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, 2014

[ ] 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 53788 (608) 252-7000 mgeenergy.com	39-2040501
000-1125	Madison Gas and Electric Company (a Wisconsin Corporation) 133 South Blair Street Madison, Wisconsin 53788 (608) 252-7000 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, 2014
MGE Energy, Inc.	Common stock, $1.00 par value, 34,668,370 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 economic conditions, 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," "will," 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' 2013 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 release publicly any revision to these forward-looking statements to reflect events or circumstances after the date of this report.

Stock Split

On December 20, 2013, MGE Energy's Board of Directors declared a three-for-two stock split of MGE Energy's outstanding shares of common stock, effective in the form of a stock dividend. Shareholders of record at the close of business on January 24, 2014, received one additional share of MGE Energy common stock for every two shares of common stock owned on that date. The additional shares were distributed on February 7, 2014. All share and per share data provided in this report give effect to this stock split.

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 sec.gov, MGE Energy's website at mgeenergy.com, and MGE's website at 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
NGV Fueling Services	NGV Fueling Services, LLC
North Mendota	North Mendota Energy & Technology Park, LLC
Other Defined Terms:
AFUDC	Allowance for Funds Used During Construction
ATC	American Transmission Company LLC
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
Dth	Dekatherms, a quantity measure used in respect of natural gas
Elm Road Units	Elm Road Generating Station
EPA	United States Environmental Protection Agency
FASB	Financial Accounting Standards Board
FTR	Financial Transmission Rights
GHG	Greenhouse Gas
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
MATS	Mercury and Air Toxics Standards
MISO	Midcontinent 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
NOV	Notice of Violation
NOx	Nitrogen Oxides
NSPS	New Source Performance Standards
OPRB	Other Postretirement Benefits
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)
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

4

SIP	State Implementation Plan
SO2	Sulfur Dioxide
the State	State of Wisconsin
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
WEPCO	Wisconsin Electric Power Company
Working capital	Current assets less current liabilities
WPL	Wisconsin Power and Light Company
WPSC	Wisconsin Public Service Corporation
XBRL	eXtensible Business Reporting Language

5

Item 1. Financial Statements.

MGE Energy, Inc.

Consolidated Statements of Income (unaudited)

(In thousands, except per-share amounts)

			Three Months Ended March 31,
			2014		2013
	Operating Revenues:
	Regulated electric revenues	$	98,852	$	93,494
	Regulated gas revenues		110,713		72,467
	Nonregulated revenues		680		1,276
	Total Operating Revenues		210,245		167,237
	Operating Expenses:
	Fuel for electric generation		14,132		10,760
	Purchased power		18,555		18,205
	Cost of gas sold		78,508		44,692
	Other operations and maintenance		40,472		41,649
	Depreciation and amortization		9,746		9,624
	Other general taxes		4,861		4,679
	Total Operating Expenses		166,274		129,609
	Operating Income		43,971		37,628
	Other income, net		4,552		3,309
	Interest expense, net		(4,541)		(4,675)
	Income before income taxes		43,982		36,262
	Income tax provision		(16,265)		(13,678)
	Net Income	$	27,717	$	22,584
	Earnings Per Share of Common Stock
	(basic and diluted)	$	0.80	$	0.65
	Dividends per share of common stock	$	0.272	$	0.263
	Average Shares Outstanding
	(basic and diluted)		34,668		34,668
The accompanying notes are an integral part of the above unaudited consolidated financial statements.

MGE Energy, Inc.

Consolidated Statements of Comprehensive Income (unaudited)

(In thousands)

			Three Months Ended March 31,
			2014		2013
	Net Income	$	27,717	$	22,584
	Other comprehensive income, net of tax:
	Unrealized gain on available-for-sale securities, net of
	tax ($5 and $43)		7		65
	Comprehensive Income	$	27,724	$	22,649
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,
		2014		2013
Operating Activities:
Net income	$	27,717	$	22,584
Items not affecting cash:
Depreciation and amortization		9,746		9,624
Deferred income taxes		(877)		11,294
Provision for doubtful receivables		743		743
Employee benefit plan expenses		(332)		3,336
Equity earnings in ATC		(2,481)		(2,396)
Other items		(679)		750
Changes in working capital items:
Decrease in current assets		3,283		17,341
Increase (decrease) in current liabilities		19,604		(4,590)
Dividend income from ATC		1,917		1,807
Cash contributions to pension and other postretirement plans		(818)		(30,764)
Other noncurrent items, net		547		(1,077)
Cash Provided by Operating Activities		58,370		28,652
Investing Activities:
Capital expenditures		(21,800)		(29,164)
Capital contributions to investments		(693)		(373)
Other		(682)		(279)
Cash Used for Investing Activities		(23,175)		(29,816)
Financing Activities:
Cash dividends paid on common stock		(9,420)		(9,132)
Repayment of long-term debt		(1,019)		(667)
Increase in short-term debt		-		10,500
Other		(80)		-
Cash (Used for) Provided by Financing Activities		(10,519)		701
Change in cash and cash equivalents		24,676		(463)
Cash and cash equivalents at beginning of period		68,813		46,357
Cash and Cash Equivalents at End of Period	$	93,489	$	45,894
Supplemental disclosures of cash flow information:
Significant noncash investing activities:
Accrued capital expenditures	$	8,967	$	12,699
The accompanying notes are an integral part of the unaudited consolidated financial statements.

7

MGE Energy, Inc.

Consolidated Balance Sheets (unaudited)

(In thousands)

ASSETS		March 31, 2014		December 31, 2013
Current Assets:
Cash and cash equivalents	$	93,489	$	68,813
Accounts receivable, less reserves of $4,501 and $4,219, respectively		62,760		44,890
Other accounts receivable, less reserves of $608 and $750, respectively		5,019		5,352
Unbilled revenues		29,568		31,982
Materials and supplies, at average cost		17,023		16,662
Fossil fuel		4,675		5,206
Stored natural gas, at average cost		642		13,988
Prepaid taxes		11,773		19,106
Regulatory assets - current		4,690		6,377
Other current assets		9,301		8,225
Total Current Assets		238,940		220,601
Regulatory assets		105,253		107,166
Pension benefits		16,013		15,071
Other deferred assets and other		6,758		8,046
Property, Plant, and Equipment:
Property, plant, and equipment, net		1,026,807		1,018,809
Construction work in progress		147,449		141,415
Total Property, Plant, and Equipment		1,174,256		1,160,224
Investments		69,203		67,952
Total Assets	$	1,610,423	$	1,579,060
LIABILITIES AND CAPITALIZATION
Current Liabilities:
Long-term debt due within one year	$	4,121	$	4,102
Accounts payable		56,171		43,684
Accrued taxes		11,275		822
Accrued interest		3,250		4,839
Accrued payroll related items		8,103		10,731
Deferred income taxes		-		1,711
Regulatory liabilities - current		11,537		13,538
Derivative liabilities		6,540		7,750
Other current liabilities		8,518		9,489
Total Current Liabilities		109,515		96,666
Other Credits:
Deferred income taxes		287,224		284,791
Investment tax credit - deferred		1,362		1,413
Regulatory liabilities		20,788		19,792
Accrued pension and other postretirement benefits		49,512		49,184
Derivative liabilities		53,750		57,930
Other deferred liabilities and other		54,155		52,360
Total Other Credits		466,791		465,470
Capitalization:
Common shareholders' equity		635,734		617,510
Long-term debt		398,383		399,414
Total Capitalization		1,034,117		1,016,924
Commitments and contingencies (see Footnote 8)		-		-
Total Liabilities and Capitalization	$	1,610,423	$	1,579,060
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)

	Common Stock				Additional Paid-in Capital		Retained Earnings		Accumulated Other Comprehensive Income		Total
	Shares		Value
2013
Beginning balance - December 31, 2012	34,668	$	34,668	$	316,268	$	228,399	$	94	$	579,429
Net income							22,584				22,584
Other comprehensive income									65		65
Common stock dividends declared
($0.263 per share)							(9,132)				(9,132)
Ending balance - March 31, 2013	34,668	$	34,668	$	316,268	$	241,851	$	159	$	592,946
2014
Beginning balance - December 31, 2013	34,668	$	34,668	$	316,268	$	266,197	$	377	$	617,510
Net income							27,717				27,717
Other comprehensive income									7		7
Common stock dividends declared
($0.272 per share)							(9,420)				(9,420)
Cash in lieu of fractional shares related
to stock split							(80)				(80)
Ending balance - March 31, 2014	34,668	$	34,668	$	316,268	$	284,414	$	384	$	635,734
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,
			2014		2013
	Operating Revenues:
	Regulated electric revenues	$	98,858	$	93,494
	Regulated gas revenues		110,718		72,467
	Nonregulated revenues		680		1,276
	Total Operating Revenues		210,256		167,237
	Operating Expenses:
	Fuel for electric generation		14,134		10,760
	Purchased power		18,558		18,205
	Cost of gas sold		78,513		44,692
	Other operations and maintenance		40,317		41,504
	Depreciation and amortization		9,734		9,624
	Other general taxes		4,861		4,679
	Income tax provision		14,924		12,870
	Total Operating Expenses		181,041		142,334
	Operating Income		29,215		24,903
	Other Income and Deductions:
	AFUDC - equity funds		1,950		596
	Equity in earnings in ATC		2,481		2,396
	Income tax provision		(1,264)		(781)
	Other (expense) income, net		(158)		141
	Total Other Income and Deductions		3,009		2,352
	Income before interest expense		32,224		27,255
	Interest Expense:
	Interest on long-term debt		5,249		4,928
	Other interest, net		(25)		(37)
	AFUDC - borrowed funds		(643)		(196)
	Net Interest Expense		4,581		4,695
	Net Income	$	27,643	$	22,560
	Less Net Income Attributable to Noncontrolling Interest, net of tax		(6,510)		(6,826)
	Net Income Attributable to MGE	$	21,133	$	15,734
The accompanying notes are an integral part of the above unaudited consolidated financial statements.

Madison Gas and Electric Company

Consolidated Statements of Comprehensive Income (unaudited)

(In thousands)

			Three Months Ended March 31,
			2014		2013
	Net Income	$	27,643	$	22,560
	Other comprehensive income, net of tax:
	Unrealized gain on available-for-sale securities, net of
	tax ($12 and $18)		18		27
	Comprehensive Income	$	27,661	$	22,587
	Less: Comprehensive income attributable to Noncontrolling
	Interest, net of tax		(6,510)		(6,826)
	Comprehensive Income attributable to MGE	$	21,151	$	15,761
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,
		2014		2013
Operating Activities:
Net income	$	27,643	$	22,560
Items not affecting cash:
Depreciation and amortization		9,734		9,624
Deferred income taxes		(1,141)		11,016
Provision for doubtful receivables		743		743
Employee benefit plan expenses		(332)		3,336
Equity earnings in ATC		(2,481)		(2,396)
Other items		(546)		882
Changes in working capital items:
Decrease in current assets		7,817		17,135
Increase (decrease) in current liabilities		17,488		(4,326)
Dividend income from ATC		1,917		1,807
Cash contributions to pension and other postretirement plans		(818)		(30,764)
Other noncurrent items, net		521		(1,096)
Cash Provided by Operating Activities		60,545		28,521
Investing Activities:
Capital expenditures		(21,800)		(29,164)
Capital contributions to investments		(533)		(178)
Other		(637)		(184)
Cash Used for Investing Activities		(22,970)		(29,526)
Financing Activities:
Cash dividends paid to parent by MGE		(7,000)		-
Distributions to parent from noncontrolling interest		(6,909)		(5,500)
Equity contribution received by noncontrolling interest		533		178
Repayment of long-term debt		(1,019)		(667)
Increase in short-term debt		-		10,500
Cash (Used for) Provided by Financing Activities		(14,395)		4,511
Change in cash and cash equivalents		23,180		3,506
Cash and cash equivalents at beginning of period		14,808		6,350
Cash and Cash Equivalents at End of Period	$	37,988	$	9,856
Supplemental disclosures of cash flow information:
Significant noncash investing activities:
Accrued capital expenditures	$	8,967	$	12,699
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)

ASSETS		March 31, 2014		December 31, 2013
Current Assets:
Cash and cash equivalents	$	37,988	$	14,808
Accounts receivable, less reserves of $4,501 and $4,219, respectively		62,760		44,890
Affiliate receivables		550		534
Other accounts receivable, less reserves of $608 and $750, respectively		4,937		5,274
Unbilled revenues		29,568		31,982
Materials and supplies, at average cost		17,023		16,662
Fossil fuel		4,675		5,206
Stored natural gas, at average cost		642		13,988
Prepaid taxes		12,044		23,934
Regulatory assets - current		4,690		6,377
Other current assets		8,979		8,197
Total Current Assets		183,856		171,852
Affiliate receivable long-term		5,692		5,825
Regulatory assets		105,253		107,166
Pension benefits		16,013		15,071
Other deferred assets and other		4,818		6,138
Property, Plant, and Equipment:
Property, plant, and equipment, net		1,025,886		1,017,877
Construction work in progress		147,449		141,415
Total Property, Plant, and Equipment		1,173,335		1,159,292
Investments		66,426		65,299
Total Assets	$	1,555,393	$	1,530,643
LIABILITIES AND CAPITALIZATION
Current Liabilities:
Long-term debt due within one year	$	4,121	$	4,102
Accounts payable		56,171		43,684
Accrued interest and taxes		10,019		6,040
Accrued payroll related items		8,103		10,731
Deferred income taxes		707		2,723
Regulatory liabilities - current		11,537		13,538
Derivative liabilities		6,540		7,750
Other current liabilities		8,244		6,446
Total Current Liabilities		105,442		95,014
Other Credits:
Deferred income taxes		281,261		279,085
Investment tax credit - deferred		1,362		1,413
Regulatory liabilities		20,788		19,792
Accrued pension and other postretirement benefits		49,512		49,184
Derivative liabilities		53,750		57,930
Other deferred liabilities and other		54,156		52,357
Total Other Credits		460,829		459,761
Capitalization:
Common shareholder's equity		471,642		457,491
Noncontrolling interest		119,097		118,963
Total Equity		590,739		576,454
Long-term debt		398,383		399,414
Total Capitalization		989,122		975,868
Commitments and contingencies (see Footnote 8)		-		-
Total Liabilities and Capitalization	$	1,555,393	$	1,530,643
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)

	Common Stock				Additional Paid-in Capital		Retained Earnings	Accumulated Other Comprehensive Income			Non- Controlling Interest		Total
	Shares		Value
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
2014
Beginning balance - Dec. 31, 2013	17,348	$	17,348	$	192,417	$	247,534	$	192	$	118,963	$	576,454
Net income							21,133				6,510		27,643
Other comprehensive income									18				18
Cash dividends paid to parent
by MGE							(7,000)						(7,000)
Equity contribution received by
noncontrolling interest											533		533
Distributions to parent from
noncontrolling interest											(6,909)		(6,909)
Ending balance - March 31, 2014	17,348	$	17,348	$	192,417	$	261,667	$	210	$	119,097	$	590,739
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, 2014

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 2013 Annual Report on Form 10-K.

The accompanying consolidated financial statements as of March 31, 2014, 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 2013 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 57 through 100 of the 2013 Annual Report on Form 10-K.

On December 20, 2013, MGE Energy's Board of Directors declared a three-for-two stock split of MGE Energy's common stock in the form of a stock dividend. The additional shares were distributed February 7, 2014, to all shareholders of record as of January 24, 2014. All shares and per share data provided in this report give effect to this stock split.

2.

Equity and Financing Arrangements.

a.

Common Stock - MGE Energy.

MGE Energy sells shares of its common stock through its Stock Plan. Those shares may be newly issued shares or shares that MGE Energy has purchased in the open market for resale to participants in the Stock Plan. All sales under the stock plan are covered by a shelf registration statement that MGE Energy filed with the SEC. For both the three months ended March 31, 2014 and 2013, MGE Energy did not issue any new shares of common stock under the Stock Plan.

b.

Dilutive Shares Calculation - MGE Energy.

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 as required by Wisconsin law. That interest is presently held by MGE Transco, which is jointly owned by MGE Energy and MGE.

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MGE Transco has accounted for its investment in ATC under the equity method of accounting. For the three months ended March 31, 2014 and 2013, MGE Transco recorded the following:

		Three Months Ended March 31,
(In thousands)		2014		2013
Equity in earnings from investment in ATC	$	2,481	$	2,396
Dividends received from ATC		1,917		1,807
Capital contributions to ATC		533		178

On April 30, 2014, MGE Transco made an additional $0.5 million capital contribution to ATC.

MGE Transco's investment in ATC as of March 31, 2014, and December 31, 2013, was $65.6 million and $64.5 million, respectively.

At March 31, 2014, 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, 2014 and 2013, is as follows:

		Three Months Ended March 31,
(In thousands)		2014		2013
Operating revenues	$	163,337	$	151,737
Operating expenses		(78,623)		(69,770)
Other income (expense), net		388		(448)
Interest expense, net		(21,996)		(21,044)
Earnings before members' income taxes	$	63,106	$	60,475

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. Unit 2 was placed into service in April 2014 and Unit 1 is expected to be placed into service in the third quarter of 2014. The scrubbers and bag houses are expected to support compliance obligations for current and anticipated air quality regulations, including CAIR, CSAPR, 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 $135 million. As of March 31, 2014, MGE had accumulated $124.3 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 expects to incur capital expenditures of approximately $10.7 million for the remainder of 2014. These amounts may change as a result of modifications to the project estimate or timing differences. MGE's share of various contractual commitments entered for the project as of March 31, 2014, is $10.7 million. For the three months ended March 31, 2014 and 2013, MGE has recognized after tax $1.9 million and $0.5 million, respectively, in AFUDC equity related to this project.

MGE expects that the costs pertaining to this project will be fully recoverable through rates. For 2014, the PSCW authorized MGE 100% AFUDC on this project during construction. For 2013, the PSCW authorized MGE a 50% current return (included in customer rates) and the remaining 50% as AFUDC.

5.

Taxes - MGE Energy and MGE.

Effective Tax Rate.

MGE Energy's effective income tax rate for the three months ended March 31, 2014 and 2013, was 37.0% and 37.7%, respectively. MGE's effective income tax rate for the three months ended March 31, 2014 and 2013, was

15

36.9% and 37.7%, respectively. The decrease in the effective tax rate is primarily attributable to higher AFUDC equity earnings in 2014.

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, 2014 and 2013. A portion of the net periodic benefit cost is capitalized within the consolidated balance sheets.

		Three Months Ended March 31,
(In thousands)		2014		2013
Pension Benefits
Components of net periodic (benefit) cost:
Service cost	$	1,484	$	1,929
Interest cost		3,251		3,186
Expected return on assets		(5,279)		(4,776)
Amortization of:
Prior service (benefit) cost		49		79
Actuarial loss		173		2,015
Net periodic (benefit) cost	$	(322)	$	2,433
Postretirement Benefits
Components of net periodic (benefit) cost:
Service cost	$	330	$	596
Interest cost		772		970
Expected return on assets		(654)		(544)
Amortization of:
Transition obligation		1		1
Prior service (benefit) cost		(668)		28
Actuarial loss		39		311
Net periodic (benefit) cost	$	(180)	$	1,362

7.

Share-Based Compensation - MGE Energy and MGE.

Under MGE Energy's Performance Unit Plan, eligible employees 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 2013, on February 21, 2014, 21,991 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 and have been adjusted to reflect the three-for-two stock split declared December 20, 2013. 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, 2014, 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 December 2013, a Director Incentive Plan was approved for the non-employee members of the Board of Directors. This plan is similar to MGE Energy's Performance Unit Plan for eligible employees described above. Under the plan, a non-employee director can 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

16

payments, at the end of the set performance period. The units are subject to a three-year graded vesting schedule. In January 2014, unit awards of 4,683 (post-split) were granted to the non-employee Directors. For accounting purposes, the awards will be measured similarly to the employee unit awards.

During the three months ended March 31, 2014 and 2013, MGE recorded $0.8 million and $0.9 million, respectively, in compensation expense as a result of the plans. In January 2014, cash payments of $1.2 million were distributed relating to awards that were granted in 2009. No forfeitures occurred during the three months ended March 31, 2014 or 2013. At March 31, 2014, $3.9 million of outstanding awards are vested.

8.

Commitments and Contingencies - MGE Energy and MGE.

a.

Environmental.

MGE Energy and MGE are subject to frequently changing local, state, and federal regulations concerning air quality, water quality, land use, threatened and endangered species, hazardous materials handling, and solid waste disposal. These regulations affect the manner in which they conduct their operations, the costs of those operations, as well as capital and operating expenditures. Regulatory initiatives, proposed rules, and court challenges to adopted rules, have the potential to have a material effect on our capital expenditures and operating costs. These initiatives, proposed rules, and court challenges include:

·

The President's announced plan and directive to the EPA to regulate carbon pollution, or GHG emissions, from new and existing electric power generation, and EPA's related proposed GHG New Source Performance Standards (NSPS).

·

Rules to regulate NO_x and SO₂ emissions, including the EPA's Cross State Air Pollution Rule (CSAPR), which recently has been reinstated by the U.S. Supreme Court (see below for recent developments with CSAPR). The Sierra Club has sought federal appellate court review of Wisconsin's implementation plan for CAVR. Both the pending reinstatement of CSAPR and the appellate court review of Wisconsin's implementation plan for Clean Air Visibility Rule (CAVR) make the nature of compliance requirements uncertain.

·

Rules to regulate mercury and similar emissions, including Wisconsin's adopted Mercury Rule and the EPA's adopted Mercury and Air Toxics Standards.

·

The EPA's proposed cooling water intake rules. The EPA issued a proposed Phase II rule and alternative compliance strategies for existing facilities in April 2011 and has announced that it intends to release the final rule in May 2014 pursuant to a consent agreement.

·

The EPA's proposed water effluent limitations guidelines and standards for steam electric power plants, which focus on the reduction of metals and other pollutants in wastewater from new and existing power plants from coal-burning plants such as our Columbia and Elm Road Units.

·

The EPA's ongoing review of several National Ambient Air Quality Standards (NAAQS), including the potential lowering of ozone NAAQS, and upcoming guidance for determining attainment for sulfur dioxide NAAQS.

·

The EPA is reconsidering the current emergency dispatch restrictions in the Reciprocating Internal Combustion Engines Maximum Achievable Control Technology (RICE MACT) regulation. The reconsideration could result in increased or decreased restrictions for these engines.

The matters in the bullet points above are discussed further in Footnote 18.d. in MGE Energy's and MGE's 2013 Annual Report on Form 10-K. In addition to the developments noted above, the following discussion is an update to the current status of environmental matters set forth in that Footnote.

EPA's Cross-State Air Pollution Rule (CSAPR) Upheld by the Supreme Court

On April 29, 2014, the U.S. Supreme Court issued a decision upholding CSAPR, thereby reversing the D.C. Circuit Court's decision on CSAPR, and remanding the matter back to the D.C. Circuit for further proceedings. The EPA may amend CSAPR to modify compliance deadlines that have passed since the rule was vacated by the D.C. Circuit. It is unclear if the rule will be reinstated for 2014 emissions or later. The

17

Clean Air Interstate Rule (CAIR) will remain in effect until CSAPR is reinstated. See MGE Energy's and MGE's 2013 Annual Report on Form 10K for additional information on the legal proceedings associated with these environmental matters.

Past evaluations of CSAPR's effect on MGE have pointed to SO₂ emissions at our Columbia plant as being our primary concern in meeting emissions allocations under CSAPR. Planned new SO₂ controls at Columbia are underway; Unit 2 was completed in April 2014 and Unit 1 is expected to be completed by third quarter of 2014 (see Footnote 4 for information regarding the Columbia environmental construction project). MGE expects that the costs pertaining to meeting CSAPR requirements will be fully recoverable through rates. We will continue to monitor and evaluate recoverability through the D.C. Circuit Court process and the EPA implementation phase.

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 as noted below.

Columbia Environmental Project

See Footnote 4 for information regarding the Columbia environmental construction project.

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 owner-operator, and the other co-owners 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 April 2013, the EPA filed a lawsuit against the co-owners of Columbia asserting similar allegations. In September 2010 and April 2013, Sierra Club filed lawsuits against WPL alleging violations of the CAA at Columbia and other WPL-operated Wisconsin facilities.

In April 2013, WPL, as owner-operator, along with the other owners of Columbia, entered into a consent decree with the EPA and the Sierra Club to resolve these claims, while admitting no liability. In June 2013, the consent decree was approved and entered by the Court. 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, 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 also paid approximately $0.2 million as its share of a civil penalty and will complete approximately $0.6 million in environmental mitigation projects. MGE intends to seek recovery in rates of the costs associated with its compliance with the terms of the final consent decree and currently expects to recover any material compliance costs.

b.

Chattel Paper Agreement and Other Guarantees.

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, 2014. At March 31, 2014, MGE had sold a $5.1 million interest in these receivables. MGE retains the servicing responsibility for these receivables. As of March 31, 2014, the servicing asset recognized by MGE is $0.3 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, 2014, approximate the fair value of the energy-related equipment acting as

18

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 2014 and the next four years on the loans are:

(In thousands)		2014		2015		2016		2017		2018
Chattel Paper	$	477	$	1,007	$	910	$	506	$	449

c.

Legal Matters.

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

d.

Purchase Contracts.

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, 2014, the future commitments related to these purchase contracts were as follows:

(In thousands)		2014		2015		2016		2017		2018
Purchase power(a)	$	50,542	$	49,072	$	49,743	$	50,243	$	51,265

(a)

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

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, 2014	December 31, 2013
Commodity derivative contracts	409,800 MWh	458,660 MWh
Commodity derivative contracts	2,200,000 Dth	3,750,000 Dth
FTRs	790 MW	1,984 MW

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c.

Financial Statement Presentation.

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 offset with a corresponding 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, 2014, and December 31, 2013, the fair value of exchange traded derivatives and FTRs exceeded their cost basis by $2.1 million and $1.8 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, 2014, and December 31, 2013, reflects a loss position of $60.3 million and $65.7 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, 2014
Commodity derivative contracts	Other current assets	$	2,086	Derivative liability (current)	$	111
Commodity derivative contracts	Other deferred charges		37	Derivative liability (long-term)		41
FTRs	Other current assets		106	Derivative liability (current)		-
Ten-year PPA	N/A		N/A	Derivative liability (current)		6,540
Ten-year PPA	N/A		N/A	Derivative liability (long-term)		53,750
December 31, 2013
Commodity derivative contracts	Other current assets	$	1,356	Derivative liability (current)	$	51
Commodity derivative contracts	Other deferred charges		167	Derivative liability (long-term)		48
FTRs	Other current assets		363	Derivative liability (current)		-
Ten-year PPA	N/A		N/A	Derivative liability (current)		7,750
Ten-year PPA	N/A		N/A	Derivative liability (long-term)		57,930

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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
(In thousands)		Gross amounts		Gross amounts offset in balance sheet		Collateral posted against derivative positions		Net amount presented in balance sheet
March 31, 2014
Commodity derivative contracts	$	2,123	$	(152)	$	-	$	1,971
FTRs		106		-		-		106
December 31, 2013
Commodity derivative contracts	$	1,523	$	(99)	$	(175)	$	1,249
FTRs		363		-		-		363

Offsetting of Derivative Liabilities
(In thousands)		Gross amounts		Gross amounts offset in balance sheet		Collateral posted against derivative positions		Net amount presented in balance sheet
March 31, 2014
Commodity derivative contracts	$	152	$	(152)	$	-	$	-
Ten-year PPA		60,290		-		-		60,290
December 31, 2013
Commodity derivative contracts	$	99	$	(99)	$	-	$	-
Ten-year PPA		65,680		-		-		65,680

The following tables summarize the unrealized and realized gains (losses) related to the derivative instruments on the consolidated balance sheet at March 31, 2014 and 2013, and the consolidated income statement for the three months ended March 31, 2014 and 2013.

		2014				2013
(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,	$	63,893	$	411	$	72,329	$	574
Change in unrealized gain		(13,601)		-		(1,697)		-
Realized loss reclassified to a deferred account		1,535		(1,535)		(290)		290
Realized gain (loss) reclassified to income
statement		6,386		1,475		(1,145)		(605)
Balance at March 31,	$	58,213	$	351	$	69,197	$	259

		Realized losses (gains)
(In thousands)		Fuel for electric generation/ purchased power		Cost of gas sold
Three Months Ended March 31, 2014:
Commodity derivative contracts	$	(4,795)	$	(1,220)
FTRs		(636)		-
Ten-year PPA		(1,210)		-
Three Months Ended March 31, 2013:
Commodity derivative contracts	$	22	$	608
FTRs		(158)		-
Ten-year PPA		1,278		-

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

21

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, 2014, 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, 2014, and December 31, 2013, 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, 2014, no counterparties have defaulted.

10.

Rate Matters - MGE Energy and MGE.

a.

Rate Proceedings.

On April 17, 2014, MGE filed an application with the PSCW requesting a 2.8% increase to electric rates and a 2.3% decrease to gas rates for 2015. Electric and natural gas rates would then be frozen in 2016, subject to review of fuel costs. As a condition of the rate freeze, MGE has requested escrow accounting treatment for transmission related costs starting in 2015. This treatment will allow MGE to reflect any differential in actual costs incurred in its next rate case filing. The proposed electric rate increases cover costs associated with the construction of emission-reduction equipment at Columbia and improvements and reliability of the state's electric transmission system.

On July 26, 2013, the PSCW authorized MGE to freeze electric and natural gas rates at 2013 levels for 2014. The order includes authorizing 100% AFUDC on the Columbia scrubber construction project and deferral of increased costs related to ATC and MISO Schedule 26 fees. As part of the rate freeze plan authorized by the PSCW, effective January 1, 2014, approximately $6.2 million associated with a 2012 fuel rule surplus credit will not be required to be refunded to customers and will be amortized in 2014. The fuel credit will accrue interest at MGE's weighted cost of capital. The authorized return on equity will remain unchanged at 10.3%.

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%.

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, 2014, MGE did not defer any electric fuel-related savings/costs that are outside the range authorized by the PSCW. As part of the rate freeze plan authorized by the PSCW for 2014, $1.6 million of the approximately $6.2 million associated with the 2012 fuel rule surplus credit was amortized against purchase power expense during the three months ended March 31, 2014.

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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, 2014, and December 31, 2013, 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, 2014, and December 31, 2013. Since 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, 2014				December 31, 2013
(In thousands)		Carrying Amount		Fair Value		Carrying Amount		Fair Value
MGE Energy
Assets:
Cash and cash equivalents	$	93,489	$	93,489	$	68,813	$	68,813
Liabilities:
Long-term debt*		402,774		436,788		403,793		432,010
MGE
Assets:
Cash and cash equivalents	$	37,988	$	37,988	$	14,808	$	14,808
Liabilities:
Long-term debt*		402,774		436,788		403,793		432,010
*Includes long-term debt due within one year.

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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, 2014
(In thousands)		Total		Level 1		Level 2		Level 3
MGE Energy
Assets:
Exchange-traded investments	$	804	$	804	$	-	$	-
Total Assets	$	804	$	804	$	-	$	-
Liabilities:
Derivatives, net	$	58,213	$	(584)	$	-	$	58,797
Deferred compensation		2,472		-		2,472		-
Total Liabilities	$	60,685	$	(584)	$	2,472	$	58,797
MGE
Assets:
Exchange-traded investments	$	461	$	461	$	-	$	-
Total Assets	$	461	$	461	$	-	$	-
Liabilities:
Derivatives, net	$	58,213	$	(584)	$	-	$	58,797
Deferred compensation		2,472		-		2,472		-
Total Liabilities	$	60,685	$	(584)	$	2,472	$	58,797

		Fair Value as of December 31, 2013
(In thousands)		Total		Level 1		Level 2		Level 3
MGE Energy
Assets:
Exchange-traded investments	$	792	$	792	$	-	$	-
Total Assets	$	792	$	792	$	-	$	-
Liabilities:
Derivatives, net(a)	$	63,893	$	(735)	$	-	$	64,628
Deferred compensation		2,364		-		2,364		-
Total Liabilities	$	66,257	$	(735)	$	2,364	$	64,628
MGE
Assets:
Exchange-traded investments	$	431	$	431	$	-	$	-
Total Assets	$	431	$	431	$	-	$	-
Liabilities:
Derivatives, net(a)	$	63,893	$	(735)	$	-	$	64,628
Deferred compensation		2,364		-		2,364		-
Total Liabilities	$	66,257	$	(735)	$	2,364	$	64,628
(a) These amounts are shown gross and exclude $0.2 million of collateral that was posted against derivative positions with counterparties.

No transfers were made in or out of Level 1 or Level 2 for the three months ended March 31, 2014.

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 considered unobservable and classified as Level 3. These transactions are

24

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

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

Significant Unobservable Inputs	Model Input
Basis adjustment:
On peak	95.5%
Off peak	93.1%
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.

25

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)		2014		2013
Beginning balance,	$	(64,628)	$	(72,346)
Realized and unrealized gains (losses):
Included in regulatory liabilities		5,831		2,748
Included in other comprehensive income		-		-
Included in earnings		6,634		(1,148)
Included in current assets		(53)		-
Purchases		6,859		5,562
Sales		(60)		(3)
Issuances		-		-
Settlements		(13,380)		(4,411)
Transfers in and/or out of Level 3		-		-
Balance as of March 31,	$	(58,797)	$	(69,598)
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)		2014		2013
Purchased Power Expense	$	6,634	$	(1,148)

(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.

12.

New Accounting Pronouncements - MGE Energy and MGE.

a.

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 became effective January 1, 2014. The authoritative guidance did not have a financial or disclosure impact.

b.

Presentation of an Unrecognized Tax Benefit.

In July 2013, the FASB issued authoritative guidance within the Codification's Income Statement topic that provides guidance on the presentation of an unrecognized tax benefit when a net operating loss carryforward, a similar tax loss, or a tax credit carryforward exist. The authoritative guidance was issued to eliminate diversity in practice by providing guidance on the presentation of unrecognized tax benefits. This authoritative guidance became effective January 1, 2014. The authoritative guidance will not have a financial statement or disclosure impact, unless MGE Energy or its subsidiaries are in a net operating loss position. MGE Energy or its subsidiaries are currently not in a net operating loss position.

26

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 2013 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, 2014
Operating revenues	$	98,852	$	110,713	$	680	$	-	$	-	$	-	$	210,245
Interdepartmental revenues		118		3,624		10,670		-		-		(14,412)		-
Total operating revenues		98,970		114,337		11,350		-		-		(14,412)		210,245
Depreciation and amortization		(6,337)		(1,563)		(1,834)		-		(12)		-		(9,746)
Other operating expenses		(77,901)		(92,843)		(40)		-		(156)		14,412		(156,528)
Operating income (loss)		14,732		19,931		9,476		-		(168)		-		43,971
Other (deductions) income, net		1,827		(35)		-		2,481		279		-		4,552
Interest (expense) income, net		(2,205)		(804)		(1,572)		-		40		-		(4,541)
Income before taxes		14,354		19,092		7,904		2,481		151		-		43,982
Income tax provision		(4,353)		(7,665)		(3,172)		(998)		(77)		-		(16,265)
Net income	$	10,001	$	11,427	$	4,732	$	1,483	$	74	$	-	$	27,717
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

27

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

(In thousands) MGE		Electric		Gas		Nonregulated Energy		Transmission Investment		Consolidation/ Elimination Entries		Consolidated Total
Three Months Ended March 31, 2014
Operating revenues	$	98,858	$	110,718	$	680	$	-	$	-	$	210,256
Interdepartmental revenues		112		3,619		10,670		-		(14,401)		-
Total operating revenues		98,970		114,337		11,350		-		(14,401)		210,256
Depreciation and amortization		(6,337)		(1,563)		(1,834)		-		-		(9,734)
Other operating expenses*		(82,046)		(100,450)		(3,212)		-		14,401		(171,307)
Operating income*		10,587		12,324		6,304		-		-		29,215
Other (deductions) income, net*		1,619		(93)		-		1,483		-		3,009
Interest expense, net		(2,205)		(804)		(1,572)		-		-		(4,581)
Net income		10,001		11,427		4,732		1,483		-		27,643
Less: Net income attributable to
noncontrolling interest, net of tax		-		-		-		-		(6,510)		(6,510)
Net income attributable to MGE	$	10,001	$	11,427	$	4,732	$	1,483	$	(6,510)	$	21,133
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
*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, 2014	$	905,319	$	268,294	$	40,011	$	312,223	$	65,600	$	432,919	$	(413,943)	$	1,610,423
December 31, 2013		899,257		265,694		19,853		288,116		64,504		431,436		(389,800)		1,579,060
Capital Expenditures:
Three Months Ended March 31, 2014	$	18,906	$	2,384	$	-	$	510	$	-	$	-	$	-	$	21,800
Year ended Dec. 31, 2013		100,146		15,554		-		3,347		-		-		-		119,047

		Utility						Consolidated
(In thousands) MGE		Electric		Gas		Assets not Allocated		Nonregulated Energy		Transmission Investment		Consolidation/ Elimination Entries		Total
Assets:
March 31, 2014	$	907,952	$	266,383	$	39,883	$	288,268	$	65,600	$	(12,693)	$	1,555,393
December 31, 2013		899,257		265,694		19,853		288,066		64,504		(6,731)		1,530,643
Capital Expenditures:
Three Months Ended March 31, 2014	$	18,906	$	2,384	$	-	$	510	$	-	$	-	$	21,800
Year ended Dec. 31, 2013		100,146		15,554		-		3,347		-		-		119,047

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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 141,000 customers in Dane County, Wisconsin, including the city of Madison, and purchases and distributes natural gas to approximately 147,000 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.

Executive 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 2013 Annual Report on Form 10-K.

29

For the three months ended March 31, 2014, MGE Energy's earnings were $27.7 million or $0.80 per share compared to $22.6 million or $0.65 per share for the same period in the prior year. MGE's earnings for the three months ended March 31, 2014, were $21.1 million compared to $15.7 million for the same period in the prior year.

		Three Months Ended March 31,
(In thousands)
Business Segment:		2014		2013
Electric Utility	$	10,001	$	7,016
Gas Utility		11,427		8,976
Nonregulated Energy		4,732		5,143
Transmission Investments		1,483		1,425
All Other		74		24
Net Income	$	27,717	$	22,584

Our net income during the three months ended March 31, 2014, compared to the same period in the prior year primarily reflects the effects of the following factors:

·

Electric net income increased due to a 2.8% increase in electric retail sales and a $1.4 million (after tax) increase in AFUDC equity related to the Columbia environmental project compared to the same period in the prior year. In addition, operating and maintenance expenditures decreased compared to the prior period.

·

Gas net income increased due to a 23.5% increase in gas retail sales reflecting higher customer demand due to a colder winter compared to the same period in the prior year. The average temperatures in January and February 2014 were 11.5 degrees and 12.5 degrees, respectively, compared to 21.8 degrees and 21.3 degrees in the prior year. Heating degree days (a measure for determining the impact of weather during the heating season) increased by 14.2% compared to the prior period. In addition, operating and maintenance expenditures decreased compared to the prior period.

·

Lower nonregulated revenues primarily attributable to approved recovery in December 2012 of force majeure costs associated with the construction of the Elm Road Units. The PSCW, as part of WEPCO's 2013 Wisconsin rate case, determined that the costs were prudently incurred and approved the recovery in rates. The recovery of the force majeure costs began in 2013. A portion of the recovery pertaining to periods prior to the PSCW order only affected 2013.

During the first three months of 2014, 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 $135 million. As of March 31, 2014, MGE has accumulated $124.3 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 $3.4 million in 2014. MGE has recognized $1.9 million (after tax) in AFUDC equity related to this project for the three months ended March 31, 2014. The air emission reduction systems and associated equipment for Unit 2 were placed into service in April 2014.

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

2015 Rate Filing: On April 17, 2014, MGE filed an application with the PSCW requesting a 2.8% increase to electric rates and a 2.3% decrease to gas rates for 2015. Electric and natural gas rates would then be frozen in 2016, subject to review of fuel costs. As a condition of the rate freeze, MGE has requested escrow accounting treatment for transmission related costs starting in 2015. This treatment will allow MGE to reflect any differential in actual costs incurred in its next rate case filing. The proposed electric rate increases cover costs associated with the construction of emission-reduction equipment at Columbia and improvements and reliability of the state's electric transmission system.

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 45% 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

30

to the timing and form of the legislation and rules, and the scope and time of the recovery of costs in rates. In addition, the Columbia owners, including MGE, resolved claims surrounding the alleged failure, among other things, to obtain necessary air permits and implement necessary emission controls associated with past activities at Columbia. See Columbia discussion in Footnote 8.a. in the Notes to Consolidated Financial Statements.

Columbia Environmental Project: MGE's share of the capital expenditures associated with the Columbia environmental project will be approximately $10.7 million for the remainder of 2014. The air emission reduction systems and associated equipment for Unit 1 are expected to be placed into service in the third quarter of 2014.

Pension and Other Postretirement Benefit Costs: Costs for pension and other postretirement benefits are affected by actual investment returns on the assets held for those benefits and by the discount rate, which is sensitive to interest rates, used to calculate those benefits. Interest rates have declined since the end of the year that could cause discount rates used to value the pension and postretirement benefit obligations to decline. The change in the value of the plan assets and the change in the discount rate are not expected to have an impact on the income statement for 2014. However, these changes may increase benefit costs in future years. MGE expects any changes in the cost for employee benefit plans will be factored into future rate actions.

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 $150 million for MGE Energy (including MGE) and $100 million for MGE to address our liquidity needs. As of March 31, 2014, there were no borrowings outstanding under our lines of credit.

The following discussion is based on the business segments as discussed in Footnote 13 of the Notes to Consolidated Financial Statements.

Three Months Ended March 31, 2014 and 2013

Electric Utility Operations - MGE Energy and MGE

Electric sales and revenues

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

		Revenues				Sales (kWh)
(In thousands)		Three Months Ended March 31,				Three Months Ended March 31,
		2014		2013	% Change	2014	2013	% Change
Residential	$	35,293	$	33,574	5.1%	221,696	209,782	5.7%
Commercial		50,161		48,147	4.2%	448,480	429,359	4.5%
Industrial		4,581		4,531	1.1%	58,305	59,187	(1.5)%
Other-retail/municipal		8,254		8,639	(4.5)%	89,435	97,538	(8.3)%
Total retail		98,289		94,891	3.6%	817,916	795,866	2.8%
Sales to the market		1,960		19	N/A	44,167	10,146	N/A
Adjustments to revenues		(1,397)		(1,416)	1.3%	-	-	-%
Total	$	98,852	$	93,494	5.7%	862,083	806,012	7.0%

Electric operating revenues increased $5.4 million or 5.7% for the three months ended March 31, 2014, due to the following:

(In millions)
Volume	$	2.6
Sales to the market		2.0
Other		0.8
Total	$	5.4

31

In July 2013, the PSCW authorized MGE to freeze 2014 rates for retail electric customers.

·

Volume. During the three months ended March 31, 2014, there was a 2.8% increase in total retail sales volumes compared to the same period in the prior year driven by higher customer demand.

·

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.

Electric fuel and purchased power

The expense for fuel for electric generation increased $3.4 million or 31.3% during the three months ended March 31, 2014, compared to the same period in the prior year. Internal electric generation costs increased $2.4 million as a result of a 21.9% increase in the per-unit cost. Internal electric generated volume delivered to the system increased 7.7%, which resulted in $1.0 million of increased expense.

Excluding costs associated with the 2012 fuel rule surplus credit, purchased power expense increased $2.0 million during the three months ended March 31, 2014, compared to the same period in the prior year. This increase in expense reflects a $1.0 million or 5.4% increase in the volume of power purchased from third parties and a $1.0 million or 5.0% increase in the per-unit cost of purchased power. After adjusting for the 2012 fuel rule surplus credit of $1.6 million, net purchase power expense increased $0.4 million during the three months ended March 31, 2014, compared to the prior year.

Electric operating and maintenance expenses

Electric operating and maintenance expenses decreased $0.8 million during the three months ended March 31, 2014, compared to the same period in 2013. The following changes contributed to the net change:

(In millions)
Decreased administrative and general costs	$	(1.6)
Decreased customer service costs		(0.3)
Decreased distribution expenses		(0.1)
Increased transmission costs		0.6
Increased production expenses		0.6
Total	$	(0.8)

For the three months ended March 31, 2014, decreased administrative and general costs are primarily due to decreased pension and other postretirement benefit costs.

Gas Utility Operations - MGE Energy and MGE

Gas deliveries and revenues

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

		Revenues				Therms Delivered
(In thousands, except HDD and average rate per therm of retail customer)		Three Months Ended March 31,				Three Months Ended March 31,
		2014		2013	% Change	2014	2013	% Change
Residential	$	59,191	$	41,611	42.2%	57,368	47,454	20.9%
Commercial/Industrial		50,411		29,771	69.3%	62,024	49,211	26.0%
Total retail		109,602		71,382	53.5%	119,392	96,665	23.5%
Gas transportation		953		943	1.1%	12,494	12,327	1.4%
Other revenues		158		142	11.3%	-	-	-%
Total	$	110,713	$	72,467	52.8%	131,886	108,992	21.0%
Heating degree days (normal 3,500)						4,278	3,745	14.2%
Average rate per therm of
retail customer	$	0.918	$	0.738	24.4%

32

Gas revenues increased $38.2 million or 52.8% for the three months ended March 31, 2014. These changes are related to the following factors:

(In millions)
Rate/PGA changes	$	21.4
Volume		16.8
Total	$	38.2

·

Rate/PGA changes. The average retail rate per therm for the three months ended March 31, 2014, increased 24.3% compared to the same period in 2013, reflecting higher natural gas commodity costs. 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.

·

Volume. For the three months ended March 31, 2014, retail gas deliveries increased 23.5% compared to the same period in 2013, as a result of colder weather during the winter months compared to the prior year.

Cost of gas sold

For the three months ended March 31, 2014, cost of gas sold increased by $33.8 million, compared to the same period in the prior year. The cost per therm of natural gas increased 42.2%, which resulted in $23.3 million of increased expense. In addition, the volume of gas purchased increased 23.5%, which resulted in $10.5 million of increased expense.

Gas operating and maintenance expenses

Gas operating and maintenance expenses decreased by $0.4 million for the three months ended March 31, 2014, compared to the same period in 2013. The following changes contributed to the net change:

(In millions)
Decreased administrative and general costs	$	(0.7)
Decreased customer service costs		(0.1)
Increased distribution costs		0.2
Increased customer accounts costs		0.2
Total	$	(0.4)

For the three months ended March 31, 2014, decreased administrative and general costs are primarily due to decreased pension and other postretirement benefit costs.

Nonregulated Energy Operations - MGE Energy and MGE

For the three months ended March 31, 2014 and 2013, net income at the nonregulated energy operations segment was $4.7 million and $5.1 million, respectively. The nonregulated energy operations are conducted through MGE Energy's subsidiaries: MGE Power Elm Road and MGE Power West Campus which have been formed to own and lease electric generating capacity to assist MGE.

Results for the three months ended March 31, 2013, reflect the recovery of force majeure costs associated with the construction of the Elm Road Units. In December 2012, as part of WEPCO's (the operator and primary owner of the Elm Road Units) 2013 Wisconsin rate case, the PSCW determined that 100% of the construction costs for the Elm Road Units were prudently incurred, and approved the recovery in rates of more than 99.5% of these costs. The recovery of the force majeure costs began in 2013. A portion of the recovery pertaining to periods prior to the PSCW order only affected 2013.

Transmission Investment Operations - MGE Energy and MGE

Transmission investment other income

For the three months ended March 31, 2014 and 2013, other income at the transmission investment segment was $2.5 million and $2.4 million, respectively. The transmission investment segment holds our interest in ATC, and its income reflects our equity in the earnings of ATC. See Footnote 3 of the Notes to Consolidated Financial Statements for additional information concerning ATC and summarized financial information regarding ATC.

33

Consolidated Income Taxes - MGE Energy and MGE

MGE Energy's effective income tax rate for the three months ended March 31, 2014 and 2013, was 37.0% and 37.7%, respectively. MGE's effective income tax rate for the three months ended March 31, 2014 and 2013, was 36.9% and 37.7%, respectively. The decrease in the effective tax rate is primarily attributable to higher AFUDC equity earnings in 2014.

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)		2014		2013
MGE Power Elm Road	$	3.9	$	4.3
MGE Power West Campus		1.9		1.9
MGE Transco		0.7		0.6

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, 2014, except as noted below. Further discussion of the contractual obligations and commercial commitments is included in Footnote 8 of Notes to Consolidated Financial Statements in this Report, and Footnote 18 of Notes to Consolidated Financial Statements, 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 2013 Annual Report on Form 10-K.

Purchase Contracts - MGE Energy and MGE

See Footnote 8.d. of Notes to Consolidated Financial Statements for a description of commitments at March 31, 2014, 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.

Liquidity and Capital Resources

Cash Flows

The following summarizes cash flows for MGE Energy and MGE during the three months ended March 31, 2014 and 2013:

		MGE Energy				MGE
(In thousands)		2014		2013		2014		2013
Cash provided by/(used for):
Operating activities	$	58,370	$	28,652	$	60,545	$	28,521
Investing activities		(23,175)		(29,816)		(22,970)		(29,526)
Financing activities		(10,519)		701		(14,395)		4,511

34

Cash Provided by Operating Activities

MGE Energy

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

Cash provided by operating activities for the three months ended March 31, 2014, was $58.4 million, an increase of $29.7 million when compared to the same period in the prior year primarily related to no pension contributions being made in 2014.

MGE Energy's net income increased $5.1 million for the three months ended March 31, 2014, when compared to the same period in the prior year.

Working capital accounts (excluding prepaid and accrued taxes) resulted in $5.1 million in cash provided by operating activities for the three months ended March 31, 2014, primarily due to increased accounts payable and decreased gas inventories, partially offset by increased accounts receivable and decreased other current liabilities. Working capital accounts resulted in $7.1 million in cash provided by operating activities for the three months ended March 31, 2013, primarily due to decreased gas inventories and decreased unbilled revenues, partially offset by increased accounts receivable and decreased accounts payable.

A decrease in pension contribution resulted in an additional $29.9 million in cash provided by operating activities for the three months ended March 31, 2014, 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, 2014, was $60.5 million, an increase of $32.0 million when compared to the same period in the prior year primarily related to no pension contributions being made in 2014.

Net income increased $5.1 million for the three months ended March 31, 2014, when compared to the same period in the prior year.

Working capital accounts (excluding prepaid and accrued taxes) resulted in $7.8 million in cash provided by operating activities for the three months ended March 31, 2014, primarily due to increased accounts payable and decreased gas inventories, partially offset by increased accounts receivable. Working capital accounts resulted in $7.5 million in cash provided by operating activities for the three months ended March 31, 2013, primarily due to decreased gas inventories and decreased unbilled revenues, partially offset by increased accounts receivable and decreased accounts payable.

A decrease in pension contribution resulted in an additional $29.9 million in cash provided by operating activities for the three months ended March 31, 2014, 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 decreased $6.6 million for the three months ended March 31, 2014, when compared to the same period in the prior year.

Capital expenditures for the three months ended March 31, 2014, were $21.8 million. This amount represents a decrease of $7.4 million from the expenditures made in the same period in the prior year. This decrease is due primarily to $12.1 million of decreased expenditures on the Columbia environmental project.

MGE

MGE's cash used for investing activities decreased $6.6 million for the three months ended March 31, 2014, when compared to the same period in the prior year.

35

Capital expenditures for the three months ended March 31, 2014, were $21.8 million. This amount represents a decrease of $7.4 million from the expenditures made in the same period in the prior year. This decrease is due primarily to $12.1 million of decreased expenditures on the Columbia environmental project.

Cash Provided by (Used for) Financing Activities

MGE Energy

Cash used by MGE Energy's financing activities was $10.5 million for the three months ended March 31, 2014, compared to $0.7 million of cash provided for the three months ended March 31, 2013.

For the three months ended March 31, 2014, dividends paid were $9.4 million compared to $9.1 million in the prior year. This increase was a result of a higher dividend per share ($0.272 vs. $0.263).

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, 2014, cash used by MGE's financing activities was $14.4 million compared to $4.5 million of cash provided for MGE's financing activities in the prior year.

Dividends paid from MGE to MGE Energy were $7.0 million during the three months ended March 31, 2014.

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

Distributions to parent from noncontrolling interest, which represent distributions from MGE Power Elm Road and MGE Power West Campus, were $6.9 million for the three months ended March 31, 2014, compared to $5.5 million in the prior year.

Capitalization Ratios

MGE Energy's capitalization ratios were as follows:

	MGE Energy
	March 31, 2014	December 31, 2013
Common shareholders' equity	61.2%	60.5%
Long-term debt*	38.8%	39.5%
*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, 2014, capital expenditures for MGE Energy and MGE totaled $21.8 million, which included $21.3 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 $135 million. MGE's share of the capital expenditures associated with the Columbia environmental project will be approximately $10.7 million for the remainder of 2014. For the three months ended March 31, 2014, MGE had incurred $4.9 million (excluding carrying costs) in construction expenditures at Columbia related to the project and had accrued $6.6 million in incurred, but unpaid capital expenditures. MGE has recognized $1.9 million (after tax) in AFUDC equity related to this project for the three months ended March 31, 2014.

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.

36

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

Environmental Matters

The following discussion is limited to updates or developments in environmental matters that occurred during the three months ended March 31, 2014. Further discussion of environmental matters is included in MGE Energy's and MGE's 2013 Annual Report on Form 10-K and Footnote 8.a. of Notes to Consolidated Financial Statements in this Report.

EPA's Cross-State Air Pollution Rule (CSAPR) Upheld by the Supreme Court

On April 29, 2014, the U.S. Supreme Court issued a decision upholding CSAPR, thereby reversing the D.C. Circuit Court's decision on CSAPR, and remanding the matter back to the D.C. Circuit for further proceedings. The EPA may amend CSAPR to modify compliance deadlines that have passed since the rule was vacated by the D.C. Circuit. It is unclear if the rule will be reinstated for 2014 emissions or later. The Clean Air Interstate Rule (CAIR) will remain in effect until CSAPR is reinstated. See MGE Energy's and MGE's 2013 Annual Report on Form 10K for additional information on the legal proceedings associated with these environmental matters.

Past evaluations of CSAPR's effect on MGE have pointed to SO₂ emissions at our Columbia plant as being our primary concern in meeting emissions allocations under CSAPR. Planned new SO₂ controls at Columbia are underway; Unit 2 was completed in April 2014 and Unit 1 is expected to be completed by third quarter of 2014 (see Footnote 4 for information regarding the Columbia environmental construction project). MGE expects that the costs pertaining to meeting CSAPR requirements will be fully recoverable through rates. We will continue to monitor and evaluate recoverability through the D.C. Circuit Court process and the EPA implementation phase.

New Accounting Principles

See Footnote 12 of Notes to Consolidated Financial Statements for discussion of new accounting pronouncements.

37

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 costs fall outside the lower end of the range and would defer costs, less any excess revenues, if the actual electric fuel 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 2014, fuel and purchased power costs included in MGE's base fuel rates are $106.1 million. See Footnote 10.b. of the Notes to Consolidated Financial Statements 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, 2014, the fair value of these instruments exceeded their cost basis by $2.1 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 an option to extend the contract after the base term. The agreement is considered 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, 2014, reflects a loss position of $60.3 million.

Interest Rate Risk

Both MGE Energy and MGE may have short term borrowings at varying interest rates. MGE issues commercial paper for its short-term borrowings, while MGE Energy draws from its current credit facility to meet its short-term borrowing needs. Borrowing levels vary from period to period depending upon capital investments and other factors. Future short-

38

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, 2014, 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 1,649 square miles in Wisconsin. Based on results for the year ended December 31, 2013, 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.

39

Item 4. Controls and Procedures.

During the first quarter of 2014, 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, 2014, 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, 2014, 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.

40

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. of Notes to Consolidated Financial Statements 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) or Shares That May Yet Be Purchased Under the Plans or Programs*
January 1-31, 2014	70,988	$	37.99	-	-
February 1-28, 2014	53,500		38.14	-	-
March 1-31, 2014	86,300		39.58	-	-
Total	210,788	$	38.68	-	-

*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, 2014, 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

41

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, 2014, 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

42

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 8, 2014	/s/ Gary J. Wolter
	Gary J. Wolter Chairman, President and Chief Executive Officer (Duly Authorized Officer)
Date: May 8, 2014	/s/ Jeffrey C. Newman
	Jeffrey C. Newman Vice President, Chief Financial Officer, Secretary and Treasurer (Chief Financial and Accounting Officer)

43

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 8, 2014	/s/ Gary J. Wolter
	Gary J. Wolter Chairman, President and Chief Executive Officer (Duly Authorized Officer)
Date: May 8, 2014	/s/ Jeffrey C. Newman
	Jeffrey C. Newman Vice President, Chief Financial Officer, Secretary and Treasurer (Chief Financial and Accounting Officer)

44

EX-12

EXHIBIT 12

Madison Gas and Electric Company

Ratio of Earnings to Fixed Charges

Three Months Ended March 31, 2014

(In thousands)

Earnings
Net income before minority interest	$27,643
Equity earnings	(2,481)
Income distribution from equity investees	1,917
Minority interest in pretax income	(1,103)
Amortization of capitalized interest	132
Federal and state income taxes	16,188
Fixed charges	5,446
Total Earnings as Defined	$47,742
Fixed Charges
Interest expense on long-term debt and other	$4,405
Interest on rentals*	222
Amortization of debt issuance costs	176
AFUDC - borrowed funds	643
Total Fixed Charges	$5,446
Ratio of Earnings to Fixed Charges	8.77X

*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 8, 2014

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 8, 2014

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 8, 2014

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 8, 2014

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, 2014, 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 8, 2014

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, 2014, 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 8, 2014

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, 2014, 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 8, 2014

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, 2014, 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 8, 2014

XML

Pension and Other Postretirement Plans (Details) (USD $) In Thousands, unless otherwise specified	3 Months Ended
	Mar. 31, 2014	Mar. 31, 2013
Pension Benefits [Member]
Components of net periodic (benefit) cost:
Service cost	$ 1,484	$ 1,929
Interest cost	3,251	3,186
Expected return on assets	(5,279)	(4,776)
Amortization of:
Prior service (benefit) cost	49	79
Actuarial loss	173	2,015
Net periodic (benefit) cost	(322)	2,433
Postretirement Benefits [Member]
Components of net periodic (benefit) cost:
Service cost	330	596
Interest cost	772	970
Expected return on assets	(654)	(544)
Amortization of:
Transition obligation	1	1
Prior service (benefit) cost	(668)	28
Actuarial loss	39	311
Net periodic (benefit) cost	$ (180)	$ 1,362

XML

Segment Information (Details) (USD $) In Thousands, unless otherwise specified	3 Months Ended				12 Months Ended
	Mar. 31, 2014		Mar. 31, 2013		Dec. 31, 2013
Segment Reporting Information [Line Items]
Operating revenues	$ 210,245		$ 167,237
Depreciation and amortization	(9,746)		(9,624)
Other operating expenses	(156,528)		(119,985)
Operating Income	43,971		37,628
Other income (deductions), net	4,552		3,309
Interest (expense) income, net	(4,541)		(4,675)
Income before income taxes	43,982		36,262
Income tax (provision) benefit	(16,265)		(13,678)
Net Income (Loss)	27,717		22,584
Segment Reporting Assets And Capital Expenditures [Abstract]
Assets	1,610,423				1,579,060
Capital expenditures	21,800		29,164		119,047
Electric [Member]
Segment Reporting Information [Line Items]
Operating revenues	98,852		93,494
Gas [Member]
Segment Reporting Information [Line Items]
Operating revenues	110,713		72,467
Non Regulated Energy [Member]
Segment Reporting Information [Line Items]
Operating revenues	680		1,276
Transmission Investment [Member]
Segment Reporting Information [Line Items]
Operating revenues	0		0
All Others [Member]
Segment Reporting Information [Line Items]
Operating revenues	0		0
Operating Segments [Member] | Electric [Member]
Segment Reporting Information [Line Items]
Operating revenues	98,970		93,603
Depreciation and amortization	(6,337)		(6,400)
Other operating expenses	(77,901)		(74,925)
Operating Income	14,732		12,278
Other income (deductions), net	1,827		575
Interest (expense) income, net	(2,205)		(2,404)
Income before income taxes	14,354		10,449
Income tax (provision) benefit	(4,353)		(3,433)
Net Income (Loss)	10,001		7,016
Segment Reporting Assets And Capital Expenditures [Abstract]
Assets	905,319				899,257
Capital expenditures	18,906				100,146
Operating Segments [Member] | Gas [Member]
Segment Reporting Information [Line Items]
Operating revenues	114,337		77,343
Depreciation and amortization	(1,563)		(1,425)
Other operating expenses	(92,843)		(60,437)
Operating Income	19,931		15,481
Other income (deductions), net	(35)		162
Interest (expense) income, net	(804)		(678)
Income before income taxes	19,092		14,965
Income tax (provision) benefit	(7,665)		(5,989)
Net Income (Loss)	11,427		8,976
Segment Reporting Assets And Capital Expenditures [Abstract]
Assets	268,294				265,694
Capital expenditures	2,384				15,554
Operating Segments [Member] | Non Regulated Energy [Member]
Segment Reporting Information [Line Items]
Operating revenues	11,350		11,849
Depreciation and amortization	(1,834)		(1,799)
Other operating expenses	(40)		(37)
Operating Income	9,476		10,013
Other income (deductions), net	0		0
Interest (expense) income, net	(1,572)		(1,613)
Income before income taxes	7,904		8,400
Income tax (provision) benefit	(3,172)		(3,257)
Net Income (Loss)	4,732		5,143
Segment Reporting Assets And Capital Expenditures [Abstract]
Assets	312,223				288,116
Capital expenditures	510				3,347
Operating Segments [Member] | Transmission Investment [Member]
Segment Reporting Information [Line Items]
Operating revenues	0		0
Depreciation and amortization	0		0
Other operating expenses	0		0
Operating Income	0		0
Other income (deductions), net	2,481		2,396
Interest (expense) income, net	0		0
Income before income taxes	2,481		2,396
Income tax (provision) benefit	(998)		(971)
Net Income (Loss)	1,483		1,425
Segment Reporting Assets And Capital Expenditures [Abstract]
Assets	65,600				64,504
Capital expenditures	0				0
Operating Segments [Member] | All Others [Member]
Segment Reporting Information [Line Items]
Operating revenues	0		0
Depreciation and amortization	(12)		0
Other operating expenses	(156)		(144)
Operating Income	(168)		(144)
Other income (deductions), net	279		176
Interest (expense) income, net	40		20
Income before income taxes	151		52
Income tax (provision) benefit	(77)		(28)
Net Income (Loss)	74		24
Segment Reporting Assets And Capital Expenditures [Abstract]
Assets	432,919				431,436
Capital expenditures	0				0
Operating Segments [Member] | Assets Not Allocated [Member]
Segment Reporting Assets And Capital Expenditures [Abstract]
Assets	40,011				19,853
Capital expenditures	0				0
Consolidation Elimination Entries [Member]
Segment Reporting Information [Line Items]
Operating revenues	(14,412)		(15,558)
Depreciation and amortization	0		0
Other operating expenses	14,412		15,558
Operating Income	0		0
Other income (deductions), net	0		0
Interest (expense) income, net	0		0
Income before income taxes	0		0
Income tax (provision) benefit	0		0
Net Income (Loss)	0		0
Segment Reporting Assets And Capital Expenditures [Abstract]
Assets	(413,943)				(389,800)
Capital expenditures	0				0
Consolidation Elimination Entries [Member] | Electric [Member]
Segment Reporting Information [Line Items]
Operating revenues	118		109
Consolidation Elimination Entries [Member] | Gas [Member]
Segment Reporting Information [Line Items]
Operating revenues	3,624		4,876
Consolidation Elimination Entries [Member] | Non Regulated Energy [Member]
Segment Reporting Information [Line Items]
Operating revenues	10,670		10,573
Consolidation Elimination Entries [Member] | Transmission Investment [Member]
Segment Reporting Information [Line Items]
Operating revenues	0		0
Consolidation Elimination Entries [Member] | All Others [Member]
Segment Reporting Information [Line Items]
Operating revenues	0		0
MGE [Member]
Segment Reporting Information [Line Items]
Operating revenues	210,256		167,237
Depreciation and amortization	(9,734)		(9,624)
Other operating expenses	(171,307)	[1]	(132,710)	[1]
Operating Income	29,215	[1]	24,903	[1]
Other income (deductions), net	3,009	[1]	2,352	[1]
Interest (expense) income, net	(4,581)		(4,695)
Income tax (provision) benefit	(14,924)		(12,870)
Net Income Including Noncontrolling Interest	27,643		22,560
Less Net Income Attributable to Noncontrolling Interest, net of tax	(6,510)		(6,826)
Net Income (Loss)	21,133		15,734
Segment Reporting Assets And Capital Expenditures [Abstract]
Assets	1,555,393				1,530,643
Capital expenditures	21,800		29,164		119,047
MGE [Member] | Electric [Member]
Segment Reporting Information [Line Items]
Operating revenues	98,858		93,494
MGE [Member] | Gas [Member]
Segment Reporting Information [Line Items]
Operating revenues	110,718		72,467
MGE [Member] | Non Regulated Energy [Member]
Segment Reporting Information [Line Items]
Operating revenues	680		1,276
MGE [Member] | Transmission Investment [Member]
Segment Reporting Information [Line Items]
Operating revenues	0		0
MGE [Member] | Operating Segments [Member] | Electric [Member]
Segment Reporting Information [Line Items]
Operating revenues	98,970		93,603
Depreciation and amortization	(6,337)		(6,400)
Other operating expenses	(82,046)	[1]	(78,506)	[1]
Operating Income	10,587	[1]	8,697	[1]
Other income (deductions), net	1,619	[1]	723	[1]
Interest (expense) income, net	(2,205)		(2,404)
Net Income Including Noncontrolling Interest	10,001		7,016
Less Net Income Attributable to Noncontrolling Interest, net of tax	0		0
Net Income (Loss)	10,001		7,016
Segment Reporting Assets And Capital Expenditures [Abstract]
Assets	907,952				899,257
Capital expenditures	18,906				100,146
MGE [Member] | Operating Segments [Member] | Gas [Member]
Segment Reporting Information [Line Items]
Operating revenues	114,337		77,343
Depreciation and amortization	(1,563)		(1,425)
Other operating expenses	(100,450)	[1]	(66,468)	[1]
Operating Income	12,324	[1]	9,450	[1]
Other income (deductions), net	(93)	[1]	204	[1]
Interest (expense) income, net	(804)		(678)
Net Income Including Noncontrolling Interest	11,427		8,976
Less Net Income Attributable to Noncontrolling Interest, net of tax	0		0
Net Income (Loss)	11,427		8,976
Segment Reporting Assets And Capital Expenditures [Abstract]
Assets	266,383				265,694
Capital expenditures	2,384				15,554
MGE [Member] | Operating Segments [Member] | Non Regulated Energy [Member]
Segment Reporting Information [Line Items]
Operating revenues	11,350		11,849
Depreciation and amortization	(1,834)		(1,799)
Other operating expenses	(3,212)	[1]	(3,294)	[1]
Operating Income	6,304	[1]	6,756	[1]
Other income (deductions), net	0	[1]	0	[1]
Interest (expense) income, net	(1,572)		(1,613)
Net Income Including Noncontrolling Interest	4,732		5,143
Less Net Income Attributable to Noncontrolling Interest, net of tax	0		0
Net Income (Loss)	4,732		5,143
Segment Reporting Assets And Capital Expenditures [Abstract]
Assets	288,268				288,066
Capital expenditures	510				3,347
MGE [Member] | Operating Segments [Member] | Transmission Investment [Member]
Segment Reporting Information [Line Items]
Operating revenues	0		0
Depreciation and amortization	0		0
Other operating expenses	0	[1]	0	[1]
Operating Income	0	[1]	0	[1]
Other income (deductions), net	1,483	[1]	1,425	[1]
Interest (expense) income, net	0		0
Net Income Including Noncontrolling Interest	1,483		1,425
Less Net Income Attributable to Noncontrolling Interest, net of tax	0		0
Net Income (Loss)	1,483		1,425
Segment Reporting Assets And Capital Expenditures [Abstract]
Assets	65,600				64,504
Capital expenditures	0				0
MGE [Member] | Operating Segments [Member] | Assets Not Allocated [Member]
Segment Reporting Assets And Capital Expenditures [Abstract]
Assets	39,883				19,853
Capital expenditures	0				0
MGE [Member] | Consolidation Elimination Entries [Member]
Segment Reporting Information [Line Items]
Operating revenues	(14,401)		(15,558)
Depreciation and amortization	0		0
Other operating expenses	14,401	[1]	15,558	[1]
Operating Income	0	[1]	0	[1]
Other income (deductions), net	0	[1]	0	[1]
Interest (expense) income, net	0		0
Net Income Including Noncontrolling Interest	0		0
Less Net Income Attributable to Noncontrolling Interest, net of tax	(6,510)		(6,826)
Net Income (Loss)	(6,510)		(6,826)
Segment Reporting Assets And Capital Expenditures [Abstract]
Assets	(12,693)				(6,731)
Capital expenditures	0				0
MGE [Member] | Consolidation Elimination Entries [Member] | Electric [Member]
Segment Reporting Information [Line Items]
Operating revenues	112		109
MGE [Member] | Consolidation Elimination Entries [Member] | Gas [Member]
Segment Reporting Information [Line Items]
Operating revenues	3,619		4,876
MGE [Member] | Consolidation Elimination Entries [Member] | Non Regulated Energy [Member]
Segment Reporting Information [Line Items]
Operating revenues	10,670		10,573
MGE [Member] | Consolidation Elimination Entries [Member] | Transmission Investment [Member]
Segment Reporting Information [Line Items]
Operating revenues	$ 0		$ 0

[1] *Amounts are shown net of the related tax expense, consistent with the presentation on the consolidated MGE Income Statement.

XML

Derivative and Hedging Instruments (Details-5) (USD $)			3 Months Ended									3 Months Ended
	Mar. 31, 2014 counterparty	Dec. 31, 2013 counterparty	Mar. 31, 2014 Commodity Derivative Contracts [Member] Fuel For Electric Generation Purchased Power [Member]	Mar. 31, 2013 Commodity Derivative Contracts [Member] Fuel For Electric Generation Purchased Power [Member]	Mar. 31, 2014 Commodity Derivative Contracts [Member] Cost Of Gas Sold Expense [Member]	Mar. 31, 2013 Commodity Derivative Contracts [Member] Cost Of Gas Sold Expense [Member]	Mar. 31, 2014 Financial Transmission Rights [Member] Fuel For Electric Generation Purchased Power [Member]	Mar. 31, 2013 Financial Transmission Rights [Member] Fuel For Electric Generation Purchased Power [Member]	Mar. 31, 2014 Financial Transmission Rights [Member] Cost Of Gas Sold Expense [Member]	Mar. 31, 2013 Financial Transmission Rights [Member] Cost Of Gas Sold Expense [Member]	Mar. 31, 2014 Purchased Power Agreement [Member]	Mar. 31, 2014 Purchased Power Agreement [Member] Fuel For Electric Generation Purchased Power [Member]	Mar. 31, 2013 Purchased Power Agreement [Member] Fuel For Electric Generation Purchased Power [Member]	Mar. 31, 2014 Purchased Power Agreement [Member] Cost Of Gas Sold Expense [Member]	Mar. 31, 2013 Purchased Power Agreement [Member] Cost Of Gas Sold Expense [Member]
Realized losses (gains) on income statement [Line Items]
Realized losses (gains) on income statement			$ (4,795,000)	$ 22,000	$ (1,220,000)	$ 608,000	$ (636,000)	$ (158,000)	$ 0	$ 0		$ (1,210,000)	$ 1,278,000	$ 0	$ 0
Derivative collateral required to be posted for ten-year PPA [Abstract]
Minimum collateral that may be required to be posted											20,000,000
Maximum collateral that may be required to be posted											40,000,000
Collateral posted											$ 0
Counterparties in net liability position or default [Abstract]
Counterparties in net liability position	0	0
Number of counterparties in default	0

XML

Derivative and Hedging Instruments (Details-3) (USD $) In Thousands, unless otherwise specified	Mar. 31, 2014	Dec. 31, 2013
Commodity Derivative Contracts [Member]
Offsetting Liabilities [Line Items]
Gross amounts	$ 152	$ 99
Gross amounts offset in balance sheet	(152)	(99)
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	60,290	65,680
Gross amounts offset in balance sheet	0	0
Collateral posted against derivative positions	0	0
Net amount presented in balance sheet	$ 60,290	$ 65,680

XML

Segment Information (Tables)

3 Months Ended

Mar. 31, 2014

Segment Reporting [Abstract]

Segment Information

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, 2014
Operating revenues	$	98,852	$	110,713	$	680	$	-	$	-	$	-	$	210,245
Interdepartmental revenues		118		3,624		10,670		-		-		(14,412)		-
Total operating revenues		98,970		114,337		11,350		-		-		(14,412)		210,245
Depreciation and amortization		(6,337)		(1,563)		(1,834)		-		(12)		-		(9,746)
Other operating expenses		(77,901)		(92,843)		(40)		-		(156)		14,412		(156,528)
Operating income (loss)		14,732		19,931		9,476		-		(168)		-		43,971
Other (deductions) income, net		1,827		(35)		-		2,481		279		-		4,552
Interest (expense) income, net		(2,205)		(804)		(1,572)		-		40		-		(4,541)
Income before taxes		14,354		19,092		7,904		2,481		151		-		43,982
Income tax provision		(4,353)		(7,665)		(3,172)		(998)		(77)		-		(16,265)
Net income	$	10,001	$	11,427	$	4,732	$	1,483	$	74	$	-	$	27,717
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

(In thousands) MGE		Electric		Gas		Non- Regulated Energy		Transmission Investment		Consolidation/ Elimination Entries		Consolidated Total
Three Months Ended March 31, 2014
Operating revenues	$	98,858	$	110,718	$	680	$	-	$	-	$	210,256
Interdepartmental revenues		112		3,619		10,670		-		(14,401)		-
Total operating revenues		98,970		114,337		11,350		-		(14,401)		210,256
Depreciation and amortization		(6,337)		(1,563)		(1,834)		-		-		(9,734)
Other operating expenses*		(82,046)		(100,450)		(3,212)		-		14,401		(171,307)
Operating income*		10,587		12,324		6,304		-		-		29,215
Other (deductions) income, net*		1,619		(93)		-		1,483		-		3,009
Interest expense, net		(2,205)		(804)		(1,572)		-		-		(4,581)
Net income		10,001		11,427		4,732		1,483		-		27,643
Less: Net income attributable to
noncontrolling interest, net of tax		-		-		-		-		(6,510)		(6,510)
Net income attributable to MGE	$	10,001	$	11,427	$	4,732	$	1,483	$	(6,510)	$	21,133
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
*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, 2014	$	905,319	$	268,294	$	40,011	$	312,223	$	65,600	$	432,919	$	(413,943)	$	1,610,423
December 31, 2013		899,257		265,694		19,853		288,116		64,504		431,436		(389,800)		1,579,060
Capital Expenditures:
Three Months Ended March 31, 2014	$	18,906	$	2,384	$	-	$	510	$	-	$	-	$	-	$	21,800
Year ended Dec. 31, 2013		100,146		15,554		-		3,347		-		-		-		119,047

		Utility						Consolidated
(In thousands) MGE		Electric		Gas		Assets not Allocated		Nonregulated Energy		Transmission Investment		Elimination Entries		Total
Assets:
March 31, 2014	$	907,952	$	266,383	$	39,883	$	288,268	$	65,600	$	(12,693)	$	1,555,393
December 31, 2013		899,257		265,694		19,853		288,066		64,504		(6,731)		1,530,643
Capital Expenditures:
Three Months Ended March 31, 2014	$	18,906	$	2,384	$	-	$	510	$	-	$	-	$	21,800
Year ended Dec. 31, 2013		100,146		15,554		-		3,347		-		-		119,047

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New Accounting Pronouncements

3 Months Ended

Mar. 31, 2014

New Accounting Pronouncements and Changes in Accounting Principles [Abstract]

New Accounting Pronouncements

New Accounting Pronouncements - MGE Energy and MGE.

a.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 became effective January 1, 2014. The authoritative guidance did not have a financial or disclosure impact.

b. Presentation of an Unrecognized Tax Benefit.

In July 2013, the FASB issued authoritative guidance within the Codification's Income Statement topic that provides guidance on the presentation of an unrecognized tax benefit when a net operating loss carryforward, a similar tax loss, or a tax credit carryforward exist. The authoritative guidance was issued to eliminate diversity in practice by providing guidance on the presentation of unrecognized tax benefits. This authoritative guidance became effective January 1, 2014. The authoritative guidance will not have a financial statement or disclosure impact, unlessMGE Energy or its subsidiaries are in a net operating loss position. MGE Energy or its subsidiaries are currently not in a net operating loss position.

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Fair Value of Financial Instruments (Details-1) (USD $) In Thousands, unless otherwise specified	Mar. 31, 2014		Dec. 31, 2013
Carrying Amount [Member]
Assets:
Cash and cash equivalents	$ 93,489		$ 68,813
Liabilities:
Long-term debt	402,774	[1]	403,793	[1]
Fair Value [Member]
Assets:
Cash and cash equivalents	93,489		68,813
Liabilities:
Long-term debt	436,788	[1]	432,010	[1]
MGE [Member] | Carrying Amount [Member]
Assets:
Cash and cash equivalents	37,988		14,808
Liabilities:
Long-term debt	402,774	[1]	403,793	[1]
MGE [Member] | Fair Value [Member]
Assets:
Cash and cash equivalents	37,988		14,808
Liabilities:
Long-term debt	$ 436,788	[1]	$ 432,010	[1]

[1] *Includes long-term debt due within one year.

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Commitments and Contingencies (Details-2) (Chattel Paper Agreement [Member], USD $)	3 Months Ended
	Mar. 31, 2014
Guarantor Obligations [Line Items]
Guarantor obligation, maximum financing receivable	$ 10,000,000
Guarantor obligation, current carrying value	5,100,000
Servicing asset recognized	300,000
Guarantor Obligation, Fiscal Year Maturity [Abstract]
Guarantor obligation, 2014	477,000
Guarantor obligation, 2015	1,007,000
Guarantor obligation, 2016	910,000
Guarantor obligation, 2017	506,000
Guarantor obligation, 2018	$ 449,000
Minimum [Member]
Guarantor Obligations [Line Items]
Guarantee to financial institution, term	1 year
Maximum [Member]
Guarantor Obligations [Line Items]
Guarantee to financial institution, term	10 years

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Columbia Environmental Project Construction (Details) (USD $)			3 Months Ended			3 Months Ended			12 Months Ended
	Mar. 31, 2014	Dec. 31, 2013	Mar. 31, 2014 MGE [Member]	Mar. 31, 2013 MGE [Member]	Dec. 31, 2013 MGE [Member]	Mar. 31, 2014 MGE [Member] Columbia Environmental Project [Member]	Mar. 31, 2013 MGE [Member] Columbia Environmental Project [Member]	Mar. 31, 2014 MGE [Member] Columbia Environmental Project [Member] PSCW [Member]	Dec. 31, 2013 MGE [Member] Columbia Environmental Project [Member] PSCW [Member]	Mar. 31, 2014 Columbia Units [Member] WPL [Member]	Mar. 31, 2014 Columbia Units [Member] WPSC [Member]	Mar. 31, 2014 Columbia Units [Member] MGE [Member]
Jointly Owned Utility Plant Interests [Line Items]
Jointly owned utility plant, ownership interest										46.20%	31.80%	22.00%
Jointly owned utility plant, total expected capital expenditures						$ 135,000,000
Total incurred costs to date	147,449,000	141,415,000	147,449,000		141,415,000	124,300,000
Jointly owned utility plant, total expected capital expenditures, remainder of current year						10,700,000
Contractual commitments						10,700,000
AFUDC - equity funds			$ 1,950,000	$ 596,000		$ 1,900,000	$ 500,000
Authorized AFUDC Rate								100.00%	50.00%
Authorized MGE rate of return									50.00%

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Fair Value of Financial Instruments (Details-3)	3 Months Ended
	Mar. 31, 2014
Fair Value Inputs Assets Quantitative Information [Line Items]
Basis adjustment - on peak	95.50%
Basis adjustment - off peak	93.10%
US Treasury Bill Securities [Member]
Deferred compensation plan [Abstract]
Investment interest calculation, investment maturity period (26 weeks)	182 days
Investment interest calculation, monthly compounding rate	1.00%
Investment interest calculation, minimum annual rate compounded monthly	7.00%
Minimum [Member]
Counterparty fuel mix [Abstract]
Internal generation	50.00%
Purchased power	50.00%
Maximum [Member]
Counterparty fuel mix [Abstract]
Internal generation	70.00%
Purchased power	30.00%

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Derivative and Hedging Instruments (Details-4) (USD $) In Thousands, unless otherwise specified	3 Months Ended
	Mar. 31, 2014	Mar. 31, 2013
Regulatory Asset [Member]
Change In Derivative Fair Value [Roll Forward]
Beginning balance,	$ 63,893	$ 72,329
Change in unrealized gain	(13,601)	(1,697)
Realized loss reclassified to a deferred account	1,535	(290)
Realized gain (loss) on income statement	6,386	(1,145)
Ending balance,	58,213	69,197
Other Current Assets [Member]
Change In Derivative Fair Value [Roll Forward]
Beginning balance,	411	574
Change in unrealized gain	0	0
Realized loss reclassified to a deferred account	(1,535)	290
Realized gain (loss) on income statement	1,475	(605)
Ending balance,	$ 351	$ 259

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Consolidated Balance Sheets (Unaudited) (USD $) In Thousands, unless otherwise specified	Mar. 31, 2014	Dec. 31, 2013
Current Assets:
Cash and cash equivalents	$ 93,489	$ 68,813
Accounts receivable, less reserves	62,760	44,890
Other accounts receivables, less reserves	5,019	5,352
Unbilled revenues	29,568	31,982
Materials and supplies, at average cost	17,023	16,662
Fossil fuel	4,675	5,206
Stored natural gas, at average cost	642	13,988
Prepaid taxes	11,773	19,106
Regulatory assets - current	4,690	6,377
Other current assets	9,301	8,225
Total Current Assets	238,940	220,601
Regulatory assets	105,253	107,166
Pension benefits	16,013	15,071
Other deferred assets and other	6,758	8,046
Property, Plant, and Equipment:
Property, plant, and equipment, net	1,026,807	1,018,809
Construction work in progress	147,449	141,415
Total Property, Plant, and Equipment	1,174,256	1,160,224
Investments	69,203	67,952
Total Assets	1,610,423	1,579,060
Current Liabilities:
Long-term debt due within one year	4,121	4,102
Accounts payable	56,171	43,684
Accrued taxes	11,275	822
Accrued interest	3,250	4,839
Accrued payroll related items	8,103	10,731
Deferred income taxes	0	1,711
Regulatory liabilities - current	11,537	13,538
Derivative liabilities	6,540	7,750
Other current liabilities	8,518	9,489
Total Current Liabilities	109,515	96,666
Other Credits:
Deferred income taxes	287,224	284,791
Investment tax credit - deferred	1,362	1,413
Regulatory liabilities	20,788	19,792
Accrued pension and other postretirement benefits	49,512	49,184
Derivative liabilities	53,750	57,930
Other deferred liabilities and other	54,155	52,360
Total Other Credits	466,791	465,470
Capitalization:
Common shareholders equity	635,734	617,510
Long-term debt	398,383	399,414
Total Capitalization	1,034,117	1,016,924
Commitments and contingencies (see Footnote 8)
Total Liabilities and Capitalization	1,610,423	1,579,060
MGE [Member]
Current Assets:
Cash and cash equivalents	37,988	14,808
Accounts receivable, less reserves	62,760	44,890
Affiliate receivables	550	534
Other accounts receivables, less reserves	4,937	5,274
Unbilled revenues	29,568	31,982
Materials and supplies, at average cost	17,023	16,662
Fossil fuel	4,675	5,206
Stored natural gas, at average cost	642	13,988
Prepaid taxes	12,044	23,934
Regulatory assets - current	4,690	6,377
Other current assets	8,979	8,197
Total Current Assets	183,856	171,852
Affiliate receivable long-term	5,692	5,825
Regulatory assets	105,253	107,166
Pension benefits	16,013	15,071
Other deferred assets and other	4,818	6,138
Property, Plant, and Equipment:
Property, plant, and equipment, net	1,025,886	1,017,877
Construction work in progress	147,449	141,415
Total Property, Plant, and Equipment	1,173,335	1,159,292
Investments	66,426	65,299
Total Assets	1,555,393	1,530,643
Current Liabilities:
Long-term debt due within one year	4,121	4,102
Accounts payable	56,171	43,684
Accrued interest and taxes	10,019	6,040
Accrued payroll related items	8,103	10,731
Deferred income taxes	707	2,723
Regulatory liabilities - current	11,537	13,538
Derivative liabilities	6,540	7,750
Other current liabilities	8,244	6,446
Total Current Liabilities	105,442	95,014
Other Credits:
Deferred income taxes	281,261	279,085
Investment tax credit - deferred	1,362	1,413
Regulatory liabilities	20,788	19,792
Accrued pension and other postretirement benefits	49,512	49,184
Derivative liabilities	53,750	57,930
Other deferred liabilities and other	54,156	52,357
Total Other Credits	460,829	459,761
Capitalization:
Common shareholders equity	471,642	457,491
Noncontrolling interest	119,097	118,963
Total Equity	590,739	576,454
Long-term debt	398,383	399,414
Total Capitalization	989,122	975,868
Commitments and contingencies (see Footnote 8)
Total Liabilities and Capitalization	$ 1,555,393	$ 1,530,643

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Commitments and Contingencies (Details-3) (Purchase Power [Member], USD $) In Thousands, unless otherwise specified	Mar. 31, 2014
Purchase Power [Member]
Operating expense purchase contracts [Abstract]
Purchase obligation, 2014	$ 50,542	[1]
Purchase obligation, 2015	49,072	[1]
Purchase obligation, 2016	49,743	[1]
Purchase obligation, 2017	50,243	[1]
Purchase obligation, 2018	$ 51,265	[1]

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

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Pension and Other Postretirement Plans (Tables)

3 Months Ended

Mar. 31, 2014

Compensation and Retirement Disclosure [Abstract]

Schedule of Net Periodic Benefit Costs

The following table presents the components of MGE Energy's and MGE's net periodic benefit costs recognized for the three months endedMarch 31,2014 and 2013. A portion of the net periodic benefit cost is capitalized within the consolidated balance sheets.

		Three Months Ended
		March 31,
(In thousands)		2014		2013
Pension Benefits
Components of net periodic (benefit) cost:
Service cost	$	1,484	$	1,929
Interest cost		3,251		3,186
Expected return on assets		(5,279)		(4,776)
Amortization of:
Prior service (benefit) cost		49		79
Actuarial loss		173		2,015
Net periodic (benefit) cost	$	(322)	$	2,433
Postretirement Benefits
Components of net periodic (benefit) cost:
Service cost	$	330	$	596
Interest cost		772		970
Expected return on assets		(654)		(544)
Amortization of:
Transition obligation		1		1
Prior service (benefit) cost		(668)		28
Actuarial loss		39		311
Net periodic (benefit) cost	$	(180)	$	1,362

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Investment in ATC (Tables)

3 Months Ended

Mar. 31, 2014

Equity Method Investments and Joint Ventures [Abstract]

ATC's Summarized Financial Data

For the three months endedMarch 31,2014 and 2013, MGE Transco recorded the following:

		Three Months Ended
		March 31,
(In thousands)		2014		2013
Equity in earnings from investment in ATC	$	2,481	$	2,396
Dividends received from ATC		1,917		1,807
Capital contributions to ATC		533		178

ATC's summarized financial data for the three months ended March 31, 2014 and 2013, is as follows:

		Three Months Ended
		March 31,
(In thousands)		2014		2013
Operating revenues	$	163,337	$	151,737
Operating expenses		(78,623)		(69,770)
Other income (expense), net		388		(448)
Interest expense, net		(21,996)		(21,044)
Earnings before members' income taxes	$	63,106	$	60,475

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Derivative and Hedging Instruments (Details-1) (USD $) In Thousands, unless otherwise specified							3 Months Ended	12 Months Ended									3 Months Ended		12 Months Ended
	Mar. 31, 2014 Other Current Assets [Member]	Dec. 31, 2013 Other Current Assets [Member]	Mar. 31, 2013 Other Current Assets [Member]	Dec. 31, 2012 Other Current Assets [Member]	Mar. 31, 2014 Commodity Contracts And Financial Transimission Rights [Member]	Dec. 31, 2013 Commodity Contracts And Financial Transimission Rights [Member]	Mar. 31, 2014 Commodity Derivative Contracts [Member] MWh Dth	Dec. 31, 2013 Commodity Derivative Contracts [Member] MWh Dth	Mar. 31, 2014 Commodity Derivative Contracts [Member] Other Current Assets [Member]	Dec. 31, 2013 Commodity Derivative Contracts [Member] Other Current Assets [Member]	Mar. 31, 2014 Commodity Derivative Contracts [Member] Other Deferred Charges [Member]	Dec. 31, 2013 Commodity Derivative Contracts [Member] Other Deferred Charges [Member]	Mar. 31, 2014 Commodity Derivative Contracts [Member] Derivative Liability (Current) [Member]	Dec. 31, 2013 Commodity Derivative Contracts [Member] Derivative Liability (Current) [Member]	Mar. 31, 2014 Commodity Derivative Contracts [Member] Derivative Liability (Long-term) [Member]	Dec. 31, 2013 Commodity Derivative Contracts [Member] Derivative Liability (Long-term) [Member]	Mar. 31, 2014 Energy Related Commodity Contract [Member] Cash Flow Hedging [Member]	Mar. 31, 2014 Financial Transmission Rights [Member] MW	Dec. 31, 2013 Financial Transmission Rights [Member] MW	Mar. 31, 2014 Financial Transmission Rights [Member] Other Current Assets [Member]	Dec. 31, 2013 Financial Transmission Rights [Member] Other Current Assets [Member]	Mar. 31, 2014 Financial Transmission Rights [Member] Derivative Liability (Current) [Member]	Dec. 31, 2013 Financial Transmission Rights [Member] Derivative Liability (Current) [Member]	Mar. 31, 2014 Ten-year PPA [Member]	Dec. 31, 2013 Ten-year PPA [Member]	Mar. 31, 2014 Ten-year PPA [Member] Derivative Liability (Current) [Member]	Dec. 31, 2013 Ten-year PPA [Member] Derivative Liability (Current) [Member]	Mar. 31, 2014 Ten-year PPA [Member] Derivative Liability (Long-term) [Member]	Dec. 31, 2013 Ten-year PPA [Member] Derivative Liability (Long-term) [Member]
Derivatives Fair Value [Line Items]
Maximum term of derivative hedging contract																	4 years
Gross Notional Volume of Open Derivatives
Notional amount, energy measure (in MWh)							409,800	458,660
Notional amount, decatherm measure (in Dth)							2,200,000	3,750,000
Notional amount, power measure (in MW)																		790	1,984
Derivative fair values [Abstract]
Derivative fair value, net	$ 351	$ 411	$ 259	$ 574	$ 2,100	$ 1,800																		$ (60,300)	$ (65,700)
Derivative Asset, Fair Value, Gross Asset							2,123	1,523	2,086	1,356	37	167						106	363	106	363
Derivative Liability, Fair Value, Gross Liability							$ 152	$ 99					$ 111	$ 51	$ 41	$ 48						$ 0	$ 0	$ 60,290	$ 65,680	$ 6,540	$ 7,750	$ 53,750	$ 57,930

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Commitments and Contingencies (Tables)

3 Months Ended

Mar. 31, 2014

Commitments and Contingencies Disclosure [Abstract]

Chattel Paper Agreement, Fiscal Year Maturity Schedule

Principal payments for the remainder of 2014 and the next four years on the loans are:

(In thousands)		2014		2015		2016		2017		2018
Chattel Paper	$	477	$	1,007	$	910	$	506	$	449

Purchase Contracts, Fiscal Year Maturity Schedule

As of March 31,2014, the future commitments related to these purchase contracts were as follows:

(In thousands)		2014		2015		2016		2017		2018
Purchase power(a)	$	50,542	$	49,072	$	49,743	$	50,243	$	51,265

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

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Derivative and Hedging Instruments (Tables)

3 Months Ended

Mar. 31, 2014

Derivative Instruments and Hedging Activities Disclosure [Abstract]

Gross Notional Volume of Open Derivatives

The gross notional volume of open derivatives is as follows:

	March 31, 2014	December 31, 2013
Commodity derivative contracts	409,800 MWh	458,660 MWh
Commodity derivative contracts	2,200,000 Dth	3,750,000 Dth
FTRs	790 MW	1,984 MW

Fair Value of Derivative Instruments on the Balance Sheet

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, 2014
Commodity derivative contracts	Other current assets	$	2,086	Derivative liability (current)	$	111
Commodity derivative contracts	Other deferred charges		37	Derivative liability (long-term)		41
FTRs	Other current assets		106	Derivative liability (current)		-
Ten-year PPA	N/A		N/A	Derivative liability (current)		6,540
Ten-year PPA	N/A		N/A	Derivative liability (long-term)		53,750
December 31, 2013
Commodity derivative contracts	Other current assets	$	1,356	Derivative liability (current)	$	51
Commodity derivative contracts	Other deferred charges		167	Derivative liability (long-term)		48
FTRs	Other current assets		363	Derivative liability (current)		-
Ten-year PPA	N/A		N/A	Derivative liability (current)		7,750
Ten-year PPA	N/A		N/A	Derivative liability (long-term)		57,930

Offsetting Assets

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
(In thousands)		Gross amounts		Gross amounts offset in balance sheet		Collateral posted against derivative positions		Net amount presented in balance sheet
March 31, 2014
Commodity derivative contracts	$	2,123	$	(152)	$	-	$	1,971
FTRs		106		-		-		106
December 31, 2013
Commodity derivative contracts	$	1,523	$	(99)	$	(175)	$	1,249
FTRs		363		-		-		363

Offsetting Liabilities

Offsetting of Derivative Liabilities
(In thousands)		Gross amounts		Gross amounts offset in balance sheet		Collateral posted against derivative positions		Net amount presented in balance sheet
March 31, 2014
Commodity derivative contracts	$	152	$	(152)	$	-	$	-
Ten-year PPA		60,290		-		-		60,290
December 31, 2013
Commodity derivative contracts	$	99	$	(99)	$	-	$	-
Ten-year PPA		65,680		-		-		65,680

Derivative Gains and Losses in Balance Sheet

The following tables summarize the unrealized and realized gains (losses) related to the derivative instruments on the consolidated balance sheet at March 31,2014 and 2013, and the consolidated income statement for the three months endedMarch 31,2014 and 2013.

		2014				2013
(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,	$	63,893	$	411	$	72,329	$	574
Change in unrealized gain		(13,601)		-		(1,697)		-
Realized loss reclassified to a deferred account		1,535		(1,535)		(290)		290
Realized gain (loss) reclassified to income
statement		6,386		1,475		(1,145)		(605)
Balance at March 31,	$	58,213	$	351	$	69,197	$	259

Derivative Gains and Losses in Income Statement

		Realized losses (gains)
(In thousands)		Fuel for electric generation/ purchased power		Cost of gas sold
Three Months Ended March 31, 2014:
Commodity derivative contracts	$	(4,795)	$	(1,220)
FTRs		(636)		-
Ten-year PPA		(1,210)		-
Three Months Ended March 31, 2013:
Commodity derivative contracts	$	22	$	608
FTRs		(158)		-
Ten-year PPA		1,278		-

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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, 2014	Mar. 31, 2013
Items not affecting cash:
Depreciation and amortization	$ 9,746	$ 9,624
Deferred income taxes	(877)	11,294
Provision for doubtful receivables	743	743
Employee benefit plan expenses	(332)	3,336
Equity earnings in ATC	(2,481)	(2,396)
Other items	(679)	750
Changes in working capital items:
Decrease in current assets	3,283	17,341
Increase (decrease) in current liabilities	19,604	(4,590)
Dividend income from ATC	1,917	1,807
Cash contributions to pension and other postretirement plans	(818)	(30,764)
Other noncurrent items, net	547	(1,077)
Cash Provided by Operating Activities	58,370	28,652
Investing Activities:
Capital expenditures	(21,800)	(29,164)
Capital contributions to investments	(693)	(373)
Other	(682)	(279)
Cash Used for Investing Activities	(23,175)	(29,816)
Financing Activities:
Repayment of long-term debt	(1,019)	(667)
Increase (decrease) in short-term debt	0	10,500
Other	(80)	0
Cash (Used for) Provided by Financing Activities	(10,519)	701
Change in cash and cash equivalents	24,676	(463)
Cash and cash equivalents at beginning of period	68,813	46,357
Cash and Cash Equivalents at End of Period	93,489	45,894
Significant noncash investing activities:
Accrued capital expenditures	8,967	12,699
MGE [Member]
Operating Activities:
Net Income	27,643	22,560
Items not affecting cash:
Depreciation and amortization	9,734	9,624
Deferred income taxes	(1,141)	11,016
Provision for doubtful receivables	743	743
Employee benefit plan expenses	(332)	3,336
Equity earnings in ATC	(2,481)	(2,396)
Other items	(546)	882
Changes in working capital items:
Decrease in current assets	7,817	17,135
Increase (decrease) in current liabilities	17,488	(4,326)
Dividend income from ATC	1,917	1,807
Cash contributions to pension and other postretirement plans	(818)	(30,764)
Other noncurrent items, net	521	(1,096)
Cash Provided by Operating Activities	60,545	28,521
Investing Activities:
Capital expenditures	(21,800)	(29,164)
Capital contributions to investments	(533)	(178)
Other	(637)	(184)
Cash Used for Investing Activities	(22,970)	(29,526)
Financing Activities:
Cash dividends paid to parent by MGE	(7,000)	0
Distributions to parent from noncontrolling interest	(6,909)	(5,500)
Equity contribution received by noncontrolling interest	533	178
Repayment of long-term debt	(1,019)	(667)
Increase (decrease) in short-term debt	0	10,500
Cash (Used for) Provided by Financing Activities	(14,395)	4,511
Change in cash and cash equivalents	23,180	3,506
Cash and cash equivalents at beginning of period	14,808	6,350
Cash and Cash Equivalents at End of Period	37,988	9,856
Significant noncash investing activities:
Accrued capital expenditures	$ 8,967	$ 12,699

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Fair Value of Financial Instruments (Tables)

3 Months Ended

Mar. 31, 2014

Fair Value Disclosures [Abstract]

Estimated Fair Market Value of Financial Instruments

The estimated fair market value of MGE Energy's and MGE's financial instruments are as follows:

		March 31, 2014				December 31, 2013
(In thousands)		Carrying Amount		Fair Value		Carrying Amount		Fair Value
MGE Energy
Assets:
Cash and cash equivalents	$	93,489	$	93,489	$	68,813	$	68,813
Liabilities:
Long-term debt*		402,774		436,788		403,793		432,010
MGE
Assets:
Cash and cash equivalents	$	37,988	$	37,988	$	14,808	$	14,808
Liabilities:
Long-term debt*		402,774		436,788		403,793		432,010
*Includes long-term debt due within one year.

Assets and Liabilities Measured at Fair Value on a Recurring Basis

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, 2014
(In thousands)		Total		Level 1		Level 2		Level 3
MGE Energy
Assets:
Exchange-traded investments	$	804	$	804	$	-	$	-
Total Assets	$	804	$	804	$	-	$	-
Liabilities:
Derivatives, net	$	58,213	$	(584)	$	-	$	58,797
Deferred compensation		2,472		-		2,472		-
Total Liabilities	$	60,685	$	(584)	$	2,472	$	58,797
MGE
Assets:
Exchange-traded investments	$	461	$	461	$	-	$	-
Total Assets	$	461	$	461	$	-	$	-
Liabilities:
Derivatives, net	$	58,213	$	(584)	$	-	$	58,797
Deferred compensation		2,472		-		2,472		-
Total Liabilities	$	60,685	$	(584)	$	2,472	$	58,797

		Fair Value as of December 31, 2013
(In thousands)		Total		Level 1		Level 2		Level 3
MGE Energy
Assets:
Exchange-traded investments	$	792	$	792	$	-	$	-
Total Assets	$	792	$	792	$	-	$	-
Liabilities:
Derivatives, net(a)	$	63,893	$	(735)	$	-	$	64,628
Deferred compensation		2,364		-		2,364		-
Total Liabilities	$	66,257	$	(735)	$	2,364	$	64,628
MGE
Assets:
Exchange-traded investments	$	431	$	431	$	-	$	-
Total Assets	$	431	$	431	$	-	$	-
Liabilities:
Derivatives, net(a)	$	63,893	$	(735)	$	-	$	64,628
Deferred compensation		2,364		-		2,364		-
Total Liabilities	$	66,257	$	(735)	$	2,364	$	64,628
(a) These amounts are shown gross and exclude $0.2 million of collateral that was posted
against derivative positions with counterparties.

Significant Unobservable Inputs

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

Significant Unobservable Inputs	Model Input
Basis adjustment:
On peak	95.5%
Off peak	93.1%
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

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)		2014		2013
Beginning balance,	$	(64,628)	$	(72,346)
Realized and unrealized gains (losses):
Included in regulatory liabilities		5,831		2,748
Included in other comprehensive income		-		-
Included in earnings		6,634		(1,148)
Included in current assets		(53)		-
Purchases		6,859		5,562
Sales		(60)		(3)
Issuances		-		-
Settlements		(13,380)		(4,411)
Transfers in and/or out of Level 3		-		-
Balance as of March 31,	$	(58,797)	$	(69,598)
Total gains (losses) included in earnings attributed to the change in unrealized gains (losses) related to assets and liabilities held at March 31,(b)	$	-	$	-

(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.

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

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)		2014		2013
Purchased Power Expense	$	6,634	$	(1,148)

(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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Share Based Compensation (Details) (Performance Units [Member], USD $) In Millions, except Share data, unless otherwise specified	3 Months Ended			0 Months Ended	3 Months Ended	1 Months Ended	3 Months Ended
	Mar. 31, 2014	Mar. 31, 2013	Jan. 31, 2014	Feb. 21, 2014 Performance Unit Plan [Member]	Mar. 31, 2014 Performance Unit Plan [Member]	Jan. 31, 2014 Director Incentive Agreement [Member]	Mar. 31, 2014 Director Incentive Agreement [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Awards granted during period (in units)				21,991		4,683
Award vesting period					5 years		3 years
Compensation expense	$ 0.8	$ 0.9
Cash payments distributed related to awards previously granted and now payable			1.2
Awards forfeited during period	0	0
Outstanding awards vested during period	$ 3.9

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Fair Value of Financial Instruments (Details-4) (USD $) In Thousands, unless otherwise specified	3 Months Ended
	Mar. 31, 2014		Mar. 31, 2013
Fair Value, Liabilities Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Beginning balance,	$ (64,628)		$ (72,346)
Realized and unrealized gains (losses):
Included in regulatory liabilities (assets)	5,831		2,748
Included in other comprehensive income	0		0
Included in earnings	6,634	[1]	(1,148)	[1]
Included in current assets	(53)		0
Purchases	6,859		5,562
Sales	(60)		(3)
Issuances	0		0
Settlements	(13,380)		(4,411)
Transfers in and/or out of level 3	0		0
Ending balance,	(58,797)		(69,598)
Total gains (losses) included in earnings attributed to the change in unrealized gains (losses) related to assets and liabilities	0	[1]	0	[1]
Purchased Power Expense [Member]
Realized and unrealized gains (losses):
Included in earnings	$ 6,634	[1]	$ (1,148)	[1]

[1] 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 Income (Unaudited) (USD $) In Thousands, except Per Share data, unless otherwise specified	3 Months Ended
	Mar. 31, 2014	Mar. 31, 2013
Operating Revenues:
Regulated electric revenues	$ 98,852	$ 93,494
Regulated gas revenues	110,713	72,467
Nonregulated revenues	680	1,276
Total Operating Revenues	210,245	167,237
Operating Expenses:
Fuel for electric generation	14,132	10,760
Purchased power	18,555	18,205
Cost of gas sold	78,508	44,692
Other operations and maintenance	40,472	41,649
Depreciation and amortization	9,746	9,624
Other general taxes	4,861	4,679
Total Operating Expenses	166,274	129,609
Operating Income	43,971	37,628
Other income, net	4,552	3,309
Interest expense, net	(4,541)	(4,675)
Income before income taxes	43,982	36,262
Income tax provision	(16,265)	(13,678)
Net Income (Loss)	$ 27,717	$ 22,584
Earnings Per Share of Common Stock (basic and diluted)	$ 0.80	$ 0.65
Dividends per share of common stock	$ 0.272	$ 0.263
Weighted Average Shares Outstanding (basic and diluted)	34,668	34,668

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Derivative and Hedging Instruments (Details-2) (USD $) In Thousands, unless otherwise specified	Mar. 31, 2014	Dec. 31, 2013
Offsetting Assets [Line Items]
Collateral posted against derivative positions		$ (200)
Commodity Derivative Contracts [Member]
Offsetting Assets [Line Items]
Gross amounts	2,123	1,523
Gross amounts offset in balance sheet	(152)	(99)
Collateral posted against derivative positions	0	(175)
Net amount presented in balance sheet	1,971	1,249
Financial Transmission Rights [Member]
Offsetting Assets [Line Items]
Gross amounts	106	363
Gross amounts offset in balance sheet	0	0
Collateral posted against derivative positions	0	0
Net amount presented in balance sheet	$ 106	$ 363

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Consolidated Statements of Comprehensive Income (Unaudited) (Parantheticals) (USD $) In Thousands, unless otherwise specified	3 Months Ended
	Mar. 31, 2014	Mar. 31, 2013
Unrealized gain (loss) on available-for-sale securities, taxes	$ 5	$ 43
MGE [Member]
Unrealized gain (loss) on available-for-sale securities, taxes	$ 12	$ 18

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Investment in ATC (Details-1) (USD $)	3 Months Ended					0 Months Ended
	Mar. 31, 2014	Mar. 31, 2013	Mar. 31, 2014 MGE Transco [Member] ATC [Member]	Mar. 31, 2013 MGE Transco [Member] ATC [Member]	Dec. 31, 2013 MGE Transco [Member] ATC [Member]	Apr. 30, 2014 MGE Transco [Member] ATC [Member] Subsequent Event [Member]
Schedule Of Equity Method Investments [Line Items]
Equity earnings from investment	$ 2,481,000	$ 2,396,000	$ 2,481,000	$ 2,396,000
Dividend income from investment	1,917,000	1,807,000	1,917,000	1,807,000
Capital contributions to investment	693,000	373,000	533,000	178,000		500,000
Equity method investment			$ 65,600,000		$ 64,500,000

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Derivative and Hedging Instruments

3 Months Ended

Mar. 31, 2014

Derivative Instruments and Hedging Activities Disclosure [Abstract]

Derivative and Hedging Instruments

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, 2014	December 31, 2013
Commodity derivative contracts	409,800 MWh	458,660 MWh
Commodity derivative contracts	2,200,000 Dth	3,750,000 Dth
FTRs	790 MW	1,984 MW

c.Financial Statement Presentation.

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 offset with a corresponding 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 31,2014 and December 31,2013, the fair value of exchange traded derivatives and FTRs exceeded their cost basis by $2.1 million and $1.8 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 31,2014 and December 31, 2013, reflects a loss position of $60.3 million and $65.7 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, 2014
Commodity derivative contracts	Other current assets	$	2,086	Derivative liability (current)	$	111
Commodity derivative contracts	Other deferred charges		37	Derivative liability (long-term)		41
FTRs	Other current assets		106	Derivative liability (current)		-
Ten-year PPA	N/A		N/A	Derivative liability (current)		6,540
Ten-year PPA	N/A		N/A	Derivative liability (long-term)		53,750
December 31, 2013
Commodity derivative contracts	Other current assets	$	1,356	Derivative liability (current)	$	51
Commodity derivative contracts	Other deferred charges		167	Derivative liability (long-term)		48
FTRs	Other current assets		363	Derivative liability (current)		-
Ten-year PPA	N/A		N/A	Derivative liability (current)		7,750
Ten-year PPA	N/A		N/A	Derivative liability (long-term)		57,930

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
(In thousands)		Gross amounts		Gross amounts offset in balance sheet		Collateral posted against derivative positions		Net amount presented in balance sheet
March 31, 2014
Commodity derivative contracts	$	2,123	$	(152)	$	-	$	1,971
FTRs		106		-		-		106
December 31, 2013
Commodity derivative contracts	$	1,523	$	(99)	$	(175)	$	1,249
FTRs		363		-		-		363

Offsetting of Derivative Liabilities
(In thousands)		Gross amounts		Gross amounts offset in balance sheet		Collateral posted against derivative positions		Net amount presented in balance sheet
March 31, 2014
Commodity derivative contracts	$	152	$	(152)	$	-	$	-
Ten-year PPA		60,290		-		-		60,290
December 31, 2013
Commodity derivative contracts	$	99	$	(99)	$	-	$	-
Ten-year PPA		65,680		-		-		65,680

The following tables summarize the unrealized and realized gains (losses) related to the derivative instruments on the consolidated balance sheet at March 31,2014 and 2013, and the consolidated income statement for the three months endedMarch 31,2014 and 2013.

		2014				2013
(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,	$	63,893	$	411	$	72,329	$	574
Change in unrealized gain		(13,601)		-		(1,697)		-
Realized loss reclassified to a deferred account		1,535		(1,535)		(290)		290
Realized gain (loss) reclassified to income
statement		6,386		1,475		(1,145)		(605)
Balance at March 31,	$	58,213	$	351	$	69,197	$	259

		Realized losses (gains)
(In thousands)		Fuel for electric generation/ purchased power		Cost of gas sold
Three Months Ended March 31, 2014:
Commodity derivative contracts	$	(4,795)	$	(1,220)
FTRs		(636)		-
Ten-year PPA		(1,210)		-
Three Months Ended March 31, 2013:
Commodity derivative contracts	$	22	$	608
FTRs		(158)		-
Ten-year PPA		1,278		-

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 $40.0million, depending on MGE's nominated capacity amount. As of March 31,2014, 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 31,2014 and December 31, 2013, 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 31,2014,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, 2014	Mar. 31, 2013
ATC [Member]
Schedule Of Equity Method Investments [Line Items]
Operating revenues	$ 163,337	$ 151,737
Operating expenses	(78,623)	(69,770)
Other income (expense), net	388	(448)
Interest expense, net	(21,996)	(21,044)
Earnings before members' income taxes	$ 63,106	$ 60,475

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Fair Value of Financial Instruments

3 Months Ended

Mar. 31, 2014

Fair Value Disclosures [Abstract]

Fair Value of Financial Instruments

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 31,2014 and December 31, 2013, 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 31,2014 and December 31, 2013. Since 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, 2014				December 31, 2013
(In thousands)		Carrying Amount		Fair Value		Carrying Amount		Fair Value
MGE Energy
Assets:
Cash and cash equivalents	$	93,489	$	93,489	$	68,813	$	68,813
Liabilities:
Long-term debt*		402,774		436,788		403,793		432,010
MGE
Assets:
Cash and cash equivalents	$	37,988	$	37,988	$	14,808	$	14,808
Liabilities:
Long-term debt*		402,774		436,788		403,793		432,010
*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, 2014
(In thousands)		Total		Level 1		Level 2		Level 3
MGE Energy
Assets:
Exchange-traded investments	$	804	$	804	$	-	$	-
Total Assets	$	804	$	804	$	-	$	-
Liabilities:
Derivatives, net	$	58,213	$	(584)	$	-	$	58,797
Deferred compensation		2,472		-		2,472		-
Total Liabilities	$	60,685	$	(584)	$	2,472	$	58,797
MGE
Assets:
Exchange-traded investments	$	461	$	461	$	-	$	-
Total Assets	$	461	$	461	$	-	$	-
Liabilities:
Derivatives, net	$	58,213	$	(584)	$	-	$	58,797
Deferred compensation		2,472		-		2,472		-
Total Liabilities	$	60,685	$	(584)	$	2,472	$	58,797

		Fair Value as of December 31, 2013
(In thousands)		Total		Level 1		Level 2		Level 3
MGE Energy
Assets:
Exchange-traded investments	$	792	$	792	$	-	$	-
Total Assets	$	792	$	792	$	-	$	-
Liabilities:
Derivatives, net(a)	$	63,893	$	(735)	$	-	$	64,628
Deferred compensation		2,364		-		2,364		-
Total Liabilities	$	66,257	$	(735)	$	2,364	$	64,628
MGE
Assets:
Exchange-traded investments	$	431	$	431	$	-	$	-
Total Assets	$	431	$	431	$	-	$	-
Liabilities:
Derivatives, net(a)	$	63,893	$	(735)	$	-	$	64,628
Deferred compensation		2,364		-		2,364		-
Total Liabilities	$	66,257	$	(735)	$	2,364	$	64,628
(a) These amounts are shown gross and exclude $0.2 million of collateral that was posted
against derivative positions with counterparties.

No transfers were made in or out of Level 1 or Level 2 for the three months endedMarch 31,2014.

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 considered unobservable and 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 Accounting group. It is reviewed on a quarterly basis by management in Energy Supply and Finance to review the assumptions, inputs, and fair value measurements.

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

Significant Unobservable Inputs	Model Input
Basis adjustment:
On peak	95.5%
Off peak	93.1%
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)		2014		2013
Beginning balance,	$	(64,628)	$	(72,346)
Realized and unrealized gains (losses):
Included in regulatory liabilities		5,831		2,748
Included in other comprehensive income		-		-
Included in earnings		6,634		(1,148)
Included in current assets		(53)		-
Purchases		6,859		5,562
Sales		(60)		(3)
Issuances		-		-
Settlements		(13,380)		(4,411)
Transfers in and/or out of Level 3		-		-
Balance as of March 31,	$	(58,797)	$	(69,598)
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)		2014		2013
Purchased Power Expense	$	6,634	$	(1,148)

(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, 2014	Mar. 31, 2013
Operating Activities:
Net Income	$ 27,717	$ 22,584
Items not affecting cash:
Depreciation and amortization	9,746	9,624
Deferred income taxes	(877)	11,294
Provision for doubtful receivables	743	743
Employee benefit plan expenses	(332)	3,336
Equity earnings in ATC	(2,481)	(2,396)
Other items	(679)	750
Changes in working capital items:
Decrease in current assets	3,283	17,341
Increase (decrease) in current liabilities	19,604	(4,590)
Dividend income from ATC	1,917	1,807
Cash contributions to pension and other postretirement plans	(818)	(30,764)
Other noncurrent items, net	547	(1,077)
Cash Provided by Operating Activities	58,370	28,652
Investing Activities:
Capital expenditures	(21,800)	(29,164)
Capital contributions to investments	(693)	(373)
Other	(682)	(279)
Cash Used for Investing Activities	(23,175)	(29,816)
Financing Activities:
Cash dividends paid on common stock	(9,420)	(9,132)
Repayment of long-term debt	(1,019)	(667)
Increase (decrease) in short-term debt	0	10,500
Other	(80)	0
Cash (Used for) Provided by Financing Activities	(10,519)	701
Change in cash and cash equivalents	24,676	(463)
Cash and cash equivalents at beginning of period	68,813	46,357
Cash and Cash Equivalents at End of Period	93,489	45,894
Significant noncash investing activities:
Accrued capital expenditures	$ 8,967	$ 12,699

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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, 2014		Mar. 31, 2013
Operating Revenues:
Regulated electric revenues	$ 98,852		$ 93,494
Regulated gas revenues	110,713		72,467
Nonregulated revenues	680		1,276
Total Operating Revenues	210,245		167,237
Operating Expenses:
Fuel for electric generation	14,132		10,760
Purchased power	18,555		18,205
Cost of gas sold	78,508		44,692
Other operations and maintenance	40,472		41,649
Depreciation and amortization	9,746		9,624
Other general taxes	4,861		4,679
Income tax provision	16,265		13,678
Total Operating Expenses	166,274		129,609
Operating Income	43,971		37,628
Other Income and Deductions:
Equity in earnings in ATC	2,481		2,396
Total Other Income and Deductions	4,552		3,309
Interest Expense:
Net Interest Expense	4,541		4,675
Net Income (Loss)	27,717		22,584
MGE [Member]
Operating Revenues:
Regulated electric revenues	98,858		93,494
Regulated gas revenues	110,718		72,467
Nonregulated revenues	680		1,276
Total Operating Revenues	210,256		167,237
Operating Expenses:
Fuel for electric generation	14,134		10,760
Purchased power	18,558		18,205
Cost of gas sold	78,513		44,692
Other operations and maintenance	40,317		41,504
Depreciation and amortization	9,734		9,624
Other general taxes	4,861		4,679
Income tax provision	14,924		12,870
Total Operating Expenses	181,041		142,334
Operating Income	29,215	[1]	24,903	[1]
Other Income and Deductions:
AFUDC - equity funds	1,950		596
Equity in earnings in ATC	2,481		2,396
Income tax provision	(1,264)		(781)
Other income, net	(158)		141
Total Other Income and Deductions	3,009	[1]	2,352	[1]
Income before interest expense	32,224		27,255
Interest Expense:
Interest on long-term debt	5,249		4,928
Other interest, net	(25)		(37)
AFUDC - borrowed funds	(643)		(196)
Net Interest Expense	4,581		4,695
Net Income Including Noncontrolling Interest	27,643		22,560
Less Net Income Attributable to Noncontrolling Interest, net of tax	(6,510)		(6,826)
Net Income (Loss)	$ 21,133		$ 15,734

[1] *Amounts are shown net of the related tax expense, consistent with the presentation on the consolidated MGE Income Statement.

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Columbia Environmental Project Construction

3 Months Ended

Mar. 31, 2014

Regulated Operations [Abstract]

Columbia Environmental Project Construction

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. Unit 2 was placed into service in April 2014 and Unit 1 is expected to be placed into service in the third quarter of 2014. The scrubbers and bag houses are expected to support compliance obligations for current and anticipated air quality regulations, including CAIR, CSAPR, 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 $135 million. As of March 31,2014, MGE had accumulated $124.3 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 expects to incur capital expenditures of approximately $10.7 million for the remainder of 2014. These amounts may change as a result of modifications to the project estimate or timing differences. MGE's share of various contractual commitments entered for the project as of March 31,2014 is $10.7 million. For the three months endedMarch 31,2014 and 2013, MGE has recognized after tax $1.9 million and $0.5 million, respectively, in AFUDC equity related to this project.

MGE expects that the costs pertaining to this project will be fully recoverable through rates. For 2014, the PSCW authorized MGE 100% AFUDC on this project during construction. For 2013, the PSCW authorized MGEa 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, 2014
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, 2014
Amendment Flag	false
Document Fiscal Year Focus	2014
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	34,668,370
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, 2014

Income Tax Disclosure [Abstract]

Taxes

Taxes - MGE Energy and MGE.

Effective Tax Rate.

MGE Energy's effective income tax rate for the three months endedMarch 31,2014 and 2013, was 37.0% and 37.7%, respectively. MGE's effective income tax rate for thethree months endedMarch 31,2014 and 2013, was 36.9% and 37.7%, respectively. The decrease in the effective tax rate is primarily attributable to higher AFUDC equity earnings in 2014.

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MGE Energy Inc Consolidated Statements of Comprehensive Income (Unaudited) (USD $) In Thousands, unless otherwise specified	3 Months Ended
	Mar. 31, 2014	Mar. 31, 2013
Comprehensive Income [Abstract]
Net Income	$ 27,717	$ 22,584
Other comprehensive income (loss), net of tax:
Unrealized gain (loss) on available-for-sale securities, net of tax	7	65
Comprehensive Income	$ 27,724	$ 22,649

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Madison Gas and Electric Company Consolidated Statements of Common Equity (Unaudited) (USD $) In Thousands, unless otherwise specified	Total USD ($)	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, 2012		$ 550,766		$ 17,348	$ 192,417	$ 223,527		$ 4	$ 117,470
Beginning balance, shares at Dec. 31, 2012			34,668	17,348
Increase (Decrease) In Stockholders' Equity [Roll Forward]
Net Income		22,560				15,734			6,826
Other comprehensive income (loss)	65	27					65	27
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			34,668	17,348
Beginning balance, value at Dec. 31, 2013		576,454		17,348	192,417	247,534		192	118,963
Beginning balance, shares at Dec. 31, 2013			34,668	17,348
Increase (Decrease) In Stockholders' Equity [Roll Forward]
Net Income		27,643				21,133			6,510
Other comprehensive income (loss)	7	18					7	18
Cash dividends paid to parent by MGE		(7,000)				(7,000)
Equity contribution received by noncontrolling interest		533							533
Distributions to parent from noncontrolling interest		(6,909)							(6,909)
Ending balance, value at Mar. 31, 2014		$ 590,739		$ 17,348	$ 192,417	$ 261,667		$ 210	$ 119,097
Ending balance, shares at Mar. 31, 2014			34,668	17,348

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MGE Energy Inc Consolidated Statements of Common Equity (Unaudited) (USD $) In Thousands, unless otherwise specified	Total	Common Stock [Member]	Additional Paid-In Capital [Member]	Retained Earnings [Member]	Accumulated Other Comprehensive Income [Member]
Beginning balance, value at Dec. 31, 2012	$ 579,429	$ 34,668	$ 316,268	$ 228,399	$ 94
Beginning balance, shares at Dec. 31, 2012		34,668
Increase (Decrease) In Stockholders' Equity [Roll Forward]
Net Income	22,584			22,584
Other comprehensive income (loss)	65				65
Common stock dividends declared	(9,132)			(9,132)
Ending balance, value at Mar. 31, 2013	592,946	34,668	316,268	241,851	159
Ending balance, shares at Mar. 31, 2013		34,668
Beginning balance, value at Dec. 31, 2013	617,510	34,668	316,268	266,197	377
Beginning balance, shares at Dec. 31, 2013		34,668
Increase (Decrease) In Stockholders' Equity [Roll Forward]
Net Income	27,717			27,717
Other comprehensive income (loss)	7				7
Common stock dividends declared	(9,420)			(9,420)
Cash in lieu of fractional shares related to stock split	(80)			(80)
Ending balance, value at Mar. 31, 2014	$ 635,734	$ 34,668	$ 316,268	$ 284,414	$ 384
Ending balance, shares at Mar. 31, 2014		34,668

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Rate Matters

3 Months Ended

Mar. 31, 2014

Regulated Operations [Abstract]

Rate Matters

Rate Matters - MGE Energy and MGE.

a. Rate Proceedings.

On April 17, 2014, MGE filed an application with the PSCW requesting a 2.8% increase to electric rates and a 2.3% decrease to gas rates for 2015. Electric and natural gas rates would then be frozen in 2016, subject to review of fuel costs. As a condition of the rate freeze, MGE has requested escrow accounting treatment for transmission related costs starting in 2015. This treatment will allow MGE to reflect any differential in actual costs incurred in its next rate case filing. The proposed electric rate increases cover costs associated with the construction of emission-reduction equipment at Columbia and improvements and reliability of the state's electric transmission system.

On July 26, 2013, the PSCW authorized MGE to freeze electric and natural gas rates at 2013 levels for 2014. The order includes authorizing 100% AFUDC on the Columbia scrubber construction project and deferral of increased costs related to ATC and MISO Schedule 26 fees. As part of the rate freeze plan authorized by the PSCW, effective January 1, 2014 approximately $6.2 million associated with a 2012 fuel rule surplus credit will not be required to be refunded to customers and will be amortized in 2014. The fuel credit will accrue interest at MGE's weighted cost of capital. The authorized return on equity will remain unchanged at 10.3%.

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%.

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 31,2014, MGE did not defer any electric fuel-related savings/costs that are outside the range authorized by the PSCW. As part of the rate freeze plan authorized by the PSCW for 2014, $1.6 million of the approximately $6.2 million associated with the 2012 fuel rule surplus credit was amortized against purchase power expense during the three months endedMarch 31,2014.

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Pension and Other Postretirement Plans

3 Months Ended

Mar. 31, 2014

Compensation and Retirement Disclosure [Abstract]

Pension and Other Postretirement Plans

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 endedMarch 31,2014 and 2013. A portion of the net periodic benefit cost is capitalized within the consolidated balance sheets.

		Three Months Ended
		March 31,
(In thousands)		2014		2013
Pension Benefits
Components of net periodic (benefit) cost:
Service cost	$	1,484	$	1,929
Interest cost		3,251		3,186
Expected return on assets		(5,279)		(4,776)
Amortization of:
Prior service (benefit) cost		49		79
Actuarial loss		173		2,015
Net periodic (benefit) cost	$	(322)	$	2,433
Postretirement Benefits
Components of net periodic (benefit) cost:
Service cost	$	330	$	596
Interest cost		772		970
Expected return on assets		(654)		(544)
Amortization of:
Transition obligation		1		1
Prior service (benefit) cost		(668)		28
Actuarial loss		39		311
Net periodic (benefit) cost	$	(180)	$	1,362

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Equity and Financing Arrangements

3 Months Ended

Mar. 31, 2014

Equity and Financing Arrangements Disclosure [Abstract]

Equity and Financing Arrangements

Equity and Financing Arrangements.

a. Common Stock - MGE Energy.

MGE Energy sells shares of its common stock through its Stock Plan. Those shares may be newly issued shares or shares that MGE Energy has purchased in the open market for resale to participants in the Stock Plan. All sales under the stock plan are covered by a shelf registration statement that MGE Energy filed with the SEC. For both the three months endedMarch 31,2014 and 2013, MGE Energy did not issue any new shares of common stock under the Stock Plan.

b. Dilutive Shares Calculation - MGE Energy.

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, 2014	Mar. 31, 2013
Consolidated Statements of Common Equity
Dividends per share of common stock	$ 0.272	$ 0.263

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Basis of Presentation

3 Months Ended

Mar. 31, 2014

Organization, Consolidation and Presentation of Financial Statements [Abstract]

Basis of Presentation

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 2013 Annual Report on Form 10-K.

The accompanying consolidated financial statements as of March 31,2014, 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 2013 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 57 through 100 of the 2013 Annual Report on Form 10-K.

On December 20, 2013, MGE Energy's Board of Directors declared a three-for-two stock split of MGE Energy's common stock in the form of a stock dividend. The additional shares were distributed February 7, 2014 to all shareholders of record as of January 24, 2014. All shares and per share data provided in this report give effect to this stock split.

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Investment in ATC

3 Months Ended

Mar. 31, 2014

Equity Method Investments and Joint Ventures [Abstract]

Investment in ATC

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 as required by Wisconsin law. 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 31,2014 and 2013, MGE Transco recorded the following:

		Three Months Ended
		March 31,
(In thousands)		2014		2013
Equity in earnings from investment in ATC	$	2,481	$	2,396
Dividends received from ATC		1,917		1,807
Capital contributions to ATC		533		178

On April 30, 2014, MGE Transco made an additional $0.5million capital contribution to ATC.

MGE Transco's investment in ATC as of March 31,2014 and December 31, 2013 was $65.6 million and $64.5 million, respectively.

At March 31,2014, 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, 2014 and 2013, is as follows:

		Three Months Ended
		March 31,
(In thousands)		2014		2013
Operating revenues	$	163,337	$	151,737
Operating expenses		(78,623)		(69,770)
Other income (expense), net		388		(448)
Interest expense, net		(21,996)		(21,044)
Earnings before members' income taxes	$	63,106	$	60,475

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Equity and Financing Arrangements (Details) (USD $)	3 Months Ended
	Mar. 31, 2014	Mar. 31, 2013
Common Stock [Abstract]
Common stock issued during period	0	0
Dilutive Shares Calculation [Abstract]
Dilutive securities	$ 0

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Fair Value of Financial Instruments (Details-2) (USD $) In Thousands, unless otherwise specified	Mar. 31, 2014	Dec. 31, 2013
Liabilities:
Derivative asset, collateral offset		$ 200
Recurring [Member]
Assets:
Total Assets	804	792
Liabilities:
Derivatives, net	58,213	63,893	[1]
Deferred compensation	2,472	2,364
Total liabilities	60,685	66,257
Recurring [Member] | Exchange Traded [Member]
Assets:
Available-for-sale securities	804	792
Recurring [Member] | Level 1 [Member]
Assets:
Total Assets	804	792
Liabilities:
Derivatives, net	(584)	(735)	[1]
Deferred compensation	0	0
Total liabilities	(584)	(735)
Recurring [Member] | Level 1 [Member] | Exchange Traded [Member]
Assets:
Available-for-sale securities	804	792
Recurring [Member] | Level 2 [Member]
Assets:
Total Assets	0	0
Liabilities:
Derivatives, net	0	0	[1]
Deferred compensation	2,472	2,364
Total liabilities	2,472	2,364
Recurring [Member] | Level 2 [Member] | Exchange Traded [Member]
Assets:
Available-for-sale securities	0	0
Recurring [Member] | Level 3 [Member]
Assets:
Total Assets	0	0
Liabilities:
Derivatives, net	58,797	64,628	[1]
Deferred compensation	0	0
Total liabilities	58,797	64,628
Recurring [Member] | Level 3 [Member] | Exchange Traded [Member]
Assets:
Available-for-sale securities	0	0
MGE [Member]
Liabilities:
Derivative asset, collateral offset		200
MGE [Member] | Recurring [Member]
Assets:
Total Assets	461	431
Liabilities:
Derivatives, net	58,213	63,893	[1]
Deferred compensation	2,472	2,364
Total liabilities	60,685	66,257
MGE [Member] | Recurring [Member] | Exchange Traded [Member]
Assets:
Available-for-sale securities	461	431
MGE [Member] | Recurring [Member] | Level 1 [Member]
Assets:
Total Assets	461	431
Liabilities:
Derivatives, net	(584)	(735)	[1]
Deferred compensation	0	0
Total liabilities	(584)	(735)
MGE [Member] | Recurring [Member] | Level 1 [Member] | Exchange Traded [Member]
Assets:
Available-for-sale securities	461	431
MGE [Member] | Recurring [Member] | Level 2 [Member]
Assets:
Total Assets	0	0
Liabilities:
Derivatives, net	0	0	[1]
Deferred compensation	2,472	2,364
Total liabilities	2,472	2,364
MGE [Member] | Recurring [Member] | Level 2 [Member] | Exchange Traded [Member]
Assets:
Available-for-sale securities	0	0
MGE [Member] | Recurring [Member] | Level 3 [Member]
Assets:
Total Assets	0	0
Liabilities:
Derivatives, net	58,797	64,628	[1]
Deferred compensation	0	0
Total liabilities	58,797	64,628
MGE [Member] | Recurring [Member] | Level 3 [Member] | Exchange Traded [Member]
Assets:
Available-for-sale securities	$ 0	$ 0

[1] These amounts are shown gross and exclude $0.2 million of collateral that was posted against derivative positions with counterparties.

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Commitments and Contingencies

3 Months Ended

Mar. 31, 2014

Commitments and Contingencies Disclosure [Abstract]

Commitments and Contingencies

Commitments and Contingencies - MGE Energy and MGE.

a. Environmental.

MGE Energy and MGE are subject to frequently changing local, state, and federal regulations concerning air quality, water quality, land use, threatened and endangered species, hazardous materials handling, and solid waste disposal. These regulations affect the manner in which they conduct their operations, the costs of those operations, as well as capital and operating expenditures. Regulatory initiatives, proposed rules, and court challenges to adopted rules, have the potential to have a material effect on our capital expenditures and operating costs. These initiatives, proposed rules, and court challenges include:

The President's announced plan and directive to the EPA to regulate carbon pollution, or GHG emissions, from new and existing electric power generation, and EPA's related proposed GHG New Source Performance Standards (NSPS).

Rules to regulate NOx and SO2 emissions, including the EPA's Cross State Air Pollution Rule (CSAPR), which recently has been reinstated by the US Supreme Court (see below for recent developments with CSAPR). The Sierra Club has sought federal appellate court review of Wisconsin's implementation plan for CAVR. Both the pending reinstatement of CSAPR and the appellate court review of Wisconsin's implementation plan for Clean Air Visibility Rule (CAVR) make the nature of compliance requirements uncertain.

Rules to regulate mercury and similar emissions, including Wisconsin's adopted Mercury Rule and the EPA's adopted Mercury and Air Toxics Standards.

The EPA's proposed cooling water intake rules. The EPA issued a proposed Phase II rule and alternative compliance strategies for existing facilities in April 2011 and has announced that it intends to release the final rule in May 2014 pursuant to a consent agreement.

The EPA's proposed water effluent limitations guidelines and standards for steam electric power plants, which focus on the reduction of metals and other pollutants in wastewater from new and existing power plants from coal-burning plants such as our Columbia and Elm Road Units.

The EPA's ongoing review of several National Ambient Air Quality Standards (NAAQS), including the potential lowering of ozone NAAQS, and upcoming guidance for determining attainment for sulfur dioxide NAAQS.

The EPA is reconsidering the current emergency dispatch restrictions in the Reciprocating Internal Combustion Engines Maximum Achievable Control Technology (RICE MACT) regulation. The reconsideration could result in increased or decreased restrictions for these engines.

The matters in the bullet points above are discussed further in Footnote 18.d. in MGE Energy's and MGE's 2013 Annual Report on Form 10-K. In addition to the developments noted above, the following discussion is an update to the current status of environmental matters set forth in that Footnote.

EPA's Cross-State Air Pollution Rule (CSAPR) Upheld by the Supreme Court

On April 29, 2014, the US Supreme Court issued a decision upholding CSAPR, thereby reversing the D.C. Circuit Court's decision on CSAPR, and remanding the matter back to the D.C. Circuit for further proceedings. The EPA may amend CSAPR to modify compliance deadlines that have passed since the rule was vacated by the D.C. Circuit. It is unclear if the rule will be reinstated for 2014 emissions or later. The Clean Air Interstate Rule (CAIR) will remain in effect until CSAPR is reinstated. See MGE Energy's and MGE's 2013 Annual Report on Form 10K for additional information on the legal proceedings associated with these environmental matters.

Past evaluations of CSAPR's effect on MGE have pointed to SO₂ emissions at our Columbia plant as being our primary concern in meeting emissions allocations under CSAPR. Planned new SO₂ controls at Columbia are underway; Unit 2 was completed in April 2014 and Unit 1 is expected to be completed by third quarter of 2014 (see Footnote 4 for information regarding the Columbia environmental construction project). MGE expects that the costs pertaining to meeting CSAPR requirements will be fully recoverable through rates. We will continue to monitor and evaluate recoverability through the D.C. Circuit Court process and the EPA implementation phase.

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 as noted below.

Columbia Environmental Project

See Footnote 4 for information regarding the Columbia environmental construction project.

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 owner-operator, and the other co-owners 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 April 2013, the EPA filed a lawsuit against the co-owners of Columbia asserting similar allegations. In September 2010 and April 2013, Sierra Club filed lawsuits against WPL alleging violations of the CAA at Columbia and other WPL-operated Wisconsin facilities.

In April 2013, WPL, as owner-operator, along with the other owners of Columbia, entered into a consent decree with the EPA and the Sierra Club to resolve these claims, while admitting no liability. In June 2013, the consent decree was approved and entered by the Court. 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, 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 also paid approximately $0.2 million as its share of a civil penalty and will complete approximately $0.6 million in environmental mitigation projects. MGE intends to seek recovery in rates of the costs associated with its compliance with the terms of the final consent decree and currently expects to recover any material compliance costs.

b. Chattel Paper Agreement and Other Guarantees.

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, 2014. At March 31,2014, MGE had sold a $5.1 million interest in these receivables. MGE retains the servicing responsibility for these receivables. As of March 31,2014, the servicing asset recognized by MGE is $0.3 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 31,2014, 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 2014 and the next four years on the loans are:

(In thousands)		2014		2015		2016		2017		2018
Chattel Paper	$	477	$	1,007	$	910	$	506	$	449

c. Legal Matters.

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

d. Purchase Contracts.

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 31,2014, the future commitments related to these purchase contracts were as follows:

(In thousands)		2014		2015		2016		2017		2018
Purchase power(a)	$	50,542	$	49,072	$	49,743	$	50,243	$	51,265

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

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Segment Information

3 Months Ended

Mar. 31, 2014

Segment Reporting [Abstract]

Segment Information

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 2013 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, 2014
Operating revenues	$	98,852	$	110,713	$	680	$	-	$	-	$	-	$	210,245
Interdepartmental revenues		118		3,624		10,670		-		-		(14,412)		-
Total operating revenues		98,970		114,337		11,350		-		-		(14,412)		210,245
Depreciation and amortization		(6,337)		(1,563)		(1,834)		-		(12)		-		(9,746)
Other operating expenses		(77,901)		(92,843)		(40)		-		(156)		14,412		(156,528)
Operating income (loss)		14,732		19,931		9,476		-		(168)		-		43,971
Other (deductions) income, net		1,827		(35)		-		2,481		279		-		4,552
Interest (expense) income, net		(2,205)		(804)		(1,572)		-		40		-		(4,541)
Income before taxes		14,354		19,092		7,904		2,481		151		-		43,982
Income tax provision		(4,353)		(7,665)		(3,172)		(998)		(77)		-		(16,265)
Net income	$	10,001	$	11,427	$	4,732	$	1,483	$	74	$	-	$	27,717
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

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, 2014
Operating revenues	$	98,858	$	110,718	$	680	$	-	$	-	$	210,256
Interdepartmental revenues		112		3,619		10,670		-		(14,401)		-
Total operating revenues		98,970		114,337		11,350		-		(14,401)		210,256
Depreciation and amortization		(6,337)		(1,563)		(1,834)		-		-		(9,734)
Other operating expenses*		(82,046)		(100,450)		(3,212)		-		14,401		(171,307)
Operating income*		10,587		12,324		6,304		-		-		29,215
Other (deductions) income, net*		1,619		(93)		-		1,483		-		3,009
Interest expense, net		(2,205)		(804)		(1,572)		-		-		(4,581)
Net income		10,001		11,427		4,732		1,483		-		27,643
Less: Net income attributable to
noncontrolling interest, net of tax		-		-		-		-		(6,510)		(6,510)
Net income attributable to MGE	$	10,001	$	11,427	$	4,732	$	1,483	$	(6,510)	$	21,133
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
*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, 2014	$	905,319	$	268,294	$	40,011	$	312,223	$	65,600	$	432,919	$	(413,943)	$	1,610,423
December 31, 2013		899,257		265,694		19,853		288,116		64,504		431,436		(389,800)		1,579,060
Capital Expenditures:
Three Months Ended March 31, 2014	$	18,906	$	2,384	$	-	$	510	$	-	$	-	$	-	$	21,800
Year ended Dec. 31, 2013		100,146		15,554		-		3,347		-		-		-		119,047

		Utility						Consolidated
(In thousands) MGE		Electric		Gas		Assets not Allocated		Nonregulated Energy		Transmission Investment		Elimination Entries		Total
Assets:
March 31, 2014	$	907,952	$	266,383	$	39,883	$	288,268	$	65,600	$	(12,693)	$	1,555,393
December 31, 2013		899,257		265,694		19,853		288,066		64,504		(6,731)		1,530,643
Capital Expenditures:
Three Months Ended March 31, 2014	$	18,906	$	2,384	$	-	$	510	$	-	$	-	$	21,800
Year ended Dec. 31, 2013		100,146		15,554		-		3,347		-		-		119,047

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Rate Matters (Details) (PSCW [Member], USD $) In Millions, unless otherwise specified	3 Months Ended		12 Months Ended	3 Months Ended	12 Months Ended	3 Months Ended	12 Months Ended		3 Months Ended	12 Months Ended
	Mar. 31, 2014 Legal Entity Type of Counterparty [Domain]	Mar. 31, 2014 MGE [Member]	Dec. 31, 2013 MGE [Member]	Mar. 31, 2014 Columbia Environmental Project [Member] MGE [Member]	Dec. 31, 2013 Columbia Environmental Project [Member] MGE [Member]	Mar. 31, 2014 Electric [Member] MGE [Member]	Dec. 31, 2013 Electric [Member] MGE [Member]	Dec. 31, 2015 Electric [Member] Proposed Future Rate Matters [Member] MGE [Member]	Mar. 31, 2014 Gas [Member] MGE [Member]	Dec. 31, 2013 Gas [Member] MGE [Member]	Dec. 31, 2015 Gas [Member] Proposed Future Rate Matters [Member] MGE [Member]
Rate Proceedings [Abstract]
Proposed rate increase (decrease), percentage								2.80%			(2.30%)
Authorized rate increase (decrease), percentage						0.00%	3.80%		0.00%	1.00%
Authorized rate increase (decrease), amount						$ 0	$ 14.9		$ 0	$ 1.6
Authorized AFUDC Rate				100.00%	50.00%
Return of electric fuel credit, total		6.2
Authorized return on equity, percentage		10.30%	10.30%
Fuel Rules [Abstract]
Fuel rules, bandwidth	2.00%
Fuel rules, electric fuel deferred costs upper threshold	102.00%
Fuel rules, electric fuel deferred costs lower threshold	98.00%
Return of electric fuel credit, current period		$ 1.6

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Commitments and Contingencies (Details-1) (Columbia Units [Member], USD $) In Millions, unless otherwise specified	3 Months Ended
	Mar. 31, 2014
Columbia Units [Member]
Columbia Commitments [Abstract]
Accrual for future environmental mitigation projects	$ 0.6
Envrionmental civil penalty expense	$ 0.2

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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, 2014	Mar. 31, 2013
Other comprehensive income/(loss), net of tax:
Unrealized gain (loss) on available-for-sale securities, net of tax	$ 7	$ 65
Comprehensive Income	27,724	22,649
MGE [Member]
Net Income	27,643	22,560
Other comprehensive income/(loss), net of tax:
Unrealized gain (loss) on available-for-sale securities, net of tax	18	27
Total comprehensive income including noncontrolling interest	27,661	22,587
Less: Comprehensive income attributable to Noncontrolling Interest, net of tax	(6,510)	(6,826)
Comprehensive Income	$ 21,151	$ 15,761

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Consolidated Balance Sheets (Unaudited) (Parentheticals) (USD $) In Thousands, unless otherwise specified	Mar. 31, 2014	Dec. 31, 2013
Receivables, Net
Reserve for uncollectible accounts receivable	$ 4,501	$ 4,219
Reserve for uncollectible other accounts receivable	608	750
MGE [Member]
Receivables, Net
Reserve for uncollectible accounts receivable	4,501	4,219
Reserve for uncollectible other accounts receivable	$ 608	$ 750

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Significant Accounting Policies (Policies)

3 Months Ended

Mar. 31, 2014

Accounting Policies [Abstract]

Variable Interest Entities

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.

Common Stock

MGE Energy sells shares of its common stock through its Stock Plan. Those shares may be newly issued shares or shares that MGE Energy has purchased in the open market for resale to participants in the Stock Plan. All sales under the stock plan are covered by a shelf registration statement that MGE Energy filed with the SEC.

Share-based Compensation

Under MGE Energy'sPerformance Unit Plan, eligible employees 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 2013, on February 21, 2014, 21,991 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 and have been adjusted to reflect the three-for-two stock split declared December 20, 2013. 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 31,2014, 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 December 2013, a Director Incentive Plan was approved for the non-employee members of the Board of Directors. This plan is similar to MGE Energy's Performance Unit Plan for eligible employees described above. Under the plan, a non-employee director can 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 payments, at the end of the set performance period. The units are subject to a three-year graded vesting schedule. In January 2014, unit awards of 4,683 (post-split) were granted to the non-employee Directors. For accounting purposes, the awards will be measured similarly to the employee unit awards.

Chattel Paper Agreement

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, 2014.

MGE retains the servicing responsibility for these receivables.

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 31,2014, 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.

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.

At March 31,2014 and December 31, 2013, 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 31,2014 and December 31, 2013. Since long-term debt is not traded in an active market, it is classified as Level 2.

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

Derivatives include exchange-traded derivative contracts, over-the-counter 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 considered unobservable and 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 Accounting group. It is reviewed on a quarterly basis by management in Energy Supply and Finance to review the assumptions, inputs, and fair value measurements.

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

Significant Unobservable Inputs	Model Input
Basis adjustment:
On peak	95.5%
Off peak	93.1%
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 Disclosure

a.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 became effective January 1, 2014. The authoritative guidance did not have a financial or disclosure impact.

b. Presentation of an Unrecognized Tax Benefit.

In July 2013, the FASB issued authoritative guidance within the Codification's Income Statement topic that provides guidance on the presentation of an unrecognized tax benefit when a net operating loss carryforward, a similar tax loss, or a tax credit carryforward exist. The authoritative guidance was issued to eliminate diversity in practice by providing guidance on the presentation of unrecognized tax benefits. This authoritative guidance became effective January 1, 2014. The authoritative guidance will not have a financial statement or disclosure impact, unlessMGE Energy or its subsidiaries are in a net operating loss position. MGE Energy or its subsidiaries are currently not in a net operating loss position.

XML

Taxes (Details)	3 Months Ended
	Mar. 31, 2014	Mar. 31, 2013
Income Tax Disclosure [Line Items]
Effective income tax rate	37.00%	37.70%
MGE [Member]
Income Tax Disclosure [Line Items]
Effective income tax rate	36.90%	37.70%

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Share-Based Compensation

3 Months Ended

Mar. 31, 2014

Disclosure of Compensation Related Costs, Share-based Payments [Abstract]

Share-Based Compensation

Share-Based Compensation - MGE Energy and MGE.

Under MGE Energy'sPerformance Unit Plan, eligible employees 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 2013, on February 21, 2014, 21,991 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 and have been adjusted to reflect the three-for-two stock split declared December 20, 2013. 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 31,2014, 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 December 2013, a Director Incentive Plan was approved for the non-employee members of the Board of Directors. This plan is similar to MGE Energy's Performance Unit Plan for eligible employees described above. Under the plan, a non-employee director can 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 payments, at the end of the set performance period. The units are subject to a three-year graded vesting schedule. In January 2014, unit awards of 4,683 (post-split) were granted to the non-employee Directors. For accounting purposes, the awards will be measured similarly to the employee unit awards.

During the three months endedMarch 31,2014 and 2013, MGE recorded $0.8 million and $0.9 million, respectively, in compensation expense as a result of the plans. In January 2014, cash payments of $1.2 million were distributed relating to awards that were granted in 2009. No forfeitures occurred during the three months endedMarch 31,2014 or 2013. At March 31,2014, $3.9 million of outstanding awards are vested.