortization of:
Prior service cost		79		108
Actuarial loss		2,015		2,006
Net periodic benefit cost	$	2,433	$	3,273
Postretirement Benefits
Components of net periodic benefit cost:
Service cost	$	596	$	647
Interest cost		970		1,125
Expected return on assets		(544)		(435)
Amortization of:
Transition obligation		1		106
Prior service cost		28		28
Actuarial loss		311		621
Net periodic benefit cost	$	1,362	$	2,092

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Investment in ATC (Tables)

3 Months Ended

Mar. 31, 2013

Investment in ATC (Tables) [Abstract]

ATC's Summarized Financial Data

		Three Months Ended
		March 31,
(In thousands)		2013		2012
Operating revenues	$	151,737	$	147,662
Operating expenses		(69,770)		(69,566)
Other expense, net		(448)		(500)
Interest expense, net		(21,044)		(19,501)
Earnings before members' income taxes	$	60,475	$	58,095

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Derivative and Hedging Instruments (Details-2) (USD $) In Thousands, unless otherwise specified	Mar. 31, 2013	Dec. 31, 2012
Commodity Derivative Contracts [Member]
Offsetting Liabilities [Line Items]
Gross amounts	$ 30	$ 405
Gross amounts offset in balance sheet	(30)	(405)
Collateral posted against derivative positions	0	0
Net amount presented in balance sheet	0	0
Purchased Power Agreement [Member]
Offsetting Liabilities [Line Items]
Gross amounts	70,690	72,590
Gross amounts offset in balance sheet	0	0
Collateral posted against derivative positions	0	0
Net amount presented in balance sheet	$ 70,690	$ 72,590

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Commitments and Contingencies (Tables)

3 Months Ended

Mar. 31, 2013

Commitments and Contingencies (Tables) [Abstract]

Chattel Paper Principal Payments

(In thousands)		2013		2014		2015		2016		2017
Chattel Paper	$	531	$	554	$	867	$	791	$	382

Purchase Contracts

(In thousands)		2013		2014		2015		2016		2017
Coal(a)	$	16,922	$	9,933	$	9,252	$	1,623	$	1,040
Purchase power(b)		49,182		48,425		47,293		48,121		49,242
Other		1,939		0		0		0		0
	$	68,043	$	58,358	$	56,545	$	49,744	$	50,282

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Derivative and Hedging Instruments (Tables)

3 Months Ended

Mar. 31, 2013

Derivative and Hedging Instruments (Tables) [Abstract]

Gross Notional Volume of Open Derivatives

	March 31, 2013	December 31, 2012
Commodity derivative contracts	331,315 MWh	444,650 MWh
Commodity derivative contracts	1,360,000 Dth	1,980,000 Dth
FTRs	1,085 MW	2,670 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, 2013
Commodity derivative contracts	Other current assets	$	1,343	Derivative liability (current)	$	30
Commodity derivative contracts	Other deferred charges		158	Derivative liability (long-term)		0
FTRs	Other current assets		22	Derivative liability (current)		0
Ten-year PPA	N/A		N/A	Derivative liability (current)		8,880
Ten-year PPA	N/A		N/A	Derivative liability (long-term)		61,810
December 31, 2012
Commodity derivative contracts	Other current assets	$	365	Derivative liability (current)	$	394
Commodity derivative contracts	Other deferred charges		95	Derivative liability (long-term)		11
FTRs	Other current assets		206	Derivative liability (current)		0
Ten-year PPA	N/A		N/A	Derivative liability (current)		9,270
Ten-year PPA	N/A		N/A	Derivative liability (long-term)		63,320

Offsetting Assets

Offsetting of Derivative Assets
				Gross amounts		Collateral		Net amount
				offset in		posted against		presented in
(In thousands)		Gross amounts		balance sheet		derivative positions		balance sheet
March 31, 2013
Commodity derivative contracts	$	1,502	$	(30)	$	(465)	$	1,007
FTRs		22		-		-		22
December 31, 2012
Commodity derivative contracts	$	460	$	(405)	$	-	$	55
FTRs		206		-		-		206

Offsetting Liabilities

Offsetting of Derivative Liabilities
				Gross amounts		Collateral		Net amount
				offset in		posted against		presented in
(In thousands)		Gross amounts		balance sheet		derivative positions		balance sheet
March 31, 2013
Commodity derivative contracts	$	30	$	(30)	$	-	$	-
Ten-year PPA		70,690		-		-		70,690
December 31, 2012
Commodity derivative contracts	$	405	$	(405)	$	-	$	-
Ten-year PPA		72,590		-		-		72,590

Derivative Gains and Losses in Balance Sheet

		2013				2012
(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,	$	72,329	$	574	$	42,356	$	1,604
Change in unrealized (gain) loss		(1,697)		0		33,310		0
Realized loss reclassified to a deferred account		(290)		290		(2,658)		2,658
Realized loss reclassified to income
statement		(1,145)		(605)		(1,494)		(3,590)
Balance at March 31,	$	69,197	$	259	$	71,514	$	672

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, 2013:
Commodity derivative contracts	$	0	$	22	$	608
FTRs		0		(158)		0
Ten-year PPA		0		1,278		0
Three Months Ended March 31, 2012:
Commodity derivative contracts	$	0	$	1,928	$	3,090
FTRs		0		66		0
Ten-year PPA		0		0		0

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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, 2013	Mar. 31, 2012
Items not affecting cash:
Depreciation and amortization	$ 9,624	$ 9,624
Deferred income taxes	11,294	8,846
Provision for doubtful receivables	743	1,167
Employee benefit plan expenses	3,336	4,682
Equity earnings in ATC	(2,396)	(2,242)
Other items	750	660
Changes in working capital items:
(Increase) decrease in current assets	17,341	12,377
Decrease in current liabilities	(4,590)	(6,631)
Dividend income from ATC	1,807	1,740
Cash contributions to pension and other postretirement plans	(30,764)	(20,789)
Other noncurrent items, net	(1,077)	(746)
Cash Provided by Operating Activities	28,652	24,736
Investing Activities:
Capital expenditures	(29,164)	(15,467)
Capital contributions to investments	(373)	(355)
Other	(279)	106
Cash Used for Investing Activities	(29,816)	(15,716)
Financing Activities:
Cash dividends paid on common stock	(9,132)	(8,843)
Repayment of long-term debt	(667)	(667)
Increase (Decrease) in short-term debt	10,500	0
Other	0	(19)
Cash Provided by (Used for) Financing Activities	701	(9,529)
Change in Cash and Cash Equivalents:	(463)	(509)
Cash and cash equivalents at beginning of period	46,357	41,169
Cash and cash equivalents at end of period	45,894	40,660
Significant noncash investing activities [Abstract]
Accrued capital expenditures	12,699	4,674
MGE [Member]
Operating Activities:
Net Income	22,560	16,214
Items not affecting cash:
Depreciation and amortization	9,624	9,624
Deferred income taxes	11,016	8,768
Provision for doubtful receivables	743	1,005
Employee benefit plan expenses	3,336	4,682
Equity earnings in ATC	(2,396)	(2,242)
Other items	882	792
Changes in working capital items:
(Increase) decrease in current assets	17,135	11,542
Decrease in current liabilities	(4,326)	(6,991)
Dividend income from ATC	1,807	1,740
Cash contributions to pension and other postretirement plans	(30,764)	(20,789)
Other noncurrent items, net	(1,096)	(762)
Cash Provided by Operating Activities	28,521	23,583
Investing Activities:
Capital expenditures	(29,164)	(15,467)
Capital contributions to investments	(178)	(355)
Other	(184)	49
Cash Used for Investing Activities	(29,526)	(15,773)
Financing Activities:
Cash dividends paid to parent by MGE	0	(6,728)
Distributions to parent from noncontrolling interest	(5,500)	0
Equity contribution received by noncontrolling interest	178	355
Repayment of long-term debt	(667)	(667)
Increase (Decrease) in short-term debt	10,500	0
Other	0	(9)
Cash Provided by (Used for) Financing Activities	4,511	(7,049)
Change in Cash and Cash Equivalents:	3,506	761
Cash and cash equivalents at beginning of period	6,350	13,898
Cash and cash equivalents at end of period	9,856	14,659
Significant noncash investing activities [Abstract]
Accrued capital expenditures	$ 12,699	$ 4,674

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Fair Value of Financial Instruments (Tables)

3 Months Ended

Mar. 31, 2013

Fair Value of Financial Instruments (Tables) [Abstract]

Estimated Fair Market Value of Financial Instruments

		March 31, 2013				December 31, 2012
		Carrying		Fair		Carrying		Fair
(In thousands)		Amount		Value		Amount		Value
MGE Energy
Assets:
Cash and cash equivalents	$	45,894	$	45,894	$	46,357	$	46,357
Liabilities:
Short-term debt - commercial paper		10,500		10,500		0		0
Long-term debt*		361,138		432,430		361,805		427,456
MGE
Assets:
Cash and cash equivalents		9,856		9,856		6,350		6,350
Liabilities:
Short-term debt - commercial paper		10,500		10,500		0		0
Long-term debt*		361,138		432,430		361,805		427,456
*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, 2013
(In thousands)		Total		Level 1		Level 2		Level 3
MGE Energy
Assets:
Exchange-traded investments	$	428	$	428	$	0	$	0
Total Assets	$	428	$	428	$	0	$	0
Liabilities:
Derivatives, net(a)	$	69,197	$	(401)	$	0	$	69,598
Deferred compensation		2,085		0		2,085		0
Total Liabilities	$	71,282	$	(401)	$	2,085	$	69,598
MGE
Assets:
Exchange-traded investments	$	161	$	161	$	0	$	0
Total Assets	$	161	$	161	$	0	$	0
Liabilities:
Derivatives, net(a)	$	69,197	$	(401)	$	0	$	69,598
Deferred compensation		2,085		0		2,085		0
Total Liabilities	$	71,282	$	(401)	$	2,085	$	69,598
(a)     These amounts are shown gross and exclude $0.5 million of collateral that was posted
against derivative positions with counterparties.
	Fair Value as of December 31, 2012
(In thousands)		Total		Level 1		Level 2		Level 3
MGE Energy
Assets:
Exchange-traded investments	$	320	$	320	$	0	$	0
Total Assets	$	320	$	320	$	0	$	0
Liabilities:
Derivatives, net	$	72,329	$	(17)	$	0	$	72,346
Deferred compensation		2,010		0		2,010		0
Total Liabilities	$	74,339	$	(17)	$	2,010	$	72,346
MGE
Assets:
Exchange-traded investments	$	117	$	117	$	0	$	0
Total Assets	$	117	$	117	$	0	$	0
Liabilities:
Derivatives, net	$	72,329	$	(17)	$	0	$	72,346
Deferred compensation		2,010		0		2,010		0
Total Liabilities	$	74,339	$	(17)	$	2,010	$	72,346

Significant Unobservable Inputs

Significant Unobservable Inputs	Model Input
Basis adjustment:
On peak	97.1%
Off peak	96.0%
Counterparty fuel mix:
Internal generation	50 % - 70 %
Purchased power	50 % - 30 %

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

		Three Months Ended
		March 31,
(In thousands)		2013		2012
Beginning balance,	$	(72,346)	$	(40,661)
Realized and unrealized gains (losses):
Included in regulatory liabilities (assets)		2,748		(30,527)
Included in other comprehensive income		0		0
Included in earnings		(1,148)		(1,502)
Included in current assets		0		(50)
Purchases		5,562		50
Sales		(3)		31
Issuances		0		0
Settlements		(4,411)		1,471
Transfers in and/or out of Level 3		0		0
Balance as of March 31,	$	(69,598)	$	(71,188)
Total gains (losses) included in earnings attributed to
the change in unrealized gains (losses) related to
assets and liabilities held at March 31,(b)	$	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
		March 31,
(In thousands)		2013		2012
Purchased Power Expense	$	(1,148)	$	(1,502)
Cost of Gas Sold Expense		0		0
Regulated Gas Revenues		0		0
Total	$	(1,148)	$	(1,502)

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Share Based Compensation (Details) (USD $) In Millions, except Share data, unless otherwise specified	0 Months Ended	3 Months Ended
	Feb. 15, 2013	Mar. 31, 2013	Mar. 31, 2012
Performance Unit Plan [Abstract]
Performance units granted	15,256
Compensation expense		$ 0.9	$ 0.4
Cash payments for prior activity		1.0
Forfeitures		0	0
Vested awards		$ 3.7

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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, 2013	Mar. 31, 2012
Operating Revenues:
Regulated electric revenues	$ 93,494	$ 89,936
Regulated gas revenues	72,467	57,019
Nonregulated revenues	1,276	2,304
Total Operating Revenues	167,237	149,259
Operating Expenses:
Fuel for electric generation	10,760	8,851
Purchased power	18,205	19,546
Cost of gas sold	44,692	34,845
Other operations and maintenance	41,649	42,949
Depreciation and amortization	9,624	9,624
Other general taxes	4,679	5,000
Total Operating Expenses	129,609	120,815
Operating Income	37,628	28,444
Other income, net	3,309	2,570
Interest expense, net	(4,675)	(5,104)
Income before income taxes	36,262	25,910
Income tax provision	(13,678)	(9,862)
Net Income (Loss)	$ 22,584	$ 16,048
Earnings Per Share of Common Stock (basic and diluted)	$ 0.98	$ 0.69
Dividends per share of common stock	$ 0.395	$ 0.383
Average Shares Outstanding (basic and diluted)	23,114	23,114

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Derivative and Hedging Instruments (Details-3) (USD $) In Thousands, unless otherwise specified	3 Months Ended
	Mar. 31, 2013	Mar. 31, 2012
Regulatory Asset [Member]
Unrealized and realized gains (losses) on balance sheet [Line Items]
Beginning balance,	$ 72,329	$ 42,356
Change in unrealized loss (gain)	(1,697)	33,310
Realized loss reclassified to a deferred account	(290)	(2,658)
Realized gain (loss) reclassified to income statement	(1,145)	(1,494)
Ending balance,	69,197	71,514
Other Current Assets [Member]
Unrealized and realized gains (losses) on balance sheet [Line Items]
Beginning balance,	574	1,604
Change in unrealized loss (gain)	0	0
Realized loss reclassified to a deferred account	290	2,658
Realized gain (loss) reclassified to income statement	(605)	(3,590)
Ending balance,	$ 259	$ 672

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Consolidated Statements of Comprehensive Income (Unaudited) (Parantheticals) (USD $) In Thousands, unless otherwise specified	3 Months Ended
	Mar. 31, 2013	Mar. 31, 2012
Comprehensive Income [Abstract]
Unrealized gain (loss) on available-for-sale securities, taxes	$ 43	$ 5
MGE [Member]
Comprehensive Income [Abstract]
Unrealized gain (loss) on available-for-sale securities, taxes	$ 18	$ (11)

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Investment in ATC (Details-1) (USD $)	3 Months Ended		4 Months Ended			3 Months Ended
	Mar. 31, 2013	Mar. 31, 2012	Apr. 30, 2013 Mge Transco [Member] ATC Capital Contribution [Member]	Mar. 31, 2013 ATC [Member]	Dec. 31, 2012 ATC [Member]	Mar. 31, 2013 ATC [Member] Mge Transco [Member]	Mar. 31, 2012 ATC [Member] Mge Transco [Member]
Equity method investments [Line Items]
Equity earnings from investment in ATC	$ 2,396,000	$ 2,242,000				$ 2,400,000	$ 2,200,000
Dividend income from ATC	1,807,000	1,740,000				1,800,000	1,700,000
Contributions to ATC						200,000	400,000
Investment in ATC				61,800,000	61,000,000
Subsequent Events [Line Items]
Subsequent Event, Description			On April 30, 2013, MGE Transco made a $0.5 million capital contribution to ATC.
Contributions to ATC	$ 373,000	$ 355,000	$ 500,000

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Derivative and Hedging Instruments

3 Months Ended

Mar. 31, 2013

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, 2013	December 31, 2012
Commodity derivative contracts	331,315 MWh	444,650 MWh
Commodity derivative contracts	1,360,000 Dth	1,980,000 Dth
FTRs	1,085 MW	2,670 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.

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 market,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, 2013 and December 31,2012,the fair value of exchange traded derivatives and FTRs exceeded their cost basis by $1.5 million and $0.3 million, respectively.

MGE is a party to 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 consolidated 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, 2013 and December 31, 2012, reflects a loss position of $70.7 million and $72.6 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 consolidated 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, 2013
Commodity derivative contracts	Other current assets	$	1,343	Derivative liability (current)	$	30
Commodity derivative contracts	Other deferred charges		158	Derivative liability (long-term)		0
FTRs	Other current assets		22	Derivative liability (current)		0
Ten-year PPA	N/A		N/A	Derivative liability (current)		8,880
Ten-year PPA	N/A		N/A	Derivative liability (long-term)		61,810
December 31, 2012
Commodity derivative contracts	Other current assets	$	365	Derivative liability (current)	$	394
Commodity derivative contracts	Other deferred charges		95	Derivative liability (long-term)		11
FTRs	Other current assets		206	Derivative liability (current)		0
Ten-year PPA	N/A		N/A	Derivative liability (current)		9,270
Ten-year PPA	N/A		N/A	Derivative liability (long-term)		63,320

The following tables show the effect of netting arrangements for recognized derivative assets and liabilities that are subject to a master netting arrangement or similar arrangement on the balance sheet.

Offsetting of Derivative Assets
				Gross amounts		Collateral		Net amount
				offset in		posted against		presented in
(In thousands)		Gross amounts		balance sheet		derivative positions		balance sheet
March 31, 2013
Commodity derivative contracts	$	1,502	$	(30)	$	(465)	$	1,007
FTRs		22		-		-		22
December 31, 2012
Commodity derivative contracts	$	460	$	(405)	$	-	$	55
FTRs		206		-		-		206

Offsetting of Derivative Liabilities
				Gross amounts		Collateral		Net amount
				offset in		posted against		presented in
(In thousands)		Gross amounts		balance sheet		derivative positions		balance sheet
March 31, 2013
Commodity derivative contracts	$	30	$	(30)	$	-	$	-
Ten-year PPA		70,690		-		-		70,690
December 31, 2012
Commodity derivative contracts	$	405	$	(405)	$	-	$	-
Ten-year PPA		72,590		-		-		72,590

The following tables summarize the unrealized and realized gains (losses) related to the derivative instruments on the consolidated balance sheet at March 31, 2013 and 2012, and the consolidated income statement for the three months endedMarch 31, 2013 and 2012.

		2013				2012
(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,	$	72,329	$	574	$	42,356	$	1,604
Change in unrealized (gain) loss		(1,697)		0		33,310		0
Realized loss reclassified to a deferred account		(290)		290		(2,658)		2,658
Realized loss reclassified to income
statement		(1,145)		(605)		(1,494)		(3,590)
Balance at March 31,	$	69,197	$	259	$	71,514	$	672

		Realized losses (gains)
				Fuel for electric
		Regulated		generation/		Cost of
(In thousands)		gas revenues		purchased power		gas sold
Three Months Ended March 31, 2013:
Commodity derivative contracts	$	0	$	22	$	608
FTRs		0		(158)		0
Ten-year PPA		0		1,278		0
Three Months Ended March 31, 2012:
Commodity derivative contracts	$	0	$	1,928	$	3,090
FTRs		0		66		0
Ten-year PPA		0		0		0

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 consolidated 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-). 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. As of March 31, 2013, no collateral has been posted. Certain counterparties extend MGE a credit limit. If MGE exceeds these limits, the counterparties may require collateral to be posted.As ofMarch 31, 2013 and December 31,2012,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, 2013,no counterparties have defaulted.

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Investment in ATC (Details-2) (ATC [Member], USD $) In Thousands, unless otherwise specified	3 Months Ended
	Mar. 31, 2013	Mar. 31, 2012
ATC [Member]
Equity method investment summarized income statement [Line Items]
Operating revenues	$ 151,737	$ 147,662
Operating expenses	(69,770)	(69,566)
Other expense, net	(448)	(500)
Interest expense, net	(21,044)	(19,501)
Earnings before members' income taxes	$ 60,475	$ 58,095

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Fair Value of Financial Instruments

3 Months Ended

Mar. 31, 2013

Fair Value of Financial Instruments Disclosure [Abstract]

Fair Value of Financial Instruments

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

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.

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

At March 31,2013 and December 31, 2012, the carrying amount of cash and cash equivalents 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 31,2013 and December 31, 2012. Since the long-term debt is not traded in an active market, it is classified as Level 2.The estimated fair market value of MGE Energy's and MGE's financial instruments are as follows:

		March 31, 2013				December 31, 2012
		Carrying		Fair		Carrying		Fair
(In thousands)		Amount		Value		Amount		Value
MGE Energy
Assets:
Cash and cash equivalents	$	45,894	$	45,894	$	46,357	$	46,357
Liabilities:
Short-term debt - commercial paper		10,500		10,500		0		0
Long-term debt*		361,138		432,430		361,805		427,456
MGE
Assets:
Cash and cash equivalents		9,856		9,856		6,350		6,350
Liabilities:
Short-term debt - commercial paper		10,500		10,500		0		0
Long-term debt*		361,138		432,430		361,805		427,456
*Includes long-term debt due within one year.

b.       Recurring Fair Value Measurements.

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, 2013
(In thousands)		Total		Level 1		Level 2		Level 3
MGE Energy
Assets:
Exchange-traded investments	$	428	$	428	$	0	$	0
Total Assets	$	428	$	428	$	0	$	0
Liabilities:
Derivatives, net(a)	$	69,197	$	(401)	$	0	$	69,598
Deferred compensation		2,085		0		2,085		0
Total Liabilities	$	71,282	$	(401)	$	2,085	$	69,598
MGE
Assets:
Exchange-traded investments	$	161	$	161	$	0	$	0
Total Assets	$	161	$	161	$	0	$	0
Liabilities:
Derivatives, net(a)	$	69,197	$	(401)	$	0	$	69,598
Deferred compensation		2,085		0		2,085		0
Total Liabilities	$	71,282	$	(401)	$	2,085	$	69,598
(a)     These amounts are shown gross and exclude $0.5 million of collateral that was posted
against derivative positions with counterparties.
	Fair Value as of December 31, 2012
(In thousands)		Total		Level 1		Level 2		Level 3
MGE Energy
Assets:
Exchange-traded investments	$	320	$	320	$	0	$	0
Total Assets	$	320	$	320	$	0	$	0
Liabilities:
Derivatives, net	$	72,329	$	(17)	$	0	$	72,346
Deferred compensation		2,010		0		2,010		0
Total Liabilities	$	74,339	$	(17)	$	2,010	$	72,346
MGE
Assets:
Exchange-traded investments	$	117	$	117	$	0	$	0
Total Assets	$	117	$	117	$	0	$	0
Liabilities:
Derivatives, net	$	72,329	$	(17)	$	0	$	72,346
Deferred compensation		2,010		0		2,010		0
Total Liabilities	$	74,339	$	(17)	$	2,010	$	72,346

No transfers were made in or out of Level 1 or Level 2 for the three months endedMarch 31,2013.

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 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 from 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 MGE's 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	97.1%
Off peak	96.0%
Counterparty fuel mix:
Internal generation	50 % - 70 %
Purchased power	50 % - 30 %

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 consolidated 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
		March 31,
(In thousands)		2013		2012
Beginning balance,	$	(72,346)	$	(40,661)
Realized and unrealized gains (losses):
Included in regulatory liabilities (assets)		2,748		(30,527)
Included in other comprehensive income		0		0
Included in earnings		(1,148)		(1,502)
Included in current assets		0		(50)
Purchases		5,562		50
Sales		(3)		31
Issuances		0		0
Settlements		(4,411)		1,471
Transfers in and/or out of Level 3		0		0
Balance as of March 31,	$	(69,598)	$	(71,188)
Total gains (losses) included in earnings attributed to
the change in unrealized gains (losses) related to
assets and liabilities held at March 31,(b)	$	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(b).

		Three Months Ended
		March 31,
(In thousands)		2013		2012
Purchased Power Expense	$	(1,148)	$	(1,502)
Cost of Gas Sold Expense		0		0
Regulated Gas Revenues		0		0
Total	$	(1,148)	$	(1,502)

(b)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, 2013	Mar. 31, 2012
Operating Activities:
Net Income	$ 22,584	$ 16,048
Items not affecting cash:
Depreciation and amortization	9,624	9,624
Deferred income taxes	11,294	8,846
Provision for doubtful receivables	743	1,167
Employee benefit plan expenses	3,336	4,682
Equity earnings in ATC	(2,396)	(2,242)
Other items	750	660
Changes in working capital items:
(Increase) decrease in current assets	17,341	12,377
Decrease in current liabilities	(4,590)	(6,631)
Dividend income from ATC	1,807	1,740
Cash contributions to pension and other postretirement plans	(30,764)	(20,789)
Other noncurrent items, net	(1,077)	(746)
Cash Provided by Operating Activities	28,652	24,736
Investing Activities:
Capital expenditures	(29,164)	(15,467)
Capital contributions to investments	(373)	(355)
Other	(279)	106
Cash Used for Investing Activities	(29,816)	(15,716)
Financing Activities:
Cash dividends paid on common stock	(9,132)	(8,843)
Repayment of long-term debt	(667)	(667)
Increase (Decrease) in short-term debt	10,500	0
Other	0	(19)
Cash Provided by (Used for) Financing Activities	701	(9,529)
Change in Cash and Cash Equivalents:	(463)	(509)
Cash and cash equivalents at beginning of period	46,357	41,169
Cash and cash equivalents at end of period	45,894	40,660
Significant noncash investing activities [Abstract]
Accrued capital expenditures	$ 12,699	$ 4,674

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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, 2013	Mar. 31, 2012
Operating Revenues:
Regulated electric revenues	$ 93,494	$ 89,936
Regulated gas revenues	72,467	57,019
Nonregulated revenues	1,276	2,304
Total Operating Revenues	167,237	149,259
Operating Expenses:
Fuel for electric generation	10,760	8,851
Purchased power	18,205	19,546
Cost of gas sold	44,692	34,845
Other operations and maintenance	41,649	42,949
Depreciation and amortization	9,624	9,624
Other general taxes	4,679	5,000
Income tax provision	13,678	9,862
Total Operating Expenses	129,609	120,815
Operating Income	37,628	28,444
Other Income and Deductions:
Equity in earnings in ATC	2,396	2,242
Total Other Income and Deductions	3,309	2,570
Interest Expense:
Net Interest Expense	4,675	5,104
Net Income (Loss)	22,584	16,048
MGE [Member]
Operating Revenues:
Regulated electric revenues	93,494	89,936
Regulated gas revenues	72,467	57,019
Nonregulated revenues	1,276	2,304
Total Operating Revenues	167,237	149,259
Operating Expenses:
Fuel for electric generation	10,760	8,851
Purchased power	18,205	19,546
Cost of gas sold	44,692	34,845
Other operations and maintenance	41,504	42,528
Depreciation and amortization	9,624	9,624
Other general taxes	4,679	5,000
Income tax provision	12,870	8,969
Total Operating Expenses	142,334	129,363
Operating Income	24,903	19,896
Other Income and Deductions:
AFUDC - equity funds	596	154
Equity in earnings in ATC	2,396	2,242
Income tax provision	(781)	(993)
Other income, net	141	56
Total Other Income and Deductions	2,352	1,459
Income before interest expense	27,255	21,355
Interest Expense:
Interest on long-term debt	4,928	5,197
Other interest, net	(37)	7
AFUDC - borrowed funds	(196)	(63)
Net Interest Expense	4,695	5,141
Net Income Including Noncontrolling Interest	22,560	16,214
Less Net Income Attributable to Noncontrolling Interest, net of tax	(6,826)	(6,072)
Net Income (Loss)	$ 15,734	$ 10,142

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Columbia Environmental Project Construction

3 Months Ended

Mar. 31, 2013

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, CAIR's eventual replacement, the Mercury and Air Toxics Standards (MATS), and the Wisconsin Mercury Rule. The operator's current estimate shows that MGE's share of the capital expenditures required for this project is approximately $140 million. As of March 31, 2013, MGE had accumulated $78.8 million (excluding carrying costs) related to its share of the project, which is reflected in the Construction Work in Progress balance on MGE Energy's and MGE's consolidated balance sheets. MGE's share of the capital expenditures associated with the Columbia environmental project will be approximately $49million for the remainder of 2013 and $12 million in 2014. These amounts may change as a result of modifications to the project estimate or timing differences. For the three months endedMarch 31, 2013 and 2012,MGE has recognized after tax $0.5 millionand $0.1 million, respectively, in AFUDC equity related to this project.

MGE expects that the costs pertaining to this project will be fully recoverable through rates. In 2012, the PSCW authorized MGE 100% AFUDC on this project during construction. Beginning in 2013, similar to MGE's other utility construction projects, the PSCW authorized MGE a 50% current return (included in customer rates) and the remaining 50% as AFUDC.

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Document and Entity Information	3 Months Ended
	Mar. 31, 2013
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, 2013
Amendment Flag	false
Document Fiscal Year Focus	2013
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, 2013

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.MGE Energy and MGE have an unrecognized tax benefit at March 31, 2013 and December 31, 2012, in the amount of $3.4 million and $3.2million, respectively, for the tax uncertainty related to the change in tax method of accounting forrepairs.

On April 18, 2013, MGE Energy received notification from the Internal Revenue Service that the examination of tax periods 2007-2009 has been completed. Unrecognized tax benefits of $1.5 million related to those years will be reversed (in the second quarter) due to those positions not being adversely adjusted in the examination.

b.       Effective Tax Rate.

MGE Energy's and MGE's effective income tax rate for the three months endedMarch 31, 2013, was37.7%, compared to 38.1%for the same period in 2012.

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MGE Energy Inc Consolidated Statements of Comprehensive Income (Unaudited) (USD $) In Thousands, unless otherwise specified	3 Months Ended
	Mar. 31, 2013		Mar. 31, 2012
Comprehensive Income [Abstract]
Net Income	$ 22,584		$ 16,048
Other comprehensive income (loss), net of tax:
Unrealized gain (loss) on available-for-sale securities, net of tax	65	[1]	7	[2]
Comprehensive Income	$ 22,649		$ 16,055

[1] Net of $43 tax

[2] Net of $5 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, 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
Beginning balance, value at Dec. 31, 2012		550,766		17,348	192,417	223,527		4	117,470
Beginning balance, shares at Dec. 31, 2012			23,114	17,348
Net Income		22,560				15,734			6,826
Other comprehensive income (loss)	65	27					65	27
Cash dividends paid to parent by MGE		0
Equity contribution received by noncontrolling interest		178							178
Distributions to parent from noncontrolling interest		(5,500)							(5,500)
Ending balance, value at Mar. 31, 2013		$ 568,031		$ 17,348	$ 192,417	$ 239,261		$ 31	$ 118,974
Ending balance, shares at Mar. 31, 2013			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, 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	[1]	(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
Beginning balance, value at Dec. 31, 2012		579,429	23,114	316,268	239,953	94
Beginning balance, shares at Dec. 31, 2012			23,114,000
Net Income		22,584			22,584
Other comprehensive income (loss)		65				65
Common stock dividends declared	[2]	(9,132)			(9,132)
Common stock issued during period		0
Ending balance, value at Mar. 31, 2013		$ 592,946	$ 23,114	$ 316,268	$ 253,405	$ 159
Ending balance, shares at Mar. 31, 2013			23,114,000

[1] $0.383 per share

[2] $0.395 per share

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Rate Matters

3 Months Ended

Mar. 31, 2013

Rate Matters Disclosure [Abstract]

Rate Matters

10.       Rate Matters - MGE Energy and MGE.

a.       Rate Proceedings.

On April 15, 2013, MGE applied with the PSCW for authority to freeze electric and natural gas rates at 2013 levels for 2014. The application includes a request for categorizing 100% of the cost of the Columbia scrubber construction project as AFUDC. The plan includes a request for deferral of increases in ATC and MISO Schedule 26 fees. In addition, MGE is requesting that approximately $6.2 million pertaining to a fuel rule surplus credit be offset against MGE's increased costs. The fuel credit will accrue interest at MGE's weighted cost of capital during 2013, and the requested treatment of the credit will contribute to the overall rate freeze for 2014.

On December 14, 2012, the PSCW authorized MGE to increase 2013 rates for retail electric customers by 3.8% or $14.9 million and to increase gas rates by 1.0% or $1.6 million. The change in retail electric rates was driven by costs for new environmental equipment at Columbia, final construction costs for the Elm Road Units, transmission reliability enhancements, and purchased power costs. The authorized return on common stock equity remains unchanged at 10.3%.

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.

b.       Fuel Rules.

Fuel rules require the PSCW and Wisconsin utilities to defer electric fuel-related costs that fall outside a symmetrical cost tolerance band around the amount approved for a utility in its most recent base rate proceedings. Any over/under recovery of the actual costs is determined on an annual basis and will be adjusted in future billings to electric retail customers. The fuel rules bandwidth is currently set at plus or minus 2%. 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, 2013, MGE did not defer any electric fuel-related savings/costs that are outside the range authorized by the PSCW.

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, 2013, MGE had over collected $5.3 million, recorded in other current liabilities on the consolidated balance sheet. At December 31, 2012, MGE had under collected $0.1 million, recorded in other current assetson the consolidated balance sheet.

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Pension and Other Postretirement Plans

3 Months Ended

Mar. 31, 2013

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, 2013 and 2012. A portion of the net periodic benefit cost is capitalized within the consolidated balance sheets.

		Three Months Ended
		March 31,
(In thousands)		2013		2012
Pension Benefits
Components of net periodic benefit cost:
Service cost	$	1,929	$	1,823
Interest cost		3,186		3,154
Expected return on assets		(4,776)		(3,818)
Amortization of:
Prior service cost		79		108
Actuarial loss		2,015		2,006
Net periodic benefit cost	$	2,433	$	3,273
Postretirement Benefits
Components of net periodic benefit cost:
Service cost	$	596	$	647
Interest cost		970		1,125
Expected return on assets		(544)		(435)
Amortization of:
Transition obligation		1		106
Prior service cost		28		28
Actuarial loss		311		621
Net periodic benefit cost	$	1,362	$	2,092

The PSCW allowed MGE to defer the 2009 incremental pension and OPRB costs above the amounts recovered in rates. During both the three months endedMarch 31,2013 and 2012, $0.3 millionhas been recovered in rates. These costs are not reflected in the table above.

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Equity and Financing Arrangements

3 Months Ended

Mar. 31, 2013

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, 2013 and 2012, 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.

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Consolidated Statements of Common Equity (Unaudited) (Parentheticals) (USD $)	3 Months Ended
	Mar. 31, 2013	Mar. 31, 2012
Consolidated Statements of Common Equity
Dividends per share of common stock	$ 0.395	$ 0.383

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Basis of Presentation

3 Months Ended

Mar. 31, 2013

Basis of Presentation Disclosure [Abstract]

Basis of Presentation

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. See Footnote 2 of Notes to Consolidated Financial Statements under Item 8, Financial Statements and Supplementary Data, of MGE Energy's and MGE's 2012 Annual Report on Form 10-K.

       The accompanying consolidated financial statements as of March 31, 2013, 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 2012 Annual Report on Form 10-K, but does not include all disclosures required by accounting principles generally accepted in the United States of America. These notes should be read in conjunction with the financial statements and the notes on pages 51 through 104 of the 2012 Annual Report on Form 10-K.

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Investment in ATC

3 Months Ended

Mar. 31, 2013

Investment in ATC Disclosure [Abstract]

Investment in ATC

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 endedMarch 31, 2013and 2012, MGE Transco recorded equity earnings from the investment in ATC of $2.4million and $2.2million, respectively. Dividend income received from ATC was $1.8 million and $1.7 millionforthe three months endedMarch 31, 2013and 2012, respectively. In addition, during the three months endedMarch 31, 2013and 2012, MGE Transcomade $0.2 million and $0.4 millionin capital contributions to ATC, respectively.On April 30, 2013, MGE Transco made a $0.5million capital contribution to ATC.

MGE Energy and MGE's investment in ATC as of March 31, 2013 and December 31, 2012 was $61.8 million and $61.0 million, respectively.

At March 31, 2013, 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.

ATC's summarized financial data for the three months endedMarch 31, 2013and 2012, is as follows:

		Three Months Ended
		March 31,
(In thousands)		2013		2012
Operating revenues	$	151,737	$	147,662
Operating expenses		(69,770)		(69,566)
Other expense, net		(448)		(500)
Interest expense, net		(21,044)		(19,501)
Earnings before members' income taxes	$	60,475	$	58,095

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Equity and Financing Arrangements (Details) (USD $) In Millions, except Share data, unless otherwise specified	3 Months Ended
	Mar. 31, 2013	Mar. 31, 2012
Common Stock Disclosures [Abstract]
Common stock issued during period	0	0
Dilutive Securities [Abstract]
Dilutive Securities	$ 0

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Segment Information (Details) (USD $) In Thousands, unless otherwise specified	3 Months Ended		12 Months Ended
	Mar. 31, 2013	Mar. 31, 2012	Dec. 31, 2012
Segment Reporting Information [Line Items]
Operating revenues	$ 167,237	$ 149,259
Interdepartmental revenues	0	0
Total operating revenues	167,237	149,259
Depreciation and amortization	(9,624)	(9,624)
Other operating expenses	(119,985)	(111,191)
Operating Income	37,628	28,444
Other (deductions) income, net	3,309	2,570
Interest (expense) income, net	(4,675)	(5,104)
Income before income taxes	36,262	25,910
Income tax provision	(13,678)	(9,862)
Net Income (Loss)	22,584	16,048
Segment Reporting Assets And Capital Expenditures [Abstract]
Assets	1,580,440		1,586,924
Capital Expenditures	29,164		98,435
Electric [Member]
Segment Reporting Information [Line Items]
Operating revenues	93,494	89,936
Interdepartmental revenues	109	109
Total operating revenues	93,603	90,045
Depreciation and amortization	(6,400)	(6,478)
Other operating expenses	(74,925)	(72,788)
Operating Income	12,278	10,779
Other (deductions) income, net	575	164
Interest (expense) income, net	(2,404)	(2,727)
Income before income taxes	10,449	8,216
Income tax provision	(3,433)	(2,785)
Net Income (Loss)	7,016	5,431
Segment Reporting Assets And Capital Expenditures [Abstract]
Assets	904,578		888,444
Capital Expenditures	27,007		81,965
Gas [Member]
Segment Reporting Information [Line Items]
Operating revenues	72,467	57,019
Interdepartmental revenues	4,876	2,986
Total operating revenues	77,343	60,005
Depreciation and amortization	(1,425)	(1,370)
Other operating expenses	(60,437)	(49,741)
Operating Income	15,481	8,894
Other (deductions) income, net	162	46
Interest (expense) income, net	(678)	(769)
Income before income taxes	14,965	8,171
Income tax provision	(5,989)	(3,238)
Net Income (Loss)	8,976	4,933
Segment Reporting Assets And Capital Expenditures [Abstract]
Assets	275,815		285,468
Capital Expenditures	1,689		13,812
Non Regulated Energy [Member]
Segment Reporting Information [Line Items]
Operating revenues	1,276	2,304
Interdepartmental revenues	10,573	8,676
Total operating revenues	11,849	10,980
Depreciation and amortization	(1,799)	(1,776)
Other operating expenses	(37)	(12)
Operating Income	10,013	9,192
Other (deductions) income, net	0	0
Interest (expense) income, net	(1,613)	(1,645)
Income before income taxes	8,400	7,547
Income tax provision	(3,257)	(3,029)
Net Income (Loss)	5,143	4,518
Segment Reporting Assets And Capital Expenditures [Abstract]
Assets	324,894		323,216
Capital Expenditures	468		2,658
Transmission Investment [Member]
Segment Reporting Information [Line Items]
Operating revenues	0	0
Interdepartmental revenues	0	0
Total operating revenues	0	0
Depreciation and amortization	0	0
Other operating expenses	0	0
Operating Income	0	0
Other (deductions) income, net	2,396	2,242
Interest (expense) income, net	0	0
Income before income taxes	2,396	2,242
Income tax provision	(971)	(910)
Net Income (Loss)	1,425	1,332
Segment Reporting Assets And Capital Expenditures [Abstract]
Assets	61,826		61,064
Capital Expenditures	0		0
All Others [Member]
Segment Reporting Information [Line Items]
Operating revenues	0	0
Interdepartmental revenues	0	0
Total operating revenues	0	0
Depreciation and amortization	0	0
Other operating expenses	(144)	(421)
Operating Income	(144)	(421)
Other (deductions) income, net	176	118
Interest (expense) income, net	20	37
Income before income taxes	52	(266)
Income tax provision	(28)	100
Net Income (Loss)	24	(166)
Segment Reporting Assets And Capital Expenditures [Abstract]
Assets	409,602		413,291
Capital Expenditures	0		0
Consolidation Elimination Entries [Member]
Segment Reporting Information [Line Items]
Operating revenues	0	0
Interdepartmental revenues	(15,558)	(11,771)
Total operating revenues	(15,558)	(11,771)
Depreciation and amortization	0	0
Other operating expenses	15,558	11,771
Operating Income	0	0
Other (deductions) income, net	0	0
Interest (expense) income, net	0	0
Income before income taxes	0	0
Income tax provision	0	0
Net Income (Loss)	0	0
Segment Reporting Assets And Capital Expenditures [Abstract]
Assets	(408,175)		(403,118)
Capital Expenditures	0		0
Assets Not Allocated [Member]
Segment Reporting Assets And Capital Expenditures [Abstract]
Assets	11,900		18,559
Capital Expenditures	0		0
MGE [Member]
Segment Reporting Information [Line Items]
Operating revenues	167,237	149,259
Interdepartmental revenues	0	0
Total operating revenues	167,237	149,259
Depreciation and amortization	(9,624)	(9,624)
Other operating expenses	(132,710)	(119,739)
Operating Income	24,903	19,896
Other (deductions) income, net	2,352	1,459
Interest (expense) income, net	(4,695)	(5,141)
Income tax provision	(12,870)	(8,969)
Net Income Including Noncontrolling Interest	22,560	16,214
Less Net Income Attributable to Noncontrolling Interest, net of tax	(6,826)	(6,072)
Net Income (Loss)	15,734	10,142
Segment Reporting Assets And Capital Expenditures [Abstract]
Assets	1,550,605		1,553,651
Capital Expenditures	29,164		98,435
MGE [Member] | Electric [Member]
Segment Reporting Information [Line Items]
Operating revenues	93,494	89,936
Interdepartmental revenues	109	109
Total operating revenues	93,603	90,045
Depreciation and amortization	(6,400)	(6,478)
Other operating expenses	(78,506)	(75,508)
Operating Income	8,697	8,059
Other (deductions) income, net	723	99
Interest (expense) income, net	(2,404)	(2,727)
Net Income Including Noncontrolling Interest	7,016	5,431
Less Net Income Attributable to Noncontrolling Interest, net of tax	0	0
Net Income (Loss)	7,016	5,431
Segment Reporting Assets And Capital Expenditures [Abstract]
Assets	904,578		888,444
Capital Expenditures	27,007		81,965
MGE [Member] | Gas [Member]
Segment Reporting Information [Line Items]
Operating revenues	72,467	57,019
Interdepartmental revenues	4,876	2,986
Total operating revenues	77,343	60,005
Depreciation and amortization	(1,425)	(1,370)
Other operating expenses	(66,468)	(52,961)
Operating Income	9,450	5,674
Other (deductions) income, net	204	28
Interest (expense) income, net	(678)	(769)
Net Income Including Noncontrolling Interest	8,976	4,933
Less Net Income Attributable to Noncontrolling Interest, net of tax	0	0
Net Income (Loss)	8,976	4,933
Segment Reporting Assets And Capital Expenditures [Abstract]
Assets	275,815		285,468
Capital Expenditures	1,689		13,812
MGE [Member] | Non Regulated Energy [Member]
Segment Reporting Information [Line Items]
Operating revenues	1,276	2,304
Interdepartmental revenues	10,573	8,676
Total operating revenues	11,849	10,980
Depreciation and amortization	(1,799)	(1,776)
Other operating expenses	(3,294)	(3,041)
Operating Income	6,756	6,163
Other (deductions) income, net	0	0
Interest (expense) income, net	(1,613)	(1,645)
Net Income Including Noncontrolling Interest	5,143	4,518
Less Net Income Attributable to Noncontrolling Interest, net of tax	0	0
Net Income (Loss)	5,143	4,518
Segment Reporting Assets And Capital Expenditures [Abstract]
Assets	324,844		323,166
Capital Expenditures	468		2,658
MGE [Member] | Transmission Investment [Member]
Segment Reporting Information [Line Items]
Operating revenues	0	0
Interdepartmental revenues	0	0
Total operating revenues	0	0
Depreciation and amortization	0	0
Other operating expenses	0	0
Operating Income	0	0
Other (deductions) income, net	1,425	1,332
Interest (expense) income, net	0	0
Net Income Including Noncontrolling Interest	1,425	1,332
Less Net Income Attributable to Noncontrolling Interest, net of tax	0	0
Net Income (Loss)	1,425	1,332
Segment Reporting Assets And Capital Expenditures [Abstract]
Assets	61,826		61,064
Capital Expenditures	0		0
MGE [Member] | Consolidation Elimination Entries [Member]
Segment Reporting Information [Line Items]
Operating revenues	0	0
Interdepartmental revenues	(15,558)	(11,771)
Total operating revenues	(15,558)	(11,771)
Depreciation and amortization	0	0
Other operating expenses	15,558	11,771
Operating Income	0	0
Other (deductions) income, net	0	0
Interest (expense) income, net	0	0
Net Income Including Noncontrolling Interest	0	0
Less Net Income Attributable to Noncontrolling Interest, net of tax	(6,826)	(6,072)
Net Income (Loss)	(6,826)	(6,072)
Segment Reporting Assets And Capital Expenditures [Abstract]
Assets	(28,358)		(23,050)
Capital Expenditures	0		0
MGE [Member] | Assets Not Allocated [Member]
Segment Reporting Assets And Capital Expenditures [Abstract]
Assets	11,900		18,559
Capital Expenditures	$ 0		$ 0

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Commitments and Contingencies

3 Months Ended

Mar. 31, 2013

Commitments and Contingencies Disclosure [Abstract]

Commitments and Contingencies

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 discharges 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 also includes discharge standards, which require the use of effluent-treatment processes equivalent to categorical "best practicable" or "best available" technologies. The CWA regulates discharges from "point sources" such as power plants through 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))

Section 316(b) of the Clean Water Act requires that the cooling water intake structures at electric power plants meet best available technology standards so that mortality from entrainment (drawing aquatic life into a plant's cooling system) and impingement (trapping aquatic life on screens) are reduced. Section 316(b) has been introduced in two phases. Phase I, which has been finalized, covered new facilities at the time that the rule was introduced. Phase II, which has not been finalized, is designed to cover what is defined as existing facilities. The EPA issued a proposed Phase II rule and alternative compliance strategies for existing facilities in April 2011 and has until June 27, 2013 to issue a final rule, pursuant to a settlement agreement.

The currently proposed Phase II rule and potential alternatives allow for a state permitting agency's discretion in determining best technology available at plants that are under their permitting authority and is not requiring cooling towers in all instances. The WDNR holds permitting authority for Wisconsin and implementation of the rule will be through modification of the plants' WPDES permits. Blount and Columbia generating plants are subject to both the impingement and entrainment aspects of the current proposed rule. WCCF is subject to the impingement aspect only. The Elm Road Units are covered under Phase I of the rule and meets those requirements. We anticipate that under the current proposed rule, equipment would need to be installed at Blount, WCCF, and Columbia to meet these new standards. However it is not presently possible to estimate the potential costs associated with this rule because the rule has not been finalized.

Air Quality

Federal and state air quality regulations impose restrictions on emission of particulate matter (PM), sulfur dioxide (SO2), nitrogen oxides (NOx), 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 interstate pollution transport rules, maximum achievable control technology (MACT) standards, new source performance standards (NSPS), the Clean Air Visibility Rule (also known as the Regional Haze Rule), and mercury emissions limits are expected to result in additional operating and capital expenditure costs for electric generating units.

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

In 2005, EPA promulgated the Clean Air Interstate Rule (CAIR) to reduce ozone and fine particulate matter emissions by reducing NOx and SO2 emissions. NOx and SO2 interact in the atmosphere to form ambient ozone from NOx and fine particulate matter pollution from NOx and SO2.The CAIR generally requires NOx and SO2 emission reductions from fossil fuel-fired EGUs (25 MW or greater) 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 NOx and 40% for SO2. The second phase (beginning in 2015) reduces regional NOx 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 Units, 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 with directions to revise or replace the rule. The Court's remand order directed that the CAIR remain in effect until the EPA promulgated a replacement rule. The Court's order did not include a deadline for the EPA to act.

In August 2011, the EPA responded to the remand of the CAIR by promulgating the Cross State Air Pollution Rule (CSAPR). However, in August 2012, the U.S. Court of Appeals for the D.C. Circuit vacated CSAPR and instructed the EPA to continue administering the CAIR pending finalizing a valid alternative program to control interstate pollution. In January 2013, the U.S. Court of Appeals for the D.C. Circuit denied the EPA's petition for reconsideration en banc. The EPA and several environmental groups have appealed the D.C. Circuit Court's August 2012 decision to the Supreme Court in separate filings. At this time, the CAIR remains effective.

MGE is currently in compliance with the CAIR Phase I requirements. MGE will be able to meet Phase II NOx emissions reductions through using our NOx allowances provided through the rule, and we will meet Phase II SO2 emissions reductions through installation of pollution controls. New SO2 controls at Columbia are already underway and are planned to be completed by mid 2014 (see the discussion regarding the Columbia environmental project below). MGE expects that any costs incurred to meet Phase II of the CAIR will be fully recoverable through rates. MGE will monitor the Supreme Court's response to the CSAPR appeals and any subsequent actions by the EPA to continue to evaluate potential impacts to our operations.

Clean Air Visibility Rule (CAVR)

Air modeling indicates that SO2 and NOx emissions (and to a lesser extent particulate matter) 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 may require pollution retrofits. The EPA had proposed that a power plant's compliance with emissions limitations in the CAIR and later under CSAPR could also serve as compliance with the BART regulations for SO2 and NOx emissions. However, this proposal is now uncertain because of the D.C. Circuit decisions to remand the CAIR and vacate CSAPR and the EPA's decision to pursue Supreme Court review of the CSAPR vacature. See CAIR and CSAPR discussion above for additional information on these proceedings. Capital expenditures at Columbia under BART still remain a possibility however at this time, the BART regulatory obligations, compliance strategies and costs remain uncertain until the Supreme Court makes adecision regarding CSAPR.

Wisconsin State Mercury Rule

Beginning January 1, 2015, phase two of the Wisconsin mercury rule will require large coal-fired EGUs (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 NOx and SO2 emissions at prescribed rates. The Elm Road Units currently meet this requirement. The Columbia co-owners expect to meet the 90% reduction option by installing baghouses and scrubbers by mid 2014 (see the discussion regarding the Columbia environmental project below). With the finalization of the EPA's Mercury and Air Toxics Standard, or MATs, the WDNR is currently evaluating how the state mercury rule should be supplanted by the EPA's rule (see discussion on MATs below).

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

In December 2011, the EPA finalized its Mercury and Air Toxics Standards for coal and oil-burning EGU boilers. MATs will require emissions standards for mercury, non-mercury HAPs metals, and acid gases. Compliance with MATs is generally required three years from the rule issuance, but permitting authorities can grant an additional year for compliance to facilities. 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 (baghouse and scrubbers) to be installed by mid 2014, are expected to allow both facilities to comply with the MATs rule without extensions (see the discussion regarding Columbia environmental project below).

National Ambient Air Quality Standards

The EPA has developed National Ambient Air Quality Standards (NAAQS) for six compounds currently identified as criteria pollutants: nitrogen dioxide, particulate matter, ozone, sulfur dioxide, lead, and carbon monoxide. The NAAQS for criteria pollutants establish acceptable ambient air levels of each pollutant based on a review of their 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.

Certain stationary sources, such as MGE's generation facilities, must meet NAAQS standards for emissions that travel offsite. Stationary source air quality modeling is used to determine whether emissions from permitted sources meet these NAAQS. Failure to meet NAAQS may require a permit applicant to incur capital or operational costs to bring a source into compliance. We cannot predict if MGE's permitted stationary sources will have difficulty meeting new standards not previously modeled. Modeling performed by the WDNR for MGE's permitted facilities has demonstrated compliance with current NAAQS. Additional modeling may be required in future permitting actions.

MGE tracks NAAQS developments to determine if new standards may affect us. MGE is currently tracking two NAAQS developments: (1) determination and placement of monitoring networks in Wisconsin for the 2010 nitrogen dioxide (NO2) NAAQS (Wisconsin is currently considered in attainment with NO2 NAAQS, however stationary source modeling may be required for NO2in the future) and (2)implementation requirements under the 2010 sulfur dioxide (SO2) NAAQS. The EPA has issued draft guidance that indicates larger sources, such as Columbia, may be required to install ambient air monitors and/or perform dispersion modeling to demonstrate attainment. A concern has been raised regarding the current EPA-preferred dispersion model. The model may not be accurate for estimating SO2 stationary source impacts and may overestimate off-site concentrations of SO2 from stationary sources. The EPA is working to resolve issues with the model.

Reciprocating Internal Combustion Engine (RICE) MACT Standard

In January 2013, the EPA finalized amendments to its RICE MACT standard. RICE MACT applies to industrial or electrical engines that are classified as reciprocating internal combustion engines. Engines owned by MGE that would fall under the RICE MACT rule include backup generators and small engines at various locations, including our fleet of distributed generators that serve as electric system backup and emergency dispatch. The distributed generators in particular will either require additional pollution controls or a change in how they are dispatched. MGE is continuing to evaluate the impacts to our engines based on this new standard, including evaluating the costs associated with adding pollution controls on some or all our aforementioned distributed generators.

Greenhouse Gas Regulation

On March 27, 2012, the EPA proposed GHG New Source Performance Standards (NSPS) for coal fired and natural gas combined cycle (NGCC) EGUs. The proposal applies to new EGUs only.

However, the EPA plans to propose NSPS for existing units some time in 2013as part of a 2010 settlement agreement. There is a great deal of uncertainty as to what the EPA will include in their NSPS for existing units and thus we are unable to comment on potential impacts to MGE at this time.

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, CAIR's eventual replacement, the Mercury and Air Toxics Standards (MATs), and the Wisconsin Mercury Rule. WPL, the plant operator, currently estimates that MGE's share of the capital expenditures required for this project is approximately $140 million. The project is underway and estimated to be completed bymid 2014.

MGE's share of various contractual commitments entered for the project as of March 31, 2013 is $56.7 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.

Title V Operating Permit Petition

In September 2008, the WDNR issued a Title V renewal operating permit to WPL for Columbia. However, a citizen group petitioned the EPA to object to 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. 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 June 2012, the EPA notified the plant operator of its intent to assume responsibility for issuing the renewed operating permit for Columbia, but agreed to provide the plant operator with more time to potentially resolve the issues raised in the EPA's order. On February 4, 2013, the parties involved dismissed the litigation without prejudice. The matter is still pending at the EPA but has been postponed pending possible resolution of the Clean Air Act litigation discussed below. 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 operations or financial condition.

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 co-owners (WPL, WPS, and MGE) failed to comply with appropriate pre-construction review and permitting requirements and, as a result, violated the PSD program requirements, the Title V operating permit requirements of the CAA and the Wisconsin State Implementation Plan (SIP). In September 2010, Sierra Club filed a lawsuit against WPL alleging violations of the CAA at Columbia and other WPL-operated Wisconsin facilities. WPL responded that the projects at Columbia were routine, or not projected to increase emissions, and therefore did not violate the permitting requirements of the CAA.

In April 2013, WPL, as operator, along with the other owners of Columbia (MGE and WPS), entered into a consent decree with the EPA and the Sierra Club to resolve these claims, while admitting no liability. The consent decree has been lodged with, and is subject to approval by, the Court, which could occur in the second quarter of 2013. The consent decree, requires installation of the following emission controls at Columbia; scrubbers and baghouses at Columbia Units 1 and 2 by December 31, 2014 and an SCR system at Columbia Unit 2 by December 31, 2018.In addition, the consent decree establishes emission rate limits for SO2, nitrogen oxide (NOx) and particulate matter for Columbia Units 1 and 2. The consent decree also includes annual plant-wide emission caps for SO2 and NOx for Columbia. MGE will also pay approximately $0.2 million as its share of a civil penalty and complete approximately $0.6 million in environmental mitigation projects. MGE currently expects to recover any material costs that could be incurred by MGE related to the terms of the final consent decree from MGE's electric customers, except for costs related to the civil penalty. In accordance with applicable accounting standards, MGE has accrued an amount for this matter representing its best estimate of its probable liability, based upon its assessment of the settlement. That accrued amount is not material to the financial statements. MGE believes the likelihood of a materially greater liability than the accrued amount is remote based upon the current status.

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 July31, 2013. At March 31, 2013, MGE has outstanding a $4.3 million interest in these receivables. MGE retains the servicing responsibility for these receivables. As of March 31, 2013, 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.

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, 2013, 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 depending on the term of the underlying customer loan. Principal payments for the remainder of 2013 and the next four years on the loans are:

(In thousands)		2013		2014		2015		2016		2017
Chattel Paper	$	531	$	554	$	867	$	791	$	382

c.       Legal Matters - MGE Energy and MGE.

MGE is involved in various legal matters that are being defended and handled in the normal course of business, including the Columbia matters discussed above. MGE maintains accruals for such costs that are probable of being incurred and subject to reasonable estimation. The accrued amount for these matters is not material to the financial statements.

d.       Purchase Contracts - MGE Energy and MGE.

MGE Energy and MGE have entered into various commodity supply, transportation and storage contracts to meet their obligations to deliver electricity and natural gas to customers. As of March 31, 2013, the future commitments related to these purchase contracts were as follows:

(In thousands)		2013		2014		2015		2016		2017
Coal(a)	$	16,922	$	9,933	$	9,252	$	1,623	$	1,040
Purchase power(b)		49,182		48,425		47,293		48,121		49,242
Other		1,939		0		0		0		0
	$	68,043	$	58,358	$	56,545	$	49,744	$	50,282

(a)Total coal commitments for the Columbia and Elm Road Units, including transportation. Fuel procurement for MGE's jointly owned Columbia and Elm Road Units are handled by WPL and WEPCO, respectively, who are the operators of those facilities. If any minimum purchase obligations must be paid under these contracts, management believes these obligations would be considered costs of service and recoverable in rates.

(b)       MGE has several purchase power agreements to help meet future electric supply requirements. Management expects to recover these costs in future customer rates.

e.       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, 2013, MGE has spent $9.6 million related to these projects and has outstanding agreements to purchase $0.9 million in smart grid related products for the remainder of 2013.

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Segment Information

3 Months Ended

Mar. 31, 2013

Segment Information Disclosure [Abstract]

Segment Information

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 2012 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, 2013
Operating revenues	$	93,494	$	72,467	$	1,276	$	0	$	0	$	0	$	167,237
Interdepartmental revenues		109		4,876		10,573		0		0		(15,558)		0
Total operating revenues		93,603		77,343		11,849		0		0		(15,558)		167,237
Depreciation and amortization		(6,400)		(1,425)		(1,799)		0		0		0		(9,624)
Other operating expenses		(74,925)		(60,437)		(37)		0		(144)		15,558		(119,985)
Operating income (loss)		12,278		15,481		10,013		0		(144)		0		37,628
Other income, net		575		162		0		2,396		176		0		3,309
Interest (expense) income, net		(2,404)		(678)		(1,613)		0		20		0		(4,675)
Income before taxes		10,449		14,965		8,400		2,396		52		0		36,262
Income tax provision		(3,433)		(5,989)		(3,257)		(971)		(28)		0		(13,678)
Net income	$	7,016	$	8,976	$	5,143	$	1,425	$	24	$	0	$	22,584
Three Months Ended March 31, 2012
Operating revenues	$	89,936	$	57,019	$	2,304	$	0	$	0	$	0	$	149,259
Interdepartmental revenues		109		2,986		8,676		0		0		(11,771)		0
Total operating revenues		90,045		60,005		10,980		0		0		(11,771)		149,259
Depreciation and amortization		(6,478)		(1,370)		(1,776)		0		0		0		(9,624)
Other operating expenses		(72,788)		(49,741)		(12)		0		(421)		11,771		(111,191)
Operating income (loss)		10,779		8,894		9,192		0		(421)		0		28,444
Other income, net		164		46		0		2,242		118		0		2,570
Interest (expense) income, net		(2,727)		(769)		(1,645)		0		37		0		(5,104)
Income (loss) before taxes		8,216		8,171		7,547		2,242		(266)		0		25,910
Income tax (provision) benefit		(2,785)		(3,238)		(3,029)		(910)		100		0		(9,862)
Net income (loss)	$	5,431	$	4,933	$	4,518	$	1,332	$	(166)	$	0	$	16,048

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, 2013
Operating revenues	$	93,494	$	72,467	$	1,276	$	0	$	0	$	167,237
Interdepartmental revenues		109		4,876		10,573		0		(15,558)		0
Total operating revenues		93,603		77,343		11,849		0		(15,558)		167,237
Depreciation and amortization		(6,400)		(1,425)		(1,799)		0		0		(9,624)
Other operating expenses*		(78,506)		(66,468)		(3,294)		0		15,558		(132,710)
Operating income*		8,697		9,450		6,756		0		0		24,903
Other income, net*		723		204		0		1,425		0		2,352
Interest expense, net		(2,404)		(678)		(1,613)		0		0		(4,695)
Net income		7,016		8,976		5,143		1,425		0		22,560
Less: Net income attributable to
noncontrolling interest, net of tax		0		0		0		0		(6,826)		(6,826)
Net income attributable to MGE	$	7,016	$	8,976	$	5,143	$	1,425	$	(6,826)	$	15,734
Three Months Ended March 31, 2012
Operating revenues	$	89,936	$	57,019	$	2,304	$	0	$	0	$	149,259
Interdepartmental revenues		109		2,986		8,676		0		(11,771)		0
Total operating revenues		90,045		60,005		10,980		0		(11,771)		149,259
Depreciation and amortization		(6,478)		(1,370)		(1,776)		0		0		(9,624)
Other operating expenses*		(75,508)		(52,961)		(3,041)		0		11,771		(119,739)
Operating income*		8,059		5,674		6,163		0		0		19,896
Other income, net*		99		28		0		1,332		0		1,459
Interest expense, net		(2,727)		(769)		(1,645)		0		0		(5,141)
Net income		5,431		4,933		4,518		1,332		0		16,214
Less: net income attributable to
noncontrolling interest, net of tax		0		0		0		0		(6,072)		(6,072)
Net income attributable to MGE	$	5,431	$	4,933	$	4,518	$	1,332	$	(6,072)	$	10,142
*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, 2013	$	904,578	$	275,815	$	11,900	$	324,894	$	61,826	$	409,602	$	(408,175)	$	1,580,440
December 31, 2012		888,444		285,468		18,559		323,216		61,064		413,291		(403,118)		1,586,924
Capital Expenditures:
Three Months Ended March 31, 2013	$	27,007	$	1,689	$	0	$	468	$	0	$	0	$	0	$	29,164
Year ended Dec. 31, 2012		81,965		13,812		0		2,658		0		0		0		98,435

		Utility						Consolidated
(In thousands)						Assets
MGE						not	Nonregulated			Transmission		Elimination
		Electric		Gas		Allocated		Energy		Investment		Entries		Total
Assets:
March 31, 2013	$	904,578	$	275,815	$	11,900	$	324,844	$	61,826	$	(28,358)	$	1,550,605
December 31, 2012		888,444		285,468		18,559		323,166		61,064		(23,050)		1,553,651
Capital Expenditures:
Three Months Ended March 31, 2013	$	27,007	$	1,689	$	0	$	468	$	0	$	0	$	29,164
Year ended Dec. 31, 2012		81,965		13,812		0		2,658		0		0		98,435

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Fair Value of Financial Instruments (Details-2) (USD $)	3 Months Ended
	Mar. 31, 2013	Dec. 31, 2012
Deferred compensation interest calculation [Abstract]
U.S Treasury Bills maturity	26
Increase compounded monthly	1.00%
Minimum annual rate	7.00%
Assets:
Exchange-traded investments	$ 428,000	$ 320,000
Total Assets	428,000	320,000
Liabilities:
Derivatives, net	69,197,000	72,329,000
Deferred compensation	2,085,000	2,010,000
Total liabilities	71,282,000	74,339,000
Derivative collateral	500,000	0
Level 1 [Member]
Assets:
Exchange-traded investments	428,000	320,000
Total Assets	428,000	320,000
Liabilities:
Derivatives, net	(401,000)	(17,000)
Deferred compensation	0	0
Total liabilities	(401,000)	(17,000)
Level 2 [Member]
Assets:
Exchange-traded investments	0	0
Total Assets	0	0
Liabilities:
Derivatives, net	0	0
Deferred compensation	2,085,000	2,010,000
Total liabilities	2,085,000	2,010,000
Level 3 [Member]
Assets:
Exchange-traded investments	0	0
Total Assets	0	0
Liabilities:
Derivatives, net	69,598,000	72,346,000
Deferred compensation	0	0
Total liabilities	69,598,000	72,346,000
MGE [Member]
Assets:
Exchange-traded investments	161,000	117,000
Total Assets	161,000	117,000
Liabilities:
Derivatives, net	69,197,000	72,329,000
Deferred compensation	2,085,000	2,010,000
Total liabilities	71,282,000	74,339,000
Derivative collateral	500,000	0
MGE [Member] | Level 1 [Member]
Assets:
Exchange-traded investments	161,000	117,000
Total Assets	161,000	117,000
Liabilities:
Derivatives, net	(401,000)	(17,000)
Deferred compensation	0	0
Total liabilities	(401,000)	(17,000)
MGE [Member] | Level 2 [Member]
Assets:
Exchange-traded investments	0	0
Total Assets	0	0
Liabilities:
Derivatives, net	0	0
Deferred compensation	2,085,000	2,010,000
Total liabilities	2,085,000	2,010,000
MGE [Member] | Level 3 [Member]
Assets:
Exchange-traded investments	0	0
Total Assets	0	0
Liabilities:
Derivatives, net	69,598,000	72,346,000
Deferred compensation	0	0
Total liabilities	$ 69,598,000	$ 72,346,000

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Commitments and Contingencies (Details-1) (USD $) In Millions, unless otherwise specified	3 Months Ended
	Mar. 31, 2013 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	$ 0.2
Columbia Clean Air Act litigation environmental mitigation costs	0.6
Columbia Environmental Project [Member]
Expected Capital Expenditures [Line Items]
MGE's share of expected capital expenditures	140.0
Columbia Commitments [Abstract]
Columbia environmental project commitments	$ 56.7
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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Madison Gas and Electric Company Consolidated Statements of Comprehensive Income (Unaudited) (USD $) In Thousands, unless otherwise specified	3 Months Ended
	Mar. 31, 2013		Mar. 31, 2012
Other comprehensive income (loss), net of tax:
Unrealized gain (loss) on available-for-sale securities, net of tax	$ 65	[1]	$ 7	[2]
Comprehensive Income	22,649		16,055
MGE [Member]
Net Income	22,560		16,214
Other comprehensive income (loss), net of tax:
Unrealized gain (loss) on available-for-sale securities, net of tax	27	[3]	(16)	[4]
Total comprehensive income including noncontrolling interest	22,587		16,198
Less: Comprehensive income attributable to Noncontrolling Interest, net of tax	(6,826)		(6,072)
Comprehensive Income	$ 15,761		$ 10,126

[1] Net of $43 tax

[2] Net of $5 tax

[3] Net of $18 tax

[4] Net of $11 tax

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Consolidated Balance Sheets (Unaudited) (Parentheticals) (USD $) In Thousands, unless otherwise specified	Mar. 31, 2013	Dec. 31, 2012
Receivables, Net
Reserve for uncollectible accounts receivable	$ 3,914	$ 3,885
Reserve for uncollectible other accounts receivable	931	931
MGE [Member]
Receivables, Net
Reserve for uncollectible accounts receivable	3,914	3,885
Reserve for uncollectible other accounts receivable	$ 931	$ 931

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Significant Accounting Policies (Policies)

3 Months Ended

Mar. 31, 2013

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 2009 through 2012, on February 15, 2013,15,256 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 a performance unit 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, 2013, 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 the event of a bona fide retirement, not followed by work for a competitor, the executive will receive full vesting credit for each outstanding award.

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

Fuel rules require the PSCW and Wisconsin utilities to defer electric fuel-related costs that fall outside a symmetrical cost tolerance band around the amount approved for a utility in its most recent base rate proceedings. Any over/under recovery of the actual costs is determined on an annual basis and will be adjusted in future billings to electric retail customers. The fuel rules bandwidth is currently set at plus or minus 2%. 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

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.

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 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 from 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 MGE's 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	97.1%
Off peak	96.0%
Counterparty fuel mix:
Internal generation	50 % - 70 %
Purchased power	50 % - 30 %

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 consolidated 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.       Presentation of Comprehensive Income.

In February 2013, the FASB issued authoritative guidance within the Codification's Comprehensive Income topic that provides guidance on the reporting of amounts reclassified out of accumulated other comprehensive income. Reclassification adjustments will be presented either on the financial statement where income is presented or as a separate disclosure in the notes to the financial statements. This authoritative guidance became effective January 1, 2013.The authoritative guidance hadno effect on our financial statement presentation or notes to the financial statements.

b.       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. On January 31, 2013, the FASB issued additional authoritative guidance which clarified the scope of disclosures about offsetting assets and liabilities. The revised guidance limits the scope of the new balance sheet offsetting disclosures to derivatives, repurchase agreements, and securities lending transactions to the extent that they are (1) offset in the financial statements or (2) subject to an enforceable master netting arrangement or similar agreement. This authoritative guidance became effective January 1, 2013. The authoritative guidance did not have a financial impact, but required additional disclosures. See Footnote 9 for additional information.

c.       Obligations Resulting from Joint and Several Liability Arrangements for Which the Total Amount of the Obligation Is Fixed at the Reporting Date.

In February 2013, the FASB issued authoritative guidance within the Codification's Balance Sheet topic that provides guidance on the recognition, measurement, and disclosure of obligations resulting from joint and several liability arrangements for which the total amount of the obligation is fixed at the reporting date. This authoritative guidance will become effective January 1, 2014. The authoritative guidance will not have a financial or disclosure impact.

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Taxes (Details) (USD $) In Millions, unless otherwise specified	3 Months Ended			3 Months Ended
	Mar. 31, 2013	Mar. 31, 2012	Dec. 31, 2012	Mar. 31, 2013 MGE [Member]	Mar. 31, 2012 MGE [Member]	Apr. 18, 2013 Unrecognized Tax Benefit [Member]
Unrecognized tax benefits that would impact effective tax rate [Abstract]
Total unrecognized tax benefit	$ 3.4		$ 3.2
Subsequent Events [Line Items]
Subsequent Event, Description						On April 18, 2013, MGE Energy received notification from the Internal Revenue Service that the examination of tax periods 2007-2009 has been completed. Unrecognized tax benefits of $1.5 million related to those years will be reversed (in the second quarter) due to those positions not being adversely adjusted in the examination.
Unrecognized Tax Benefits, decreases resulting from settlements with taxing authorities						$ 1.5
Effective income tax rate [Line Items]
Effective income tax rate	37.70%	38.10%		37.70%	38.10%

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Share-Based Compensation

3 Months Ended

Mar. 31, 2013

Share-Based Compensation Disclosure [Abstract]

Share-Based Compensation

7.       Share-Based Compensation - MGE Energy and MGE.

Under MGE Energy'sPerformance 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 2009 through 2012, on February 15, 2013,15,256 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 a performance unit 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, 2013, 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 the event of a bona fide retirement, not followed by work for a competitor, the executive will receive full vesting credit for each outstanding award.

During the three months ended March 31, 2013 and 2012, MGE recorded $0.9 million and $0.4 million, respectively, in compensation expense as a result of the Performance Unit Plan. In January 2013, cash payments of $1.0 million were distributed relating to awards that were granted in 2008 and became payable under the Performance Unit Plan. No forfeitures occurred during the three months ended March 31, 2013 or 2012. At March 31, 2013, $3.7 million of outstanding awards are vested.