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, 2016

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

For the transition period from _______________ to _______________

Commission File 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, 2016
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' 2015 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 7 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, except as required by law.

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 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 Services	MGE Services, LLC
MGE State Energy Services	MGE State Energy Services, 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
BART	Best Available Retrofit Technology
Blount	Blount Station
CAVR	Clean Air Visibility Rule
CCR	Coal Combustion Residual
Codification	Financial Accounting Standards Board Accounting Standards Codification
Columbia	Columbia Energy Center
CPP	Clean Power Plan
CSAPR	Cross-State Air Pollution Rule
Dth	Dekatherms, a quantity measure used in respect of natural gas
EGUs	Electric Generating Units
ELG	Effluent Limitations Guidelines
Elm Road Units	Elm Road Generating Station
EPA	United States Environmental Protection Agency
FASB	Financial Accounting Standards Board
FERC	Federal Energy Regulatory Commission
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
kWh	Kilowatt-hour, a measure of electric energy produced
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
NO2	Nitrogen Dioxide
NOx	Nitrogen Oxides
PGA	Purchased Gas Adjustment clause, a regulatory mechanism used to reconcile natural gas costs recovered in rates to actual costs
PM	Particulate Matter
PPA	Purchased Power Agreement
ppb	Parts Per Billion
PSCW	Public Service Commission of Wisconsin
ROE	Return on Equity
SCR	Selective Catalytic Reduction
SEC	Securities and Exchange Commission
SO2	Sulfur Dioxide

4

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
WDNR	Wisconsin Department of Natural Resources
Working capital	Current assets less current liabilities
WPDES	Wisconsin Pollutant Discharge Elimination System
WPL	Wisconsin Power and Light Company
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,
			2016		2015
	Operating Revenues:
	Electric revenues	$	93,690	$	100,206
	Gas revenues		53,837		69,928
	Total Operating Revenues		147,527		170,134
	Operating Expenses:
	Fuel for electric generation		12,013		11,892
	Purchased power		14,670		22,865
	Cost of gas sold		32,523		46,919
	Other operations and maintenance		42,730		40,674
	Depreciation and amortization		11,032		10,849
	Other general taxes		5,028		5,084
	Total Operating Expenses		117,996		138,283
	Operating Income		29,531		31,851
	Other income, net		2,442		2,105
	Interest expense, net		(5,000)		(5,091)
	Income before income taxes		26,973		28,865
	Income tax provision		(9,945)		(10,587)
	Net Income	$	17,028	$	18,278
	Earnings Per Share of Common Stock
	(basic and diluted)	$	0.49	$	0.53
	Dividends per share of common stock	$	0.295	$	0.283
	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,
			2016		2015
	Net Income	$	17,028	$	18,278
	Other comprehensive income, net of tax:
	Unrealized loss on available-for-sale securities, net of
	tax ($110 and $57)		(164)		(85)
	Comprehensive Income	$	16,864	$	18,193
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,
		2016		2015
Operating Activities:
Net income	$	17,028	$	18,278
Items not affecting cash:
Depreciation and amortization		11,032		10,849
Deferred income taxes		2,840		3,723
Provision for doubtful receivables		592		97
Employee benefit plan expenses		(57)		792
Equity earnings in ATC		(2,233)		(1,881)
Other items		86		(658)
Changes in working capital items:
Decrease in current assets		22,311		17,985
Increase (decrease) in current liabilities		1,487		(11,091)
Dividend income from ATC		865		1,420
Cash contributions to pension and other postretirement plans		(11,159)		(10,809)
Other noncurrent items, net		937		5,935
Cash Provided by Operating Activities		43,729		34,640
Investing Activities:
Capital expenditures		(15,642)		(11,533)
Capital contributions to investments		(671)		(280)
Other		(183)		(48)
Cash Used for Investing Activities		(16,496)		(11,861)
Financing Activities:
Cash dividends paid on common stock		(10,227)		(9,794)
Repayment of long-term debt		(1,059)		(1,037)
Repayment of short-term debt		-		(7,000)
Cash Used for Financing Activities		(11,286)		(17,831)
Change in cash and cash equivalents		15,947		4,948
Cash and cash equivalents at beginning of period		81,384		65,755
Cash and cash equivalents at end of period	$	97,331	$	70,703
The accompanying notes are an integral part of the unaudited consolidated financial statements.

7

MGE Energy, Inc.

Consolidated Balance Sheets (unaudited)

(In thousands)

		March 31, 2016		December 31, 2015
ASSETS
Current Assets:
Cash and cash equivalents	$	97,331	$	81,384
Accounts receivable, less reserves of $3,289 and $3,052, respectively		36,710		37,112
Other accounts receivable, less reserves of $569 and $642, respectively		5,637		7,477
Unbilled revenues		23,375		25,008
Materials and supplies, at average cost		20,335		19,155
Fossil fuel		10,222		13,110
Stored natural gas, at average cost		8,548		16,145
Prepaid taxes		24,606		35,252
Regulatory assets - current		10,448		9,538
Other current assets		9,992		10,570
Total Current Assets		247,204		254,751
Regulatory assets		149,987		148,199
Other deferred assets and other		6,476		6,377
Property, Plant, and Equipment:
Property, plant, and equipment, net		1,218,282		1,217,094
Construction work in progress		33,198		26,351
Total Property, Plant, and Equipment		1,251,480		1,243,445
Investments		75,269		73,631
Total Assets	$	1,730,416	$	1,726,403
LIABILITIES AND CAPITALIZATION
Current Liabilities:
Long-term debt due within one year	$	34,264	$	4,266
Accounts payable		41,132		40,830
Accrued interest and taxes		3,975		5,067
Accrued payroll related items		8,926		11,215
Regulatory liabilities - current		11,071		9,515
Derivative liabilities		9,374		8,343
Other current liabilities		9,181		4,910
Total Current Liabilities		117,923		84,146
Other Credits:
Deferred income taxes		363,671		360,785
Investment tax credit - deferred		1,024		1,050
Regulatory liabilities		21,493		20,785
Accrued pension and other postretirement benefits		64,259		75,680
Derivative liabilities		46,540		44,935
Other deferred liabilities and other		62,620		61,820
Total Other Credits		559,607		565,055
Capitalization:
Common shareholders' equity		697,095		690,458
Long-term debt		355,791		386,744
Total Capitalization		1,052,886		1,077,202
Commitments and contingencies (see Footnote 7)		-		-
Total Liabilities and Capitalization	$	1,730,416	$	1,726,403
The accompanying notes are an integral part of the above unaudited consolidated financial statements.

8

MGE Energy, Inc.

Consolidated Statements of Common Equity (unaudited)

(In thousands, except per-share amounts)

									Accumulated
					Additional				Other
	Common Stock				Paid-in		Retained		Comprehensive
	Shares		Value		Capital		Earnings		Income		Total
2015
Beginning balance - December 31, 2014	34,668	$	34,668	$	316,268	$	308,007	$	458	$	659,401
Cumulative effect of new accounting principle							(142)				(142)
Beginning balance - Adjusted							307,865				659,259
Net income							18,278				18,278
Other comprehensive loss									(85)		(85)
Common stock dividends declared
($0.283 per share)							(9,794)				(9,794)
Ending balance - March 31, 2015	34,668	$	34,668	$	316,268	$	316,349	$	373	$	667,658
2016
Beginning balance - December 31, 2015	34,668	$	34,668	$	316,268	$	339,165	$	357	$	690,458
Net income							17,028				17,028
Other comprehensive loss									(164)		(164)
Common stock dividends declared
($0.295 per share)							(10,227)				(10,227)
Ending balance - March 31, 2016	34,668	$	34,668	$	316,268	$	345,966	$	193	$	697,095
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,
			2016		2015
	Operating Revenues:
	Electric revenues	$	93,696	$	100,211
	Gas revenues		53,847		69,933
	Total Operating Revenues		147,543		170,144
	Operating Expenses:
	Fuel for electric generation		12,016		11,894
	Purchased power		14,674		22,868
	Cost of gas sold		32,534		46,923
	Other operations and maintenance		42,402		40,472
	Depreciation and amortization		11,020		10,837
	Other general taxes		5,028		5,084
	Income tax provision		9,090		9,776
	Total Operating Expenses		126,764		147,854
	Operating Income		20,779		22,290
	Other Income and Deductions:
	AFUDC - equity funds		261		128
	Equity in earnings in ATC		2,233		1,881
	Income tax provision		(942)		(808)
	Other expense, net		(73)		(39)
	Total Other Income and Deductions		1,479		1,162
	Income before interest expense		22,258		23,452
	Interest Expense:
	Interest on long-term debt		5,109		5,151
	Other interest, net		37		32
	AFUDC - borrowed funds		(85)		(42)
	Net Interest Expense		5,061		5,141
	Net Income	$	17,197	$	18,311
	Less Net Income Attributable to Noncontrolling Interest, net of tax		(6,252)		(6,553)
	Net Income Attributable to MGE	$	10,945	$	11,758
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,
			2016		2015
	Net Income	$	17,197	$	18,311
	Other comprehensive income, net of tax:
	Unrealized loss on available-for-sale securities, net of
	tax ($20 and $55)		(30)		(82)
	Comprehensive Income	$	17,167	$	18,229
	Less: Comprehensive income attributable to Noncontrolling
	Interest, net of tax		(6,252)		(6,553)
	Comprehensive Income attributable to MGE	$	10,915	$	11,676
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,
		2016		2015
Operating Activities:
Net income	$	17,197	$	18,311
Items not affecting cash:
Depreciation and amortization		11,020		10,837
Deferred income taxes		2,502		2,391
Provision for doubtful receivables		592		97
Employee benefit plan expenses		(57)		792
Equity earnings in ATC		(2,233)		(1,881)
Other items		112		(526)
Changes in working capital items:
Decrease in current assets		22,053		18,825
Increase (decrease) in current liabilities		1,524		(8,859)
Dividend income from ATC		865		1,420
Cash contributions to pension and other postretirement plans		(11,159)		(10,809)
Other noncurrent items, net		906		5,901
Cash Provided by Operating Activities		43,322		36,499
Investing Activities:
Capital expenditures		(15,642)		(11,533)
Capital contributions to investments		(533)		(178)
Other		(72)		(17)
Cash Used for Investing Activities		(16,247)		(11,728)
Financing Activities:
Cash dividends paid to parent by MGE		(10,000)		-
Distributions to parent from noncontrolling interest		(6,500)		(6,818)
Equity contribution received by noncontrolling interest		533		2,678
Repayment of long-term debt		(1,059)		(1,037)
Repayment of short-term debt		-		(7,000)
Cash Used for Financing Activities		(17,026)		(12,177)
Change in cash and cash equivalents		10,049		12,594
Cash and cash equivalents at beginning of period		26,760		4,562
Cash and cash equivalents at end of period	$	36,809	$	17,156
The accompanying notes are an integral part of the unaudited consolidated financial statements.

11

Madison Gas and Electric Company

Consolidated Balance Sheets (unaudited)

(In thousands)

		March 31, 2016		December 31, 2015
ASSETS
Current Assets:
Cash and cash equivalents	$	36,809	$	26,760
Accounts receivable, less reserves of $3,289 and $3,052, respectively		36,710		37,112
Affiliate receivables		686		542
Other accounts receivable, less reserves of $569 and $642, respectively		5,522		7,390
Unbilled revenues		23,375		25,008
Materials and supplies, at average cost		20,335		19,155
Fossil fuel		10,222		13,110
Stored natural gas, at average cost		8,547		16,145
Prepaid taxes		23,764		34,279
Regulatory assets - current		10,448		9,538
Other current assets		9,978		10,544
Total Current Assets		186,396		199,583
Affiliate receivable long-term		4,633		4,766
Regulatory assets		149,987		148,199
Other deferred assets and other		4,219		4,216
Property, Plant, and Equipment:
Property, plant, and equipment, net		1,217,614		1,216,415
Construction work in progress		33,198		26,351
Total Property, Plant, and Equipment		1,250,812		1,242,766
Investments		71,835		69,984
Total Assets	$	1,667,882	$	1,669,514
LIABILITIES AND CAPITALIZATION
Current Liabilities:
Long-term debt due within one year	$	34,264	$	4,266
Accounts payable		41,140		40,742
Accrued interest and taxes		3,927		5,021
Accrued payroll related items		8,926		11,215
Regulatory liabilities - current		11,071		9,515
Derivative liabilities		9,374		8,343
Other current liabilities		9,005		4,791
Total Current Liabilities		117,707		83,893
Other Credits:
Deferred income taxes		355,264		352,626
Investment tax credit - deferred		1,024		1,050
Regulatory liabilities		21,493		20,785
Accrued pension and other postretirement benefits		64,259		75,680
Derivative liabilities		46,540		44,935
Other deferred liabilities and other		62,620		61,817
Total Other Credits		551,200		556,893
Capitalization:
Common shareholder's equity		502,591		501,676
Noncontrolling interest		140,593		140,308
Total Equity		643,184		641,984
Long-term debt		355,791		386,744
Total Capitalization		998,975		1,028,728
Commitments and contingencies (see Footnote 7)		-		-
Total Liabilities and Capitalization	$	1,667,882	$	1,669,514
The accompanying notes are an integral part of the above unaudited consolidated financial statements.

12

Madison Gas and Electric Company

Consolidated Statements of Common Equity (unaudited)

(In thousands)

								Accumulated
					Additional				Other		Non-
	Common Stock				Paid-in		Retained	Comprehensive			Controlling
	Shares		Value		Capital		Earnings	Income/(Loss)			Interest		Total
2015
Beginning balance - Dec. 31, 2014	17,348	$	17,348	$	192,417	$	276,662	$	144	$	125,689	$	612,260
Cumulative effect of new accounting principle							(142)						(142)
Beginning balance - Adjusted							276,520						612,118
Net income							11,758				6,553		18,311
Other comprehensive loss									(82)				(82)
Equity contribution received by
noncontrolling interest											2,678		2,678
Distributions to parent from
noncontrolling interest											(6,818)		(6,818)
Ending balance - March 31, 2015	17,348	$	17,348	$	192,417	$	288,278	$	62	$	128,102	$	626,207
2016
Beginning balance - Dec. 31, 2015	17,348	$	17,348	$	192,417	$	291,888	$	23	$	140,308	$	641,984
Net income							10,945				6,252		17,197
Other comprehensive loss									(30)				(30)
Cash dividends paid to parent
by MGE							(10,000)						(10,000)
Equity contribution received by
noncontrolling interest											533		533
Distributions to parent from
noncontrolling interest											(6,500)		(6,500)
Ending balance - March 31, 2016	17,348	$	17,348	$	192,417	$	292,833	$	(7)	$	140,593	$	643,184
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, 2016

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 accounting 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 2015 Annual Report on Form 10-K.

The accompanying consolidated financial statements as of March 31, 2016, 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 2015 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 55 through 105 of the 2015 Annual Report on Form 10-K.

2.

Equity and Financing Arrangements - MGE Energy.

a.

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. For both the three months ended March 31, 2016 and 2015, MGE Energy did not issue any new shares of common stock under the Stock Plan.

b.

Dilutive Shares Calculation.

MGE Energy does not hold any dilutive securities.

3.

Investment in ATC - MGE Energy and MGE.

ATC owns and operates electric transmission facilities primarily in Wisconsin. MGE received an interest in ATC when it, like other Wisconsin electric utilities, contributed its electric transmission facilities to ATC 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 ended March 31, 2016 and 2015, MGE Transco recorded the following:

		Three Months Ended March 31,
(In thousands)		2016		2015
Equity in earnings from investment in ATC	$	2,233	$	1,881
Dividends received from ATC		865		1,420
Capital contributions to ATC		533		178

MGE Transco's investment in ATC as of March 31, 2016, and December 31, 2015, was $71.4 million and $69.5 million, respectively.

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At March 31, 2016, MGE is the majority owner (51%), and MGE Energy, the holding company, is the minority owner (49%) 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. MGE's ownership interest is expected to decline below a majority during 2016 as a result of continued funding of ATC capital contributions by MGE Energy, and may be completely eliminated in favor of MGE Energy if the PSCW accepts a staff recommendation that MGE transfer its interest in ATC to MGE Energy. The recommendation arose in the context of requests for regulatory approvals by several owners of ATC in connection with a reorganization of ATC designed to separate its existing Wisconsin-based transmission operations from its non-Wisconsin transmission development activities. The change will have no effect on MGE Energy's consolidated financial statements. No gain or loss is expected to be recognized on the date MGE ceases to have a controlling financial interest.

ATC's summarized financial data for the three months ended March 31, 2016 and 2015, is as follows:

		Three Months Ended March 31,
(In thousands)		2016		2015
Operating revenues	$	164,240	$	152,357
Operating expenses		(79,065)		(79,951)
Other income, net		127		62
Interest expense, net		(24,208)		(24,483)
Earnings before members' income taxes	$	61,094	$	47,985

4.

Taxes - MGE Energy and MGE.

Effective Tax Rate.

MGE Energy's effective income tax rate for the three months ended March 31, 2016 and 2015, was 36.9% and 36.7%, respectively. MGE's effective income tax rate for the three months ended March 31, 2016 and 2015, was 36.8% and 36.6%, respectively. The increase in the effective tax rate is due in part to a lower estimated domestic manufacturing deduction and lower estimated AFUDC equity earnings in 2016.

5.

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. MGE refined its methodology for using discount rates to measure the components of net periodic benefit cost for 2016. The refined methodology uses individual spot rates, instead of a weighted average of the yield curve spot rates, for measuring the service cost and interest cost components.

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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, 2016 and 2015. A portion of the net periodic benefit cost is capitalized within the consolidated balance sheets.

		Three Months Ended March 31,
(In thousands)		2016		2015
Pension Benefits
Components of net periodic cost:
Service cost	$	1,381	$	1,798
Interest cost		3,089		3,440
Expected return on assets		(5,593)		(5,677)
Amortization of:
Prior service cost		2		6
Actuarial loss		1,356		1,334
Net periodic cost	$	235	$	901
Postretirement Benefits
Components of net periodic (benefit) cost:
Service cost	$	324	$	383
Interest cost		674		778
Expected return on assets		(705)		(703)
Amortization of:
Transition obligation		1		1
Prior service benefit		(667)		(667)
Actuarial loss		159		262
Net periodic (benefit) cost	$	(214)	$	54

6.

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 February 2016, 19,055 units were granted based on the MGE Energy closing stock price as of that date. Units are subject to a five-year graded vesting schedule. On the grant date, MGE Energy and MGE measure the cost of the employee services received in exchange for a performance unit award based on the current market value of MGE Energy common stock. The fair value of the awards is re-measured quarterly, including at March 31, 2016, as required by applicable accounting standards. Changes in fair value as well as the original grant are recognized as compensation cost. Since this amount is re-measured 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.

Under the Director Incentive 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. This plan is similar to MGE Energy's Performance Unit Plan for eligible employees described above. In January 2016, 3,773 units were granted.

During the three months ended March 31, 2016 and 2015, MGE recorded $1.3 million and $0.5 million, respectively, in compensation expense as a result of awards under the plans. In January 2016, cash payments of $1.2 million were distributed relating to awards that were granted in 2011. During the three months ended March 31, 2015, MGE recorded a $0.2 million gain on 4,676 units forfeited. No forfeitures occurred during the three months ended March 31, 2016. At March 31, 2016, $5.3 million of outstanding awards are vested, and of this amount, no cash settlements have occurred.

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7.

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 we conduct our 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:

EPA's Effluent Limitations Guidelines (ELG) and Standards for Steam Electric Power Generating Point Source Category

In November 2015, the EPA published its final rule setting Effluent Limitations Guidelines (ELG) for the steam electric power generating industry. The ELG rule establishes federal limits on the amount of metals and other pollutants that can be discharged in wastewater from new and existing steam electric generation plants. The ELG rule mostly covers pollutants that are captured by certain air pollution control systems and via wet ash handling systems at coal-burning power plants with units greater than 50 MW generation capacity. The operators of our Columbia and Elm Road Units have indicated that equipment upgrades may be necessary to comply with the new discharge standards. The rule will be applied to Wisconsin-based power plants as they renew their WPDES permits, beginning in 2018 but no later than 2023. Management believes that any compliance costs will be recovered in future rates based on previous treatment of environmental compliance projects.

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

Section 316(b) of the Clean Water Act requires that the cooling water intake structures at electric power plants meet best available technology standards so that mortality from entrainment (drawing aquatic life into a plant's cooling system) and impingement (trapping aquatic life on screens) are reduced. The EPA finalized its 316(b) rule for existing facilities in 2014. Section 316(b) requirements are implemented in Wisconsin through modifications to plants' WPDES permits, which govern plant wastewater discharges. WDNR is currently developing rules to implement the EPA 316(b) rule.

Our WCCF, Blount, and Columbia plants are considered existing plants under this rule. Our WCCF facility already employs a system that meets the 316(b) rule. Our Blount plant has conducted studies showing that it will likely be in compliance with this rule when its WPDES permit is renewed in 2017. The operator of our Columbia plant plans to conduct an intake study to demonstrate compliance with the 316(b) rule and/or identify design criteria needed to meet the new rule requirements prior to Columbia's 2017 WPDES permit renewal. The exact requirements at Blount and Columbia, however, will not be known until the WDNR finalizes its rule, approves the plant operators' approach, and those sites' WPDES permits are modified to account for this rule. Nonetheless, MGE expects that the 316(b) rule will not have material effects on its existing plants.

EPA's Greenhouse Gas (GHG) Reduction Guidelines under the Clean Air Act 111(d) Rule

In October 2015, the EPA published its Clean Power Plan (CPP) rule, which went into effect in December 2015, setting guidelines and approval criteria for states to use in developing plans to control GHG emissions from existing fossil fuel-fired electric generating units (EGUs) and systems. In October 2015, the EPA also published a proposed federal implementation plan under the CPP rule. The proposed federal implementation plan is designed to provide mass-based and rate-based emissions trading options to serve as a model and/or resource for states that are adopting their own plans, or for use by the EPA in states that do not implement their own plans under the finalized CPP. Implementation of the rule is expected to have a direct impact on existing coal and natural gas fired generating units, including possible changes in dispatch and additional operating costs.

On January 26, 2016, several parties filed a request for a stay of the CPP with the U.S. Supreme Court; and on February 9, 2016, the U.S. Supreme Court granted that request. The CPP may not be implemented until the courts ultimately resolve the underlying legality of the rule. Oral arguments are scheduled before the D.C. Circuit for June 2, 2016.

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Given the pending legal proceedings and the need for a yet-to-be-developed state implementation plan or finalization of the federal implementation plan, the nature and timing of any final requirements is subject to uncertainty. If the rule remains substantially in its present form, it is expected to have a material impact on MGE.

National Ambient Air Quality Standards (NAAQS)

The EPA's NAAQS regulations have been developed to set ambient levels of six pollutants to protect sensitive populations (primary NAAQS) and the environment (secondary NAAQS) from the negative effects of exposure to these pollutants at higher levels. MGE is following developments for several NAAQS, including for particulate matter, nitrogen dioxide, sulfur dioxide, and ozone. Further discussion on sulfur dioxide, ozone, and nitrogen dioxide NAAQS follows. For additional information on the NAAQS process, see Footnote 18.c. of Notes to Consolidated Financial Statements under Item 8, Financial Statements and Supplementary Data, of MGE Energy's and MGE's 2015 Annual Report on Form 10-K.

Ozone NAAQS

In October 2015, the EPA revised the primary and secondary ozone NAAQS, lowering each to 70 ppb. The rule became effective in December 2015. Based on current ozone monitoring data, it appears that Milwaukee County (where our Elm Road Units are located) will likely not attain the lowered standards, and Dane and Columbia Counties (where our WCCF/Blount and Columbia Units are located, respectively) may or may not attain them. It is too early to determine, however, as final attainment designations for these three counties will be based upon air monitoring data for years 2014-2016 and must be approved by the EPA. Once these designations are complete, the State of Wisconsin will develop implementation plans for each county designated as nonattainment, which could affect operations and emission control obligations for plants located within the nonattainment counties. The State of Wisconsin has joined a lawsuit filed by several states challenging the EPA's new ozone standard alleging that the new standard is not attainable and the EPA is not properly considering background levels in setting its ozone attainment levels. Briefings in this challenge began in April 2016 and will continue through the summer. The final briefs are scheduled to be filed in September 2016. MGE will continue to monitor legal developments, attainment designations, and any state actions and implementation plans.

Sulfur Dioxide (SO₂) NAAQS

In March 2015, the EPA entered into a court-approved consent decree requiring 1-hour SO₂ attainment/nonattainment area designations to be completed in three phases extending out until 2020. In August 2015, the EPA published its data requirements rule and under this new rule, states must submit their first designation proposals by July 2016 for those areas that contain large stationary sources of SO₂ (sources that emit over a threshold mass of SO₂, and/or over a threshold emissions rate). MGE's Columbia Plant was identified as one of these types of sources and thus Wisconsin is required to submit a designation proposal for Columbia County (the county in which the Columbia Plant is located). Wisconsin sent a designation proposal for Columbia County to the EPA on September 15, 2015. Wisconsin proposed that Columbia be considered in attainment based on recent SO₂ air emissions modeling that took newly installed pollution controls into account. In February 2016, the EPA sent a response letter to the State of Wisconsin indicating that it agreed with Wisconsin's recommended designations, and has given a preliminary classification of Columbia County as an unclassified/ attainment area. The EPA stated in their response letter that they intend to finalize designations by July 2, 2016. In addition to the EPA's actions on SO₂ NAAQS, the WDNR is revising its state rules to incorporate the one hour SO₂ standard with a proposed final rule date of August 2016. MGE will continue to monitor developments until final designations are made, however, we do not anticipate any material costs from this rule.

Nitrogen Dioxide (NO₂) NAAQS

The WDNR is revising its state rules to incorporate the EPA's one hour NO₂ NAAQS rule that was finalized in 2010. The anticipated effective date of the state rule is August 1, 2016. Wisconsin's NO₂ NAAQS rule may affect our stationary fossil-fuel generation sources by requiring that we demonstrate consistency with the NAAQS when applying for certain air permits. Preliminary assessments conducted by MGE suggest that these NAAQS rules will not have a material impact. MGE will continue to monitor rule developments.

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EPA's Cross-State Air Pollution Rule: Proposed Ozone Season Update based on 2008 Ozone NAAQS

The EPA's Cross-State Air Pollution Rule (CSAPR) is an interstate air pollution transport rule designed to reduce ozone and fine particulate (PM2.5) air levels in areas that the EPA has determined are being affected by pollution from neighboring and upwind states. This is accomplished in the CSAPR through a reduction in SO₂ and Nitrogen Oxides (NO_x) from fossil-fuel fired power plants. NO_x and SO₂ contribute to fine particulate pollution, and NO_x contributes to ozone. Reductions are achieved through a cap and trade model. Individual plants can meet their caps through modifications and/or buying allowances on the market.

In December 2015, the EPA published a proposed rule to amend the existing CSAPR. The proposed rule is designed to incorporate 2008 Ozone NAAQS attainment levels (the current CSAPR is based on 1997 Ozone NAAQS levels) in 23 states, including Wisconsin, by further limiting ozone season NO_x levels through a reduction in NO_x allowances. The proposed rule also includes revisions to CSAPR that are designed to address issues remaining from the D.C. Circuit remand of CSAPR, including Wisconsin's inclusion in the NO_x ozone season portion of the rule.

The proposed rule would reduce summertime NO_x emissions from power plants starting in 2017. Initial review of this proposed rule shows that we will likely need to buy NO_x Ozone Season allowances to comply with the rule. Depending on the cost of allowances, this requirement could be material for MGE. It is however too soon to tell what costs MGE will incur as the rule is not finalized, all legal proceedings are not completed, and the allowances are not on the market yet. We expect to monitor the rule developments and the D.C. Circuit Court remand completion to help determine how this rule will ultimately affect MGE.

Clean Air Visibility Rule (CAVR)

Columbia may be subject to the best available retrofit technology (BART) regulations, a subsection of the EPA's Clean Air Visibility Rule (CAVR), which may require pollution control retrofits. Columbia's pollution control upgrades and the EPA's stance that compliance with the CSAPR equals compliance with BART should mean that Columbia will not need to do additional work to meet BART requirements. In February 2016, the EPA submitted a proposed revision to the CAVR. The proposed revision would move state plan due dates from July 2018 to July 2021. This would allow for states to coordinate their CAVR compliance with other compliance efforts. If this proposed revision is finalized, it would reduce the chances that CAVR would be material for MGE. At this time, however, the BART regulatory obligations, compliance strategies, and costs remain uncertain due to the continued legal uncertainty surrounding CSAPR.

Solid Waste

EPA's Coal Combustion Residuals Rule

In December 2014, the EPA finalized its Disposal of Coal Combustion Residuals from Electric Utilities (CCR) rule. The rule became effective in October 2015. It provides that coal ash will be regulated as a solid waste, and defines what ash use activities would be considered generally exempt beneficial reuse of coal ash. The rule also regulates landfills, ash ponds, and other surface impoundments for coal combustion residuals by regulating their design, location, monitoring, and operation. This portion of the rule is accomplished in phases to allow for sites with onsite storage and/or disposal to evaluate their compliance with the rule's design criteria. Landfills and impoundments that cannot meet design criteria will need to close formally within defined timeframes.

The Columbia and Elm Road Units co-owners and plant operators are working through the phased requirements to determine what changes may be necessary at those facilities to meet design criteria. We anticipate that some design and operational changes may need to be made at these facilities. Review of our Elm Road facility has indicated that the costs to comply with this rule are not expected to be significant. Columbia's operator has developed a preliminary implementation schedule for meeting the various deadlines spelled out in the rule. Costs at Columbia will be dependent on what is determined during the evaluation stage. Management believes compliance costs will be recovered in future rates based on previous treatment of environmental compliance projects.

b.

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.

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c.

Purchase Contracts.

MGE Energy and MGE have entered into various commodity transportation and storage contracts to meet their obligations to deliver natural gas to customers. As of March 31, 2016, the future commitments related to these purchase contracts were as follows:

(In thousands)		2016		2017		2018		2019		2020
Natural gas transportation & storage(a)	$	14,000	$	24,902	$	24,833	$	23,048	$	16,274

(a)

MGE's natural gas transportation and storage contracts require fixed monthly payments for firm supply pipeline transportation and storage capacity. The pricing components of the fixed monthly payments for the transportation and storage contracts are established by FERC but may be subject to change.

8.

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. 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. MGE's commodity 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, 2016	December 31, 2015
Commodity derivative contracts	468,590 MWh	355,580 MWh
Commodity derivative contracts	2,317,500 Dth	5,037,500 Dth
FTRs	770 MW	2,000 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 electricity 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, 2016, and December 31, 2015, the cost basis of exchange traded derivatives and FTRs exceeded their fair value by $1.0 million and $0.8 million, respectively.

MGE is a party to a 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 sheets. 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

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loss or gain position. The fair value of the contract at March 31, 2016, and December 31, 2015, reflects a loss position of $55.9 million and $53.3 million, respectively. The actual 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 sheets. 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. At March 31, 2016, MGE Energy and MGE had the right to reclaim collateral (a receivable) of $1.0 million.

	Asset Derivatives			Liability Derivatives
(In thousands)	Balance Sheet Location		Fair Value	Balance Sheet Location		Fair Value
March 31, 2016
Commodity derivative contracts	Other current assets	$	441	Derivative liability (current)	$	1,303
Commodity derivative contracts	Other deferred charges		53	Derivative liability (long-term)		184
FTRs	Other current assets		19	Derivative liability (current)		-
PPA	N/A		N/A	Derivative liability (current)		9,370
PPA	N/A		N/A	Derivative liability (long-term)		46,540
December 31, 2015
Commodity derivative contracts	Other current assets	$	146	Derivative liability (current)	$	1,266
Commodity derivative contracts	Other deferred charges		144	Derivative liability (long-term)		70
FTRs	Other current assets		234	Derivative liability (current)		-
PPA	N/A		N/A	Derivative liability (current)		8,340
PPA	N/A		N/A	Derivative liability (long-term)		44,930

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 consolidated balance sheets.

Offsetting of Derivative Assets
(In thousands)		Gross Amounts		Gross Amounts Offset in Balance Sheets		Collateral Posted Against Derivative Positions		Net Amount Presented in Balance Sheets
March 31, 2016
Commodity derivative contracts	$	494	$	(494)	$	-	$	-
FTRs		19		-		-		19
December 31, 2015
Commodity derivative contracts	$	290	$	(290)	$	-	$	-
FTRs		234		-		-		234

Offsetting of Derivative Liabilities
(In thousands)		Gross Amounts		Gross Amounts Offset in Balance Sheets		Collateral Posted Against Derivative Positions		Net Amount Presented in Balance Sheets
March 31, 2016
Commodity derivative contracts	$	1,487	$	(494)	$	(989)	$	4
PPA		55,910		-		-		55,910
December 31, 2015
Commodity derivative contracts	$	1,336	$	(290)	$	(1,038)	$	8
PPA		53,270		-		-		53,270

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The following tables summarize the unrealized and realized gains (losses) related to the derivative instruments on the consolidated balance sheets at March 31, 2016 and 2015, and the consolidated income statements for the three months ended March 31, 2016 and 2015.

		2016				2015
(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,	$	54,083	$	1,208	$	54,998	$	1,001
Unrealized loss		6,370		-		1,318		-
Realized (loss) gain reclassified to a deferred account		(1,451)		1,451		(1,061)		1,061
Realized loss reclassified to income
statement		(2,118)		(2,004)		(1,289)		(1,794)
Balance at March 31,	$	56,884	$	655	$	53,966	$	268

		Realized losses (gains)
		2016				2015
(In thousands)		Fuel for Electric Generation/ Purchased Power		Cost of Gas Sold		Fuel for Electric Generation/ Purchased Power		Cost of Gas Sold
Three Months Ended March 31:
Commodity derivative contracts	$	1,007	$	1,814	$	420	$	1,761
FTRs		(68)		-		(119)		-
PPA		1,369		-		1,021		-

MGE's commodity derivative contracts, FTRs, and 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 sheets 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 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, 2016, no collateral is required to be, or 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, 2016, and December 31, 2015, certain counterparties were in a net liability of less than $0.1 million.

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, 2016, no counterparties have defaulted.

9.

Rate Matters - MGE Energy and MGE.

a.

Rate Proceedings.

In April 2016, MGE filed an application with the PSCW requesting a 1.7% increase to electric rates and a 3.7% increase to gas rates for 2017. The proposed electric and gas rate increases cover costs primarily associated with the state's electric transmission and MGE's natural gas system infrastructure improvements. In its application, MGE has also proposed mechanisms to address potential 2018 electric and gas rate changes, including a rate adjustment for limited issues and escrow accounting on certain costs.

In July 2015, the PSCW approved MGE's request to extend the current accounting treatment for transmission related costs through 2016, conditioned upon MGE not filing a base rate case for 2016. This accounting treatment will allow MGE to reflect any differential between transmission costs reflected in rates and actual costs incurred in its next rate case filing, which occurred in the April 2016 filing.

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On December 23, 2014, the PSCW authorized MGE to increase 2015 rates for retail electric customers by 3.8% or $15.4 million and to decrease gas rates by 2.0% or $3.8 million. The increase in retail electric rates cover costs associated with the construction of emission-reduction equipment at Columbia, improvements and reliability of the state's electric transmission system, fuel and purchased power related to coal delivery costs, partially offset by lower cost as a result of market conditions for pension and postretirement benefit costs. The authorized return on common stock equity is 10.2%.

The PSCW also approved changes to customer rates and rate design for gas service that became effective January 1, 2015. Gas rate design consists of a fixed monthly customer charge and a variable charge tied to actual usage, in addition to the separate charge through the PGA for natural gas commodity costs. The change shifted more of the rate recovery to the monthly charge, reflecting the related fixed costs of providing gas services, and reduced the variable usage-based charge. Thus, gas net income is expected to be more evenly distributed during the year and less sensitive to weather.

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 annual fuel proceedings. Any over/under recovery of the actual costs is determined on an annual basis and is 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.

In August 2015, the PSCW approved a $0.00256/kWh fuel credit that began on September 1, 2015, and will continue throughout 2016. The fuel credit established a mechanism to return fuel savings to electric customers as a bill credit. MGE returned $2.6 million of electric fuel-related savings in customer bill credits during the period from September 1, 2015, through December 31, 2015. MGE returned $1.9 million of electric fuel-related savings for the three months ended March 31, 2016. As of December 31, 2015, and March 31, 2016, MGE has a remaining deferred balance of $9.5 million and $7.6 million of electric fuel-related savings that are outside the range authorized by the PSCW, respectively. These costs are subject to PSCW's annual review, expected to be completed in 2016.

In January 2016, the PSCW lowered MGE's 2016 fuel rules monitored costs by $14.8 million as a result of continued lower projected fuel costs in 2016. The return of the fuel savings to customers for 2016 will be addressed during the PSCW's annual review during 2016 of 2015 fuel costs. MGE will defer these fuel savings until a determination is made by the PSCW. As of March 31, 2016, MGE has deferred $3.6 million of these 2016 electric fuel rules monitored costs.

10.

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 accounting 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.

23

a.

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

At March 31, 2016, and December 31, 2015, the carrying amount of cash, cash equivalents, and outstanding commercial paper approximates fair market value due to the short maturity of those investments and obligations. The estimated fair market value of MGE Energy's and MGE's long-term debt is based on quoted market prices for similar financial instruments at March 31, 2016, and December 31, 2015. 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, 2016				December 31, 2015
(In thousands)		Carrying Amount		Fair Value		Carrying Amount		Fair Value
MGE Energy
Assets:
Cash and cash equivalents	$	97,331	$	97,331	$	81,384	$	81,384
Liabilities:
Long-term debt*		394,450		459,213		395,508		435,767
MGE
Assets:
Cash and cash equivalents	$	36,809	$	36,809	$	26,760	$	26,760
Liabilities:
Long-term debt*		394,450		459,213		395,508		435,767
*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, 2016
(In thousands)		Total		Level 1		Level 2		Level 3
MGE Energy
Assets:
Derivatives, net(a)	$	236	$	217	$	-	$	19
Exchange-traded investments		485		485		-		-
Total Assets	$	721	$	702	$	-	$	19
Liabilities:
Derivatives, net(a)	$	57,120	$	-	$	-	$	57,120
Deferred compensation		3,228		-		3,228		-
Total Liabilities	$	60,348	$	-	$	3,228	$	57,120
MGE
Assets:
Derivatives, net(a)	$	236	$	217	$	-	$	19
Exchange-traded investments		99		99		-		-
Total Assets	$	335	$	316	$	-	$	19
Liabilities:
Derivatives, net(a)	$	57,120	$	-	$	-	$	57,120
Deferred compensation		3,228		-		3,228		-
Total Liabilities	$	60,348	$	-	$	3,228	$	57,120

24

		Fair Value as of December 31, 2015
(In thousands)		Total		Level 1		Level 2		Level 3
MGE Energy
Assets:
Derivatives, net	$	234	$	-	$	-	$	234
Exchange-traded investments		759		759		-		-
Total Assets	$	993	$	759	$	-	$	234
Liabilities:
Derivatives, net(a)	$	54,316	$	581	$	-	$	53,735
Deferred compensation		3,145		-		3,145		-
Total Liabilities	$	57,461	$	581	$	3,145	$	53,735
MGE
Assets:
Derivatives, net	$	234	$	-	$	-	$	234
Exchange-traded investments		148		148		-		-
Total Assets	$	382	$	148	$	-	$	234
Liabilities:
Derivatives, net(a)	$	54,316	$	581	$	-	$	53,735
Deferred compensation		3,145		-		3,145		-
Total Liabilities	$	57,461	$	581	$	3,145	$	53,735
(a) These amounts are shown gross and exclude $1.0 million of collateral that was posted against derivative positions with counterparties as of March 31, 2016, and December 31, 2015.

No transfers were made in or out of Level 1 or Level 2 for the three months ended March 31, 2016.

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 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 considered unobservable and classified as Level 3. Transactions done with an over-the-counter party are on inactive markets and are therefore classified as Level 3. These transactions are valued based on quoted prices from markets with similar exchange traded transactions. FTRs are priced based upon monthly auction results for identical or similar instruments in a closed market with limited data available and are therefore classified as Level 3.

The purchased power agreement (see Footnote 8) 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.

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

	Model Input
Significant Unobservable Inputs	March 31, 2016	December 31, 2015
Basis adjustment:
On peak	96.7%	96.9%
Off peak	95.9%	95.1%
Counterparty fuel mix:
Internal generation	55% - 75%	60% - 75%
Purchased power	45% - 25%	40% - 25%

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)		2016		2015
Beginning balance	$	(53,501)	$	(53,986)
Realized and unrealized gains (losses):
Included in regulatory (assets) liabilities		(3,600)		119
Included in other comprehensive income		-		-
Included in earnings		(2,163)		(1,328)
Included in current assets		-		-
Purchases		5,301		6,162
Sales		-		-
Issuances		-		-
Settlements		(3,138)		(4,833)
Transfers in and/or out of Level 3		-		-
Balance as of March 31,	$	(57,101)	$	(53,866)
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)		2016		2015
Purchased Power Expense	$	(2,163)	$	(1,328)

(b)

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

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11.

New Accounting Pronouncements - MGE Energy and MGE.

a.

Revenue from Contracts with Customers.

In May 2014, the FASB issued authoritative guidance within the Codification's Revenue Recognition topic that provides guidance on the recognition, measurement, and disclosure of revenue from contracts with customers. This authoritative guidance will become effective January 1, 2018. MGE Energy and MGE are currently assessing the impact this pronouncement will have on their financial statements.

b.

Consolidation.

In February 2015, the FASB issued authoritative guidance within the Codification's Consolidation topic that provides guidance on the evaluation of certain legal entities for consolidation purposes. This authoritative guidance became effective January 1, 2016. This guidance had no impact on our financial statements.

c.

Debt Issuance Costs.

In April 2015, the FASB issued authoritative guidance within the Codification's Interest topic that provides guidance on the presentation of debt issuance costs in financial statements. This authoritative guidance became effective January 1, 2016, and changed the presentation of debt issuance costs on the balance sheet. Prior to the authoritative guidance, debt issuance costs were treated as a deferred asset, and beginning January 1, 2016, these costs are included as a direct deduction to the related debt liability on the consolidated balance sheet. As of March 31, 2016, assets (other deferred assets and other) and liabilities (long-term debt) decreased approximately $4.2 million as a cumulative result of the guidance. In addition, this guidance was applied retrospectively to all prior periods presented, resulting in a decrease to assets and liabilities of $4.3 million for the year ended December 31, 2015.

d.

Financial Instruments.

In January 2016, the FASB issued authoritative guidance within the Codification's Financial Instruments topic that provides guidance on the recognition and measurement of financial instruments. This authoritative guidance will become effective January 1, 2018. The impact of this guidance on our financial statements is not expected to be material.

e.

Leases.

In February 2016, the FASB issued authoritative guidance within the Leases topic that provides guidance on the classification, recognition, measurement, and disclosure of leases. This authoritative guidance will become effective January 1, 2019. MGE Energy and MGE are currently assessing the impact this pronouncement will have on their financial statements.

12.

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 2015 Annual Report on Form 10-K for additional discussion of each of these segments.

27

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

(In thousands) MGE Energy		Electric		Gas		Nonregulated Energy		Transmission Investment		All Others		Consolidation/ Elimination Entries		Consolidated Total
Three Months Ended March 31, 2016
Operating revenues	$	93,208	$	53,837	$	482	$	-	$	-	$	-	$	147,527
Interdepartmental revenues		456		5,097		10,977		-		-		(16,530)		-
Total operating revenues		93,664		58,934		11,459		-		-		(16,530)		147,527
Depreciation and amortization		(7,163)		(1,981)		(1,876)		-		(12)		-		(11,032)
Other operating expenses		(75,379)		(47,741)		(47)		(1)		(326)		16,530		(106,964)
Operating income (loss)		11,122		9,212		9,536		(1)		(338)		-		29,531
Other (deductions) income, net		196		(8)		-		2,233		21		-		2,442
Interest (expense) income, net		(2,790)		(808)		(1,463)		-		61		-		(5,000)
Income (loss) before taxes		8,528		8,396		8,073		2,232		(256)		-		26,973
Income tax (provision) benefit		(2,536)		(3,359)		(3,240)		(897)		87		-		(9,945)
Net income (loss)	$	5,992	$	5,037	$	4,833	$	1,335	$	(169)	$	-	$	17,028
Three Months Ended March 31, 2015
Operating revenues	$	98,240	$	69,928	$	1,966	$	-	$	-	$	-	$	170,134
Interdepartmental revenues		115		2,725		9,847		-		-		(12,687)		-
Total operating revenues		98,355		72,653		11,813		-		-		(12,687)		170,134
Depreciation and amortization		(7,332)		(1,642)		(1,863)		-		(12)		-		(10,849)
Other operating expenses		(79,800)		(60,068)		(50)		-		(203)		12,687		(127,434)
Operating income (loss)		11,223		10,943		9,900		-		(215)		-		31,851
Other (deductions) income, net		90		(1)		-		1,881		135		-		2,105
Interest (expense) income, net		(2,819)		(804)		(1,518)		-		50		-		(5,091)
Income (loss) before taxes		8,494		10,138		8,382		1,881		(30)		-		28,865
Income tax provision		(2,383)		(4,081)		(3,364)		(756)		(3)		-		(10,587)
Net income (loss)	$	6,111	$	6,057	$	5,018	$	1,125	$	(33)	$	-	$	18,278

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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, 2016
Operating revenues	$	93,214	$	53,847	$	482	$	-	$	-	$	147,543
Interdepartmental revenues		450		5,087		10,977		-		(16,514)		-
Total operating revenues		93,664		58,934		11,459		-		(16,514)		147,543
Depreciation and amortization		(7,163)		(1,981)		(1,876)		-		-		(11,020)
Other operating expenses*		(77,879)		(51,091)		(3,287)		(1)		16,514		(115,744)
Operating income (loss)*		8,622		5,862		6,296		(1)		-		20,779
Other (deductions) income, net*		160		(17)		-		1,336		-		1,479
Interest expense, net		(2,790)		(808)		(1,463)		-		-		(5,061)
Net income		5,992		5,037		4,833		1,335		-		17,197
Less: Net income attributable to
noncontrolling interest, net of tax		-		-		-		-		(6,252)		(6,252)
Net income attributable to MGE	$	5,992	$	5,037	$	4,833	$	1,335	$	(6,252)	$	10,945
Three Months Ended March 31, 2015
Operating revenues	$	98,245	$	69,933	$	1,966	$	-	$	-	$	170,144
Interdepartmental revenues		110		2,720		9,847		-		(12,677)		-
Total operating revenues		98,355		72,653		11,813		-		(12,677)		170,144
Depreciation and amortization		(7,332)		(1,642)		(1,863)		-		-		(10,837)
Other operating expenses*		(82,142)		(64,138)		(3,414)		-		12,677		(137,017)
Operating income*		8,881		6,873		6,536		-		-		22,290
Other (deductions) income, net*		49		(12)		-		1,125		-		1,162
Interest expense, net		(2,819)		(804)		(1,518)		-		-		(5,141)
Net income		6,111		6,057		5,018		1,125		-		18,311
Less: Net income attributable to
noncontrolling interest, net of tax		-		-		-		-		(6,553)		(6,553)
Net income attributable to MGE	$	6,111	$	6,057	$	5,018	$	1,125	$	(6,553)	$	11,758
*Amounts are shown net of the related tax expense, consistent with the presentation on the MGE Consolidated Statement of Income.

29

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 146,000 customers in Dane County, Wisconsin, including the city of Madison, and purchases and distributes natural gas to approximately 152,000 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. MGE will continue to focus on growing earnings while controlling operating and fuel costs. MGE maintains 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,

·

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, including natural gas 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,

and other factors listed in "Item 1A. Risk Factors" in our 2015 Annual Report on Form 10-K.

For the three months ended March 31, 2016, MGE Energy's earnings were $17.0 million or $0.49 per share compared to $18.3 million or $0.53 per share for the same period in the prior year. MGE's earnings for the three months ended March 31, 2016, were $10.9 million compared to $11.8 million for the same period in the prior year.

30

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

		Three Months Ended
(In thousands)		March 31,
Business Segment:		2016		2015
Electric Utility	$	5,992	$	6,111
Gas Utility		5,037		6,057
Nonregulated Energy		4,833		5,018
Transmission Investments		1,335		1,125
All Other		(169)		(33)
Net Income	$	17,028	$	18,278

Our net income during the three months ended March 31, 2016, compared to the same period in the prior year primarily reflects the effects of the following factors:

·

Gas net income decreased primarily related to a 14.5% decrease in gas retail sales reflecting lower customer demand compared to the demand resulting from the colder weather experienced in 2015. The average temperature in February 2015 was 11.2 degrees compared to 27.1 degrees in the current year. Heating degree days (a measure for determining the impact of weather during the heating season) decreased by 15.0% compared to the prior year.

·

Carrying costs incurred during construction of the Elm Road Units and WCCF were recognized by MGE Power Elm Road and MGE Power West Campus over the period allowed for recovery in rates. The recovery period ended in 2015, contributing to a reduction in nonregulated earnings in 2016.

During the first three months of 2016, the following events occurred:

2016 Rate Case Filing: In July 2015, the PSCW approved MGE's request to extend the current accounting treatment for transmission related costs through 2016, conditioned upon MGE not filing a base rate case for 2016. This accounting treatment will allow MGE to reflect any differential between transmission costs reflected in rates and actual costs incurred in its next rate case filing, which occurred in April 2016.

2016 Annual Fuel Proceeding: In August 2015, the PSCW approved a $0.00256/kWh fuel credit that began on September 1, 2015, and will continue throughout 2016. The fuel credit established a mechanism to return fuel savings to electric customers as a bill credit. MGE returned $1.9 million of electric fuel-related savings in customer bill credits during the period from January 1, 2016, through March 31, 2016.

In January 2016, the PSCW lowered MGE's 2016 fuel rules monitored costs by $14.8 million as a result of continued lower projected fuel costs in 2016. The return of the fuel savings to customers for 2016 will be addressed during the PSCW's annual review during 2016 of 2015 fuel costs. MGE will defer these fuel savings until a determination is made by the PSCW. As of March 31, 2016, MGE has deferred $3.6 million of these 2016 fuel rules monitored costs.

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

2017 Rate Case Filing: In April 2016, MGE filed an application with the PSCW requesting a 1.7% increase to electric rates and a 3.7% increase to gas rates for 2017. The proposed electric and gas rate increases cover costs primarily associated with the state's electric transmission and MGE's natural gas system infrastructure improvements. In its application, MGE has also proposed mechanisms to address potential 2018 electric and gas rate changes, including a rate adjustment for limited issues and escrow accounting on certain costs.

ATC Return on Equity: Several parties have filed complaints with the FERC seeking to reduce the base return on equity (ROE) used by MISO transmission owners, including ATC. Any change to ATC's ROE could result in lower equity earnings and distributions from ATC in the future. We derived approximately 7.8% and 6.0% of our net income for the three months ended March 31, 2016 and 2015 respectively, from our investment in ATC. See "Other Matters" below for additional information concerning ATC.

Loss of Industrial Customer: In November 2015, a large industrial customer announced its intention to relocate its operations out of state and to close its manufacturing facilities within our service territory. That closure is expected to occur in early 2017. This customer contributed approximately $0.8 million of pre-tax earnings for the three months ended March 31, 2016 and 2015. Our rate case filing for 2017 addresses the effects of the closure. There could be some impact on our electric revenues during 2016 if the customer's operations are curtailed as a result of the impending closure.

31

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 the Elm Road Units, from which we derive approximately 44% of our electric generating capacity. We would expect to seek and receive recovery of any such costs in rates; however, it is difficult to estimate the amount of such costs due to the uncertainty as to the timing and form of the legislation and rules, and the scope and time of the recovery of costs in rates, which may lag the incurrence of those costs.

EPA's Clean Power Plan: In 2015, the EPA published its Clean Power Plan rule setting guidelines and approval criteria for states to use in developing plans to control GHG emissions from existing fossil fuel-fired EGUs and systems. Implementation of the rule is expected to have a direct impact on coal and natural gas fired generating units, including possible changes in dispatch and additional operating costs. MGE is currently evaluating the rule and its requirements. Although the implementation of the rule is presently stayed as a result of a February 9, 2016, U.S. Supreme Court ruling, compliance with the rule's requirements, including the yet-to-be-developed state implementation plan, could have a material impact on MGE if the rule is upheld and becomes effective.

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 and investment returns have experienced volatility since the end of the year which could affect the value of the pension and postretirement benefit obligations. The changes in the discount rates and value of plan assets are not expected to have an impact on the income statements for 2016. However, these changes may affect benefit costs in future years. MGE expects changes in the cost for employee benefit plans will be factored into future rate actions.

Future Generation: During the first quarter of 2016, MGE entered into an agreement with WPL under which MGE may acquire up to 50 MW of capacity in a gas-fired generating plant to be constructed by WPL at its Riverside Energy Center in Beloit, Wisconsin, during the five-year period following the in-service date of the plant. The plant is expected to be completed by early 2020. The same agreement contemplates that MGE and WPL will negotiate a further agreement under which MGE may reduce its obligation to pay certain capital expenditures (other than SCR-related expenditures) at Columbia prior to the in-service date of the Riverside gas-fired generating plant in exchange for a proportional reduction in MGE's ownership in Columbia. MGE has accrued $4.5 million of 2016 capital expenditures in construction work in progress related to Columbia, that MGE could forgo as part of the agreement with WPL. MGE currently owns 22% of Columbia.

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, 2016, there were no borrowings outstanding under MGE Energy's or MGE's lines of credit.

Financing Plans: MGE has a $30 million medium-term note maturing in 2017 and expects to refinance this debt with new long-term debt in 2016.

The following discussion is based on the business segments as discussed in Footnote 12 of the Notes to Consolidated Financial Statements.

32

Three Months Ended March 31, 2016 and 2015

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)
		Three Months Ended March 31,				Three Months Ended March 31,
(In thousands)		2016		2015	% Change	2016	2015	% Change
Residential	$	33,304	$	34,247	(2.8)%	201,090	206,813	(2.8)%
Commercial		50,497		51,178	(1.3)%	442,319	441,435	0.2 %
Industrial		4,404		4,692	(6.1)%	57,222	58,723	(2.6)%
Other-retail/municipal		8,238		9,161	(10.1)%	84,949	101,423	(16.2)%
Total retail		96,443		99,278	(2.9)%	785,580	808,394	(2.8)%
Sales to the market		142		296	(52.0)%	10,619	7,933	33.9 %
Deferral of fuel savings		(3,581)		-	-  %	-	-	-  %
Adjustments to revenues		204		(1,334)	115.3 %	-	-	-  %
Total	$	93,208	$	98,240	(5.1)%	796,199	816,327	(2.5)%

Electric operating revenues decreased $5.0 million or 5.1% for the three months ended March 31, 2016, compared to the same period in 2015, due to the following:

(In millions)
Deferral of fuel savings/fuel credit	$	(5.5)
Volume		(1.4)
Sales to the market		(0.2)
Other		0.6
Adjustments to revenues		1.5
Total	$	(5.0)

In July 2015, the PSCW authorized MGE to freeze 2016 rates at 2015 levels for retail electric customers.

·

Deferral of fuel savings/fuel credit. In January 2016, the PSCW lowered MGE's 2016 fuel rules monitored costs by $14.8 million as a result of continued lower projected fuel costs in 2016. As of March 31, 2016, MGE has deferred $3.6 million of these 2016 fuel rules monitored costs. During the three months ended March 31, 2016, customers received a fuel credit, that was approved in August 2015, on their bill related to the fuel savings of $1.9 million, which decreased electric revenues when compared to the same period in the prior year.

·

Volume. During the three months ended March 31, 2016, there was a 2.8% decrease in total retail sales volumes compared to the same period in the prior year driven by lower customer demand.

·

Adjustments to revenue. The adjustments to revenues amount includes the elimination of carrying costs for the Elm Road Units and the WCCF that were collected in electric rates ending in 2015, which were recognized as operating revenues in our Nonregulated Energy Operations segment.

MGE leases electric generating capacity from MGE Power Elm Road. MGE collects in rates the lease payments associated with the electric generating capacity as authorized by the PSCW. Any differential between estimated lease payments collected in rates and actual lease payments paid to MGE Power Elm Road are included in adjustments to revenues.

Electric fuel and purchased power

Electric fuel and purchased power costs reflect an increase in internal generation volumes offset by a decrease in the volume of purchased power when compared to the prior period. Adjustments related to the regulatory recovery for fuel costs, known as fuel rules, decreases purchased power expense. These items are explained below.

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Fuel for electric generation

The expense for fuel for internal electric generation increased $0.1 million during the three months ended March 31, 2016, compared to the same period in the prior year, due to the following:

(In millions)
Increase in volume	$	1.4
Decrease in per-unit cost		(1.3)
Total	$	0.1

This increase in expense reflects a 13.5% increase in internal generation volume delivered to the system primarily as a result of increased generation at WCCF based on market prices, partially offset by an 11.0% decrease in per-unit cost of internal electric generation, reflective of lower natural gas prices.

Purchased power

Purchased power expense decreased $8.2 million during the three months ended March 31, 2016, compared to the same period in the prior year, due to the following:

(In millions)
Decrease in volume	$	(4.7)
Increase in per-unit cost		0.8
Change in fuel rule adjustments, net of recoveries		(4.3)
Total	$	(8.2)

The decrease in expense (before fuel rules adjustments) reflects a 22.8% decrease in the volume of power purchased from third parties primarily as a result of the increased internal generation, partially offset by a 5.0% increase in the per-unit cost of purchased power.

Under fuel rules, MGE is required to defer electric fuel-related costs that fall outside a 2% cost tolerance band around the amount used in the most recent rate proceeding. Any fuel rules adjustments are reflected in purchased power expense.

Electric operating and maintenance expenses

Electric operating and maintenance expenses increased $1.5 million during the three months ended March 31, 2016, compared to the same period in 2015. The following changes contributed to the net change:

(In millions)
Increased production expenses	$	0.6
Increased other costs		0.4
Increased distribution expenses		0.3
Increased transmission costs		0.2
Total	$	1.5

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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,
		2016		2015	% Change	2016	2015	% Change
Residential	$	31,250	$	39,688	(21.3)%	43,575	50,860	(14.3)%
Commercial/Industrial		21,108		28,596	(26.2)%	37,355	43,827	(14.8)%
Total retail		52,358		68,284	(23.3)%	80,930	94,687	(14.5)%
Gas transportation		1,356		1,468	(7.6)%	21,453	24,994	(14.2)%
Other revenues		123		176	(30.1)%	-	-	-  %
Total	$	53,837	$	69,928	(23.0)%	102,383	119,681	(14.5)%
Heating degree days (normal 3,574)						3,258	3,834	(15.0)%
Average rate per therm of
retail customer	$	0.647	$	0.721	(10.3)%

Gas revenues decreased $16.1 million or 23.0% for the three months ended March 31, 2016, compared to the same period in 2015. These changes are related to the following factors:

(In millions)
Volume	$	(8.5)
Rate/PGA changes		(7.4)
Transportation and other effects		(0.2)
Total	$	(16.1)

In July 2015, the PSCW authorized MGE to freeze 2016 rates at 2015 levels for retail gas customers.

·

Volume. For the three months ended March 31, 2016, retail gas deliveries decreased 14.5% compared to the same period in the prior year due, at least in part, to warmer weather in the current period compared to the prior period.

·

Rate/PGA changes. 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. Changes in PGA recoveries affect revenues, but do not impact net income.

The average retail rate per therm for the three months ended March 31, 2016, decreased 10.3% compared to the same period in 2015, reflecting a $7.6 million decrease in natural gas commodity costs (PGA), offset by an increase in fixed rate charges.

Cost of gas sold

For the three months ended March 31, 2016, cost of gas sold decreased by $14.4 million, compared to the same period in the prior year. The cost per therm of natural gas decreased 18.7%, which resulted in $7.5 million of decreased expense. The volume of gas purchased decreased 14.8%, which resulted in $6.9 million of decreased expense.

Gas operating and maintenance expenses

Gas operating and maintenance expenses increased by $0.5 million for the three months ended March 31, 2016, compared to the same period in 2015. The following changes contributed to the net change:

(In millions)
Increased distribution expenses	$	0.2
Increased administrative and general costs		0.2
Increased other costs		0.1
Total	$	0.5

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Nonregulated Energy Operations - MGE Energy and MGE

The nonregulated energy operations are conducted through MGE Energy's subsidiaries: MGE Power Elm Road (the Elm Road Units) and MGE Power West Campus (WCCF), which have been formed to own and lease electric generating capacity to assist MGE. For the three months ended March 31, 2016 and 2015, net income at the nonregulated energy operations segment was $4.8 million and $5.0 million, respectively. Carrying costs incurred during construction of the Elm Road Units and WCCF were recognized by MGE Power Elm Road and MGE Power West Campus over the period allowed for recovery in rates. The recovery period ended in 2015, contributing to a reduction in nonregulated earnings in 2016.

Transmission Investment Operations - MGE Energy and MGE

Transmission investment other income

For the three months ended March 31, 2016 and 2015, other income at the transmission investment segment was $2.2 million and $1.9 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 and "Other Matters" below for additional information concerning ATC and summarized financial information regarding ATC.

Consolidated Income Taxes - MGE Energy and MGE

MGE Energy's effective income tax rate for the three months ended March 31, 2016 and 2015, was 36.9% and 36.7%, respectively. MGE's effective income tax rate for the three months ended March 31, 2016 and 2015, was 36.8% and 36.6%, respectively. The increase in the effective tax rate is due in part to a lower estimated domestic manufacturing deduction and lower estimated AFUDC equity earnings in 2016.

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 with respect to MGE 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, which holds our investment in ATC. 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)		2016		2015
MGE Power Elm Road	$	3.8	$	4.1
MGE Power West Campus		1.8		1.9
MGE Transco (a)		0.7		0.6

(a)

MGE's ownership interest is expected to decline below a majority during 2016 as a result of continued funding of ATC capital contributions by MGE Energy, and may be completely eliminated in favor of MGE Energy if the PSCW accepts a staff recommendation that MGE transfer its interest in ATC to MGE Energy. The recommendation arose in the context of requests for regulatory approvals by several owners of ATC in connection with a reorganization of ATC designed to separate its existing Wisconsin-based transmission operations from its non-Wisconsin transmission development activities. The change will have no effect on MGE Energy's consolidated financial statements. No gain or loss is expected to be recognized on the date MGE ceases to have a controlling financial interest.

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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, 2016, except as noted below. Further discussion of the contractual obligations and commercial commitments is included in 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 2015 Annual Report on Form 10-K.

Purchase Contracts - MGE Energy and MGE

See Footnote 7.c. of Notes to Consolidated Financial Statements for a description of commitments at March 31, 2016, that MGE Energy and MGE have entered with respect to various commodity transportation and storage contracts to meet their obligations to deliver natural gas to customers.

Liquidity and Capital Resources

MGE Energy and MGE have adequate liquidity to fund future operations and capital expenditures over the next twelve months. Available resources include cash and cash equivalents, operating cash flows, liquid assets, borrowing capacity under revolving credit facilities, and access to equity and debt capital markets.

Cash Flows

The following summarizes cash flows for MGE Energy and MGE during the three months ended March 31, 2016 and 2015:

		MGE Energy				MGE
(In thousands)		2016		2015		2016		2015
Cash provided by/(used for):
Operating activities	$	43,729	$	34,640	$	43,322	$	36,499
Investing activities		(16,496)		(11,861)		(16,247)		(11,728)
Financing activities		(11,286)		(17,831)		(17,026)		(12,177)

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, 2016, was $43.7 million, an increase of $9.1 million when compared to the same period in the prior year.

MGE Energy's net income decreased $1.3 million for the three months ended March 31, 2016, when compared to the same period in the prior year.

Working capital accounts (excluding prepaid and accrued taxes) resulted in $14.2 million in cash provided by operating activities for the three months ended March 31, 2016, primarily due to decreased gas inventories and increased other current liabilities. The increase in current liabilities includes a fuel credit, that was approved in August 2015, of $1.9 million that customers received on their bill January through March 2016 and $3.5 million of deferred fuel related cost savings to be returned to customers.

Working capital accounts (excluding prepaid and accrued taxes) resulted in $1.0 million in cash used for operating activities for the three months ended March 31, 2015, primarily due to decreased gas inventories and decreased unbilled revenues, partially offset by decreased accounts payable, decreased other current liabilities, and increased receivables.

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MGE

Cash provided by operating activities for the three months ended March 31, 2016, was $43.3 million, an increase of $6.8 million when compared to the same period in the prior year.

Net income decreased $1.1 million for the three months ended March 31, 2016, when compared to the same period in the prior year.

Working capital accounts (excluding prepaid and accrued taxes) resulted in $14.1 million in cash provided by operating activities for the three months ended March 31, 2016, primarily due to decreased gas inventories and increased current liabilities. The increase in current liabilities includes a fuel credit, that was approved in August 2015, of $1.9 million that customers received on their bill January through March 2016 and $3.5 million of deferred fuel related cost savings to be returned to customers.

Working capital accounts (excluding prepaid taxes and accrued taxes) resulted in $7.8 million in cash provided by operating activities for the three months ended March 31, 2015, primarily due to decreased unbilled revenues, decreased gas inventories, and decreased receivables, partially offset by decreased other current liabilities and decreased accounts payable.

Cash Used for Investing Activities

MGE Energy

MGE Energy's cash used for investing activities increased $4.6 million for the three months ended March 31, 2016, when compared to the same period in the prior year.

Capital expenditures for the three months ended March 31, 2016, were $15.6 million. This amount represents an increase of $4.1 million from the expenditures made in the same period in the prior year. This increase primarily reflects increased expenditures on electric and gas distribution assets.

MGE

MGE's cash used for investing activities increased $4.5 million for the three months ended March 31, 2016, when compared to the same period in the prior year.

Capital expenditures for the three months ended March 31, 2016, were $15.6 million. This amount represents an increase of $4.1 million from the expenditures made in the same period in the prior year. This increase primarily reflects increased expenditures on electric and gas distribution assets.

Cash Used for Financing Activities

MGE Energy

Cash used for MGE Energy's financing activities was $11.3 million for the three months ended March 31, 2016, compared to $17.8 million of cash used for MGE Energy's financing activities in the three months ended March 31, 2015.

For the three months ended March 31, 2016, dividends paid were $10.2 million compared to $9.8 million in the prior year. This increase was a result of a higher dividend per share ($0.295 vs. $0.283).

For the three months ended March 31, 2015, net short term debt repayments were $7.0 million. There were no short term debt repayments in the current year.

MGE

During the three months ended March 31, 2016, cash used for MGE's financing activities was $17.0 million compared to $12.2 million of cash used for MGE's financing activities in the prior year.

Dividends paid from MGE to MGE Energy were $10.0 million for the three months ended March 31, 2016. No cash dividends were paid from MGE to MGE Energy for the three months ended March 31, 2015.

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Distributions to parent from noncontrolling interest, which represent distributions from MGE Power Elm Road and MGE Power West Campus, were $6.5 million for the three months ended March 31, 2016, compared to $6.8 million in the prior year.

For the three months ended March 31, 2016, equity contributions received from MGE Power West Campus and MGE Transco were $0.5 million compared to $2.7 million in the prior year.

For the three months ended March 31, 2015, net short term debt repayments were $7.0 million. There were no short term debt repayments in the current year.

Capitalization Ratios^(a)

MGE Energy's capitalization ratios were as follows:

	MGE Energy
	March 31, 2016	December 31, 2015
Common shareholders' equity	64.1 %	63.8 %
Long-term debt(b)	35.9 %	36.2 %

(a)

Reflects application of new accounting pronouncement. See Footnote 11.c. of the Notes to Consolidated Financial Statements for additional information regarding the treatment of debt issuance costs.

(b)

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, 2016, capital expenditures for MGE Energy and MGE totaled $15.6 million, which included $15.2 million of capital expenditures for utility operations.

Credit Ratings

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

None of MGE Energy's or MGE's borrowings are 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, 2016. Further discussion of environmental matters is included in MGE Energy's and MGE's 2015 Annual Report on Form 10-K and Footnote 7.a. of Notes to Consolidated Financial Statements in this Report.

Sulfur Dioxide (SO₂) NAAQS

In March 2015, the EPA identified MGE's Columbia Plant in Columbia County as a large stationary source of SO₂ that may exceed the one hour SO₂ NAAQS standard and was subject to a State of Wisconsin proposed county attainment/nonattainment determination. In September 2015, Wisconsin sent a letter to the EPA proposing that Columbia County be designated as being in attainment for SO₂ NAAQS based on recent modeling demonstrating that SO₂ pollution controls on the Columbia Plant had brought the county into attainment. In February 2016, the EPA sent a response letter to the State of Wisconsin indicating agreement with Wisconsin's September 2015 recommended designation for Columbia County, and has given a preliminary classification of Columbia County as an unclassifiable/attainment area. The EPA stated in their response letter that they intend to finalize designations by July 2, 2016. MGE will continue to monitor developments until final designations are made, however, we do not anticipate any material costs from this rule.

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Clean Air Visibility Rule (CAVR)

Columbia may be subject to the best available retrofit technology (BART) regulations, a subsection of the EPA's Clean Air Visibility Rule (CAVR), which may require pollution control retrofits. Columbia's pollution control upgrades and the EPA's stance that compliance with the CSAPR equals compliance with BART should mean that Columbia will not need to do additional work to meet BART requirements. In February 2016, the EPA submitted a proposed revision to the rule. The proposed revision would move state plan due dates from July 2018 to July 2021. This would allow for states to coordinate their CAVR compliance with other compliance efforts. If this proposed revision is finalized, it would reduce the chances that CAVR will be material for MGE. At this time, however, the BART regulatory obligations, compliance strategies, and costs remain uncertain due to the continued legal uncertainty surrounding CSAPR.

Other Matters

ATC

In 2013, several parties filed a complaint with the FERC seeking to reduce the base return on equity (ROE) used by MISO transmission owners, including ATC, "due to changes in the capital markets." The complaint alleges that the MISO ROE should not exceed 9.15%, the equity components of hypothetical capital structures should be restricted to 50%, and the relevant incentive ROE adders should be discontinued. MISO's base ROE is 12.38% and ATC's base ROE is 12.2%. In December 2015, an administrative law judge issued an initial decision that would reduce the transmission owners' base ROE to 10.32%. That initial decision will be reviewed by FERC and it is anticipated FERC will issue an order on this issue by October 2016. In February 2015, a second complaint was filed with the FERC requesting a reduction in the base ROE used by MISO transmission owners, including ATC, to 8.67%, with a refund effective date retroactive to the filing date of the complaint. An initial decision from the administrative law judge is expected by June 30, 2016.

In January 2015, FERC accepted the transmission owner's request for a 50 basis-point incentive ROE adder for participating in MISO. The adder became effective January 6, 2015, subject to refund, and FERC accepted the transmission owner's request to defer collection of the adder pending the outcome of the first ROE complaint proceeding.

Any change to ATC's ROE could result in lower equity earnings and distributions from ATC in the future. Our share of ATC's earnings for 2016, 2015, and 2014 reflects a pre-tax charge of $0.3 million, $2.4 million, and $0.7 million, respectively, recorded by ATC for this matter representing its estimate of its refund liability for the period of November 2013 through December 2015. We derived approximately 7.8% and 6.0% of our net income for the three months ended March 31, 2016 and 2015, respectively, from our investment in ATC.

New Accounting Principles

See Footnote 11 of Notes to Consolidated Financial Statements for discussion of new accounting pronouncements.

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Item 3. Quantitative and Qualitative Disclosures About Market Risk.

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

Commodity Price Risk

MGE has commodity price risk exposure with respect to the price of natural gas, electricity, coal, emission credits, and oil. MGE'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 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. 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 is 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 is required to defer costs, less any excess revenues, if the actual electric fuel costs exceed 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 2016, fuel and purchased power costs included in MGE's base fuel rates are $108.2 million. See Footnote 9.b. of the Notes to Consolidated Financial Statements for additional information.

MGE recovers the cost of natural gas in its gas utility 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 utility 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, 2016, the cost basis of these instruments exceeded their fair value by $1.0 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 sheets as a regulatory asset/liability.

MGE has also entered into a 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, 2016, reflects a loss position of $55.9 million.

Interest Rate Risk

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

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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, 2016, 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 1,682 square miles in Wisconsin. Based on results for the year ended December 31, 2015, 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.

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Item 4. Controls and Procedures.

During the first quarter of 2016, 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, 2016, 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, 2016, 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.

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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 7.a. and 7.b. 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) of Shares That May Yet Be Purchased Under the Plans or Programs*
January 1-31, 2016	19,475	$	46.83	-	-
February 1-29, 2016	16,825		50.97	-	-
March 1-31, 2016	65,290		50.15	-	-
Total	101,590	$	49.65	-	-

* 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.

10.1*

Form of Amendment to Severance Agreement.

10.2*

Form of Severance Agreement for Officers hired on or after January 1, 2012.

10.3*

Form of Income Continuation Agreement as revised January 1, 2016.

12

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

44

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, 2016, filed by the following officers for the following companies:

31.1

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

31.2

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

31.3

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

31.4

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

Certifications Pursuant to Section 1350 of Chapter 63 of Title 18 United States Code (Sarbanes-Oxley Act of 2002) as to the Quarterly Report on Form 10-Q for the quarter ended March 31, 2016, 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

*Indicates a management contract or compensatory plan or arrangement.

45

Signatures - MGE Energy, Inc.

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

	MGE ENERGY, INC.
Date: May 5, 2016	/s/ Gary J. Wolter
	Gary J. Wolter Chairman, President and Chief Executive Officer (Duly Authorized Officer)
Date: May 5, 2016	/s/ Jeffrey C. Newman
	Jeffrey C. Newman Senior Vice President, Chief Financial Officer, Secretary and Treasurer (Chief Financial and Accounting Officer)

46

Signatures - Madison Gas and Electric Company

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

	MADISON GAS AND ELECTRIC COMPANY
Date: May 5, 2016	/s/ Gary J. Wolter
	Gary J. Wolter Chairman, President and Chief Executive Officer (Duly Authorized Officer)
Date: May 5, 2016	/s/ Jeffrey C. Newman
	Jeffrey C. Newman Senior Vice President, Chief Financial Officer, Secretary and Treasurer (Chief Financial and Accounting Officer)

47

EX-10

EXHIBIT 10.1

SEVERANCE AGREEMENT

AMENDMENT

Madison Gas and Electric Company (the “Company”) and

 (the “Employee”) entered into a Severance Agreement (the “Agreement”), dated     , pursuant to which Employee is entitled to certain severance payments and benefits under specified circumstances following Employee’s separation from service with the Company.  For good and valuable consideration the receipt and sufficiency are hereby acknowledged, the Company and Employee desire to amend the Agreement, effective as of December 30, 2010, as follows:

1.

Section 3(b) of the Agreement is deleted in its entirety, and subsection (c) of Section 3 is relettered subsection (b) accordingly.

2.

Section 4 of the Agreement is amended in its entirety to read as follows:

4.

Limitation on Payments.  Anything in this Agreement to the contrary notwithstanding, in the event that Employee becomes entitled to payments or benefits under this Agreement and the payments or benefits payable to Employee under this Agreement, when combined with other payments and benefits received or to be received by the Employee from the Company or any corporation affiliated with the Company within the meaning of Section 1504 of the Code, in the opinion of the Company, would constitute “parachute payments” within the meaning of Section 280G(b)(2) of the Code, then the amounts payable to Employee under this Agreement shall be reduced to an amount, the present value of which (when combined with the present value of any other payments or benefits otherwise received or to be received by Employee from the Company (or any corporation affiliated with the Company within the meaning of Section 1504 of the Code) that would be deemed “parachute payments”) is equal to 2.99 times the “base amount” within the meaning Section 280G(b)(3).    

3.

Section 12(b) is amended by deleting the words “or provide any benefit to Employee and Employee's dependents or other beneficiaries, as the case may be, under paragraphs (a) and (b) of Section 3, the Company shall pay all amounts, and provide all benefits, to Employee and Employee's dependents or other beneficiaries, as the case may be, that the Company would be required to pay or provide pursuant to paragraphs (a) and (b) of Section 3” and inserting in lieu thereof the following words:

under Section 3(a), the Company shall pay all amounts that the Company would be required to pay pursuant to Section 3(a)

ACCEPTED AND AGREED to this

 day of February, 2011.

MADISON GAS AND ELECTRIC COMPANY

EMPLOYEE

by:

Date

2

EX-10

EXHIBIT 10.2

SEVERANCE AGREEMENT

THIS AGREEMENT is entered into as of the _____day of __________, 20___ by and between Madison Gas and Electric Company, a Wisconsin corporation (the "Company"), and ______________ (the "Employee"), and shall be effective as of _____________ ___, 20___.  This Agreement supersedes any and all previous Severance Agreements entered into by and between the Employee and the Company.

W I T N E S S E T H

WHEREAS, Employee currently serves as a key employee of the Company and the services and knowledge of Employee are valuable to the Company in connection with the management of the Company's business; and

WHEREAS, the Board of Directors of the Company (the "Board") has determined that it is in the best interests of the Company and its shareholders to secure Employee's continued services and to ensure Employee's continued dedication and objectivity in the event of any threat or occurrence of, or negotiation or other action that could lead to, or create the possibility of, a Change in Control (as defined in Section 1) of the Company, without concern as to whether Employee might be hindered or distracted by personal uncertainties and risks created by any such possible Change in Control, and to encourage Employee's full attention and dedication to the Company, the Board has authorized the Company to enter into this Agreement [offering severance pay in the event of certain involuntary terminations of employment].

NOW, THEREFORE, for and in consideration of the premises and the mutual covenants and agreements herein contained, the Company and Employee hereby agree as follows:

1.

Definitions.  As used in this Agreement, the following terms shall have the respective meanings set forth below:

(a)  "Cause" means (1) a material breach by Employee of those duties and responsibilities of Employee which do not differ in any material respect from the duties and responsibilities of Employee during the 90-day period immediately prior to a Change in Control (other than as a result of incapacity due to physical or mental illness) which is demonstrably willful and deliberate on Employee's part, committed in bad faith or without reasonable belief that such breach is in the best interests of the Company, and is not remedied in a reasonable period of time after receipt of written notice from the Company specifying such breach or (2) the commission by Employee of a felony involving moral turpitude.

(b)  "Change in Control" means the occurrence of any of the following events:

(1)  the acquisition by any individual, entity or group (a "Person"), including any "person" within the meaning of Section 13(d)(3) or 14(d)(2) of the Securities Exchange Act of 1934, as amended (the "Exchange Act"), of beneficial ownership within the meaning of Rule 13d-3 promulgated under the Exchange Act, of 20% or more of either (i) the then outstanding shares of common stock of the Company (the "Outstanding Company Common Stock") or (ii) the combined voting power of the then outstanding securities of the Company entitled to vote generally in the election of directors (the "Outstanding Company Voting Securities"); provided, however, that the following acquisitions shall not constitute a Change in Control:

(A)  any acquisition directly from the Company (excluding any acquisition resulting from the exercise of a conversion or exchange privilege in respect of outstanding convertible or exchangeable securities),

(B)  any acquisition by the Company,

(C)  any acquisition by an employee benefit plan (or related trust) sponsored or maintained by the Company or any corporation controlled by the Company,

(D)  any acquisition by any corporation pursuant to a reorganization, merger or consolidation involving the Company, if, immediately after such reorganization, merger or consolidation, each of the Shareholder Continuity Condition (as defined below), the Beneficial Ownership Condition (as defined below) and the Board of Directors Continuity Condition (as defined below) shall be satisfied;

and provided further that, for purposes of clause (B), if any Person (other than the Company or any employee benefit plan (or related trust) sponsored or maintained by the Company or any corporation controlled by the Company) shall become the beneficial owner of 20% or more of the Outstanding Company Common Stock or 20% or more of the Outstanding Company Voting Securities by reason of an acquisition by the Company and such Person shall, after such acquisition by the Company, become the beneficial owner of any additional shares of the Outstanding Company Common Stock or any additional Outstanding Voting Securities and such beneficial ownership is publicly announced, such additional beneficial ownership shall constitute a Change in Control;

2

(2)  individuals who, as of the date hereof, constitute the Board (the "Incumbent Board") cease for any reason to constitute at least a majority of such Board; provided, however, that any individual who becomes a director of the Company subsequent to the date hereof whose election, or nomination for election by the Company's shareholders, was approved by the vote of at least a majority of the directors then comprising the Incumbent Board shall be deemed to have been a member of the Incumbent Board; and provided further, that no individual who was initially elected as a director of the Company as a result of an actual or threatened election contest, as such terms are used in Rule 14a-11 of Regulation 14A promulgated under the Exchange Act, or any other actual or threatened solicitation of proxies or consents by or on behalf of any Person other than the Board shall be deemed to have been a member of the Incumbent Board;

(3)  the approval by the shareholders of the Company of a reorganization, merger or consolidation unless, in any such case, immediately after such reorganization, merger or consolidation each of the Shareholder Continuity Condition, the Beneficial Ownership Condition and the Board of Directors Continuity Condition shall be satisfied; or

(4)  approval by the shareholders of the Company of (i) a plan of complete liquidation or dissolution of the Company or (ii) the sale or other disposition of all or substantially all of the assets of the Company other than to a corporation with respect to which, immediately after such sale or other disposition each of, the Shareholder Continuity Condition, the Beneficial Ownership Condition and the Board of Directors Continuity Condition shall be satisfied.

For purposes of this Section 1 (b), the "Shareholder Continuity Condition" shall be satisfied in connection with a transaction if at least 60% of the then outstanding shares of common stock of the corporation resulting from such transaction and at least 60% of the combined voting power of the then outstanding securities of such corporation entitled to vote generally in the election of directors is then beneficially owned, directly or indirectly, by all or substantially all of the individuals or entities who were the beneficial owners, respectively, of the Outstanding Company Common Stock and the Outstanding Company Voting Securities immediately prior to such transaction and in substantially the same proportions relative to each other as their ownership, immediately prior to such transaction, of the Outstanding Company Common Stock and the Outstanding Company Voting Securities, as the case may be.

For purposes of this Section 1 (b), the "Beneficial Ownership Condition" shall be satisfied in connection with a transaction if no Person (other than the Company, any employee benefit plan (or related trust) sponsored or maintained by the Company or the corporation resulting from such transaction (or any corporation controlled by the Company) and any Person which beneficially owned, immediately prior to such

3

transaction, directly or indirectly, 20% or more of the Outstanding Company Common Stock or the Outstanding Company Voting Securities, as the case may be) beneficially owns, directly or indirectly, 20% or more of the then outstanding shares of common stock of such corporation or 20% or more of the combined voting power of the then outstanding securities of such corporation entitled to vote generally in the election of directors.

For purposes of this Section 1(b), the "Board of Directors Continuity Condition" shall be satisfied in connection with a transaction if at least a majority of the members of the board of directors of the corporation resulting from such transaction were members of the Incumbent Board at the time of the execution of the initial agreement or action of the Board providing for such transaction.

(c)  "Date of Separation" means the effective date on which the Employee has experienced a Separation from Service.  

(d)  "Disability" means the Employee’s inability to engage in any substantial gainful activity by reason of any medically determinable physical or mental impairment that can be expected to result in death or can be expected to last for a continuous period of not less than 12 months.  

(e)  "Good Reason" means, without Employee's express written consent, the occurrence of any of the following events after a Change in Control:

(1)  a material diminution in the Employee’s base compensation;

(2)  a material diminution in the Employee’s authority, duties or responsibilities;

(3)  a material diminution in the authorities, duties or responsibilities of the supervisor to whom the Employee is required to report;

(4)  a material diminution in the budget over which the Employee retains authority; or

(5)  a material change in the geographic location at which the Employee must perform services;

provided, however, that the Employee must notify the Company of the Employee’s intention to terminate his or her employment by written notice in accordance with Section 11 of this Agreement; and provided, further, that:

4

(i)  such notice shall be provided to the Company within ninety (90) days of the initial existence of such event; and

(ii)  the Company shall have thirty (30) days to cure such event after receipt of such notice.

(f)  "Nonqualifying Separation" means Employee's Separation from Service (1) by the Company for Cause, (2) by Employee for any reason other than a Good Reason, (3) as a result of Employee's death or (4) by the Company due to Employee's absence from Employee's duties with the Company on a full-time basis for at least 180 consecutive days as a result of Employee's incapacity due to physical or mental illness.

(g)  "Separation from Service" means a termination of services provided by Employee to the Company, as determined by the Company in accordance with Treasury Regulation section 1.409A-1(h).  In determining whether Employee has experienced a Separation from Service, the following provisions shall apply:

(1)  Subject to subsection (2) below, Employee’s Separation from Service shall occur when Employee has experienced a termination of employment with the Company.  Employee shall be considered to have experienced a termination of employment when the facts and circumstances indicate that Employee and the Company reasonably anticipate that either:

(i)  no further services will be performed for the Company after a certain date; or

(ii)  that the level of bona fide services Employee will perform for the Company after such date (whether as an employee or consultant) will permanently decrease to no more than 20% of the average level of bona fide services performed by Employee (whether as an employee or consultant) over the immediately preceding 36-month period (or the full period of services to the Company if Employee has been providing services to the Company for less than 36 months).

(2)  If Employee is on military leave, sick leave, or other bona fide leave of absence, the employment relationship between Employee and the Company shall be treated as continuing intact, provided that the period of such leave does not exceed six months, or if longer, so long as Employee retains a right to reemployment with the Company under an applicable statute or by contract.  If the period of a military leave, sick leave, or other bona fide leave of absence exceeds six months and Employee does not retain a right to reemployment under an applicable statute or by contract, the employment relationship shall be considered to be terminated for purposes of this Agreement as of the first day immediately

5

following the end of such six-month period.  In applying the provisions of this paragraph, a leave of absence shall be considered a bona fide leave of absence only if the leave of absence is approved by the Company and there is a reasonable expectation that Employee will return to perform services for the Company.

(h)  "Termination Period" means the period of time beginning with a Change in Control and ending on the earliest to occur of (1) Employee's 70th birthday, (2) Employee's death, and (3) that date which is 24 months following such Change in Control.

2.  Obligations of Employee.  (a)  Employee agrees that in the event any person or group attempts a Change in Control, Employee shall not voluntarily leave the employ of the Company without Good Reason (i) until such attempted Change in Control terminates or (ii) if a Change in Control shall occur, until 90 days following such Change in Control.  For purposes of the foregoing subsection (i), Good Reason shall be determined as if a Change in Control had occurred when such attempted Change in Control became known to the Board.  

(b)  Employee acknowledges and agrees that (i) all records and other material not released to the general public and (ii) all trade secrets, confidential and proprietary information, unpublished data and information, in each case relating to the operations, services and business of the Company, whether reduced to writing or not ("Confidential Material"), are confidential and are the sole property of the Company.  Employee agrees that Employee will not disclose any Confidential Material to any person or entity, either during or subsequent to Employee's employment by the Company, nor will Employee use any Confidential Material, except in the regular course of Employee's employment by the Company, without the Company's written consent.  Employee agrees not to make use of the Confidential Material, except on behalf of the Company.  Upon termination of Employee's employment, Employee agrees to surrender all Confidential Material and any copies thereof as may be in possession or under control of Employee.

[(c) Except as compelled by legal process, Employee agrees not to make any defamatory or maliciously false statements or remarks, verbally or in writing, regarding the Company.]

3.  Payments Upon Separation from Service.  (a)  If during the Termination Period, Employee incurs a Separation from Service, other than by reason of a Nonqualifying Separation, then the Company shall pay to Employee (or Employee's beneficiary or estate), as compensation for services rendered to the Company:

(1)  a cash amount equal to each of the following:

6

(i)  Employee's full annual base salary from the Company and its affiliated companies through the Date of Separation, to the extent not theretofore paid, within 30 days following the Date of Separation, in accordance with the Company’s normal payroll practices,

(ii)  Employee's annual bonus in an amount at least equal to the highest annualized bonus paid or payable, including by reason of any deferral, to Employee by the Company and its affiliated companies in respect of any of the three fiscal years of the Company (or such portion thereof during which Employee performed services for the Company if Employee shall have been employed by the Company for less than such three fiscal year period) immediately preceding the fiscal year in which the Change in Control occurs, multiplied by a fraction, the numerator of which is the number of days in the fiscal year in which the Date of Separation occurs through the Date of Separation and the denominator of which is 365 or 366, as applicable, at the time annual bonuses are otherwise paid to employees of the Company for the fiscal year in which the Date of Separation occurs, and

(iii)  any accrued vacation pay, to the extent not theretofore paid, within 30 days following the Date of Separation, in accordance with the Company’s normal payroll practices; plus

(2)  a lump-sum cash amount, within 30 days following the Date of Separation, in an amount equal to the sum of:

(i)  two times Employee's highest annual base salary from the Company and its affiliated companies in effect during the 12-month period prior to the Date of Separation, plus

(ii)  two times Employee's highest annualized bonus, paid or payable, including by reason of any deferral, to Employee by the Company and its affiliated companies in respect of any of the five fiscal years of the Company (or such portion thereof during which Employee performed services for the Company if Employee shall have been employed by the Company for less than such five fiscal year period) immediately preceding the fiscal year in which the Change in Control occurs;

provided, however, that in the event there are fewer than 24 whole calendar months remaining from the Date of Separation to the date of Employee's 70th birthday, the amount calculated in accordance with this Section 3(a)(2) shall be reduced by multiplying such amount by a fraction the numerator of which is the number of calendar months, including a partial month (with a partial month being expressed as a fraction the

7

numerator of which is the number of days remaining in such calendar month and the denominator of which is the number of days in such calendar month), so remaining and the denominator of which is 24.

Notwithstanding the foregoing, if on the Date of Separation, Employee is a “specified employee” within the meaning of Section 409A(a)(2) of the Internal Revenue Code of 1986, as amended (the “Code”), such payments made pursuant to this Section 3(a)(2) shall instead be made on the first business day of the seventh full month after the Date of Separation.  

(b)  If during the Termination Period, Employee incurs a Separation from Service by reason of a Nonqualifying Separation, then the Company shall pay to Employee, within 30 days following the Date of Separation, in accordance with the Company’s normal payroll practices, a cash amount equal to the sum of (1) Employee's full annual base salary from the Company through the Date of Separation, to the extent not theretofore paid and (2) any accrued vacation pay, to the extent not theretofore paid.

[(c) If, during the period that commences with the effective date of this Agreement and ending on the date two years following the date in which the Chief Executive Officer of the Company, as of the effective date of this Agreement, is no longer providing service in such capacity ("CEO Transition Date"), Employee incurs a Separation From Service by the Company other than for Cause or by Employee due to, without express written consent by Employee, (i) a material diminution in the Employee’s base compensation, or (ii) a material diminution in the Employee’s authority, duties or responsibilities, the Company shall pay to Employee (or Employee’s beneficiary or estate) a cash amount equal to each of the following;

(1) Employee's full annual base salary from the Company and its affiliated companies through the Date of Separation, to the extent not theretofore paid, within 30 days following the Date of Separation, in accordance with the Company’s normal payroll practices;

(2) any accrued vacation pay, to the extent not theretofore paid, within 30 days following the Date of Separation, in accordance with the Company’s normal payroll practices; and

(3) a lump-sum cash amount, within 30 days following the Date of Separation, in an amount equal to the sum of:

(i)  two times Employee's highest annual base salary from the Company and its affiliated companies in effect prior to the Date of Separation, plus

8

(ii) two times Employee's highest annualized bonus, paid or payable, including by reason of any deferral, to Employee by the Company and its affiliated companies in respect of any of the fiscal years of the Company immediately preceding the fiscal year in which the Separation from Service occurs.

Payments under this Section 3(c) are subject to the following conditions:

(i)

the Employee must notify the Company of the Employee’s intention to terminate his or her employment by written notice in accordance with Section 11 of this Agreement;

(ii)

such notice shall be provided to the Company within ninety (90) days of the initial existence of such event, and the Company shall have thirty (30) days to cure such event after receipt of such notice;

(iii)

payments made under this subsection (c) be reduced (but not below zero) for any payments that become due to Employee under Section 3(a) during the period that commences with the effective date of this Agreement and ends two years after the CEO Transition Date; and

(iv)

if on the Date of Separation, Employee is a “specified employee” within the meaning of Section 409A(a)(2) of the Internal Revenue Code of 1986, as amended (the “Code”), such payments made pursuant to this Section 3(c) shall instead be made on the first business day of the seventh full month after the Date of Separation.]  

4.  Limitation on Payments.  Anything in this Agreement to the contrary notwithstanding, in the event that Employee becomes entitled to payments or benefits under this Agreement and the payments or benefits payable to Employee under this Agreement, when combined with other payments and benefits received or to be received by the Employee from the Company or any corporation affiliated with the Company within the meaning of Section 1504 of the Code, in the opinion of the Company, would constitute “parachute payments” within the meaning of Section 280G(b)(2) of the Code, then the amounts payable to Employee under this Agreement shall be reduced to an amount, the present value of which (when combined with the present value of any other payments or benefits otherwise received or to be received by Employee from the Company (or any corporation affiliated with the Company within the meaning of Section 1504 of the Code) that would be deemed “parachute payments”) is equal to 2.99 times the “base amount” within the meaning Section 280G(b)(3).   

5.  Withholding Taxes.  The Company may withhold from all payments due to Employee (or Employee's beneficiary or estate) hereunder all taxes which, by

9

applicable federal, state, local or other law, the Company is required to withhold therefrom.  

6.  Reimbursement of Expenses.  If any contest or dispute shall arise under this Agreement during Employee’s lifetime involving Employee's Separation from Service with the Company or involving the failure or refusal of the Company to perform fully in accordance with the terms hereof, the Company shall reimburse Employee, on a current basis, for all legal fees and expenses, if any, incurred by Employee in connection with such contest or dispute, together with interest at a rate equal to the rate of interest published in The Wall Street Journal under the caption "Money Rates" as the prime rate, but in no event higher than the maximum legal rate permissible under applicable law, such interest to accrue from the date the Company receives Employee's statement for such fees and expenses through the date of payment thereof; provided, however, that in the event the resolution of any such contest or dispute includes a finding denying, in total, Employee's claims in such contest or dispute, Employee shall be required to reimburse the Company, over a period of 12 months from the date of such resolution, for all sums advanced to Employee pursuant to this Section 6.  

7.  Operative Event.  Notwithstanding any provision herein to the contrary, [except for payments under Section 3(c),] no amounts shall be payable hereunder unless and until there is a Change in Control at a time when Employee is employed by the Company.

8.  Termination of Agreement.  (a)  This Agreement shall be effective on the date hereof and shall continue as provided in paragraph (b) of this Section 8; provided, however, that this Agreement shall terminate in any event upon the first to occur of (i) Employee's 70th birthday, (ii) Employee's death or (iii) [except for payments made under Section 3(c),] Employee's Separation from Service with the Company prior to a Change in Control.  [Notwithstanding this Section 8, Employee’s obligations pursuant to Sections 2(b) and 2(c) shall survive termination of this Agreement for any reason.]   

(b)  This Agreement shall continue in effect for three years from the date hereof; provided, however, that commencing on the first anniversary hereof, and each such anniversary thereafter, the term of this Agreement shall automatically be extended for one additional year unless, not later than the first anniversary hereof, and each such anniversary thereafter, as the case may be, the Company or the Employee shall have given notice, in accordance with Section 11, not to extend the term of this Agreement; provided, however, that no such action shall be taken by the Company during any period of time when the Board has knowledge that any person has taken steps reasonably calculated to effect a Change in Control until, in the opinion of the Board, such person has abandoned or terminated its efforts to effect a Change in Control; provided further, that in no event shall this Agreement be terminated in the event of a Change in Control;

10

and provided further that in the event of a Change in Control when there are less than twenty-four months remaining in the term of this Agreement, the term of this Agreement shall be extended so that this Agreement shall terminate twenty-four months after such Change in Control.  [The provisions of this Section 8(b) shall not apply with respect to payments made under Section 3(c) of this Agreement.]

9.  Scope of Agreement.  Nothing in this Agreement shall be deemed to entitle Employee to continued employment with the Company or its subsidiaries, and if Employee's Separation from Service with the Company shall occur prior to a Change in Control, then Employee shall have no further rights under this Agreement; provided, however, that Employee's Separation from Service following a Change in Control shall be subject to all of the provisions of this Agreement.

10.  Successors; Binding Agreement.

(a)  This Agreement shall not be terminated by any merger or consolidation of the Company whereby the Company is or is not the surviving or resulting corporation or as a result of any transfer of all or substantially all of the assets of the Company.  In the event of any such merger, consolidation or transfer of assets, the provisions of this Agreement shall be binding upon the surviving or resulting corporation or the person or entity to which such assets are transferred.

(b)  The Company agrees that concurrently with any merger, consolidation or transfer of assets referred to in paragraph (a) of this Section 10, it will cause any successor or transferee unconditionally to assume, by written instrument delivered to Employee (or Employee's beneficiary or estate), all of the obligations of the Company hereunder.  Failure of the Company to obtain such assumption prior to the effectiveness of any such merger, consolidation or transfer of assets shall be a breach of this Agreement and shall entitle Employee to compensation and other benefits from the Company in the same amount and on the same terms as Employee would be entitled hereunder if Employee's Separation from Service occurred following a Change in Control other than by reason of a Nonqualifying Separation.  For purposes of implementing the foregoing, the date on which any such merger, consolidation or transfer becomes effective shall be deemed the Date of Separation.

(c)  This Agreement shall inure to the benefit of and be enforceable by Employee's personal or legal representatives, executors, administrators, successors, heirs, distributees, devisees and legatees.  If Employee shall die while any amounts would be payable to Employee hereunder had Employee continued to live, all such amounts, unless otherwise provided herein, shall be paid in accordance with the terms of this Agreement to such person or persons appointed in writing by Employee to receive such amounts or, if no person is so appointed, to Employee's estate.

11

11.  Notice.  (a)  For purposes of this Agreement, all notices and other communications required or permitted hereunder shall be in writing and shall be deemed to have been duly given when delivered or five days after deposit in the United States mail, certified and return receipt requested, postage prepaid, addressed (1) if to the Employee, to the Employee's address of record with the Company, and if to the Company, to Madison Gas and Electric Company, P. O. Box 1231,  Madison, WI 53701-1231, attention Mr. Gary J. Wolter, or (2) to such other address as either party may have furnished to the other in writing in accordance herewith, except that notices of change of address shall be effective only upon receipt.

(b)  A written notice of Employee's Date of Separation by the Company or Employee, as the case may be, to the other, shall:

(i)  indicate the specific termination provision in this Agreement relied upon,

(ii)  to the extent applicable, set forth in reasonable detail the facts and circumstances claimed to provide a basis for Employee's Separation from Service under the provision so indicated and

(iii)  specify the Separation Date (which date shall be not less than 15 days after the giving of such notice).

The failure by Employee or the Company to set forth in such notice any fact or circumstance which contributes to a showing of Good Reason or Cause shall not waive any right of Employee or the Company hereunder or preclude Employee or the Company from asserting such fact or circumstance in enforcing Employee's or the Company's rights hereunder.

12.

Full Settlement; Resolution of Disputes.  (a) The Company's obligation to make any payments provided for in this Agreement and otherwise to perform its obligations hereunder shall not be affected by any set-off, counterclaim, recoupment, defense or other claim, right or action which the Company may have against Employee or others.  In no event shall Employee be obligated to seek other employment or take any other action by way of mitigation of the amounts payable to Employee under any of the provisions of this Agreement and, such amounts shall not be reduced whether or not Employee obtains other employment.

(b)  If there shall be any dispute between the Company and Employee in the event of Employee's Separation from Service, then, unless and until there is a final, nonappealable judgment by a court of competent jurisdiction declaring that such termination was for Cause, that the determination by Employee of the existence of Good

12

Reason was [or the satisfaction of the conditions set forth under Section 3(c) were] not made in good faith, or that the Company is not otherwise obligated to pay any amount under Section[s] 3(a) [or 3(c)], the Company shall pay all amounts that the Company would be required to pay pursuant to Section[s] 3(a) [or 3(c)] as though such termination were by the Company without Cause or by Employee with Good Reason [or by satisfaction of the conditions set forth under Section 3(c)]; provided, however, that the Company shall not be required to pay any disputed amounts pursuant to this paragraph except upon receipt of an undertaking by or on behalf of Employee to repay all such amounts to which Employee is ultimately adjudged by such court not to be entitled.

13.  Employment with Subsidiaries.  Employment with the Company for purposes of this Agreement shall include employment with affiliated corporations and other entities described in Treasury Regulation § 1.409A-1(h)(3).

14.  Governing Law; Validity.  The interpretation, construction and performance of this Agreement shall be governed by and construed and enforced in accordance with the internal laws of the State of Wisconsin without regard to the principle of conflicts of laws.  The invalidity or unenforceability of any provision of this Agreement shall not affect the validity or enforceability of any other provision of this Agreement, which other provisions shall remain in full force and effect.

15.  Counterparts.  This Agreement may be executed in two or more counterparts, each of which shall be deemed to be an original and all of which together shall constitute one and the same instrument.

16.  Miscellaneous.  No provision of this Agreement may be modified or waived unless such modification or waiver is agreed to in writing and signed by Employee and by a duly authorized officer of the Company.  No waiver by either party hereto at any time of any breach by the other party hereto of, or compliance with, any condition or provision of this Agreement to be performed by such other party shall be deemed a waiver of similar or dissimilar provisions or conditions at the same or at any prior or subsequent time.  Failure by Employee or the Company to insist upon strict compliance with any provision of this Agreement or to assert any right Employee or the Company may have hereunder, including, without limitation, the right of Employee to incur a Separation from Service for Good Reason [or pursuant to Section 3(c),] shall not be deemed to be a waiver of such provision or right or any other provision or right of this Agreement.  The rights and benefits payable hereunder are in addition to any rights of, or benefits payable to, Employee, Employee's estate or Employee's beneficiaries under (i) the Income Continuation Agreement [Defined Contribution Supplemental Executive Retirement Plan], if any, between the Company and Employee, (ii) the Deferred Compensation Agreement between the Company and Employee, if any, and (iii) any other employee benefit plan or compensation program of the Company, excluding any other severance plan, policy or arrangement of the Company.  This Agreement

13

supersedes, in its entirety, any agreement relating to severance previously entered into between Employee and the Company.

17.  Compliance with Section 409A of the Code.  This Agreement is intended to comply with the provisions of Section 409A of the Code and shall be interpreted and construed accordingly.  The Company shall have the discretion and authority to amend this Agreement at any time to satisfy any requirements of Section 409A of the Code or guidance provided by the U.S. Treasury Department to the extent applicable to this Agreement.  By accepting this Agreement, Employee agrees that no provision of this Agreement or any communications related to this Agreement shall be interpreted as guaranteeing the tax consequences or treatment of any amounts payable to Employee under this Agreement.  The amount of any reimbursements or in-kind benefits provided under this Agreement during a calendar year shall not affect the reimbursements or in-kind benefits provided in any other calendar year and Employee’s right to have the Company provide such reimbursements or in-kind benefits may not be liquidated or exchanged for any other benefit.  In addition, any such reimbursements shall not be made after the last day of the calendar year following the calendar year in which the applicable expense is incurred.

IN WITNESS WHEREOF, the Company has caused this Agreement to be executed by a duly authorized officer of the Company and Employee has executed this Agreement as of the day and year first above written.

MADISON GAS AND ELECTRIC COMPANY

By:___________________________________________________

     Gary J. Wolter, Chairman, President and Chief Executive Officer

EMPLOYEE

By:____________________________________________________

14

EX-10

EXHIBIT 10.3

INCOME CONTINUATION AGREEMENT

This Income Continuation Agreement (Agreement) is entered into as of the

 day of

     by and between Madison Gas and Electric Company, a Wisconsin corporation (MGE), and        (Employee), and shall be effective as of       . This Agreement supersedes any and all previous Income Continuation Agreements entered into by and between the Employee and MGE, including but not limited to such agreement which was effective       .

WHEREAS, MGE values the efforts, abilities, and accomplishments of the Employee, and recognizes that the Employee's future services as an Officer are vital to MGE’s continued growth and efficiency, and

WHEREAS, MGE, in order to retain the services of the Employee as an Officer and to compensate for these services, is willing to provide the Employee certain benefits, as set forth below.

NOW THEREFORE, it is mutually agreed that:

1.

Definitions.  Whenever capitalized and used in the Agreement, the following terms shall have the respective meanings stated below:

(a)

["Accumulations" means the aggregate of the Employee's contributions, and earnings credited thereto, made under and as described in the Retirement Plan.]

(b)

“Average Earnings” means the average of the Employee’s monthly Earnings for the highest average 60 consecutive calendar month period during the 120 consecutive calendar month period for which the Employee has Years of Service Credit immediately before the Employee’s date of Separation of Service, Disability or death.

(c)

“Code” means the Internal Revenue Code of 1986, as amended.

(d)

"Designated Percentage" means the percentage under the table in Section 3(c), based on the age of the Employee in completed whole years and

completed whole months on the date of his or her Separation from Service, Disability or death.

(e)

“Disability” means the Employee’s inability to engage in any substantial gainful activity by reason of any medically determinable physical or mental impairment that can be expected to result in death or can be expected to last for a continuous period of not less than 12 months.  

(f)

"Earnings" means "earnings" as defined in the Retirement Plan plus any amount deferred by the Employee under any nonqualified deferred compensation agreement with or plan of MGE and any amount payable pursuant to any severance plan, program or agreement with MGE.

(g)

"Income Continuation Amount" means the monthly amount of the annuity payable to the Employee under this Agreement.

(h)

"Normal Retirement Date" means, where the Employee's 65th birthday occurs within the first 15 days of a calendar month, the first day of that month; otherwise, the first day of the month next following the Employee's 65th birthday.

(i)

"Officer" means an employee who has been named an officer of MGE by the board of directors of MGE.

(j)

["Officer Years of Service” means the number of whole years that the Employee has served as an Officer.]

(k)

"Qualified Plan Benefit Payable" means the monthly amount, if any, of the single life annuity payable to the Employee under the Retirement Plan on the date of commencement of the Income Continuation Amount paid under this Agreement, as modified by Sections [3(d), 4(c) or] 6(a), or of this Agreement, as applicable.

(l)

"Retirement Plan" means the Madison Gas and Electric Company Retirement Plan, revised effective ____________, and as amended thereafter from time to time.

(m)

“Separation from Service”  means a termination of services provided by the Employee to MGE, as determined by MGE in accordance with Treasury Regulation section 1.409A-1(h), but excluding a termination of services by reason of the Employee’s death or Disability.  In determining whether an Employee has experienced a Separation from Service, the following provisions shall apply:

(1)

Subject to part (2) below, an Employee’s Separation from Service shall occur when the Employee has experienced a termination of employment with MGE.  The Employee shall be considered to have experienced a termination of employment when the facts and

2

circumstances indicate that the Employee and MGE reasonably anticipate that either:

(i)

no further services will be performed for MGE after a certain date, or

(ii)

that the level of bona fide services the Employee will perform for MGE after such date (whether as an employee or consultant) will permanently decrease to no more than 20% of the average level of bona fide services performed by such Employee (whether as an employee or consultant) over the immediately preceding 36-month period (or the full period of services to MGE if the Employee has been providing services to the MGE less than 36 months).

(2)

If the Employee is on military leave, sick leave, or other bona fide leave of absence, the employment relationship between the Employee and MGE shall be treated as continuing intact, provided that the period of such leave does not exceed six months, or if longer, so long as the Employee retains a right to reemployment with MGE under an applicable statute or by contract.  If the period of a military leave, sick leave, or other bona fide leave of absence exceeds six months and the Employee does not retain a right to reemployment under an applicable statute or by contract, the employment relationship shall be considered to be terminated for purposes of this Plan as of the first day immediately following the end of such six-month period.  In applying the provisions of this paragraph, a leave of absence shall be considered a bona fide leave of absence only if there is a reasonable expectation that the Employee will return to perform services for MGE.

(n)

"Ten-Year Certain and Life Annuity" means a series of equal monthly payments, payable for the life of the Employee, provided, that if the Employee dies before receiving 120 such payments, such payments shall continue to be paid to the Employee's beneficiary designated pursuant to Section 8 until the total number of such payments made to the Employee and such beneficiary equals 120.

(o)

"Years of Service Credit" means the Employee's "years of service" with MGE as defined in the Retirement Plan.

2.

Employee Services. Except as may be provided in any other agreement or contract between MGE and the Employee, either MGE or the Employee may terminate the Employee's employment or status as an Officer at any time and for any reason.

3

3.

Retirement.

(a)

Eligibility.  If the Employee's Separation from Service or Disability occurs on or after the date the Employee has attained age 55, the Employee will be deemed to have retired, and MGE will pay or cause to be paid to the Employee, with respect to the earlier to occur of such events, the Income Continuation Amount for a retired Employee in the form of a Ten-Year Certain and Life Annuity.

(b)

Amount. The Income Continuation Amount for a retired Employee is a monthly amount equal to:

(1)

the Designated Percentage of Average Earnings, minus

(2)

the Qualified Plan Benefit Payable as described in Section 1(j), [multiplied by

(3)

the vesting percentage set forth in the table below, based on the number of the Employee’s [Officer] Years of Service Credit as of the date of the Employee’s Separation from Service or Disability.]

[

[OFFICER] YEARS OF SERVICE	VESTING PERCENTAGE
[     ]	[     ]%
[     ]	[     ]%
[     ]	[     ]%
[     ]	[     ]%

]

(c)

Designated Percentages Table.

ATTAINED AGE IN WHOLE YEARS AT RETIREMENT	PERCENTAGE OF AVERAGE EARNINGS
[     ]+	[     ]%
[     ]	[     ]%
[     ]	[     ]%
[     ]	[     ]%
[     ]	[     ]%
[     ]	[     ]%
[     ]	[     ]%
[     ]	[     ]%
[     ]	[     ]%
[     ]	[     ]%
[     ]	[     ]%

4

If the Employee’s Separation from Service or Disability is on a date other than his or her birth date, the Designated Percentage shall be prorated to reflect his or her age in completed whole years and in completed whole months, as follows: Completed whole months shall be reflected by determining the difference between the percentage attributable to the current age in years of the Employee and the percentage attributable to the age in years of the Employee on his or her next birth date, multiplied by a fraction, the numerator of which is the number of completed whole months of age of the Employee (in excess of his or her age in completed whole years) and the denominator of which is 12. The numerator for the proration shall be increased by one month if the Employee is retiring between ages 64 and 65 and has a birth date in the first fifteen days of the month (the “Normal Retirement Date”). The sum of such prorated percentage (reflecting age in completed whole months) and the percentage attributable to age in completed whole years determined using the above table equals the Designated Percentage for the Employee.

(d)

[Qualified Plan Benefit Payable. For the purpose of determining the Qualified Plan Benefit Payable for a retired Employee, the Employee's actual Accumulations at Separation from Service or Disability shall be converted to a monthly annuity commencing on the first day of the month coinciding with or next following the date of the Employee's Separation from Service or Disability and continuing for his or her lifetime. Such conversion shall be

(1)

based upon the Employee's age at Separation from Service or Disability, using the mortality table described in the Retirement Plan for this purpose, and

(2)

using an interest rate equal to the greater of 8 percent or the rate that would be used by the Pension Benefit Guaranty Corporation for a trusteed single-employer plan to value immediate annuities during the month immediately before the month of commencement of the Employee's Income Continuation Amount.]

(e)

Commencement. The Income Continuation Amount for a retired Employee shall be paid beginning on the first business day of the month coinciding with or next following the Employee's Separation from Service.  Notwithstanding the foregoing, if on the date of the Employee’s Separation from Service the Employee is a “specified employee” within the meaning of Section 409A(a)(2) of the Code, such payment shall begin on the first business day of the seventh full month after the date of the Employee’s Separation from Service, and the first deferred payment shall include the aggregate amount that but for this sentence would have been paid to the

5

Employee during the period between the Employee’s Separation from Service and the date on which the Income Continuation Amounts begin pursuant to this sentence.  The preceding sentence shall not apply to payments made on account of the Employee’s Disability.

4.

Early Termination.

(a)

Eligibility. If the Employee's Separation from Service or Disability occurs before the Employee has attained age 55, MGE will pay or cause to be paid to the Employee, with respect to the earlier to occur of such events, the Income Continuation Amount for a terminated Employee in the form of a Ten-Year Certain and Life Annuity.

(b)

Amount. The Income Continuation Amount for a terminated Employee shall be a monthly amount equal to:

(1)

 percent of Average Earnings, minus

(2)

the Qualified Plan Benefit Payable described in Section 1(j), [multiplied by

(3)

the vesting percentage determined under Section 3(b)(3).]

(c)

[Qualified Plan Benefit Payable. For the purpose of determining the Qualified Plan Benefit Payable for a terminated Employee, the Employee's actual Accumulations at the date of commencement of the Employee's Income Continuation Amount (or, if, as of the date of commencement, the Employee has received his or her Accumulations under the Retirement Plan, his or her actual Accumulations as of the date of his or her Separation from Service or Disability credited with interest to the date of commencement, calculated using the actual interest credited under the Retirement Plan for those years) shall be converted to a monthly annuity commencing on the first day of the month coinciding with or next following the commencement of the Employee's Income Continuation Amount and continuing for his or her lifetime. Such conversion shall be:

(1)

based upon the Employee's age at commencement, using the mortality table described in the Retirement Plan for that purpose, and

(2)

using an interest rate equal to the greater of 8 percent or the rate that would be used by the Pension Benefit Guaranty Corporation for a trusteed single-employer plan to value immediate annuities during the month immediately before the month of commencement of the Employee's Income Continuation Amount.]

(d)

Commencement. The Income Continuation Amount for a terminated Employee shall be paid beginning on the first business day of the month

6

coinciding with or next following the Employee's 55th birthday. Notwithstanding the foregoing, if on the date of the Employee’s Separation from Service the Employee is a “specified employee” within the meaning of Section 409A(a)(2) of the Code, such payment shall not begin before the first business day of the seventh full month following the date of the Employee’s Separation from Service, and the first deferred payment shall include the aggregate amount, if any, that but for this sentence would have been paid to the Employee during the period between the Employee’s Separation from Service and the date on which the Income Continuation Amounts begin pursuant to this sentence.  The preceding sentence shall not apply to payments made on account of the Employee’s Disability.

5.

Optional Forms. Instead of a Ten-Year Certain and Life Annuity, the retired or terminated Employee may irrevocably elect prior to commencement of his or her Income Continuation Amount to receive his or her Income Continuation Amount in one of the following optional forms, which will be actuarially equivalent to the Ten-Year Certain and Life Annuity:

(a)

a reduced Ten-Year Certain and Life Annuity with 50 percent of the amount thereof payable to the surviving beneficiary for the beneficiary's lifetime beginning after the total of the payments to the Employee and the beneficiary equals 120; or

(b)

a reduced Ten-Year Certain and Life Annuity with 75 percent of the amount thereof payable to the surviving beneficiary for the beneficiary's lifetime beginning after the total of the payments to the Employee and the beneficiary equals 120; or

(c)

a reduced Ten-Year Certain and Life Annuity with 100 percent of the amount thereof payable to the surviving beneficiary for the beneficiary's lifetime beginning after the total of the payments to the Employee and the beneficiary equals 120.

For purposes of this Section 5, actuarial equivalence is determined using the same actuarial assumptions used to determine actuarially equivalent options in the Retirement Plan.

6.

Standard Death Benefit.  If the Employee dies (i) while actively employed by MGE or (ii) after Separation from Service but before commencement of the Income Continuation Amount as calculated under Section 4 of this Agreement, MGE shall pay

7

to the Employee's spouse or designated beneficiary, as set forth below, monthly for 120 months, in an amount determined as follows:

(a)

With respect to an Employee who dies while actively employed by MGE, MGE shall pay to the Employee’s spouse or, if the Employee is not married on the Employee’s date of death, the Employee’s designated beneficiary, 100 percent [of the vested portion (determined under Section 3(b)(3))] of the Income Continuation Amount calculated under Section 3 of this Agreement as if:

(1)

in the case of an Employee who dies before his or her 55th birthday, the Employee had attained age 55 and incurred a Separation from Service on the first day of the month following the date of his or her death (for the purpose of determining the Income Continuation Amount, including the Qualified Plan Benefit Payable);

(2)

in the case of an Employee who dies on or after his or her 55th birthday, the Employee incurred a Separation from Service on the first day of the month following his or her date of death;

(3)

the Employee's Average Earnings are his or her Average Earnings on the date of his or her death;

(4)

[the Employee's Accumulations are his or her actual Accumulations on the date of his or her death;

(5)

the interest rate used to convert the Employee's Accumulations to an annuity is the greater of 8 percent or the rate that would be used by the Pension Benefit Guaranty Corporation for a trusteed single-employer plan to value immediate annuities during the month of the Employee's death; and

(6)

the mortality table used to convert the Employee's Accumulations to an annuity is the same mortality table used in the Retirement Plan for this purpose.]

(b)

With respect to an Employee who dies after Separation from Service but before commencement of the Income Continuation Amount as calculated under Section 4 of this Agreement, MGE shall pay to the Employee’s spouse or, if the Employee is not married on the Employee’s date of death, the Employee’s designated beneficiary, 50 percent [of the vested portion (determined under Section 3(b)(3))] of the Income Continuation Amount the Employee would have received had the Employee survived until the commencement of the Income Continuation Amount.  

8

Such monthly amounts shall commence on the first business day of the month following the date on which such spouse or designated beneficiary notifies MGE in writing of the death of the Employee.  MGE may require such proof of the Employee's death as it deems advisable.  

7.

Additional Death Benefit for Married Employees.  In the event that the Employee’s surviving spouse has received all 120 monthly payments to which such spouse is entitled under Section 6(a) or (b), such spouse shall be entitled to an additional benefit payable as a monthly annuity equal to 50 percent of the amount calculated under Section 6(a) or (b).  Such monthly annuity shall commence on the first day of the month following the date on which such spouse receives his or her last payment pursuant to Section 6(a) or (b) and shall continue for the lifetime of such spouse.

8.

Designation of Beneficiaries. Upon signature of this Agreement, the Employee shall designate one person as his or her primary beneficiary. Such primary beneficiary shall, as applicable, be considered (1) the beneficiary for purposes of the lifetime survivor payments under the optional forms of benefit described in Section 5 and (2) the beneficiary who shall receive any payments remaining under the ten-year certain feature of this Agreement (including the death benefit described in Section 6).  The Employee may also designate one or more persons as his or her secondary beneficiary(ies). Such secondary beneficiary(ies) shall, upon the death of both the Employee and the primary beneficiary, receive any payments remaining under the ten-year certain feature of this Agreement (including the death benefit described in Section

9

6). The word "beneficiary" as used in this Agreement shall be subject to the provisions of this Section 8.

The Employee may change the designation of beneficiaries at any time upon written notice to MGE. If no beneficiary survives the Employee, then the remaining payments shall be made to the estate of the Employee. If the last beneficiary named dies after the Employee, but before the total number of payments to the Employee and his or her beneficiaries equals 120, then the remaining payments shall be made to the estate of the beneficiary last to die.

9.

Employee Violations. In the event that the Employee is convicted of a felony or judicially determined to have committed willful malfeasance, MGE can cause the payments hereunder to be forfeited.

10.

[Change in Control.  If the Employee incurs a Separation from Service under circumstances that entitle the Employee to payment of severance benefits under the Severance Agreement, by and between the Employee and MGE, effective      (and as amended from time to time), or any Severance Agreement by and between the Employee and MGE which replaces such Severance Agreement (Severance Agreement), then the following provisions shall be applicable:

(a)

Service Credit.  For all purposes of this Agreement, the Employee shall be deemed to have    [Officer] Years of Service Credit.

(b)

Definition of “Cause”.  Section 9 shall be applicable only if the Employee shall be terminated on account of “Cause” as defined in the Severance Agreement.

(c)

No Further Amendment.  Section 12 shall be inapplicable, and no further amendment of this Agreement shall be made or effective.]

11.

Unsecured Promise. The Employee, the Employee's spouse and designated beneficiary(ies) shall rely solely on the unsecured promise of MGE for

10

benefits hereunder, and nothing in this Agreement shall be construed to give any party any right, title, interest or claim in or to any specific asset, fund, reserve, account or property of any kind whatsoever, owned by MGE or in which it may have any right, title or interest now or in the future; but the Employee, the Employee's spouse and designated beneficiary(ies) shall have the right to enforce a claim against MGE in the same manner as any unsecured creditor.

12.

Amendment.  MGE may at any time amend this Agreement in whole or in part; provided, however, that no amendment shall be effective to decrease any benefits hereunder, without regard to whether such benefits have accrued as of the date of such amendment. Nothing in this Section 12 shall be interpreted as limiting MGE's rights under Section 9.

13.

Anti-Alienation Provisions.  Neither the Employee, the Employee's spouse, nor the Employee's designated beneficiary(ies), entitled to payments hereunder, shall have any power to transfer, assign, anticipate, mortgage or otherwise encumber in advance, any of such payments, nor shall such payments be subject to any gift, devise or bequest or to seizure for the payment of public or private debts, judgments, alimony or separate maintenance, or be transferable by operation of law in event of bankruptcy, insolvency or otherwise.

14.

Successors to Parties. This Agreement shall be binding upon the parties hereto and upon the parties' successors.

15.

No Contract of Employment. Nothing contained in this Agreement nor any action taken hereunder shall be construed as a contract of employment or as giving the Employee any right to be retained in the employ or as an Officer of MGE.

11

16.

Applicable Law. The laws of the State of Wisconsin shall govern this

Agreement.

17.

Compliance With Section 409A of Code.  This Plan is intended to comply with the provisions of Section 409A of the Code, and shall be interpreted and construed accordingly.  MGE shall have the discretion and authority to amend this Agreement at any time to satisfy any requirements of Section 409A of the Code or guidance provided by the U.S. Treasury Department to the extent applicable to this Agreement.  By accepting this Agreement, the Employee agrees that no provision of this Agreement or any communications related to this Agreement shall be interpreted as guaranteeing the tax consequences or treatment of any amounts payable to the Employee under this Agreement.

18.

Claims Procedure.  The Employee shall make any requests for benefits under this Agreement in accordance with the claims procedures set forth in the Retirement Plan.

19.

Tax Withholding.  Employee shall be required to pay to MGE the amount of any taxes that MGE is legally required to withhold with respect to any payment under this Agreement.  The Company shall have the right to deduct from any amounts otherwise payable under the Agreement any federal, state, local, or other applicable taxes required to be withheld, or any other legally required withholdings.  The Company shall not have any liability related to withholding.

12

IN WITNESS WHEREOF, MGE has caused this Income Continuation Agreement to be executed by a duly authorized officer of MGE and Employee has executed this Agreement as of the day and year first above written.

EMPLOYEE

By:

MADISON GAS AND ELECTRIC COMPANY

By:

13

BENEFICIARY DESIGNATION

Pursuant to the terms of an Income Continuation Agreement between myself and Madison Gas and Electric Company, I hereby designate the following as beneficiary(ies) to receive any payments which may be due under such Agreement after my death.

PRIMARY BENEFICIARY DESIGNATION

(Only one may be named)

To receive, as applicable, the lifetime survivor benefit under Section 5 and to receive any payments remaining under the ten-year certain feature of my benefit upon my death:

(Name)

(Relationship)

SECONDARY BENEFICIARY(IES)

(More than one may be named)

To receive, in equal shares, any payments remaining under the ten-year certain feature of my benefit upon the later of my death and the death of my primary beneficiary:

(Name)

(Relationship)

(Name)

(Relationship)

(Name)

(Relationship)

This designation hereby revokes any prior designation which may have been in effect.

Employee

Date

MADISON GAS AND ELECTRIC COMPANY

By:

14

EX-12

EXHIBIT 12

Madison Gas and Electric Company

Ratio of Earnings to Fixed Charges

Three Months Ended March 31, 2016

(In thousands)

Earnings
Net income before minority interest	$17,197
Equity earnings	(2,233)
Income distribution from equity investees	865
Minority interest in pretax income	(1,076)
Amortization of capitalized interest	132
Federal and state income taxes	10,032
Fixed charges	5,323
Total Earnings as Defined	$30,240
Fixed Charges
Interest expense on long-term debt and other	$4,835
Interest on rentals*	177
Amortization of debt issuance costs	226
AFUDC - borrowed funds	85
Total Fixed Charges	$5,323
Ratio of Earnings to Fixed Charges	5.68X

*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 5, 2016

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

Senior Vice President, Chief Financial Officer,

Secretary and Treasurer

Date: May 5, 2016

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 5, 2016

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

Senior Vice President, Chief Financial Officer,

Secretary and Treasurer

Date: May 5, 2016

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, 2016, 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 5, 2016

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, 2016, 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

Senior Vice President, Chief Financial Officer,

Secretary and Treasurer

Date: May 5, 2016

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, 2016, 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 5, 2016

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, 2016, 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

Senior Vice President, Chief Financial Officer,

Secretary and Treasurer

Date: May 5, 2016

XML

Document and Entity Information - shares	3 Months Ended
	Mar. 31, 2016	Apr. 30, 2016
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, 2016
Amendment Flag	false
Trading Symbol	MGEE
Document Fiscal Year Focus	2016
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

XML

MGE Energy Inc Consolidated Statements of Income (Unaudited) - USD ($) shares in Thousands, $ in Thousands	3 Months Ended
	Mar. 31, 2016	Mar. 31, 2015
Operating Revenues:
Electric revenues	$ 93,690	$ 100,206
Gas revenues	53,837	69,928
Total Operating Revenues	147,527	170,134
Operating Expenses:
Fuel for electric generation	12,013	11,892
Purchased power	14,670	22,865
Cost of gas sold	32,523	46,919
Other operations and maintenance	42,730	40,674
Depreciation and amortization	11,032	10,849
Other general taxes	5,028	5,084
Total Operating Expenses	117,996	138,283
Operating Income	29,531	31,851
Other income, net	2,442	2,105
Interest expense, net	(5,000)	(5,091)
Income before income taxes	26,973	28,865
Income tax provision	(9,945)	(10,587)
Net Income	$ 17,028	$ 18,278
Earnings Per Share of Common Stock (basic and diluted)	$ 0.49	$ 0.53
Dividends per share of common stock	$ 0.295	$ 0.283
Weighted Average Shares Outstanding (basic and diluted)	34,668	34,668

XML

Madison Gas and Electric Company Consolidated Statements of Income (Unaudited) - USD ($) $ in Thousands		3 Months Ended
		Mar. 31, 2016	Mar. 31, 2015
Operating Revenues:
Electric revenues		$ 93,690	$ 100,206
Gas revenues		53,837	69,928
Total Operating Revenues		147,527	170,134
Operating Expenses:
Fuel for electric generation		12,013	11,892
Purchased power		14,670	22,865
Cost of gas sold		32,523	46,919
Other operations and maintenance		42,730	40,674
Depreciation and amortization		11,032	10,849
Other general taxes		5,028	5,084
Income tax provision		9,945	10,587
Total Operating Expenses		117,996	138,283
Operating Income		29,531	31,851
Other Income and Deductions:
Equity in earnings in ATC		2,233	1,881
Total Other Income and Deductions		2,442	2,105
Interest Expense:
Net Interest Expense		5,000	5,091
Net Income		17,028	18,278
MGE [Member]
Operating Revenues:
Electric revenues		93,696	100,211
Gas revenues		53,847	69,933
Total Operating Revenues		147,543	170,144
Operating Expenses:
Fuel for electric generation		12,016	11,894
Purchased power		14,674	22,868
Cost of gas sold		32,534	46,923
Other operations and maintenance		42,402	40,472
Depreciation and amortization		11,020	10,837
Other general taxes		5,028	5,084
Income tax provision		9,090	9,776
Total Operating Expenses		126,764	147,854
Operating Income	[1]	20,779	22,290
Other Income and Deductions:
AFUDC - equity funds		261	128
Equity in earnings in ATC		2,233	1,881
Income tax provision		(942)	(808)
Other expense, net		(73)	(39)
Total Other Income and Deductions	[1]	1,479	1,162
Income before interest expense		22,258	23,452
Interest Expense:
Interest on long-term debt		5,109	5,151
Other interest, net		37	32
AFUDC - borrowed funds		(85)	(42)
Net Interest Expense		5,061	5,141
Net Income Including Noncontrolling Interest		17,197	18,311
Less Net Income Attributable to Noncontrolling Interest, net of tax		(6,252)	(6,553)
Net Income		$ 10,945	$ 11,758

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

XML

MGE Energy Inc Consolidated Statements of Comprehensive Income (Unaudited) - USD ($) $ in Thousands	3 Months Ended
	Mar. 31, 2016	Mar. 31, 2015
Comprehensive Income [Abstract]
Net Income	$ 17,028	$ 18,278
Other comprehensive income, net of tax:
Unrealized loss on available-for-sale securities, net of tax	(164)	(85)
Comprehensive Income	$ 16,864	$ 18,193

XML

Madison Gas and Electric Company Consolidated Statements of Comprehensive Income (Unaudited) - USD ($) $ in Thousands	3 Months Ended
	Mar. 31, 2016	Mar. 31, 2015
Other comprehensive income, net of tax:
Unrealized loss on available-for-sale securities, net of tax	$ (164)	$ (85)
Comprehensive Income	16,864	18,193
MGE [Member]
Net Income	17,197	18,311
Other comprehensive income, net of tax:
Unrealized loss on available-for-sale securities, net of tax	(30)	(82)
Total comprehensive income including noncontrolling interest	17,167	18,229
Less: Comprehensive income attributable to Noncontrolling Interest, net of tax	(6,252)	(6,553)
Comprehensive Income	$ 10,915	$ 11,676

XML

Consolidated Statements of Comprehensive Income (Unaudited) (Parantheticals) - USD ($) $ in Thousands	3 Months Ended
	Mar. 31, 2016	Mar. 31, 2015
Unrealized loss on available-for-sale securities, tax benefit	$ (110)	$ (57)
MGE [Member]
Unrealized loss on available-for-sale securities, tax benefit	$ (20)	$ (55)

XML

MGE Energy Inc Consolidated Statements of Cash Flows (Unaudited) - USD ($) $ in Thousands	3 Months Ended
	Mar. 31, 2016	Mar. 31, 2015
Operating Activities:
Net Income	$ 17,028	$ 18,278
Items not affecting cash:
Depreciation and amortization	11,032	10,849
Deferred income taxes	2,840	3,723
Provision for doubtful receivables	592	97
Employee benefit plan expenses	(57)	792
Equity earnings in ATC	(2,233)	(1,881)
Other items	86	(658)
Changes in working capital items:
Decrease in current assets	22,311	17,985
Increase (decrease) in current liabilities	1,487	(11,091)
Dividend income from ATC	865	1,420
Cash contributions to pension and other postretirement plans	(11,159)	(10,809)
Other noncurrent items, net	937	5,935
Cash Provided by Operating Activities	43,729	34,640
Investing Activities:
Capital expenditures	(15,642)	(11,533)
Capital contributions to investments	(671)	(280)
Other	(183)	(48)
Cash Used for Investing Activities	(16,496)	(11,861)
Financing Activities:
Cash dividends paid on common stock	(10,227)	(9,794)
Repayment of long-term debt	(1,059)	(1,037)
Repayment of short-term debt	0	(7,000)
Cash Used for Financing Activities	(11,286)	(17,831)
Change in cash and cash equivalents	15,947	4,948
Cash and cash equivalents at beginning of period	81,384	65,755
Cash and cash equivalents at end of period	$ 97,331	$ 70,703

XML

Madison Gas and Electric Company Consolidated Statements of Cash Flows (Unaudited) - USD ($) $ in Thousands	3 Months Ended
	Mar. 31, 2016	Mar. 31, 2015
Items not affecting cash:
Depreciation and amortization	$ 11,032	$ 10,849
Deferred income taxes	2,840	3,723
Provision for doubtful receivables	592	97
Employee benefit plan expenses	(57)	792
Equity earnings in ATC	(2,233)	(1,881)
Other items	86	(658)
Changes in working capital items:
Decrease in current assets	22,311	17,985
Increase (decrease) in current liabilities	1,487	(11,091)
Dividend income from ATC	865	1,420
Cash contributions to pension and other postretirement plans	(11,159)	(10,809)
Other noncurrent items, net	937	5,935
Cash Provided by Operating Activities	43,729	34,640
Investing Activities:
Capital expenditures	(15,642)	(11,533)
Capital contributions to investments	(671)	(280)
Other	(183)	(48)
Cash Used for Investing Activities	(16,496)	(11,861)
Financing Activities:
Repayment of long-term debt	(1,059)	(1,037)
Repayment of short-term debt	0	(7,000)
Cash Used for Financing Activities	(11,286)	(17,831)
Change in cash and cash equivalents	15,947	4,948
Cash and cash equivalents at beginning of period	81,384	65,755
Cash and cash equivalents at end of period	97,331	70,703
MGE [Member]
Operating Activities:
Net Income	17,197	18,311
Items not affecting cash:
Depreciation and amortization	11,020	10,837
Deferred income taxes	2,502	2,391
Provision for doubtful receivables	592	97
Employee benefit plan expenses	(57)	792
Equity earnings in ATC	(2,233)	(1,881)
Other items	112	(526)
Changes in working capital items:
Decrease in current assets	22,053	18,825
Increase (decrease) in current liabilities	1,524	(8,859)
Dividend income from ATC	865	1,420
Cash contributions to pension and other postretirement plans	(11,159)	(10,809)
Other noncurrent items, net	906	5,901
Cash Provided by Operating Activities	43,322	36,499
Investing Activities:
Capital expenditures	(15,642)	(11,533)
Capital contributions to investments	(533)	(178)
Other	(72)	(17)
Cash Used for Investing Activities	(16,247)	(11,728)
Financing Activities:
Cash dividends paid to parent by MGE	(10,000)	0
Distributions to parent from noncontrolling interest	(6,500)	(6,818)
Equity contribution received by noncontrolling interest	533	2,678
Repayment of long-term debt	(1,059)	(1,037)
Repayment of short-term debt	0	(7,000)
Cash Used for Financing Activities	(17,026)	(12,177)
Change in cash and cash equivalents	10,049	12,594
Cash and cash equivalents at beginning of period	26,760	4,562
Cash and cash equivalents at end of period	$ 36,809	$ 17,156

XML

Consolidated Balance Sheets (Unaudited) - USD ($) $ in Thousands	Mar. 31, 2016	Dec. 31, 2015
Current Assets:
Cash and cash equivalents	$ 97,331	$ 81,384
Accounts receivable, less reserves	36,710	37,112
Other accounts receivables, less reserves	5,637	7,477
Unbilled revenues	23,375	25,008
Materials and supplies, at average cost	20,335	19,155
Fossil fuel	10,222	13,110
Stored natural gas, at average cost	8,548	16,145
Prepaid taxes	24,606	35,252
Regulatory assets - current	10,448	9,538
Other current assets	9,992	10,570
Total Current Assets	247,204	254,751
Regulatory assets	149,987	148,199
Other deferred assets and other	6,476	6,377
Property, Plant, and Equipment:
Property, plant, and equipment, net	1,218,282	1,217,094
Construction work in progress	33,198	26,351
Total Property, Plant, and Equipment	1,251,480	1,243,445
Investments	75,269	73,631
Total Assets	1,730,416	1,726,403
Current Liabilities:
Long-term debt due within one year	34,264	4,266
Accounts payable	41,132	40,830
Accrued interest and taxes	3,975	5,067
Accrued payroll related items	8,926	11,215
Regulatory liabilities - current	11,071	9,515
Derivative liabilities	9,374	8,343
Other current liabilities	9,181	4,910
Total Current Liabilities	117,923	84,146
Other Credits:
Deferred income taxes	363,671	360,785
Investment tax credit - deferred	1,024	1,050
Regulatory liabilities	21,493	20,785
Accrued pension and other postretirement benefits	64,259	75,680
Derivative liabilities	46,540	44,935
Other deferred liabilities and other	62,620	61,820
Total Other Credits	559,607	565,055
Capitalization:
Common shareholders equity	697,095	690,458
Long-term debt	355,791	386,744
Total Capitalization	$ 1,052,886	$ 1,077,202
Commitments and contingencies (see Footnote 7)
Total Liabilities and Capitalization	$ 1,730,416	$ 1,726,403
MGE [Member]
Current Assets:
Cash and cash equivalents	36,809	26,760
Accounts receivable, less reserves	36,710	37,112
Affiliate receivables	686	542
Other accounts receivables, less reserves	5,522	7,390
Unbilled revenues	23,375	25,008
Materials and supplies, at average cost	20,335	19,155
Fossil fuel	10,222	13,110
Stored natural gas, at average cost	8,547	16,145
Prepaid taxes	23,764	34,279
Regulatory assets - current	10,448	9,538
Other current assets	9,978	10,544
Total Current Assets	186,396	199,583
Affiliate receivable long-term	4,633	4,766
Regulatory assets	149,987	148,199
Other deferred assets and other	4,219	4,216
Property, Plant, and Equipment:
Property, plant, and equipment, net	1,217,614	1,216,415
Construction work in progress	33,198	26,351
Total Property, Plant, and Equipment	1,250,812	1,242,766
Investments	71,835	69,984
Total Assets	1,667,882	1,669,514
Current Liabilities:
Long-term debt due within one year	34,264	4,266
Accounts payable	41,140	40,742
Accrued interest and taxes	3,927	5,021
Accrued payroll related items	8,926	11,215
Regulatory liabilities - current	11,071	9,515
Derivative liabilities	9,374	8,343
Other current liabilities	9,005	4,791
Total Current Liabilities	117,707	83,893
Other Credits:
Deferred income taxes	355,264	352,626
Investment tax credit - deferred	1,024	1,050
Regulatory liabilities	21,493	20,785
Accrued pension and other postretirement benefits	64,259	75,680
Derivative liabilities	46,540	44,935
Other deferred liabilities and other	62,620	61,817
Total Other Credits	551,200	556,893
Capitalization:
Common shareholders equity	502,591	501,676
Noncontrolling interest	140,593	140,308
Total Equity	643,184	641,984
Long-term debt	355,791	386,744
Total Capitalization	$ 998,975	$ 1,028,728
Commitments and contingencies (see Footnote 7)
Total Liabilities and Capitalization	$ 1,667,882	$ 1,669,514

XML

Consolidated Balance Sheets (Unaudited) (Parentheticals) - USD ($) $ in Thousands	Mar. 31, 2016	Dec. 31, 2015
Receivables, Net
Reserve for uncollectible accounts receivable	$ 3,289	$ 3,052
Reserve for uncollectible other accounts receivable	569	642
MGE [Member]
Receivables, Net
Reserve for uncollectible accounts receivable	3,289	3,052
Reserve for uncollectible other accounts receivable	$ 569	$ 642

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MGE Energy Inc Consolidated Statements of Common Equity (Unaudited) - USD ($) shares in Thousands, $ in Thousands	Total	Common Stock [Member]	Additional Paid-In Capital [Member]	Retained Earnings [Member]	Accumulated Other Comprehensive Income [Member]
Beginning balance, shares at Dec. 31, 2014		34,668
Beginning balance, value at Dec. 31, 2014	$ 659,401	$ 34,668	$ 316,268	$ 308,007	$ 458
Cumulative effect of new accounting principle at Dec. 31, 2014	(142)			(142)
Beginning balance, value - Adjusted at Dec. 31, 2014	659,259			307,865
Increase (Decrease) In Stockholders' Equity [Roll Forward]
Net Income	18,278			18,278
Other comprehensive loss	(85)				(85)
Common stock dividends declared	(9,794)			(9,794)
Ending balance, shares at Mar. 31, 2015		34,668
Ending balance, value at Mar. 31, 2015	667,658	$ 34,668	316,268	316,349	373
Beginning balance, shares at Dec. 31, 2015		34,668
Beginning balance, value at Dec. 31, 2015	690,458	$ 34,668	316,268	339,165	357
Increase (Decrease) In Stockholders' Equity [Roll Forward]
Net Income	17,028			17,028
Other comprehensive loss	(164)				(164)
Common stock dividends declared	(10,227)			(10,227)
Ending balance, shares at Mar. 31, 2016		34,668
Ending balance, value at Mar. 31, 2016	$ 697,095	$ 34,668	$ 316,268	$ 345,966	$ 193

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Madison Gas and Electric Company Consolidated Statements of Common Equity (Unaudited) - USD ($) shares in Thousands, $ in Thousands	Total	MGE [Member]	Common Stock [Member]	Common Stock [Member] MGE [Member]	Additional Paid-In Capital [Member] MGE [Member]	Retained Earnings [Member]	Retained Earnings [Member] MGE [Member]	Accumulated Other Comprehensive Income/(Loss) [Member]	Accumulated Other Comprehensive Income/(Loss) [Member] MGE [Member]	Noncontrolling Interest [Member] MGE [Member]
Beginning balance, shares at Dec. 31, 2014			34,668	17,348
Beginning balance, value at Dec. 31, 2014		$ 612,260		$ 17,348	$ 192,417		$ 276,662		$ 144	$ 125,689
Cumulative effect of new accounting principle at Dec. 31, 2014	$ (142)	(142)				$ (142)	(142)
Beginning balance, value - Adjusted at Dec. 31, 2014		612,118					276,520
Increase (Decrease) In Stockholders' Equity [Roll Forward]
Net Income		18,311					11,758			6,553
Other comprehensive loss	(85)	(82)						$ (85)	(82)
Equity contribution received by noncontrolling interest		2,678								2,678
Distributions to parent from noncontrolling interest		(6,818)								(6,818)
Ending balance, shares at Mar. 31, 2015			34,668	17,348
Ending balance, value at Mar. 31, 2015		626,207		$ 17,348	192,417		288,278		62	128,102
Beginning balance, shares at Dec. 31, 2015			34,668	17,348
Beginning balance, value at Dec. 31, 2015		641,984		$ 17,348	192,417		291,888		23	140,308
Increase (Decrease) In Stockholders' Equity [Roll Forward]
Net Income		17,197					10,945			6,252
Other comprehensive loss	$ (164)	(30)						$ (164)	(30)
Cash dividends paid to parent by MGE		(10,000)					(10,000)
Equity contribution received by noncontrolling interest		533								533
Distributions to parent from noncontrolling interest		(6,500)								(6,500)
Ending balance, shares at Mar. 31, 2016			34,668	17,348
Ending balance, value at Mar. 31, 2016		$ 643,184		$ 17,348	$ 192,417		$ 292,833		$ (7)	$ 140,593

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Consolidated Statements of Common Equity (Unaudited) (Parentheticals) - $ / shares	3 Months Ended
	Mar. 31, 2016	Mar. 31, 2015
Consolidated Statements of Common Equity
Dividends per share of common stock	$ 0.295	$ 0.283

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Basis of Presentation

3 Months Ended

Mar. 31, 2016

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 accounting 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 2015 Annual Report on Form 10-K.

The accompanying consolidated financial statements as of March 31,2016, 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 2015 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 55 through 105 of the 2015 Annual Report on Form 10-K.

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Equity and Financing Arrangements

3 Months Ended

Mar. 31, 2016

Equity and Financing Arrangements Disclosure [Abstract]

Equity and Financing Arrangements

Equity and Financing Arrangements - MGE Energy.

a. 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. For both the three months endedMarch 31,2016 and 2015, MGE Energy did not issue any new shares of common stock under the Stock Plan.

b. Dilutive Shares Calculation.

MGE Energy does not hold any dilutive securities.

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Investment in ATC

3 Months Ended

Mar. 31, 2016

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 31,2016 and 2015, MGE Transco recorded the following:

		Three Months Ended
		March 31,
(In thousands)		2016		2015
Equity in earnings from investment in ATC	$	2,233	$	1,881
Dividends received from ATC		865		1,420
Capital contributions to ATC		533		178

MGE Transco's investment in ATC as of March 31,2016, and December 31, 2015, was $71.4 million and $69.5 million, respectively.

At March 31,2016, MGE is the majority owner (51%), and MGE Energy, the holding company, is the minority owner (49%) 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. MGE's ownership interest is expected to decline below a majority during 2016 as a result of continued funding of ATC capital contributions by MGE Energy, and may be completely eliminated in favor of MGE Energy if the PSCW accepts a staff recommendation that MGE transfer its interest in ATC to MGE Energy. The recommendation arose in the context of requests for regulatory approvals by several owners of ATC in connection with a reorganization of ATC designed to separate its existing Wisconsin-based transmission operations from its non-Wisconsin transmission development activities. The change will have no effect on MGE Energy's consolidated financial statements. No gain or loss is expected to be recognized on the date MGE ceases to have a controlling financial interest.

ATC's summarized financial data for the three months endedMarch 31,2016 and 2015, is as follows:

		Three Months Ended
		March 31,
(In thousands)		2016		2015
Operating revenues	$	164,240	$	152,357
Operating expenses		(79,065)		(79,951)
Other income, net		127		62
Interest expense, net		(24,208)		(24,483)
Earnings before members' income taxes	$	61,094	$	47,985

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Taxes

3 Months Ended

Mar. 31, 2016

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 31,2016 and 2015, was 36.9% and 36.7%, respectively. MGE's effective income tax rate for thethree months endedMarch 31,2016 and 2015, was 36.8% and 36.6%, respectively. The increase in the effective tax rate is due in part to a lower estimated domestic manufacturing deduction and lower estimated AFUDC equity earnings in 2016.

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Pension and Other Postretirement Plans

3 Months Ended

Mar. 31, 2016

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.MGE refined its methodology for using discount rates to measure the components of net periodic benefit cost for 2016. The refined methodology uses individual spot rates, instead of a weighted average of the yield curve spot rates, for measuring the service cost and interest cost components.

The following table presents the components of MGE Energy's and MGE's net periodic benefit costs recognized for the three months endedMarch 31,2016 and 2015. A portion of the net periodic benefit cost is capitalized within the consolidated balance sheets.

		Three Months Ended
		March 31,
(In thousands)		2016		2015
Pension Benefits
Components of net periodic cost:
Service cost	$	1,381	$	1,798
Interest cost		3,089		3,440
Expected return on assets		(5,593)		(5,677)
Amortization of:
Prior service cost		2		6
Actuarial loss		1,356		1,334
Net periodic cost	$	235	$	901
Postretirement Benefits
Components of net periodic (benefit) cost:
Service cost	$	324	$	383
Interest cost		674		778
Expected return on assets		(705)		(703)
Amortization of:
Transition obligation		1		1
Prior service benefit		(667)		(667)
Actuarial loss		159		262
Net periodic (benefit) cost	$	(214)	$	54

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Share-Based Compensation

3 Months Ended

Mar. 31, 2016

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 February 2016, 19,055 units were granted based on the MGE Energy closing stock price as of that date. Units are subject to a five-year graded vesting schedule. On the grant date, MGE Energy and MGE measure the cost of the employee services received in exchange for a performance unit award based on the current market value of MGE Energy common stock. The fair value of the awards is re-measured quarterly, including atMarch 31,2016, as required by applicable accounting standards. Changes in fair value as well as the original grant are recognized as compensation cost. Since this amount is re-measured 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.

Under the Director Incentive 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. This plan is similar to MGE Energy's Performance Unit Plan for eligible employees described above. In January 2016, 3,773 units were granted.

During the three months endedMarch 31,2016 and 2015, MGE recorded $1.3 million and $0.5 million, respectively, in compensation expense as a result of awards under the plans. In January 2016, cash payments of $1.2 million were distributed relating to awards that were granted in 2011. During the three months endedMarch 31,2015, MGE recorded a $0.2 million gain on 4,676 units forfeited. No forfeitures occurred during the three months endedMarch 31,2016. At March 31,2016, $5.3 million of outstanding awards are vested, and of this amount, no cash settlements have occurred.

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Commitments and Contingencies

3 Months Ended

Mar. 31, 2016

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 we conduct our 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:

EPA's Effluent Limitations Guidelines (ELG) and Standards for Steam Electric Power Generating Point Source Category

In November 2015, the EPA published its final rule setting Effluent Limitations Guidelines (ELG) for the steam electric power generating industry. The ELG rule establishes federal limits on the amount of metals and other pollutants that can be discharged in wastewater from new and existing steam electric generation plants. The ELG rule mostly covers pollutants that are captured by certain air pollution control systems and via wet ash handling systems at coal-burning power plants with units greater than 50 MW generation capacity. The operators of our Columbia and Elm Road Units have indicated that equipment upgrades may be necessary to comply with the new discharge standards. The rule will be applied to Wisconsin-based power plants as they renew their WPDES permits, beginning in 2018 but no later than 2023. Management believes that any compliance costs will be recovered in future rates based on previous treatment of environmental compliance projects.

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

Section 316(b) of the Clean Water Act requires that the cooling water intake structures at electric power plants meet best available technology standards so that mortality from entrainment (drawing aquatic life into a plant's cooling system) and impingement (trapping aquatic life on screens) are reduced. The EPA finalized its 316(b) rule for existing facilities in 2014. Section 316(b) requirements are implemented in Wisconsin through modifications to plants' WPDES permits, which govern plant wastewater discharges. WDNR is currently developing rules to implement the EPA 316(b) rule.

Our WCCF, Blount, and Columbia plants are considered existing plants under this rule. Our WCCF facility already employs a system that meets the 316(b) rule. Our Blount plant has conducted studies showing that it will likely be in compliance with this rule when its WPDES permit is renewed in 2017. The operator of our Columbia plant plans to conduct an intake study to demonstrate compliance with the 316(b) rule and/or identify design criteria needed to meet the new rule requirements prior to Columbia's 2017 WPDES permit renewal. The exact requirements at Blount and Columbia, however, will not be known until the WDNR finalizes its rule, approves the plant operators' approach, and those sites' WPDES permits are modified to account for this rule. Nonetheless, MGE expects that the 316(b) rule will not have material effects on its existing plants.

EPA's Greenhouse Gas (GHG) Reduction Guidelines under the Clean Air Act 111(d) Rule

In October 2015, the EPA published its Clean Power Plan (CPP) rule, which went into effect in December 2015, setting guidelines and approval criteria for states to use in developing plans to control GHG emissions from existing fossil fuel-fired electric generating units (EGUs) and systems. In October 2015, the EPA also published a proposed federal implementation plan under the CPP rule. The proposed federal implementation plan is designed to provide mass-based and rate-based emissions trading options to serve as a model and/or resource for states that are adopting their own plans, or for use by the EPA in states that do not implement their own plans under the finalized CPP. Implementation of the rule is expected to have a direct impact on existing coal and natural gas fired generating units, including possible changes in dispatch and additional operating costs.

On January 26, 2016, several parties filed a request for a stay of the CPP with the U.S. Supreme Court; and on February 9, 2016, the U.S. Supreme Court granted that request. The CPP may not be implemented until the courts ultimately resolve the underlying legality of the rule. Oral arguments are scheduled before the D.C. Circuit for June 2, 2016.

Given the pending legal proceedings and the need for a yet-to-be-developed state implementation plan or finalization of the federal implementation plan, the nature and timing of any final requirements is subject to uncertainty. If the rule remains substantially in its present form, it is expected to have a material impact on MGE.

National Ambient Air Quality Standards (NAAQS)

The EPA's NAAQS regulations have been developed to set ambient levels of six pollutants to protect sensitive populations (primary NAAQS) and the environment (secondary NAAQS) from the negative effects of exposure to these pollutants at higher levels. MGE is following developments for several NAAQS, including for particulate matter, nitrogen dioxide, sulfur dioxide, and ozone. Further discussion on sulfur dioxide, ozone, and nitrogen dioxide NAAQS follows. For additional information on the NAAQS process, see Footnote 18.c. of Notes to Consolidated Financial Statements under Item 8, Financial Statements and Supplementary Data, of MGE Energy's and MGE's 2015 Annual Report on Form 10-K.

Ozone NAAQS

In October 2015, the EPA revised the primary and secondary ozone NAAQS, lowering each to 70 ppb. The rule became effective in December 2015. Based on current ozone monitoring data, it appears that Milwaukee County (where our Elm Road Units are located) will likely not attain the lowered standards, and Dane and Columbia Counties (where our WCCF/Blount and Columbia Units are located, respectively) may or may not attain them. It is too early to determine, however, as final attainment designations for these three counties will be based upon air monitoring data for years 2014-2016 and must be approved by the EPA. Once these designations are complete, the State of Wisconsin will develop implementation plans for each county designated as nonattainment, which could affect operations and emission control obligations for plants located within the nonattainment counties. The State of Wisconsin has joined a lawsuit filed by several states challenging the EPA's new ozone standard alleging that the new standard is not attainable and the EPA is not properly considering background levels in setting its ozone attainment levels. Briefings in this challenge began in April 2016 and will continue through the summer. The final briefs are scheduled to be filed in September 2016. MGE will continue to monitor legal developments, attainment designations, and any state actions and implementation plans.

Sulfur Dioxide (SO₂) NAAQS

In March 2015, the EPA entered into a court-approved consent decree requiring 1-hour SO₂ attainment/nonattainment area designations to be completed in three phases extending out until 2020. In August 2015, the EPA published its data requirements rule and under this new rule, states must submit their first designation proposals by July 2016 for those areas that contain large stationary sources of SO₂ (sources that emit over a threshold mass of SO₂, and/or over a threshold emissions rate). MGE's Columbia Plant was identified as one of these types of sources and thus Wisconsin is required to submit a designation proposal for Columbia County (the county in which the Columbia Plant is located). Wisconsin sent a designation proposal for Columbia County to the EPA on September 15, 2015. Wisconsin proposed that Columbia be considered in attainment based on recent SO₂ air emissions modeling that took newly installed pollution controls into account. In February 2016, the EPA sent a response letter to the State of Wisconsin indicating that it agreed with Wisconsin's recommended designations, and has given a preliminary classification of Columbia County as an unclassified/ attainment area. The EPA stated in their response letter that they intend to finalize designations by July 2, 2016. In addition to the EPA's actions on SO₂ NAAQS, the WDNR is revising its state rules to incorporate the one hour SO₂ standard with a proposed final rule date of August 2016. MGE will continue to monitor developments until final designations are made, however, we do not anticipate any material costs from this rule.

Nitrogen Dioxide (NO₂) NAAQS

The WDNR is revising its state rules to incorporate the EPA's one hour NO₂ NAAQS rule that was finalized in 2010. The anticipated effective date of the state rule is August 1, 2016. Wisconsin's NO₂ NAAQS rule may affect our stationary fossil-fuel generation sources by requiring that we demonstrate consistency with the NAAQS when applying for certain air permits. Preliminary assessments conducted by MGE suggest that these NAAQS rules will not have a material impact. MGE will continue to monitor rule developments.

EPA's Cross-State Air Pollution Rule: Proposed Ozone Season Update based on 2008 Ozone NAAQS

The EPA's Cross-State Air Pollution Rule (CSAPR) is an interstate air pollution transport rule designed to reduce ozone and fine particulate (PM2.5) air levels in areas that the EPA has determined are being affected by pollution from neighboring and upwind states. This is accomplished in the CSAPR through a reduction in SO₂ and Nitrogen Oxides (NO_x) from fossil-fuel fired power plants. NO_x and SO₂ contribute to fine particulate pollution, and NO_x contributes to ozone. Reductions are achieved through a cap and trade model. Individual plants can meet their caps through modifications and/or buying allowances on the market.

In December 2015, the EPA published a proposed rule to amend the existing CSAPR. The proposed rule is designed to incorporate 2008 Ozone NAAQS attainment levels (the current CSAPR is based on 1997 Ozone NAAQS levels) in 23 states, including Wisconsin, by further limiting ozone season NO_x levels through a reduction in NO_x allowances. The proposed rule also includes revisions to CSAPR that are designed to address issues remaining from the D.C. Circuit remand of CSAPR, including Wisconsin's inclusion in the NO_x ozone season portion of the rule.

The proposed rule would reduce summertime NO_x emissions from power plants starting in 2017. Initial review of this proposed rule shows that we will likely need to buy NO_x Ozone Season allowances to comply with the rule. Depending on the cost of allowances, this requirement could be material for MGE. It is however too soon to tell what costs MGE will incur as the rule is not finalized, all legal proceedings are not completed, and the allowances are not on the market yet. We expect to monitor the rule developments and the D.C. Circuit Court remand completion to help determine how this rule will ultimately affect MGE.

Clean Air Visibility Rule (CAVR)

Columbia may be subject to the best available retrofit technology (BART) regulations, a subsection of the EPA's Clean Air Visibility Rule (CAVR), which may require pollution control retrofits. Columbia's pollution control upgrades and the EPA's stance that compliance with the CSAPR equals compliance with BART should mean that Columbia will not need to do additional work to meet BART requirements. In February 2016, the EPA submitted a proposed revision to the CAVR. The proposed revision would move state plan due dates from July 2018 to July 2021. This would allow for states to coordinate their CAVR compliance with other compliance efforts. If this proposed revision is finalized, it would reduce the chances that CAVR would be material for MGE. At this time, however, the BART regulatory obligations, compliance strategies, and costs remain uncertain due to the continued legal uncertainty surrounding CSAPR.

Solid Waste

EPA's Coal Combustion Residuals Rule

In December 2014, the EPA finalized its Disposal of Coal Combustion Residuals from Electric Utilities (CCR) rule. The rule became effective in October 2015. It provides that coal ash will be regulated as a solid waste, and defines what ash use activities would be considered generally exempt beneficial reuse of coal ash. The rule also regulates landfills, ash ponds, and other surface impoundments for coal combustion residuals by regulating their design, location, monitoring, and operation. This portion of the rule is accomplished in phases to allow for sites with onsite storage and/or disposal to evaluate their compliance with the rule's design criteria. Landfills and impoundments that cannot meet design criteria will need to close formally within defined timeframes.

The Columbia and Elm Road Units co-owners and plant operators are working through the phased requirements to determine what changes may be necessary at those facilities to meet design criteria. We anticipate that some design and operational changes may need to be made at these facilities. Review of our Elm Road facility has indicated that the costs to comply with this rule are not expected to be significant. Columbia's operator has developed a preliminary implementation schedule for meeting the various deadlines spelled out in the rule. Costs at Columbia will be dependent on what is determined during the evaluation stage. Management believes compliance costs will be recovered in future rates based on previous treatment of environmental compliance projects.

b. 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.

c. Purchase Contracts.

MGE Energy and MGE have entered into various commodity transportation and storage contracts to meet their obligations to deliver natural gas to customers. As of March 31,2016, the future commitments related to these purchase contracts were as follows:

(In thousands)		2016		2017		2018		2019		2020
Natural gas transportation & storage(a)	$	14,000	$	24,902	$	24,833	$	23,048	$	16,274

(a)MGE's natural gas transportation and storage contracts require fixed monthly payments for firm supply pipeline transportation and storage capacity. The pricing components of the fixed monthly payments for the transportation and storage contracts are established by FERC but may be subject to change.

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Derivative and Hedging Instruments

3 Months Ended

Mar. 31, 2016

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. 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. MGE's commodity 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, 2016	December 31, 2015
Commodity derivative contracts	468,590 MWh	355,580 MWh
Commodity derivative contracts	2,317,500 Dth	5,037,500 Dth
FTRs	770 MW	2,000 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 electricity 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 31,2016, and December 31,2015, the cost basis of exchange traded derivatives and FTRs exceeded their fair value by $1.0 million and $0.8 million, respectively.

MGE is a party to a 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 sheets. 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 31,2016, and December 31, 2015, reflects a loss position of $55.9 million and $53.3 million, respectively. The actual 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 sheets. 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. At March 31,2016, MGE Energy and MGE had the right to reclaim collateral (a receivable) of $1.0 million.

	Asset Derivatives			Liability Derivatives
(In thousands)	Balance Sheet Location		Fair Value	Balance Sheet Location		Fair Value
March 31, 2016
Commodity derivative contracts	Other current assets	$	441	Derivative liability (current)	$	1,303
Commodity derivative contracts	Other deferred charges		53	Derivative liability (long-term)		184
FTRs	Other current assets		19	Derivative liability (current)		-
PPA	N/A		N/A	Derivative liability (current)		9,370
PPA	N/A		N/A	Derivative liability (long-term)		46,540
December 31, 2015
Commodity derivative contracts	Other current assets	$	146	Derivative liability (current)	$	1,266
Commodity derivative contracts	Other deferred charges		144	Derivative liability (long-term)		70
FTRs	Other current assets		234	Derivative liability (current)		-
PPA	N/A		N/A	Derivative liability (current)		8,340
PPA	N/A		N/A	Derivative liability (long-term)		44,930

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 consolidated balance sheets.

Offsetting of Derivative Assets
(In thousands)		Gross Amounts		Gross Amounts Offset in Balance Sheets		Collateral Posted Against Derivative Positions		Net Amount Presented in Balance Sheet
March 31, 2016
Commodity derivative contracts	$	494	$	(494)	$	-	$	-
FTRs		19		-		-		19
December 31, 2015
Commodity derivative contracts	$	290	$	(290)	$	-	$	-
FTRs		234		-		-		234

Offsetting of Derivative Liabilities
(In thousands)		Gross Amounts		Gross Amounts Offset in Balance Sheets		Collateral Posted Against Derivative Positions		Net Amount Presented in Balance Sheets
March 31, 2016
Commodity derivative contracts	$	1,487	$	(494)	$	(989)	$	4
PPA		55,910		-		-		55,910
December 31, 2015
Commodity derivative contracts	$	1,336	$	(290)	$	(1,038)	$	8
PPA		53,270		-		-		53,270

The following tables summarize the unrealized and realized gains (losses) related to the derivative instruments on the consolidated balance sheets at March 31,2016 and 2015, and the consolidated income statements for the three months endedMarch 31,2016 and 2015.

		2016				2015
(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,	$	54,083	$	1,208	$	54,998	$	1,001
Unrealized loss		6,370		-		1,318		-
Realized (loss) gain reclassified to a deferred account		(1,451)		1,451		(1,061)		1,061
Realized loss reclassified to income
statement		(2,118)		(2,004)		(1,289)		(1,794)
Balance at March 31,	$	56,884	$	655	$	53,966	$	268

		Realized losses (gains)
		2016				2015
(In thousands)		Fuel for Electric Generation/ Purchased Power		Cost of Gas Sold		Fuel for Electric Generation/ Purchased Power		Cost of Gas Sold
Three Months Ended March 31:
Commodity derivative contracts	$	1,007	$	1,814	$	420	$	1,761
FTRs		(68)		-		(119)		-
PPA		1,369		-		1,021		-

MGE's commodity derivative contracts, FTRs, and 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 sheets 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 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 31,2016, no collateral is required to be, or 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 31,2016, and December 31, 2015, certain counterparties were in a net liability of less than $0.1 million.

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 31,2016,no counterparties have defaulted.

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Rate Matters

3 Months Ended

Mar. 31, 2016

Regulated Operations [Abstract]

Rate Matters

Rate Matters - MGE Energy and MGE.

a. Rate Proceedings.

In April 2016, MGE filed an application with the PSCW requesting a 1.7% increase to electric rates and a 3.7% increase to gas rates for 2017. The proposed electric and gas rate increases cover costs primarily associated with the state's electric transmission and MGE's natural gas system infrastructure improvements. In its application, MGE has also proposed mechanisms to address potential 2018 electric and gas rate changes, including a rate adjustment for limited issues and escrow accounting on certain costs.

In July 2015, the PSCW approved MGE's request to extend the current accounting treatment for transmission related costs through2016, conditioned upon MGE not filing a base rate case for 2016. This accounting treatment will allow MGE to reflect any differential between transmission costs reflected in rates and actual costs incurred in its next rate case filing, which occurred in the April 2016 filing.

On December 23, 2014, the PSCW authorized MGE to increase 2015 rates for retail electric customers by 3.8% or $15.4 million and to decrease gas rates by 2.0% or $3.8 million. The increase in retail electric rates cover costs associated with the construction of emission-reduction equipment at Columbia, improvements and reliability of the state's electric transmission system, fuel and purchased power related to coal delivery costs, partially offset by lower cost as a result of market conditions for pension and postretirement benefit costs. The authorized return on common stock equity is 10.2%.

The PSCW also approved changes to customer rates and rate design for gas service that became effective January 1, 2015. Gas rate design consists of a fixed monthly customer charge and a variable charge tied to actual usage, in addition to the separate charge through the PGA for natural gas commodity costs. The change shifted more of the rate recovery to the monthly charge, reflecting the related fixed costs of providing gas services, and reduced the variable usage-based charge. Thus, gas net income is expected to be more evenly distributed during the year and less sensitive to weather.

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 annual fuel proceedings. Any over/under recovery of the actual costs is determined on an annual basis and is 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.

In August 2015, the PSCW approved a $0.00256/kWh fuel credit that began on September 1, 2015, and will continue throughout 2016. The fuel credit established a mechanism to return fuel savings to electric customers as a bill credit. MGE returned $2.6million of electric fuel-related savings in customer bill credits during the period from September 1, 2015, through December 31, 2015. MGE returned $1.9million of electric fuel-related savings for the three months endedMarch 31,2016. As of December 31, 2015 and March 31,2016, MGE has a remaining deferred balance of $9.5 million and $7.6millionof electric fuel-related savings that are outside the range authorized by the PSCW, respectively. These costs are subject to PSCW's annual review, expected to be completed in 2016.

In January 2016, the PSCW lowered MGE's 2016 fuel rules monitored costs by $14.8 million as a result of continued lower projected fuel costs in 2016. The return of the fuel savings to customers for 2016 will be addressed during the PSCW's annual review during 2016 of 2015 fuel costs. MGE will defer these fuel savings until a determination is made by the PSCW. As of March 31,2016, MGE has deferred $3.6million of these 2016 electric fuel rules monitored costs.

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Fair Value of Financial Instruments

3 Months Ended

Mar. 31, 2016

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 accounting 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 31,2016, and December 31, 2015, the carrying amount of cash, cash equivalents, and outstanding commercial paper approximates fair market value due to the short maturity of those investments and obligations. The estimated fair market value of MGE Energy's and MGE's long-term debt is based on quoted market prices for similar financial instruments at March 31,2016, and December 31, 2015. 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, 2016				December 31, 2015
(In thousands)		Carrying Amount		Fair Value		Carrying Amount		Fair Value
MGE Energy
Assets:
Cash and cash equivalents	$	97,331	$	97,331	$	81,384	$	81,384
Liabilities:
Long-term debt*		394,450		459,213		395,508		435,767
MGE
Assets:
Cash and cash equivalents	$	36,809	$	36,809	$	26,760	$	26,760
Liabilities:
Long-term debt*		394,450		459,213		395,508		435,767
*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, 2016
(In thousands)		Total		Level 1		Level 2		Level 3
MGE Energy
Assets:
Derivatives, net(a)	$	236	$	217	$	-	$	19
Exchange-traded investments		485		485		-		-
Total Assets	$	721	$	702	$	-	$	19
Liabilities:
Derivatives, net(a)	$	57,120	$	-	$	-	$	57,120
Deferred compensation		3,228		-		3,228		-
Total Liabilities	$	60,348	$	-	$	3,228	$	57,120
MGE
Assets:
Derivatives, net(a)	$	236	$	217	$	-	$	19
Exchange-traded investments		99		99		-		-
Total Assets	$	335	$	316	$	-	$	19
Liabilities:
Derivatives, net(a)	$	57,120	$	-	$	-	$	57,120
Deferred compensation		3,228		-		3,228		-
Total Liabilities	$	60,348	$	-	$	3,228	$	57,120

		Fair Value as of December 31, 2015
(In thousands)		Total		Level 1		Level 2		Level 3
MGE Energy
Assets:
Derivatives, net	$	234	$	-	$	-	$	234
Exchange-traded investments		759		759		-		-
Total Assets	$	993	$	759	$	-	$	234
Liabilities:
Derivatives, net(a)	$	54,316	$	581	$	-	$	53,735
Deferred compensation		3,145		-		3,145		-
Total Liabilities	$	57,461	$	581	$	3,145	$	53,735
MGE
Assets:
Derivatives, net	$	234	$	-	$	-	$	234
Exchange-traded investments		148		148		-		-
Total Assets	$	382	$	148	$	-	$	234
Liabilities:
Derivatives, net(a)	$	54,316	$	581	$	-	$	53,735
Deferred compensation		3,145		-		3,145		-
Total Liabilities	$	57,461	$	581	$	3,145	$	53,735
(a) These amounts are shown gross and exclude $1.0 million of collateral that was
posted against derivative positions with counterparties as of March 31, 2016, and
December 31, 2015.

No transfers were made in or out of Level 1 or Level 2 for the three months endedMarch 31,2016.

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 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 considered unobservable and classified as Level 3. Transactions done with an over-the-counter party are on inactive markets and are therefore classified as Level 3. These transactions are valued based on quoted prices from markets with similar exchange traded transactions. FTRs are priced based upon monthly auction results for identical or similar instruments in a closed market with limited data available and are therefore classified as Level 3.

The purchased power agreement (see Footnote 8) 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.

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

	Model Input
Significant Unobservable Inputs	March 31, 2016	December 31, 2015
Basis adjustment:
On peak	96.7%	96.9%
Off peak	95.9%	95.1%
Counterparty fuel mix:
Internal generation	55% - 75%	60% - 75%
Purchased power	45% - 25%	40% - 25%

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)		2016		2015
Beginning balance	$	(53,501)	$	(53,986)
Realized and unrealized gains (losses):
Included in regulatory (assets) liabilities		(3,600)		119
Included in other comprehensive income		-		-
Included in earnings		(2,163)		(1,328)
Included in current assets		-		-
Purchases		5,301		6,162
Sales		-		-
Issuances		-		-
Settlements		(3,138)		(4,833)
Transfers in and/or out of Level 3		-		-
Balance as of March 31,	$	(57,101)	$	(53,866)
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)		2016		2015
Purchased Power Expense	$	(2,163)	$	(1,328)

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

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New Accounting Pronouncements

3 Months Ended

Mar. 31, 2016

New Accounting Pronouncements and Changes in Accounting Principles [Abstract]

New Accounting Pronouncements

New Accounting Pronouncements - MGE Energy and MGE.

a.Revenue from Contracts with Customers.

In May 2014, the FASB issued authoritative guidance within the Codification's Revenue Recognition topic that provides guidance on the recognition, measurement, and disclosure of revenue from contracts with customers. This authoritative guidance will become effective January 1, 2018. MGE Energy and MGE are currently assessing the impact this pronouncement will have on their financial statements.

b.Consolidation.

In February 2015, the FASB issued authoritative guidance within the Codification's Consolidation topic that provides guidance on the evaluation of certain legal entities for consolidation purposes. This authoritative guidance became effective January 1, 2016. This guidance had no impact on our financial statements.

c.Debt Issuance Costs.

In April 2015, the FASB issued authoritative guidance within the Codification's Interest topic that provides guidance on the presentation of debt issuance costs in financial statements. This authoritative guidance became effective January 1, 2016, and changed the presentation of debt issuance costs on the balance sheet. Prior to the authoritative guidance, debt issuance costs were treated as a deferred asset, and beginning January 1, 2016, these costs are included as a direct deduction to the related debt liability on the consolidated balance sheet. As of March 31, 2016, assets (other deferred assets and other) and liabilities (long-term debt) decreased approximately $4.2 million as a cumulative result of the guidance. In addition, this guidance was applied retrospectively to all prior periods presented, resulting in a decrease to assets and liabilities of $4.3 million for the year ended December 31, 2015.

d.Financial Instruments.

In January 2016, the FASB issued authoritative guidance within the Codification's Financial Instruments topic that provides guidance on the recognition and measurement of financial instruments. This authoritative guidance will become effective January 1, 2018. The impact of this guidance on our financial statements is not expected to be material.

e.Leases.

In February 2016, the FASB issued authoritative guidance within the Leasestopic that provides guidance on the classification, recognition, measurement, and disclosure of leases. This authoritative guidance willbecome effective January 1, 2019. MGE Energy and MGE are currently assessing the impact this pronouncement will have on their financial statements.

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Segment Information

3 Months Ended

Mar. 31, 2016

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 2015 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, 2016
Operating revenues	$	93,208	$	53,837	$	482	$	-	$	-	$	-	$	147,527
Interdepartmental revenues		456		5,097		10,977		-		-		(16,530)		-
Total operating revenues		93,664		58,934		11,459		-		-		(16,530)		147,527
Depreciation and amortization		(7,163)		(1,981)		(1,876)		-		(12)		-		(11,032)
Other operating expenses		(75,379)		(47,741)		(47)		(1)		(326)		16,530		(106,964)
Operating income (loss)		11,122		9,212		9,536		(1)		(338)		-		29,531
Other (deductions) income, net		196		(8)		-		2,233		21		-		2,442
Interest (expense) income, net		(2,790)		(808)		(1,463)		-		61		-		(5,000)
Income (loss) before taxes		8,528		8,396		8,073		2,232		(256)		-		26,973
Income tax (provision) benefit		(2,536)		(3,359)		(3,240)		(897)		87		-		(9,945)
Net income (loss)	$	5,992	$	5,037	$	4,833	$	1,335	$	(169)	$	-	$	17,028
Three Months Ended March 31, 2015
Operating revenues	$	98,240	$	69,928	$	1,966	$	-	$	-	$	-	$	170,134
Interdepartmental revenues		115		2,725		9,847		-		-		(12,687)		-
Total operating revenues		98,355		72,653		11,813		-		-		(12,687)		170,134
Depreciation and amortization		(7,332)		(1,642)		(1,863)		-		(12)		-		(10,849)
Other operating expenses		(79,800)		(60,068)		(50)		-		(203)		12,687		(127,434)
Operating income (loss)		11,223		10,943		9,900		-		(215)		-		31,851
Other (deductions) income, net		90		(1)		-		1,881		135		-		2,105
Interest (expense) income, net		(2,819)		(804)		(1,518)		-		50		-		(5,091)
Income (loss) before taxes		8,494		10,138		8,382		1,881		(30)		-		28,865
Income tax provision		(2,383)		(4,081)		(3,364)		(756)		(3)		-		(10,587)
Net income (loss)	$	6,111	$	6,057	$	5,018	$	1,125	$	(33)	$	-	$	18,278

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, 2016
Operating revenues	$	93,214	$	53,847	$	482	$	-	$	-	$	147,543
Interdepartmental revenues		450		5,087		10,977		-		(16,514)		-
Total operating revenues		93,664		58,934		11,459		-		(16,514)		147,543
Depreciation and amortization		(7,163)		(1,981)		(1,876)		-		-		(11,020)
Other operating expenses*		(77,879)		(51,091)		(3,287)		(1)		16,514		(115,744)
Operating income (loss)*		8,622		5,862		6,296		(1)		-		20,779
Other (deductions) income, net*		160		(17)		-		1,336		-		1,479
Interest expense, net		(2,790)		(808)		(1,463)		-		-		(5,061)
Net income		5,992		5,037		4,833		1,335		-		17,197
Less: Net income attributable to
noncontrolling interest, net of tax		-		-		-		-		(6,252)		(6,252)
Net income attributable to MGE	$	5,992	$	5,037	$	4,833	$	1,335	$	(6,252)	$	10,945
Three Months Ended March 31, 2015
Operating revenues	$	98,245	$	69,933	$	1,966	$	-	$	-	$	170,144
Interdepartmental revenues		110		2,720		9,847		-		(12,677)		-
Total operating revenues		98,355		72,653		11,813		-		(12,677)		170,144
Depreciation and amortization		(7,332)		(1,642)		(1,863)		-		-		(10,837)
Other operating expenses*		(82,142)		(64,138)		(3,414)		-		12,677		(137,017)
Operating income*		8,881		6,873		6,536		-		-		22,290
Other (deductions) income, net*		49		(12)		-		1,125		-		1,162
Interest expense, net		(2,819)		(804)		(1,518)		-		-		(5,141)
Net income		6,111		6,057		5,018		1,125		-		18,311
Less: Net income attributable to
noncontrolling interest, net of tax		-		-		-		-		(6,553)		(6,553)
Net income attributable to MGE	$	6,111	$	6,057	$	5,018	$	1,125	$	(6,553)	$	11,758
*Amounts are shown net of the related tax expense, consistent with the presentation on the MGE Consolidated Statement of Income.

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Significant Accounting Policies (Policies)

3 Months Ended

Mar. 31, 2016

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 accounting 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.

Investments - ATC

MGE Transco has accounted for its investment in ATC under the equity method of accounting.

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 February 2016, 19,055 units were granted based on the MGE Energy closing stock price as of that date. Units are subject to a five-year graded vesting schedule. On the grant date, MGE Energy and MGE measure the cost of the employee services received in exchange for a performance unit award based on the current market value of MGE Energy common stock. The fair value of the awards is re-measured quarterly, including atMarch 31,2016, as required by applicable accounting standards. Changes in fair value as well as the original grant are recognized as compensation cost. Since this amount is re-measured 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.

Under the Director Incentive 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. This plan is similar to MGE Energy's Performance Unit Plan for eligible employees described above. In January 2016, 3,773 units were granted.

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. 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. MGE's commodity 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 annual fuel proceedings. Any over/under recovery of the actual costs is determined on an annual basis and is 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 accounting 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 31,2016, and December 31, 2015, the carrying amount of cash, cash equivalents, and outstanding commercial paper approximates fair market value due to the short maturity of those investments and obligations. The estimated fair market value of MGE Energy's and MGE's long-term debt is based on quoted market prices for similar financial instruments at March 31,2016, and December 31, 2015. 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 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 considered unobservable and classified as Level 3. Transactions done with an over-the-counter party are on inactive markets and are therefore classified as Level 3. These transactions are valued based on quoted prices from markets with similar exchange traded transactions. FTRs are priced based upon monthly auction results for identical or similar instruments in a closed market with limited data available and are therefore classified as Level 3.

The purchased power agreement (see Footnote 8) 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.

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

	Model Input
Significant Unobservable Inputs	March 31, 2016	December 31, 2015
Basis adjustment:
On peak	96.7%	96.9%
Off peak	95.9%	95.1%
Counterparty fuel mix:
Internal generation	55% - 75%	60% - 75%
Purchased power	45% - 25%	40% - 25%

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

New Accounting Pronouncements - MGE Energy and MGE.

a.Revenue from Contracts with Customers.

In May 2014, the FASB issued authoritative guidance within the Codification's Revenue Recognition topic that provides guidance on the recognition, measurement, and disclosure of revenue from contracts with customers. This authoritative guidance will become effective January 1, 2018. MGE Energy and MGE are currently assessing the impact this pronouncement will have on their financial statements.

b.Consolidation.

In February 2015, the FASB issued authoritative guidance within the Codification's Consolidation topic that provides guidance on the evaluation of certain legal entities for consolidation purposes. This authoritative guidance became effective January 1, 2016. This guidance had no impact on our financial statements.

c.Debt Issuance Costs.

In April 2015, the FASB issued authoritative guidance within the Codification's Interest topic that provides guidance on the presentation of debt issuance costs in financial statements. This authoritative guidance became effective January 1, 2016, and changed the presentation of debt issuance costs on the balance sheet. Prior to the authoritative guidance, debt issuance costs were treated as a deferred asset, and beginning January 1, 2016, these costs are included as a direct deduction to the related debt liability on the consolidated balance sheet. As of March 31, 2016, assets (other deferred assets and other) and liabilities (long-term debt) decreased approximately $4.2 million as a cumulative result of the guidance. In addition, this guidance was applied retrospectively to all prior periods presented, resulting in a decrease to assets and liabilities of $4.3 million for the year ended December 31, 2015.

d.Financial Instruments.

In January 2016, the FASB issued authoritative guidance within the Codification's Financial Instruments topic that provides guidance on the recognition and measurement of financial instruments. This authoritative guidance will become effective January 1, 2018. The impact of this guidance on our financial statements is not expected to be material.

e.Leases.

In February 2016, the FASB issued authoritative guidance within the Leasestopic that provides guidance on the classification, recognition, measurement, and disclosure of leases. This authoritative guidance willbecome effective January 1, 2019. MGE Energy and MGE are currently assessing the impact this pronouncement will have on their financial statements.

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Investment in ATC (Tables)

3 Months Ended

Mar. 31, 2016

Equity Method Investments and Joint Ventures [Abstract]

ATC's Summarized Financial Data

For the three months endedMarch 31,2016 and 2015, MGE Transco recorded the following:

		Three Months Ended
		March 31,
(In thousands)		2016		2015
Equity in earnings from investment in ATC	$	2,233	$	1,881
Dividends received from ATC		865		1,420
Capital contributions to ATC		533		178

ATC's summarized financial data for the three months endedMarch 31,2016 and 2015, is as follows:

		Three Months Ended
		March 31,
(In thousands)		2016		2015
Operating revenues	$	164,240	$	152,357
Operating expenses		(79,065)		(79,951)
Other income, net		127		62
Interest expense, net		(24,208)		(24,483)
Earnings before members' income taxes	$	61,094	$	47,985

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Pension and Other Postretirement Plans (Tables)

3 Months Ended

Mar. 31, 2016

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 31,2016 and 2015. A portion of the net periodic benefit cost is capitalized within the consolidated balance sheets.

		Three Months Ended
		March 31,
(In thousands)		2016		2015
Pension Benefits
Components of net periodic cost:
Service cost	$	1,381	$	1,798
Interest cost		3,089		3,440
Expected return on assets		(5,593)		(5,677)
Amortization of:
Prior service cost		2		6
Actuarial loss		1,356		1,334
Net periodic cost	$	235	$	901
Postretirement Benefits
Components of net periodic (benefit) cost:
Service cost	$	324	$	383
Interest cost		674		778
Expected return on assets		(705)		(703)
Amortization of:
Transition obligation		1		1
Prior service benefit		(667)		(667)
Actuarial loss		159		262
Net periodic (benefit) cost	$	(214)	$	54

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Commitments and Contingencies (Tables)

3 Months Ended

Mar. 31, 2016

Commitments and Contingencies Disclosure [Abstract]

Purchase Contracts, Fiscal Year Maturity Schedule

As of March 31,2016, the future commitments related to these purchase contracts were as follows:

(In thousands)		2016		2017		2018		2019		2020
Natural gas transportation & storage(a)	$	14,000	$	24,902	$	24,833	$	23,048	$	16,274

(a)MGE's natural gas transportation and storage contracts require fixed monthly payments for firm supply pipeline transportation and storage capacity. The pricing components of the fixed monthly payments for the transportation and storage contracts are established by FERC but may be subject to change.

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Derivative and Hedging Instruments (Tables)

3 Months Ended

Mar. 31, 2016

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, 2016	December 31, 2015
Commodity derivative contracts	468,590 MWh	355,580 MWh
Commodity derivative contracts	2,317,500 Dth	5,037,500 Dth
FTRs	770 MW	2,000 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 sheets. 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. At March 31,2016, MGE Energy and MGE had the right to reclaim collateral (a receivable) of $1.0 million.

	Asset Derivatives			Liability Derivatives
(In thousands)	Balance Sheet Location		Fair Value	Balance Sheet Location		Fair Value
March 31, 2016
Commodity derivative contracts	Other current assets	$	441	Derivative liability (current)	$	1,303
Commodity derivative contracts	Other deferred charges		53	Derivative liability (long-term)		184
FTRs	Other current assets		19	Derivative liability (current)		-
PPA	N/A		N/A	Derivative liability (current)		9,370
PPA	N/A		N/A	Derivative liability (long-term)		46,540
December 31, 2015
Commodity derivative contracts	Other current assets	$	146	Derivative liability (current)	$	1,266
Commodity derivative contracts	Other deferred charges		144	Derivative liability (long-term)		70
FTRs	Other current assets		234	Derivative liability (current)		-
PPA	N/A		N/A	Derivative liability (current)		8,340
PPA	N/A		N/A	Derivative liability (long-term)		44,930

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 consolidated balance sheets.

Offsetting of Derivative Assets
(In thousands)		Gross Amounts		Gross Amounts Offset in Balance Sheets		Collateral Posted Against Derivative Positions		Net Amount Presented in Balance Sheet
March 31, 2016
Commodity derivative contracts	$	494	$	(494)	$	-	$	-
FTRs		19		-		-		19
December 31, 2015
Commodity derivative contracts	$	290	$	(290)	$	-	$	-
FTRs		234		-		-		234

Offsetting Liabilities

Offsetting of Derivative Liabilities
(In thousands)		Gross Amounts		Gross Amounts Offset in Balance Sheets		Collateral Posted Against Derivative Positions		Net Amount Presented in Balance Sheets
March 31, 2016
Commodity derivative contracts	$	1,487	$	(494)	$	(989)	$	4
PPA		55,910		-		-		55,910
December 31, 2015
Commodity derivative contracts	$	1,336	$	(290)	$	(1,038)	$	8
PPA		53,270		-		-		53,270

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 sheets at March 31,2016 and 2015, and the consolidated income statements for the three months endedMarch 31,2016 and 2015.

		2016				2015
(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,	$	54,083	$	1,208	$	54,998	$	1,001
Unrealized loss		6,370		-		1,318		-
Realized (loss) gain reclassified to a deferred account		(1,451)		1,451		(1,061)		1,061
Realized loss reclassified to income
statement		(2,118)		(2,004)		(1,289)		(1,794)
Balance at March 31,	$	56,884	$	655	$	53,966	$	268

Derivative Gains and Losses in Income Statement

		Realized losses (gains)
		2016				2015
(In thousands)		Fuel for Electric Generation/ Purchased Power		Cost of Gas Sold		Fuel for Electric Generation/ Purchased Power		Cost of Gas Sold
Three Months Ended March 31:
Commodity derivative contracts	$	1,007	$	1,814	$	420	$	1,761
FTRs		(68)		-		(119)		-
PPA		1,369		-		1,021		-

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Fair Value of Financial Instruments (Tables)

3 Months Ended

Mar. 31, 2016

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, 2016				December 31, 2015
(In thousands)		Carrying Amount		Fair Value		Carrying Amount		Fair Value
MGE Energy
Assets:
Cash and cash equivalents	$	97,331	$	97,331	$	81,384	$	81,384
Liabilities:
Long-term debt*		394,450		459,213		395,508		435,767
MGE
Assets:
Cash and cash equivalents	$	36,809	$	36,809	$	26,760	$	26,760
Liabilities:
Long-term debt*		394,450		459,213		395,508		435,767
*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, 2016
(In thousands)		Total		Level 1		Level 2		Level 3
MGE Energy
Assets:
Derivatives, net(a)	$	236	$	217	$	-	$	19
Exchange-traded investments		485		485		-		-
Total Assets	$	721	$	702	$	-	$	19
Liabilities:
Derivatives, net(a)	$	57,120	$	-	$	-	$	57,120
Deferred compensation		3,228		-		3,228		-
Total Liabilities	$	60,348	$	-	$	3,228	$	57,120
MGE
Assets:
Derivatives, net(a)	$	236	$	217	$	-	$	19
Exchange-traded investments		99		99		-		-
Total Assets	$	335	$	316	$	-	$	19
Liabilities:
Derivatives, net(a)	$	57,120	$	-	$	-	$	57,120
Deferred compensation		3,228		-		3,228		-
Total Liabilities	$	60,348	$	-	$	3,228	$	57,120

		Fair Value as of December 31, 2015
(In thousands)		Total		Level 1		Level 2		Level 3
MGE Energy
Assets:
Derivatives, net	$	234	$	-	$	-	$	234
Exchange-traded investments		759		759		-		-
Total Assets	$	993	$	759	$	-	$	234
Liabilities:
Derivatives, net(a)	$	54,316	$	581	$	-	$	53,735
Deferred compensation		3,145		-		3,145		-
Total Liabilities	$	57,461	$	581	$	3,145	$	53,735
MGE
Assets:
Derivatives, net	$	234	$	-	$	-	$	234
Exchange-traded investments		148		148		-		-
Total Assets	$	382	$	148	$	-	$	234
Liabilities:
Derivatives, net(a)	$	54,316	$	581	$	-	$	53,735
Deferred compensation		3,145		-		3,145		-
Total Liabilities	$	57,461	$	581	$	3,145	$	53,735
(a) These amounts are shown gross and exclude $1.0 million of collateral that was
posted against derivative positions with counterparties as of March 31, 2016, and
December 31, 2015.

Significant Unobservable Inputs

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

	Model Input
Significant Unobservable Inputs	March 31, 2016	December 31, 2015
Basis adjustment:
On peak	96.7%	96.9%
Off peak	95.9%	95.1%
Counterparty fuel mix:
Internal generation	55% - 75%	60% - 75%
Purchased power	45% - 25%	40% - 25%

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)		2016		2015
Beginning balance	$	(53,501)	$	(53,986)
Realized and unrealized gains (losses):
Included in regulatory (assets) liabilities		(3,600)		119
Included in other comprehensive income		-		-
Included in earnings		(2,163)		(1,328)
Included in current assets		-		-
Purchases		5,301		6,162
Sales		-		-
Issuances		-		-
Settlements		(3,138)		(4,833)
Transfers in and/or out of Level 3		-		-
Balance as of March 31,	$	(57,101)	$	(53,866)
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, purchased power agreement, and FTRs are subject to regulatory deferral. These derivatives are therefore marked to fair value and are offset in the financial statements 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)		2016		2015
Purchased Power Expense	$	(2,163)	$	(1,328)

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

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Segment Information (Tables)

3 Months Ended

Mar. 31, 2016

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, 2016
Operating revenues	$	93,208	$	53,837	$	482	$	-	$	-	$	-	$	147,527
Interdepartmental revenues		456		5,097		10,977		-		-		(16,530)		-
Total operating revenues		93,664		58,934		11,459		-		-		(16,530)		147,527
Depreciation and amortization		(7,163)		(1,981)		(1,876)		-		(12)		-		(11,032)
Other operating expenses		(75,379)		(47,741)		(47)		(1)		(326)		16,530		(106,964)
Operating income (loss)		11,122		9,212		9,536		(1)		(338)		-		29,531
Other (deductions) income, net		196		(8)		-		2,233		21		-		2,442
Interest (expense) income, net		(2,790)		(808)		(1,463)		-		61		-		(5,000)
Income (loss) before taxes		8,528		8,396		8,073		2,232		(256)		-		26,973
Income tax (provision) benefit		(2,536)		(3,359)		(3,240)		(897)		87		-		(9,945)
Net income (loss)	$	5,992	$	5,037	$	4,833	$	1,335	$	(169)	$	-	$	17,028
Three Months Ended March 31, 2015
Operating revenues	$	98,240	$	69,928	$	1,966	$	-	$	-	$	-	$	170,134
Interdepartmental revenues		115		2,725		9,847		-		-		(12,687)		-
Total operating revenues		98,355		72,653		11,813		-		-		(12,687)		170,134
Depreciation and amortization		(7,332)		(1,642)		(1,863)		-		(12)		-		(10,849)
Other operating expenses		(79,800)		(60,068)		(50)		-		(203)		12,687		(127,434)
Operating income (loss)		11,223		10,943		9,900		-		(215)		-		31,851
Other (deductions) income, net		90		(1)		-		1,881		135		-		2,105
Interest (expense) income, net		(2,819)		(804)		(1,518)		-		50		-		(5,091)
Income (loss) before taxes		8,494		10,138		8,382		1,881		(30)		-		28,865
Income tax provision		(2,383)		(4,081)		(3,364)		(756)		(3)		-		(10,587)
Net income (loss)	$	6,111	$	6,057	$	5,018	$	1,125	$	(33)	$	-	$	18,278

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, 2016
Operating revenues	$	93,214	$	53,847	$	482	$	-	$	-	$	147,543
Interdepartmental revenues		450		5,087		10,977		-		(16,514)		-
Total operating revenues		93,664		58,934		11,459		-		(16,514)		147,543
Depreciation and amortization		(7,163)		(1,981)		(1,876)		-		-		(11,020)
Other operating expenses*		(77,879)		(51,091)		(3,287)		(1)		16,514		(115,744)
Operating income (loss)*		8,622		5,862		6,296		(1)		-		20,779
Other (deductions) income, net*		160		(17)		-		1,336		-		1,479
Interest expense, net		(2,790)		(808)		(1,463)		-		-		(5,061)
Net income		5,992		5,037		4,833		1,335		-		17,197
Less: Net income attributable to
noncontrolling interest, net of tax		-		-		-		-		(6,252)		(6,252)
Net income attributable to MGE	$	5,992	$	5,037	$	4,833	$	1,335	$	(6,252)	$	10,945
Three Months Ended March 31, 2015
Operating revenues	$	98,245	$	69,933	$	1,966	$	-	$	-	$	170,144
Interdepartmental revenues		110		2,720		9,847		-		(12,677)		-
Total operating revenues		98,355		72,653		11,813		-		(12,677)		170,144
Depreciation and amortization		(7,332)		(1,642)		(1,863)		-		-		(10,837)
Other operating expenses*		(82,142)		(64,138)		(3,414)		-		12,677		(137,017)
Operating income*		8,881		6,873		6,536		-		-		22,290
Other (deductions) income, net*		49		(12)		-		1,125		-		1,162
Interest expense, net		(2,819)		(804)		(1,518)		-		-		(5,141)
Net income		6,111		6,057		5,018		1,125		-		18,311
Less: Net income attributable to
noncontrolling interest, net of tax		-		-		-		-		(6,553)		(6,553)
Net income attributable to MGE	$	6,111	$	6,057	$	5,018	$	1,125	$	(6,553)	$	11,758
*Amounts are shown net of the related tax expense, consistent with the presentation on the MGE Consolidated Statement of Income.

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Equity and Financing Arrangements (Details) - USD ($)	3 Months Ended
	Mar. 31, 2016	Mar. 31, 2015
Common Stock [Abstract]
Common stock issued during period	0	0
Dilutive Shares Calculation [Abstract]
Dilutive securities	$ 0

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Investment in ATC (Details-1) - USD ($) $ in Thousands	3 Months Ended
	Mar. 31, 2016	Mar. 31, 2015	Dec. 31, 2015
Schedule Of Equity Method Investments [Line Items]
Equity earnings from investment	$ 2,233	$ 1,881
Dividend income from investment	865	1,420
Contributions to investments	671	280
MGE Transco [Member] | ATC [Member]
Schedule Of Equity Method Investments [Line Items]
Equity earnings from investment	2,233	1,881
Dividend income from investment	865	1,420
Contributions to investments	533	178
Equity method investment	71,400		$ 69,500
MGE [Member]
Schedule Of Equity Method Investments [Line Items]
Equity earnings from investment	2,233	1,881
Dividend income from investment	865	1,420
Contributions to investments	$ 533	$ 178
Minority Interest [Line Items]
MGE's ownership interest in MGE Transco	51.00%
MGE Energy [Member]
Minority Interest [Line Items]
MGE Energy's ownership interest in MGE Transco	49.00%

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Investment in ATC (Details-2) - ATC [Member] - USD ($) $ in Thousands	3 Months Ended
	Mar. 31, 2016	Mar. 31, 2015
Schedule Of Equity Method Investments [Line Items]
Operating revenues	$ 164,240	$ 152,357
Operating expenses	(79,065)	(79,951)
Other income, net	127	62
Interest expense, net	(24,208)	(24,483)
Earnings before members' income taxes	$ 61,094	$ 47,985

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Taxes (Details)	3 Months Ended
	Mar. 31, 2016	Mar. 31, 2015
Income Tax Disclosure [Line Items]
Effective income tax rate	36.90%	36.70%
MGE [Member]
Income Tax Disclosure [Line Items]
Effective income tax rate	36.80%	36.60%

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Pension and Other Postretirement Plans (Details) - USD ($) $ in Thousands	3 Months Ended
	Mar. 31, 2016	Mar. 31, 2015
Pension Benefits [Member]
Components of net periodic cost (benefit):
Service cost	$ 1,381	$ 1,798
Interest cost	3,089	3,440
Expected return on assets	(5,593)	(5,677)
Amortization of:
Prior service cost (benefit)	2	6
Actuarial loss	1,356	1,334
Net periodic cost (benefit)	235	901
Postretirement Benefits [Member]
Components of net periodic cost (benefit):
Service cost	324	383
Interest cost	674	778
Expected return on assets	(705)	(703)
Amortization of:
Transition obligation	1	1
Prior service cost (benefit)	(667)	(667)
Actuarial loss	159	262
Net periodic cost (benefit)	$ (214)	$ 54

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Share Based Compensation (Details) - Performance Units [Member] - USD ($) $ in Millions		1 Months Ended	3 Months Ended
	Feb. 19, 2016	Jan. 31, 2016	Mar. 31, 2016	Mar. 31, 2015
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Compensation expense			$ 1.3	$ 0.5
Cash payments distributed related to awards previously granted and now payable		$ 1.2
Awards forfeited during period, value			$ 0.0	$ 0.2
Awards forfeited during period, units			0	4,676
Outstanding awards vested during period			$ 5.3
Performance Unit Plan [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Awards granted during period (in units)	19,055
Award vesting period			5 years
Director Incentive Agreement [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Awards granted during period (in units)		3,773
Award vesting period			3 years

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Commitments and Contingencies (Details-1) - EPA [Member] - Legal Entity Type of Counterparty [Domain]	3 Months Ended
	Mar. 31, 2016 ppb pollutant phase state MW
Effluent Limitations Guidelines and Standards for Steam Electric Power Generating Source Category [Abstract]
Air pollution control and ash handling systems capacity at coal burning power plants, minimum (in MW) | MW	50
EPA's National Ambient Air Quality Standards
Number of pollutants monitored by the National Ambient Air Quality Standards | pollutant	6
Sulfur Dioxide NAAQS
Number of phases for attainment and nonattainment area designation | phase	3
Ozone NAAQS
Current primary regulated level of Ozone NAAQS (in parts per billion)	70
Current secondary regulated level of Ozone NAAQS (in parts per billion)	70
EPA's Cross State Air Pollution Rule
Number of states incorporating 2008 ozone NAAQS attainment levels | state	23

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Commitments and Contingencies (Details-2) - Natural Gas, Transportation and Storage [Member] $ in Thousands	Mar. 31, 2016 USD ($)	[1]
Operating expense purchase contracts [Abstract]
Purchase obligation, 2016	$ 14,000
Purchase obligation, 2017	24,902
Purchase obligation, 2018	24,833
Purchase obligation, 2019	23,048
Purchase obligation, 2020	$ 16,274

[1] MGE's natural gas transportation and storage contracts require fixed monthly payments for firm supply pipeline transportation and storage capacity. The pricing components of the fixed monthly payments for the transportation and storage contracts are established by FERC but may be subject to change.

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Derivative and Hedging Instruments (Details-1) $ in Thousands	3 Months Ended	12 Months Ended
	Mar. 31, 2016 USD ($) Dth MWh MW	Dec. 31, 2015 USD ($) Dth MWh MW	Mar. 31, 2015 USD ($)	Dec. 31, 2014 USD ($)
Gross Notional Volume of Open Derivatives
Derivative, right to reclaim collateral (receivable)	$ 1,000
Other Current Assets [Member]
Derivative fair values [Abstract]
Derivative fair value, net	655	$ 1,208	$ 268	$ 1,001
Commodity Contracts And Financial Transimission Rights [Member]
Derivative fair values [Abstract]
Derivative fair value, net	$ (1,000)	$ (800)
Commodity Derivative Contracts [Member]
Gross Notional Volume of Open Derivatives
Notional amount, energy measure (in MWh) | MWh	468,590	355,580
Notional amount, decatherm measure (in Dth) | Dth	2,317,500	5,037,500
Derivative fair values [Abstract]
Asset Derivatives, fair value, gross basis	$ 494	$ 290
Liability Derivatives, fair value, gross basis	1,487	1,336
Commodity Derivative Contracts [Member] | Other Current Assets [Member]
Derivative fair values [Abstract]
Asset Derivatives, fair value, gross basis	441	146
Commodity Derivative Contracts [Member] | Other Deferred Charges [Member]
Derivative fair values [Abstract]
Asset Derivatives, fair value, gross basis	53	144
Commodity Derivative Contracts [Member] | Derivative Liability (Current) [Member]
Derivative fair values [Abstract]
Liability Derivatives, fair value, gross basis	1,303	1,266
Commodity Derivative Contracts [Member] | Derivative Liability (Long-term) [Member]
Derivative fair values [Abstract]
Liability Derivatives, fair value, gross basis	$ 184	$ 70
Energy Related Commodity Contract [Member] | Cash Flow Hedging [Member]
Derivatives Fair Value [Line Items]
Maximum term of derivative hedging contract	4 years
Financial Transmission Rights [Member]
Gross Notional Volume of Open Derivatives
Notional amount, power measure (in MW) | MW	770	2,000
Derivative fair values [Abstract]
Asset Derivatives, fair value, gross basis	$ 19	$ 234
Financial Transmission Rights [Member] | Other Current Assets [Member]
Derivative fair values [Abstract]
Asset Derivatives, fair value, gross basis	19	234
Financial Transmission Rights [Member] | Derivative Liability (Current) [Member]
Derivative fair values [Abstract]
Liability Derivatives, fair value, gross basis	0	0
PPA [Member]
Derivative fair values [Abstract]
Derivative fair value, net	(55,900)	(53,300)
Liability Derivatives, fair value, gross basis	55,910	53,270
PPA [Member] | Derivative Liability (Current) [Member]
Derivative fair values [Abstract]
Liability Derivatives, fair value, gross basis	9,370	8,340
PPA [Member] | Derivative Liability (Long-term) [Member]
Derivative fair values [Abstract]
Liability Derivatives, fair value, gross basis	$ 46,540	$ 44,930

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Derivative and Hedging Instruments (Details-2) - USD ($) $ in Thousands	Mar. 31, 2016	Dec. 31, 2015
Commodity Derivative Contracts [Member]
Offsetting Assets [Line Items]
Gross amounts	$ 494	$ 290
Gross amounts offset in balance sheet	(494)	(290)
Collateral posted against derivative positions	0	0
Net amount presented in balance sheet	0	0
Financial Transmission Rights [Member]
Offsetting Assets [Line Items]
Gross amounts	19	234
Gross amounts offset in balance sheet	0	0
Collateral posted against derivative positions	0	0
Net amount presented in balance sheet	$ 19	$ 234

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Derivative and Hedging Instruments (Details-3) - USD ($) $ in Thousands	Mar. 31, 2016	Dec. 31, 2015
Offsetting Liabilities [Line Items]
Collateral posted against derivative positions	$ (1,000)	$ (1,000)
Commodity Derivative Contracts [Member]
Offsetting Liabilities [Line Items]
Gross amounts	1,487	1,336
Gross amounts offset in balance sheet	(494)	(290)
Collateral posted against derivative positions	(989)	(1,038)
Net amount presented in balance sheet	4	8
Purchased Power Agreement [Member]
Offsetting Liabilities [Line Items]
Gross amounts	55,910	53,270
Gross amounts offset in balance sheet	0	0
Collateral posted against derivative positions	0	0
Net amount presented in balance sheet	$ 55,910	$ 53,270

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Derivative and Hedging Instruments (Details-4) - USD ($) $ in Thousands	3 Months Ended
	Mar. 31, 2016	Mar. 31, 2015
Current and Long-Term Regulatory Asset [Member]
Change In Derivative Fair Value [Roll Forward]
Beginning balance,	$ 54,083	$ 54,998
Unrealized loss	6,370	1,318
Realized gain (loss) reclassified to a deferred account	(1,451)	(1,061)
Realized loss reclassified to income statement	(2,118)	(1,289)
Ending balance,	56,884	53,966
Other Current Assets [Member]
Change In Derivative Fair Value [Roll Forward]
Beginning balance,	1,208	1,001
Unrealized loss	0	0
Realized gain (loss) reclassified to a deferred account	1,451	1,061
Realized loss reclassified to income statement	(2,004)	(1,794)
Ending balance,	$ 655	$ 268

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Derivative and Hedging Instruments (Details-5) $ in Thousands	3 Months Ended
	Mar. 31, 2016 USD ($) counterparty	Mar. 31, 2015 USD ($)	Dec. 31, 2015 USD ($)
Counterparties in net liability position or default [Abstract]
Derivative, net liability position of counterparties (less than $0.1 million)	$ 100		$ 100
Number of counterparties in default | counterparty	0
Commodity Derivative Contracts [Member] | Fuel For Electric Generation Purchased Power [Member]
Realized losses (gains) on income statement [Line Items]
Realized losses (gains) on income statement	$ 1,007	$ 420
Commodity Derivative Contracts [Member] | Cost Of Gas Sold Expense [Member]
Realized losses (gains) on income statement [Line Items]
Realized losses (gains) on income statement	1,814	1,761
Financial Transmission Rights [Member] | Fuel For Electric Generation Purchased Power [Member]
Realized losses (gains) on income statement [Line Items]
Realized losses (gains) on income statement	(68)	(119)
Financial Transmission Rights [Member] | Cost Of Gas Sold Expense [Member]
Realized losses (gains) on income statement [Line Items]
Realized losses (gains) on income statement	0	0
Purchased Power Agreement [Member]
Derivative collateral required to be posted for PPA [Abstract]
Minimum collateral that may be required to be posted	20,000
Maximum collateral that may be required to be posted	40,000
Collateral posted	0
Purchased Power Agreement [Member] | Fuel For Electric Generation Purchased Power [Member]
Realized losses (gains) on income statement [Line Items]
Realized losses (gains) on income statement	1,369	1,021
Purchased Power Agreement [Member] | Cost Of Gas Sold Expense [Member]
Realized losses (gains) on income statement [Line Items]
Realized losses (gains) on income statement	$ 0	$ 0

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Rate Matters (Details) - PSCW [Member] - MGE [Member] - USD ($)	3 Months Ended	4 Months Ended	12 Months Ended
	Mar. 31, 2016	Dec. 31, 2015	Dec. 31, 2017	Dec. 31, 2015	Jan. 31, 2016
Rate Proceedings [Abstract]
Authorized return on equity, percentage				10.20%
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%
Electric Fuel Monitored Costs, 2016 [Member]
Fuel Rules [Abstract]
Change in fuel rules monitored costs					$ (14,800,000)
Deferred fuel rules monitored costs	$ 3,600,000
Fuel Rules Credit, 2015/2016 [Member]
Fuel Rules [Abstract]
Electric fuel credit (per kWh)	0.00256	$ 0.00256
Fuel rules, deferred electric cost	7,600,000	9,500,000		$ 9,500,000
Return of electric fuel credit, total	$ 1,900,000	$ 2,600,000
Electric Rate Proceeding [Member]
Rate Proceedings [Abstract]
Authorized rate increase (decrease), percentage	0.00%			3.80%
Authorized rate increase (decrease), amount	$ 0			$ 15,400,000
Electric Rate Proceeding [Member] | Proposed Future Rate Matters [Member]
Rate Proceedings [Abstract]
Proposed rate increase (decrease), percentage			1.70%
Gas Rate Proceeding [Member]
Rate Proceedings [Abstract]
Authorized rate increase (decrease), percentage	0.00%			(2.00%)
Authorized rate increase (decrease), amount	$ 0			$ (3,800,000)
Gas Rate Proceeding [Member] | Proposed Future Rate Matters [Member]
Rate Proceedings [Abstract]
Proposed rate increase (decrease), percentage			3.70%

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Fair Value of Financial Instruments (Details-1) - USD ($) $ in Thousands		Mar. 31, 2016	Dec. 31, 2015
Carrying Amount [Member]
Assets:
Cash and cash equivalents		$ 97,331	$ 81,384
Liabilities:
Long-term debt	[1]	394,450	395,508
Fair Value [Member]
Assets:
Cash and cash equivalents		97,331	81,384
Liabilities:
Long-term debt	[1]	459,213	435,767
MGE [Member] | Carrying Amount [Member]
Assets:
Cash and cash equivalents		36,809	26,760
Liabilities:
Long-term debt	[1]	394,450	395,508
MGE [Member] | Fair Value [Member]
Assets:
Cash and cash equivalents		36,809	26,760
Liabilities:
Long-term debt	[1]	$ 459,213	$ 435,767

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

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Fair Value of Financial Instruments (Details-2) - USD ($) $ in Thousands		Mar. 31, 2016		Dec. 31, 2015
Liabilities:
Derivative liability, collateral offset		$ 1,000		$ 1,000
Recurring [Member]
Assets:
Derivative assets, net		236	[1]	234
Total Assets		721		993
Liabilities:
Derivative liabilities, net	[1]	57,120		54,316
Deferred compensation		3,228		3,145
Total liabilities		60,348		57,461
Recurring [Member] | Exchange Traded [Member]
Assets:
Available-for-sale securities		485		759
Recurring [Member] | Level 1 [Member]
Assets:
Derivative assets, net		217	[1]	0
Total Assets		702		759
Liabilities:
Derivative liabilities, net	[1]	0		581
Deferred compensation		0		0
Total liabilities		0		581
Recurring [Member] | Level 1 [Member] | Exchange Traded [Member]
Assets:
Available-for-sale securities		485		759
Recurring [Member] | Level 2 [Member]
Assets:
Derivative assets, net		0	[1]	0
Total Assets		0		0
Liabilities:
Derivative liabilities, net	[1]	0		0
Deferred compensation		3,228		3,145
Total liabilities		3,228		3,145
Recurring [Member] | Level 2 [Member] | Exchange Traded [Member]
Assets:
Available-for-sale securities		0		0
Recurring [Member] | Level 3 [Member]
Assets:
Derivative assets, net		19	[1]	234
Total Assets		19		234
Liabilities:
Derivative liabilities, net	[1]	57,120		53,735
Deferred compensation		0		0
Total liabilities		57,120		53,735
Recurring [Member] | Level 3 [Member] | Exchange Traded [Member]
Assets:
Available-for-sale securities		0		0
MGE [Member]
Liabilities:
Derivative liability, collateral offset		1,000		1,000
MGE [Member] | Recurring [Member]
Assets:
Derivative assets, net		236	[1]	234
Total Assets		335		382
Liabilities:
Derivative liabilities, net	[1]	57,120		54,316
Deferred compensation		3,228		3,145
Total liabilities		60,348		57,461
MGE [Member] | Recurring [Member] | Exchange Traded [Member]
Assets:
Available-for-sale securities		99		148
MGE [Member] | Recurring [Member] | Level 1 [Member]
Assets:
Derivative assets, net		217	[1]	0
Total Assets		316		148
Liabilities:
Derivative liabilities, net	[1]	0		581
Deferred compensation		0		0
Total liabilities		0		581
MGE [Member] | Recurring [Member] | Level 1 [Member] | Exchange Traded [Member]
Assets:
Available-for-sale securities		99		148
MGE [Member] | Recurring [Member] | Level 2 [Member]
Assets:
Derivative assets, net		0	[1]	0
Total Assets		0		0
Liabilities:
Derivative liabilities, net	[1]	0		0
Deferred compensation		3,228		3,145
Total liabilities		3,228		3,145
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:
Derivative assets, net		19	[1]	234
Total Assets		19		234
Liabilities:
Derivative liabilities, net	[1]	57,120		53,735
Deferred compensation		0		0
Total liabilities		57,120		53,735
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 $1.0 million of collateral that was posted against derivative positions with counterparties as of March 31, 2016 and December 31, 2015.

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Fair Value of Financial Instruments (Details-3)	3 Months Ended	12 Months Ended
	Mar. 31, 2016	Dec. 31, 2015
Basis adjustment:
Basis adjustment - on peak	96.70%	96.90%
Basis adjustment - off peak	95.90%	95.10%
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:
Internal generation	55.00%	60.00%
Purchased power	45.00%	40.00%
Maximum [Member]
Counterparty fuel mix:
Internal generation	75.00%	75.00%
Purchased power	25.00%	25.00%

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Fair Value of Financial Instruments (Details-4) - USD ($) $ in Thousands		3 Months Ended
		Mar. 31, 2016	Mar. 31, 2015
Fair Value, Liabilities Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Beginning balance,		$ (53,501)	$ (53,986)
Realized and unrealized gains (losses):
Included in regulatory (assets) liabilities		(3,600)	119
Included in other comprehensive income		0	0
Included in earnings	[1]	(2,163)	(1,328)
Included in current assets		0	0
Purchases		5,301	6,162
Sales		0	0
Issuances		0	0
Settlements		(3,138)	(4,833)
Transfers in and/or out of level 3		0	0
Ending balance,		(57,101)	(53,866)
Total gains (losses) included in earnings attributed to the change in unrealized gains (losses) related to assets and liabilities	[1]	0	0
Purchased Power Expense [Member]
Realized and unrealized gains (losses):
Included in earnings	[1]	$ (2,163)	$ (1,328)

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

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New Accounting Pronouncements (Details-1) - Accounting Standards Update 2015-03 - Simplifying the Presentation of Debt Issuance Costs [Member] - USD ($) $ in Millions	3 Months Ended	12 Months Ended
	Mar. 31, 2016	Dec. 31, 2015
Other deferred charges [Member]
New Accounting Pronouncements or Change in Accounting Principle [Line Items]
New accounting pronouncement, effect of adoption, decrease in assets and liabilities (debt issuance costs)	$ (4.2)	$ (4.3)
Long-term debt [Member]
New Accounting Pronouncements or Change in Accounting Principle [Line Items]
New accounting pronouncement, effect of adoption, decrease in assets and liabilities (debt issuance costs)	$ (4.2)	$ (4.3)

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Segment Information (Details) - USD ($) $ in Thousands		3 Months Ended
		Mar. 31, 2016	Mar. 31, 2015
Segment Reporting Information [Line Items]
Operating revenues		$ 147,527	$ 170,134
Depreciation and amortization		(11,032)	(10,849)
Other operating expenses		(106,964)	(127,434)
Operating income (loss)		29,531	31,851
Other income (deductions), net		2,442	2,105
Interest (expense) income, net		(5,000)	(5,091)
Income before income taxes		26,973	28,865
Income tax (provision) benefit		(9,945)	(10,587)
Net Income (Loss)		17,028	18,278
Electric [Member]
Segment Reporting Information [Line Items]
Operating revenues		93,208	98,240
Gas [Member]
Segment Reporting Information [Line Items]
Operating revenues		53,837	69,928
Non Regulated Energy [Member]
Segment Reporting Information [Line Items]
Operating revenues		482	1,966
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]
Segment Reporting Information [Line Items]
Operating revenues		147,527	170,134
Operating Segments [Member] | Electric [Member]
Segment Reporting Information [Line Items]
Operating revenues		93,664	98,355
Depreciation and amortization		(7,163)	(7,332)
Other operating expenses		(75,379)	(79,800)
Operating income (loss)		11,122	11,223
Other income (deductions), net		196	90
Interest (expense) income, net		(2,790)	(2,819)
Income before income taxes		8,528	8,494
Income tax (provision) benefit		(2,536)	(2,383)
Net Income (Loss)		5,992	6,111
Operating Segments [Member] | Gas [Member]
Segment Reporting Information [Line Items]
Operating revenues		58,934	72,653
Depreciation and amortization		(1,981)	(1,642)
Other operating expenses		(47,741)	(60,068)
Operating income (loss)		9,212	10,943
Other income (deductions), net		(8)	(1)
Interest (expense) income, net		(808)	(804)
Income before income taxes		8,396	10,138
Income tax (provision) benefit		(3,359)	(4,081)
Net Income (Loss)		5,037	6,057
Operating Segments [Member] | Non Regulated Energy [Member]
Segment Reporting Information [Line Items]
Operating revenues		11,459	11,813
Depreciation and amortization		(1,876)	(1,863)
Other operating expenses		(47)	(50)
Operating income (loss)		9,536	9,900
Other income (deductions), net		0	0
Interest (expense) income, net		(1,463)	(1,518)
Income before income taxes		8,073	8,382
Income tax (provision) benefit		(3,240)	(3,364)
Net Income (Loss)		4,833	5,018
Operating Segments [Member] | Transmission Investment [Member]
Segment Reporting Information [Line Items]
Operating revenues		0	0
Depreciation and amortization		0	0
Other operating expenses		(1)	0
Operating income (loss)		(1)	0
Other income (deductions), net		2,233	1,881
Interest (expense) income, net		0	0
Income before income taxes		2,232	1,881
Income tax (provision) benefit		(897)	(756)
Net Income (Loss)		1,335	1,125
Operating Segments [Member] | All Others [Member]
Segment Reporting Information [Line Items]
Operating revenues		0	0
Depreciation and amortization		(12)	(12)
Other operating expenses		(326)	(203)
Operating income (loss)		(338)	(215)
Other income (deductions), net		21	135
Interest (expense) income, net		61	50
Income before income taxes		(256)	(30)
Income tax (provision) benefit		87	(3)
Net Income (Loss)		(169)	(33)
Consolidation Elimination Entries [Member]
Segment Reporting Information [Line Items]
Operating revenues		(16,530)	(12,687)
Depreciation and amortization		0	0
Other operating expenses		16,530	12,687
Operating income (loss)		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
Consolidation Elimination Entries [Member] | Electric [Member]
Segment Reporting Information [Line Items]
Operating revenues		456	115
Consolidation Elimination Entries [Member] | Gas [Member]
Segment Reporting Information [Line Items]
Operating revenues		5,097	2,725
Consolidation Elimination Entries [Member] | Non Regulated Energy [Member]
Segment Reporting Information [Line Items]
Operating revenues		10,977	9,847
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		147,543	170,144
Depreciation and amortization		(11,020)	(10,837)
Other operating expenses	[1]	(115,744)	(137,017)
Operating income (loss)	[1]	20,779	22,290
Other income (deductions), net	[1]	1,479	1,162
Interest (expense) income, net		(5,061)	(5,141)
Income tax (provision) benefit		(9,090)	(9,776)
Net Income Including Noncontrolling Interest		17,197	18,311
Less Net Income Attributable to Noncontrolling Interest, net of tax		(6,252)	(6,553)
Net Income (Loss)		10,945	11,758
MGE [Member] | Electric [Member]
Segment Reporting Information [Line Items]
Operating revenues		93,214	98,245
MGE [Member] | Gas [Member]
Segment Reporting Information [Line Items]
Operating revenues		53,847	69,933
MGE [Member] | Non Regulated Energy [Member]
Segment Reporting Information [Line Items]
Operating revenues		482	1,966
MGE [Member] | Transmission Investment [Member]
Segment Reporting Information [Line Items]
Operating revenues		0	0
MGE [Member] | Operating Segments [Member]
Segment Reporting Information [Line Items]
Operating revenues		147,543	170,144
MGE [Member] | Operating Segments [Member] | Electric [Member]
Segment Reporting Information [Line Items]
Operating revenues		93,664	98,355
Depreciation and amortization		(7,163)	(7,332)
Other operating expenses	[1]	(77,879)	(82,142)
Operating income (loss)	[1]	8,622	8,881
Other income (deductions), net	[1]	160	49
Interest (expense) income, net		(2,790)	(2,819)
Net Income Including Noncontrolling Interest		5,992	6,111
Less Net Income Attributable to Noncontrolling Interest, net of tax		0	0
Net Income (Loss)		5,992	6,111
MGE [Member] | Operating Segments [Member] | Gas [Member]
Segment Reporting Information [Line Items]
Operating revenues		58,934	72,653
Depreciation and amortization		(1,981)	(1,642)
Other operating expenses	[1]	(51,091)	(64,138)
Operating income (loss)	[1]	5,862	6,873
Other income (deductions), net	[1]	(17)	(12)
Interest (expense) income, net		(808)	(804)
Net Income Including Noncontrolling Interest		5,037	6,057
Less Net Income Attributable to Noncontrolling Interest, net of tax		0	0
Net Income (Loss)		5,037	6,057
MGE [Member] | Operating Segments [Member] | Non Regulated Energy [Member]
Segment Reporting Information [Line Items]
Operating revenues		11,459	11,813
Depreciation and amortization		(1,876)	(1,863)
Other operating expenses	[1]	(3,287)	(3,414)
Operating income (loss)	[1]	6,296	6,536
Other income (deductions), net	[1]	0	0
Interest (expense) income, net		(1,463)	(1,518)
Net Income Including Noncontrolling Interest		4,833	5,018
Less Net Income Attributable to Noncontrolling Interest, net of tax		0	0
Net Income (Loss)		4,833	5,018
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	[1]	(1)	0
Operating income (loss)	[1]	(1)	0
Other income (deductions), net	[1]	1,336	1,125
Interest (expense) income, net		0	0
Net Income Including Noncontrolling Interest		1,335	1,125
Less Net Income Attributable to Noncontrolling Interest, net of tax		0	0
Net Income (Loss)		1,335	1,125
MGE [Member] | Consolidation Elimination Entries [Member]
Segment Reporting Information [Line Items]
Operating revenues		(16,514)	(12,677)
Depreciation and amortization		0	0
Other operating expenses	[1]	16,514	12,677
Operating income (loss)	[1]	0	0
Other income (deductions), net	[1]	0	0
Interest (expense) income, net		0	0
Net Income Including Noncontrolling Interest		0	0
Less Net Income Attributable to Noncontrolling Interest, net of tax		(6,252)	(6,553)
Net Income (Loss)		(6,252)	(6,553)
MGE [Member] | Consolidation Elimination Entries [Member] | Electric [Member]
Segment Reporting Information [Line Items]
Operating revenues		450	110
MGE [Member] | Consolidation Elimination Entries [Member] | Gas [Member]
Segment Reporting Information [Line Items]
Operating revenues		5,087	2,720
MGE [Member] | Consolidation Elimination Entries [Member] | Non Regulated Energy [Member]
Segment Reporting Information [Line Items]
Operating revenues		10,977	9,847
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 MGE Consolidated Statement of Income.