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, 2017

[ ] 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, a smaller reporting company, or an emerging growth company. See definitions of "large accelerated filer," "accelerated filer," "smaller reporting company," and "emerging growth company" in Rule 12b-2 of the Exchange Act.

	Large Accelerated Filer	Accelerated Filer	Non-accelerated Filer	Smaller Reporting Company	Emerging Growth Company
MGE Energy, Inc.	X
Madison Gas and Electric Company			X

If an emerging growth company, indicate by check mark if the registrant has elected not to use the extended transition period for complying with any new or revised financial accounting standards provided pursuant to Section 13(a) of the Exchange Act. [ ]

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, 2017
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' 2016 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 17, 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
MGEE Transco	MGEE Transco, LLC
NGV Fueling Services	NGV Fueling Services, LLC
Other Defined Terms:
AFUDC	Allowance for Funds Used During Construction
AICPA	American Institute of Certified Public Accountants
ATC	American Transmission Company LLC
ATC Holdco	ATC Holdco, LLC
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
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
GAAP	Generally Accepted Accounting Principles
GHG	Greenhouse Gas
Heating degree days (HDD)	Measure of the extent to which the average daily temperature is below 65 degrees Fahrenheit, which is considered an indicator of possible increased demand for energy to provide heating
IRS	Internal Revenue Service
kWh	Kilowatt-hour, a measure of electric energy produced
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
PJM	PJM Interconnection, LLC (a regional transmission organization)
PPA	Purchased Power Agreement
PSCW	Public Service Commission of Wisconsin

4

ROE	Return on Equity
Riverside	Riverside Energy Center
SCR	Selective Catalytic Reduction
SEC	Securities and Exchange Commission
SO2	Sulfur Dioxide
the State	State of Wisconsin
Stock Plan	Direct Stock Purchase and Dividend Reinvestment Plan of MGE Energy
UW	University of Wisconsin at Madison
VIE	Variable Interest Entity
WCCF	West Campus Cogeneration Facility
Working capital	Current assets less current liabilities
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,
			2017		2016
	Operating Revenues:
	Electric revenues	$	98,397	$	93,690
	Gas revenues		58,426		53,837
	Total Operating Revenues		156,823		147,527
	Operating Expenses:
	Fuel for electric generation		12,199		12,013
	Purchased power		15,354		14,670
	Cost of gas sold		35,784		32,523
	Other operations and maintenance		42,690		42,730
	Depreciation and amortization		12,959		11,032
	Other general taxes		4,927		5,028
	Total Operating Expenses		123,913		117,996
	Operating Income		32,910		29,531
	Other income, net		2,451		2,442
	Interest expense, net		(4,894)		(5,000)
	Income before income taxes		30,467		26,973
	Income tax provision		(11,167)		(9,945)
	Net Income	$	19,300	$	17,028
	Earnings Per Share of Common Stock
	(basic and diluted)	$	0.56	$	0.49
	Dividends per share of common stock	$	0.308	$	0.295
	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,
			2017		2016
	Net Income	$	19,300	$	17,028
	Other comprehensive income, net of tax:
	Unrealized gain (loss) on available-for-sale securities, net of
	tax (($65) and $110)		97		(164)
	Comprehensive Income	$	19,397	$	16,864
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,
		2017		2016
Operating Activities:
Net income	$	19,300	$	17,028
Items not affecting cash:
Depreciation and amortization		12,959		11,032
Deferred income taxes		(3,732)		2,840
Provision for doubtful receivables		254		592
Employee benefit plan cost (credit)		202		(57)
Equity earnings in ATC		(2,608)		(2,233)
Other items		609		86
Changes in working capital items:
Decrease in current assets		28,191		22,311
(Decrease) increase in current liabilities		(9,318)		1,487
Dividends from ATC		2,072		865
Cash contributions to pension and other postretirement plans		(7,168)		(11,159)
Other noncurrent items, net		1,526		937
Cash Provided by Operating Activities		42,287		43,729
Investing Activities:
Capital expenditures		(16,117)		(15,642)
Capital contributions to investments		(2,939)		(671)
Other		541		(183)
Cash Used for Investing Activities		(18,515)		(16,496)
Financing Activities:
Cash dividends paid on common stock		(10,660)		(10,227)
Repayment of long-term debt		(31,080)		(1,059)
Issuance of long-term debt		40,000		-
Other		(289)		-
Cash Used for Financing Activities		(2,029)		(11,286)
Change in cash and cash equivalents		21,743		15,947
Cash and cash equivalents at beginning of period		95,959		81,384
Cash and cash equivalents at end of period	$	117,702	$	97,331
Supplemental disclosures of cash flow information:
Significant noncash investing activities:
Accrued capital expenditures	$	6,804	$	6,587
The accompanying notes are an integral part of the unaudited consolidated financial statements.

7

MGE Energy, Inc.

Consolidated Balance Sheets (unaudited)

(In thousands)

		March 31,	December 31,
ASSETS		2017		2016
Current Assets:
Cash and cash equivalents	$	117,702	$	95,959
Accounts receivable, less reserves of $2,963 and $3,017, respectively		39,750		39,887
Other accounts receivable, less reserves of $419 and $426, respectively		5,896		8,530
Unbilled revenues		25,335		29,846
Materials and supplies, at average cost		19,668		18,561
Fossil fuel, at average cost		8,827		9,757
Stored natural gas, at average cost		4,710		12,819
Prepaid taxes		12,468		26,636
Regulatory assets - current		7,581		6,414
Assets held for sale		2,338		14,813
Other current assets		9,819		12,293
Total Current Assets		254,094		275,515
Regulatory assets		153,126		158,485
Pension and other postretirement benefit asset		2,568		2,020
Other deferred assets and other		6,489		6,691
Property, Plant, and Equipment:
Property, plant, and equipment, net		1,249,648		1,245,269
Construction work in progress		37,588		36,790
Total Property, Plant, and Equipment		1,287,236		1,282,059
Investments		81,806		76,290
Total Assets	$	1,785,319	$	1,801,060
LIABILITIES AND CAPITALIZATION
Current Liabilities:
Long-term debt due within one year	$	4,381	$	4,333
Accounts payable		36,865		47,799
Accrued interest and taxes		8,254		5,495
Accrued payroll related items		7,848		11,892
Regulatory liabilities - current		11,658		6,910
Derivative liabilities		8,259		7,620
Other current liabilities		6,249		19,456
Total Current Liabilities		83,514		103,505
Other Credits:
Deferred income taxes		380,276		383,813
Investment tax credit - deferred		927		947
Regulatory liabilities		23,266		22,173
Accrued pension and other postretirement benefits		67,481		74,347
Derivative liabilities		40,430		42,970
Other deferred liabilities and other		65,131		66,426
Total Other Credits		577,511		590,676
Capitalization:
Common shareholders' equity		732,825		724,088
Long-term debt		391,469		382,791
Total Capitalization		1,124,294		1,106,879
Commitments and contingencies (see Footnote 7)
Total Liabilities and Capitalization	$	1,785,319	$	1,801,060
The accompanying notes are an integral part of the above unaudited consolidated financial statements.

8

MGE Energy, Inc.

Consolidated Statements of Common Equity (unaudited)

(In thousands, except per-share amounts)

									Accumulated
					Additional				Other
	Common Stock				Paid-in		Retained		Comprehensive
	Shares		Value		Capital		Earnings		Income/(Loss)		Total
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
2017
Beginning balance - December 31, 2016	34,668	$	34,668	$	316,268	$	372,950	$	202	$	724,088
Net income							19,300				19,300
Other comprehensive income									97		97
Common stock dividends declared
($0.308 per share)							(10,660)				(10,660)
Ending balance - March 31, 2017	34,668	$	34,668	$	316,268	$	381,590	$	299	$	732,825
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,
			2017		2016
	Operating Revenues:
	Electric revenues	$	98,401	$	93,696
	Gas revenues		58,435		53,847
	Total Operating Revenues		156,836		147,543
	Operating Expenses:
	Fuel for electric generation		12,201		12,016
	Purchased power		15,356		14,674
	Cost of gas sold		35,793		32,534
	Other operations and maintenance		42,321		42,402
	Depreciation and amortization		12,959		11,020
	Other general taxes		4,927		5,028
	Income tax provision		10,265		9,090
	Total Operating Expenses		133,822		126,764
	Operating Income		23,014		20,779
	Other Income and Deductions:
	AFUDC - equity funds		271		261
	Equity earnings in MGE Transco		-		2,233
	Income tax provision		(44)		(942)
	Other expense, net		(76)		(73)
	Total Other Income and Deductions		151		1,479
	Income before interest expense		23,165		22,258
	Interest Expense:
	Interest on long-term debt		5,043		5,109
	Other interest, net		31		37
	AFUDC - borrowed funds		(92)		(85)
	Net Interest Expense		4,982		5,061
	Net Income	$	18,183	$	17,197
	Less Net Income Attributable to Noncontrolling Interest, net of tax		(5,389)		(6,252)
	Net Income Attributable to MGE	$	12,794	$	10,945
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,
			2017		2016
	Net Income	$	18,183	$	17,197
	Other comprehensive income, net of tax:
	Unrealized loss on available-for-sale securities, net of
	tax ($4 and $20)		(6)		(30)
	Comprehensive Income	$	18,177	$	17,167
	Less: Comprehensive Income Attributable to Noncontrolling
	Interest, net of tax		(5,389)		(6,252)
	Comprehensive Income attributable to MGE	$	12,788	$	10,915
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,
		2017		2016
Operating Activities:
Net income	$	18,183	$	17,197
Items not affecting cash:
Depreciation and amortization		12,959		11,020
Deferred income taxes		(4,242)		2,502
Provision for doubtful receivables		254		592
Employee benefit plan cost (credit)		202		(57)
Equity earnings in MGE Transco		-		(2,233)
Other items		658		112
Changes in working capital items:
Decrease in current assets		27,233		22,053
(Decrease) increase in current liabilities		(9,022)		1,524
Dividends from MGE Transco		-		865
Cash contributions to pension and other postretirement plans		(7,168)		(11,159)
Other noncurrent items, net		1,488		906
Cash Provided by Operating Activities		40,545		43,322
Investing Activities:
Capital expenditures		(16,117)		(15,642)
Capital contributions to investments		-		(533)
Other		(229)		(72)
Cash Used for Investing Activities		(16,346)		(16,247)
Financing Activities:
Cash dividends paid to parent by MGE		(15,000)		(10,000)
Distributions to parent from noncontrolling interest		(5,500)		(6,500)
Equity contribution received from noncontrolling interest		-		533
Repayment of long-term debt		(31,080)		(1,059)
Issuance of long-term debt		40,000		-
Other		(289)		-
Cash Used for Financing Activities		(11,869)		(17,026)
Change in cash and cash equivalents		12,330		10,049
Cash and cash equivalents at beginning of period		10,768		26,760
Cash and cash equivalents at end of period	$	23,098	$	36,809
Supplemental disclosures of cash flow information:
Significant noncash investing activities:
Accrued capital expenditures	$	6,804	$	6,587
The accompanying notes are an integral part of the unaudited consolidated financial statements.

11

Madison Gas and Electric Company

Consolidated Balance Sheets (unaudited)

(In thousands)

		March 31,	December 31,
ASSETS		2017		2016
Current Assets:
Cash and cash equivalents	$	23,098	$	10,768
Accounts receivable, less reserves of $2,963 and $3,017, respectively		39,750		39,887
Affiliate receivables		1,149		539
Other accounts receivable, less reserves of $419 and $426, respectively		5,796		6,363
Unbilled revenues		25,335		29,846
Materials and supplies, at average cost		19,668		18,561
Fossil fuel, at average cost		8,827		9,757
Stored natural gas, at average cost		4,710		12,819
Prepaid taxes		12,449		25,798
Regulatory assets - current		7,581		6,414
Assets held for sale		2,338		14,813
Other current assets		9,805		12,268
Total Current Assets		160,506		187,833
Affiliate receivable long-term		4,104		4,236
Regulatory assets		153,126		158,485
Pension and other postretirement benefit asset		2,568		2,020
Other deferred assets and other		4,200		4,353
Property, Plant, and Equipment:
Property, plant, and equipment, net		1,249,676		1,244,648
Construction work in progress		37,588		36,790
Total Property, Plant, and Equipment		1,287,264		1,281,438
Investments		476		487
Total Assets	$	1,612,244	$	1,638,852
LIABILITIES AND CAPITALIZATION
Current Liabilities:
Long-term debt due within one year	$	4,381	$	4,333
Accounts payable		36,865		47,790
Accrued interest and taxes		8,598		5,440
Accrued payroll related items		7,848		11,892
Regulatory liabilities - current		11,658		6,910
Derivative liabilities		8,259		7,620
Other current liabilities		6,028		19,347
Total Current Liabilities		83,637		103,332
Other Credits:
Deferred income taxes		339,477		343,117
Investment tax credit - deferred		927		947
Regulatory liabilities		23,266		22,173
Accrued pension and other postretirement benefits		67,481		74,347
Derivative liabilities		40,430		42,970
Other deferred liabilities and other		65,131		66,426
Total Other Credits		536,712		549,980
Capitalization:
Common shareholder's equity		484,872		487,084
Noncontrolling interest		115,554		115,665
Total Equity		600,426		602,749
Long-term debt		391,469		382,791
Total Capitalization		991,895		985,540
Commitments and contingencies (see Footnote 7)
Total Liabilities and Capitalization	$	1,612,244	$	1,638,852
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
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 from
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
2017
Beginning balance - Dec. 31, 2016	17,348	$	17,348	$	192,417	$	277,300	$	19	$	115,665	$	602,749
Net income							12,794				5,389		18,183
Other comprehensive loss									(6)				(6)
Cash dividends paid to parent
by MGE							(15,000)						(15,000)
Distributions to parent from
noncontrolling interest											(5,500)		(5,500)
Ending balance - March 31, 2017	17,348	$	17,348	$	192,417	$	275,094	$	13	$	115,554	$	600,426
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, 2017

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 2016 Annual Report on Form 10-K.

Prior to December 1, 2016, MGE Transco was jointly owned by MGE Energy and MGE. MGE's ownership interest in MGE Transco declined below a majority in July 2016. As a result of the change in majority ownership in MGE Transco in July 2016, MGE deconsolidated MGE Energy's proportionate share of the equity in MGE Transco. The change in consolidation was applied prospectively by reducing its investment and noncontrolling interest on MGE's consolidated financial statements. On December 1, 2016, MGE's ownership interest in MGE Transco was transferred to MGE Energy. See Footnote 3 for further discussion.

The accompanying consolidated financial statements as of March 31, 2017, 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 2016 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 54 through 104 of the 2016 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, 2017 and 2016, MGE Energy did not issue any new shares of common stock under the Stock Plan.

b.

Dilutive Shares Calculation.

MGE Energy does not have any dilutive securities.

c.

Long-term Debt - MGE Energy and MGE.

On January 13, 2017, MGE issued $40 million of 3.76% senior unsecured notes due January 15, 2052. MGE used the net proceeds from the sale of senior notes to refinance $30 million of medium-term notes, which matured in January 2017, and assist with the financing of additional capital expenditures. The new, unsecured long-term debt carries an interest rate of 3.76% per annum over its 35-year term. The covenants of this debt are substantially consistent with MGE's existing unsecured long-term debt.

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3.

Investment in ATC and ATC Holdco - 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, as of December 1, 2016, is owned solely by MGE Energy. ATC Holdco was formed by several members of ATC, including MGE Energy, to pursue electric transmission development and investments outside of Wisconsin. The ownership interest in ATC Holdco is held by MGEE Transco, a wholly-owned subsidiary of MGE Energy.

MGE Transco and MGEE Transco have accounted for their investment in ATC and ATC Holdco, respectively, under the equity method of accounting. Equity earnings from investments are recorded as "Other income" on MGE Energy's consolidated statements of income. For the three months ended March 31, 2017 and 2016, MGE Transco recorded the following:

		Three Months Ended
		March 31,
(In thousands)		2017		2016
Equity earnings from investment in ATC	$	2,608	$	2,233
Dividends from ATC(a)		-		865
Capital contributions to ATC		1,420		533

(a)

As of December 31, 2016, MGE Transco recorded a $2.1 million receivable from ATC for a cash dividend received in January 2017.

ATC Holdco's activities commenced in late December 2016 and had an immaterial impact on results of operations, cash flows, and financial condition.

At March 31, 2017, and December 31, 2016, MGE Transco held a 3.6% ownership interest in ATC, and MGEE Transco held a 4.0% ownership interest in ATC Holdco, respectively.

In June 2016, the PSCW required MGE to transfer its interest in ATC to MGE Energy, which was to be completed by December 31, 2022. The requirement arose in the context of requests for regulatory approvals by several owners of ATC in connection with a reorganization of ATC. MGE's ownership interest in ATC, held through MGE Transco, was transferred net of deferred tax liabilities to MGE Energy by way of a dividend in kind of $15.8 million as of December 1, 2016. As a result of the transfer, MGE's ownership interest in MGE Transco was completely eliminated in favor of MGE Energy. The change had no effect on MGE Energy's consolidated financial statements.

ATC's summarized financial data for the three months ended March 31, 2017 and 2016, is as follows:

		Three Months Ended
		March 31,
(In thousands)		2017		2016
Operating revenues	$	174,669	$	164,240
Operating expenses		(82,388)		(79,065)
Other income, net		207		127
Interest expense, net		(26,616)		(24,208)
Earnings before members' income taxes	$	65,872	$	61,094

MGE receives transmission and other related services from ATC. During the three months ended March 31, 2017, MGE recorded $9.2 million for transmission services received compared to $9.7 million for the comparable period in 2016. MGE also provides a variety of operational, maintenance, and project management services for ATC, which is reimbursed by ATC. As of March 31, 2017, and December 31, 2016, MGE had a receivable due from ATC of $0.1 million.

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4.

Taxes - MGE Energy and MGE.

Effective Tax Rate.

MGE Energy's effective income tax rate for the three months ended March 31, 2017 and 2016, was 36.7% and 36.9%, respectively. MGE's effective income tax rate for the three months ended March 31, 2017 and 2016, was 36.2% and 36.8%, respectively. For both MGE Energy and MGE, the decrease in the effective tax rate is due in part to a higher estimated domestic manufacturing deduction and higher estimated AFUDC equity earnings in 2017. In addition, MGE's effective income tax rate decreased as a result of the transfer of its ownership interest in MGE Transco.

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.

The following table presents the components of net periodic benefit costs recognized for the three months ended March 31, 2017 and 2016. A portion of the net periodic benefit cost is capitalized within the consolidated balance sheets.

		Three Months Ended
		March 31,
(In thousands)		2017		2016
Pension Benefits
Components of net periodic benefit cost:
Service cost	$	1,332	$	1,381
Interest cost		3,119		3,089
Expected return on assets		(5,742)		(5,593)
Amortization of:
Prior service (credit) cost		(4)		2
Actuarial loss		1,464		1,356
Net periodic benefit cost	$	169	$	235
Postretirement Benefits
Components of net periodic benefit cost:
Service cost	$	206	$	324
Interest cost		444		674
Expected return on assets		(472)		(705)
Amortization of:
Transition obligation		-		1
Prior service credit		(436)		(667)
Actuarial loss		129		159
Net periodic benefit (credit) cost	$	(129)	$	(214)

6.

Share-Based Compensation - MGE Energy and MGE.

Under MGE Energy's Director Incentive Plan and Performance Unit Plan, non-employee directors and 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 January 2017, 4,032 units were granted under the Director Incentive Plan and are subject to a three-year graded vesting schedule. In March 2017, 14,704 units were granted under the Performance Unit Plan and are subject to a five-year graded vesting schedule. On the grant date, MGE Energy and MGE measure the cost of the director or 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, 2017, 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.

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For nonretirement eligible employees under the Performance Unit Plan, 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.

During the three months ended March 31, 2017, MGE recorded $0.5 million in compensation expense as a result of awards under the plans compared to $1.3 million for the comparable period in 2016. In January 2017, cash payments of $2.0 million were distributed relating to awards that were granted under the plans. No forfeitures of units occurred during the three months ended March 31, 2017 and 2016. At March 31, 2017, $5.4 million of outstanding awards are vested, and of this amount, no cash settlements have occurred.

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 they conduct their operations, the costs of those operations, as well as capital and operating expenditures. Several of these environmental rules are subject to legal challenges, reconsideration and/or other uncertainties. 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. Management believes compliance costs will be recovered in future rates based on previous treatment of environmental compliance projects. These initiatives, proposed rules, and court challenges include:

·

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

·

The EPA's cooling water intake rules, which require cooling water intake structures at electric power plants, such as our WCCF, Blount, and Columbia 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.

·

Greenhouse Gas (GHG) reduction guidelines and approval criteria established under the Clean Air Act for states to use in developing plans to control GHG emissions from existing fossil fuel-fired electric generating units (EGUs) and systems. 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. Given the pending legal proceedings, 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.

·

Federal and state air quality regulations impose restrictions on various emissions including emissions of sulfur dioxide (SO₂), nitrogen dioxides (NO₂), and other pollutants, and may require permits for operation of emission sources.

·

The EPA's rule to regulate ambient levels of a pollutant through the Ozone National Ambient Air Quality Standards (NAAQS). 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. Oral arguments in this case are scheduled to begin in mid-2017. MGE will continue to monitor the EPA's progress on attainment designations and related litigation to assess potential impacts at our facilities, particularly our Elm Road Units.

·

Rules regulating nitrogen oxide (NO_x) and SO₂ emissions including the Cross State Air Pollution Rule (CSAPR) and Clean Air Visibility Rule (CAVR). At this time, regulatory obligations, compliance strategies, and costs remain uncertain due to the continued legal challenges surrounding CSAPR and CAVR.

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·

The EPA's Coal Combustion Residuals Rule, which regulates coal ash 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. Review of our Elm Road Units 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.

The matters in the bullet points above are discussed further in Footnote 17.c. in the Financial Statements of MGE Energy's and MGE's 2016 Annual Report on Form 10-K.

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. MGE does not expect the resolution of these matters to have a material adverse effect on its consolidated results of operations, financial condition, or cash flows.

8.

Rate Matters - MGE Energy and MGE.

a.

Rate Proceedings.

In December 2016, the PSCW authorized MGE, effective January 1, 2017, to decrease 2017 rates for retail electric customers by 0.8% or $3.3 million and to increase rates for retail gas customers by 1.9% or $3.1 million. The decrease in retail electric rates is attributable to declining fuel and purchased power costs. The increase in retail gas rates covers costs associated with MGE's natural gas system infrastructure improvements. The authorized return on common stock equity for 2017 is 9.8% on 57.2% common equity. The PSCW also approved MGE's request to extend the current accounting treatment for transmission related costs through 2018. This accounting treatment allows MGE to reflect any differential between transmission costs reflected in rates and actual costs incurred in its next 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.

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 in the following year and is then reflected 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 continued throughout 2016. The fuel credit established a mechanism to return $10.9 million of fuel savings to electric customers as a bill credit. MGE returned $2.6 million of electric fuel-related savings to customers through bill credits during the period from September 1, 2015, through December 31, 2015. MGE returned $8.3 million of electric fuel-related savings during the year ended December 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. Also, in March 2016, MGE filed its 2015 fuel plan reconciliation application showing an overcollection of 2015 fuel rules monitored costs. In July 2016, the PSCW issued a final order stating that MGE shall refund $15.7 million of additional fuel savings realized during 2015 and 2016 to its retail electric customers over a one-month period. In September 2016, MGE returned $15.5 million to customers through bill credits.

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As of March 31, 2016, MGE had no deferred 2016 fuel savings that were in excess of the fuel savings included within the fuel credits referenced above. As of March 31, 2017, MGE has deferred $1.1 million of 2017 fuel savings. These costs will be subject to the PSCW's annual review of 2017 fuel costs, expected to be completed in 2018.

9.

Derivative and Hedging Instruments - MGE Energy and MGE.

a.

Purpose.

As part of its regular operations, MGE enters into contracts, including options, swaps, futures, forwards, and other contractual commitments, to manage its exposure to commodity prices. 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, the derivatives are recognized in the consolidated balance sheets at fair value. MGE's financial 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, 2017	December 31, 2016
Commodity derivative contracts	415,165 MWh	393,395 MWh
Commodity derivative contracts	1,677,500 Dth	4,195,000 Dth
FTRs	920 MW	2,251 MW
PPA	3,100 MW	3,250 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, 2017, and December 31, 2016, the fair value of exchange traded derivatives and FTRs exceeded their cost basis by $0.6 million and $1.3 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, 2017, and December 31, 2016, reflects a loss position of $48.6 million and $50.6 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, instruments are netted with the same counterparty under a

19

master netting agreement as well as the netting of collateral. As of March 31, 2017, and December 31, 2016, the receivable margin account balance of $0.6 million and $1.3 million, respectively, is shown net of any collateral posted against derivative positions.

		Derivative Assets		Derivative Liabilities
(In thousands)					Balance Sheet Location
March 31, 2017
Commodity derivative contracts(a)	$	640	$	165	Other current assets(b)
Commodity derivative contracts(a)		24		87	Other deferred charges
FTRs		155		-	Other current assets
PPA		N/A		8,210	Derivative liability (current)
PPA		N/A		40,430	Derivative liability (long-term)
December 31, 2016
Commodity derivative contracts(a)	$	1,227	$	164	Other current assets
Commodity derivative contracts(a)		157		54	Other deferred charges
FTRs		143		-	Other current assets
PPA		N/A		7,620	Derivative liability (current)
PPA		N/A		42,970	Derivative liability (long-term)

(a)

As of March 31, 2017, and December 31, 2016, no collateral was posted against and netted with derivative liability positions on the consolidated balance sheets.

(b)

As of March 31, 2017, $0.1 million was presented as current derivative liabilities on the consolidated balance sheets.

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, 2017
Commodity derivative contracts	$	664	$	(203)	$	-	$	461
FTRs		155		-		-		155
December 31, 2016
Commodity derivative contracts	$	1,384	$	(218)	$	-	$	1,166
FTRs		143		-		-		143

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, 2017
Commodity derivative contracts	$	252	$	(203)	$	-	$	49
PPA		48,640		-		-		48,640
December 31, 2016
Commodity derivative contracts	$	218	$	(218)	$	-	$	-
PPA		50,590		-		-		50,590

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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, 2017 and 2016, and the consolidated income statements for the three months ended March 31, 2017 and 2016.

		2017				2016
(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,	$	49,281	$	230	$	54,082	$	1,208
Unrealized (gain) loss		(689)		-		6,371		-
Realized (loss) gain reclassified to a deferred account		(78)		78		(1,451)		1,451
Realized loss reclassified to income statement		(441)		(166)		(2,118)		(2,004)
Balance at March 31,	$	48,073	$	142	$	56,884	$	655

		Realized losses (gains)
		2017				2016
(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	$	385	$	146	$	1,007	$	1,814
FTRs		(685)		-		(68)		-
PPA		761		-		1,369		-

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, 2017, 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, 2017, certain counterparties were in a net liability position of less than $0.1 million. As of December 31, 2016, no counterparties were in a net liability position.

Nonperformance of counterparties to the non-exchange traded derivatives could expose MGE to credit loss. However, MGE enters into transactions only with companies that meet or exceed strict credit guidelines, and it monitors these counterparties on an ongoing basis to mitigate nonperformance risk in its portfolio. As of March 31, 2017, no counterparties have defaulted.

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.

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a.

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

At March 31, 2017, and December 31, 2016, 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 long-term debt is based on quoted market prices for similar financial instruments at March 31, 2017, and December 31, 2016. Since long-term debt is not traded in an active market, it is classified as Level 2. The estimated fair market values of financial instruments are as follows:

		March 31, 2017				December 31, 2016
(In thousands)		Carrying Amount		Fair Value		Carrying Amount		Fair Value
MGE Energy
Assets:
Cash and cash equivalents	$	117,702	$	117,702	$	95,959	$	95,959
Liabilities:
Long-term debt(a)		400,161		445,037		391,242		430,122
MGE
Assets:
Cash and cash equivalents	$	23,098	$	23,098	$	10,768	$	10,768
Liabilities:
Long-term debt(a)		400,161		445,037		391,242		430,122
(a)   Includes long-term debt due within one year. Excludes debt issuance costs and unamortized discount of
$4.3 million and $4.1 million at March 31, 2017, and December 31, 2016, respectively.

b.

Recurring Fair Value Measurements.

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

		Fair Value as of March 31, 2017
(In thousands)		Total		Level 1		Level 2		Level 3
MGE Energy
Assets:
Derivatives	$	819	$	341	$	-	$	478
Exchange-traded investments		662		662		-		-
Total Assets	$	1,481	$	1,003	$	-	$	478
Liabilities:
Derivatives	$	48,892	$	60	$	-	$	48,832
Deferred compensation		3,014		-		3,014		-
Total Liabilities	$	51,906	$	60	$	3,014	$	48,832
MGE
Assets:
Derivatives	$	819	$	341	$	-	$	478
Exchange-traded investments		132		132		-		-
Total Assets	$	951	$	473	$	-	$	478
Liabilities:
Derivatives	$	48,892	$	60	$	-	$	48,832
Deferred compensation		3,014		-		3,014		-
Total Liabilities	$	51,906	$	60	$	3,014	$	48,832

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		Fair Value as of December 31, 2016
(In thousands)		Total		Level 1		Level 2		Level 3
MGE Energy
Assets:
Derivatives	$	1,527	$	1,041	$	-	$	486
Exchange-traded investments		500		500		-		-
Total Assets	$	2,027	$	1,541	$	-	$	486
Liabilities:
Derivatives	$	50,808	$	16	$	-	$	50,792
Deferred compensation		3,039		-		3,039		-
Total Liabilities	$	53,847	$	16	$	3,039	$	50,792
MGE
Assets:
Derivatives	$	1,527	$	1,041	$	-	$	486
Exchange-traded investments		143		143		-		-
Total Assets	$	1,670	$	1,184	$	-	$	486
Liabilities:
Derivatives	$	50,808	$	16	$	-	$	50,792
Deferred compensation		3,039		-		3,039		-
Total Liabilities	$	53,847	$	16	$	3,039	$	50,792

No transfers were made in or out of Level 1 or Level 2 for the three months ended March 31, 2017.

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

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

23

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

	Model Input
Significant Unobservable Inputs	March 31, 2017	December 31, 2016
Basis adjustment:
On peak	92.2%	91.9%
Off peak	94.0%	93.4%
Counterparty fuel mix:
Internal generation	55% - 75%	55% - 75%
Purchased power	45% - 25%	45% - 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. 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 commodity derivative assets and liabilities measured at fair value on a recurring basis.

		Three Months Ended
		March 31,
(In thousands)		2017		2016
Beginning balance	$	(50,306)	$	(53,501)
Realized and unrealized gains (losses):
Included in regulatory (assets) liabilities		1,953		(3,600)
Included in other comprehensive income		-		-
Included in earnings		(586)		(2,163)
Included in current assets		125		-
Purchases		5,996		5,301
Sales		-		-
Issuances		-		-
Settlements		(5,536)		(3,138)
Transfers in and/or out of Level 3		-		-
Balance as of March 31,	$	(48,354)	$	(57,101)
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 (b).

		Three Months Ended
		March 31,
(In thousands)		2017		2016
Purchased Power Expense	$	(431)	$	(2,163)
Cost of Gas Sold Expense		(155)		-
Total	$	(586)	$	(2,163)

(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.

Joint Plant Ownership - MGE Energy and MGE.

Columbia.

In 2016, MGE and WPL negotiated an amendment to the existing Columbia joint operating agreement, that has been approved by the PSCW, under which MGE will have the option to reduce its obligation to pay certain capital expenditures (other than SCR-related expenditures) at Columbia in exchange for a proportional reduction in MGE's ownership in Columbia. On January 1 of each year, beginning in 2017 and ending June 1, 2020, the ownership percentage will be adjusted, through a partial sale, based on the amount of capital expenditures foregone. In December 2016, MGE jointly filed a request with the co-owners of Columbia for FERC approval of the amendment to the Columbia joint operating agreement, effective January 1, 2017. MGE currently expects to receive FERC's decision on the amendment in 2017.

During 2016, MGE accrued $14.8 million of 2016 capital expenditures that MGE has forgone as part of the ownership transfer agreement with WPL. As of December 31, 2016, MGE classified $14.8 million of Columbia assets as held-for-sale on the consolidated balance sheets. In January 2017, MGE reduced its ownership interest in Columbia from 22.0% to 20.4% through the partial sale of plant assets to WPL.

During three months ended March 31, 2017, MGE accrued $2.3 million of 2017 capital expenditures that MGE has forgone subject to the ownership transfer agreement. As of March 31, 2017, MGE classified $2.3 million of Columbia assets as held-for-sale on the consolidated balance sheets. The assets recognized as held-for-sale are subject to a partial sale of plant assets to WPL, expected to occur in January 2018.

12.

Adoption of Accounting Principles and Recently Issued 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. The new standard establishes a five step model for recognizing and measuring revenue from contracts with customers and replaces existing guidance on revenue recognition. The objective of the new standard is to provide a single, comprehensive revenue recognition model for all contracts with customers to improve comparability within industries, across industries and across capital markets. The underlying principle is that an entity will recognize revenue to depict the transfer of goods or services to customers at an amount that the entity expects to be entitled to in exchange for those goods or services.

MGE Energy and MGE have been assessing the impact of this guidance on revenue streams within the scope of the new standard. All retail electric and gas revenues are tariff rates approved by the PSCW. Based on our evaluation of the new standard, retail revenues will be recognized within the period in which utility service is provided to the customer and the performance obligation is fulfilled, consistent with our current revenue recognition model. Electric revenues for sales to the market represent wholesale sales made to third parties who are not ultimate users of the electricity. These sales may also include bilateral sales to other utilities or power marketers. Revenues for sales to the market will be recognized when the sale is completed within the market operated by MISO, similar to the recognition under our current revenue recognition model. In addition, revenues from the transportation of gas will continue to be recognized upon the performance of services for the respective customer. Based on our assessment of the new standard, revenue recognition for retail revenues, sales to the market, and transportation of gas will be consistent with our current revenue recognition model. However, additional disclosures regarding the nature, amount, timing, and uncertainty of these revenue streams and related cash flows arising from contracts with customers will be required as a result of the new standard.

The Power and Utilities Task Force of the AICPA is formulating a utility industry-specific interpretation of the guidance regarding the collectability threshold of probable within the new standard. The collectability criterion could impact the timing of revenue recognition for uncollectible accounts. Management continues to analyze newly-released interpretative guidance and assess the related impacts to the current revenue recognition model.

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This authoritative guidance will become effective January 1, 2018, and MGE Energy and MGE anticipate adopting the standard upon the effective date. Adoption of this standard is permitted under one of two methods: the full retrospective method or the modified retrospective method. MGE Energy and MGE are continuing to assess the permitted implementation methods and the impact on our financial statements.

b.

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, and will require equity investments to be measured at fair value with changes in fair value recognized in net income rather than in other comprehensive income. As a result of this guidance, MGE Energy and MGE will no longer have any other comprehensive income related to equity investments. This standard will be applied using a modified retrospective approach, with a cumulative effect adjustment recorded to opening retained earnings as of the beginning of all prior periods presented.

c.

Leases.

In February 2016, the FASB issued authoritative guidance within the Codification's Leases topic that provides guidance on the classification, recognition, measurement, and disclosure of leases. The new leasing standard establishes that a lease conveys the right to control the use of identified property, plant, or equipment for a period of time in exchange for consideration. Under the new guidance, lessees will be required to recognize all leases with terms greater than one year, including operating leases, on the consolidated balance sheet by recording a right-of-use asset and lease liability. Prior to the authoritative guidance, only capital leases were recognized on the balance sheet by lessees. The new accounting guidance as applied by lessors is materially consistent from that applied under current GAAP.

Management has begun utilizing a bottoms-up approach to analyze the impact of the standard on our lease portfolio. MGE Energy and MGE have been reviewing current accounting policies and procedures to identify potential differences in accounting treatment that would result from applying the requirements of the new standard to our existing lease portfolio. In addition, we are identifying appropriate changes to our business processes, systems, and controls to support recognition and disclosure requirements under the new standard. This authoritative guidance will become effective January 1, 2019, with early adoption permitted. MGE Energy and MGE anticipate adopting the standard upon the effective date. The new leasing standard requires entities to recognize and measure leases at the beginning of the earliest comparative period presented using a modified retrospective approach. MGE Energy and MGE are currently assessing the impact this pronouncement will have on our financial statements.

d.

Restricted Cash.

In November 2016, the FASB issued authoritative guidance within the Codification's Statement of Cash Flows topic that provides guidance on the classification and presentation of changes in restricted cash within the statement of cash flows. The new standard was issued to eliminate a current diversity in practice for the accounting treatment of restricted cash. Under the new guidance, reporting entities will be required to explain the changes in the total of restricted and unrestricted cash and cash equivalents when reconciling the beginning and ending balances on the statement of cash flows. Prior to the authoritative guidance, changes in restricted cash were presented as either cash flows from operating, investing, or financing activities within the statement of cash flows, as appropriate based on the nature of the restriction. Also under the new standard, reporting entities will be required to provide a reconciliation from the balance sheet to the statement of cash flows and disclose the nature of the restrictions of cash. This authoritative guidance will become effective January 1, 2018. Upon the effective date, MGE Energy and MGE will change the presentation of restricted cash to reflect this change in accounting guidance. MGE Energy and MGE will also retrospectively apply the guidance to all prior periods presented. As of March 31, 2017, and December 31, 2016, MGE Energy and MGE had $4.3 million and $5.1 million, respectively, of restricted cash classified within other current assets on the consolidated balance sheets.

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e.

Pension and Other Postretirement Benefits.

In March 2017, the FASB issued authoritative guidance within the Compensation – Retirement Benefits topic that provides guidance on the presentation of net periodic pension cost and net periodic postretirement benefit cost. Under the new guidance, the service cost component of net benefit cost is required to be recorded in the same line item or items as other compensation costs arising from services rendered by the pertinent employees during the period. The other components of net benefit cost are required to be presented in the income statement separately from the service cost component and outside of income from operations. The standard also only allows the service cost component to be eligible for capitalization when applicable. 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.

13.

Segment Information - MGE Energy and MGE.

MGE Energy operates in the following business segments: electric utility, gas utility, nonregulated energy, transmission investment, and all other. See MGE Energy's and MGE's 2016 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		Nonregulated Energy		Transmission Investment		All Others		Consolidation/ Elimination Entries		Consolidated Total
Three Months Ended March 31, 2017
Operating revenues	$	98,324	$	58,426	$	73	$	-	$	-	$	-	$	156,823
Interdepartmental revenues		(105)		4,394		11,070		-		-		(15,359)		-
Total operating revenues		98,219		62,820		11,143		-		-		(15,359)		156,823
Depreciation and amortization		(8,900)		(2,213)		(1,846)		-		-		-		(12,959)
Other operating expenses		(75,326)		(50,577)		(41)		-		(369)		15,359		(110,954)
Operating income (loss)		13,993		10,030		9,256		-		(369)		-		32,910
Other income (deductions), net		190		5		-		2,478		(222)		-		2,451
Interest (expense) income, net		(2,776)		(799)		(1,407)		-		88		-		(4,894)
Income (loss) before taxes		11,407		9,236		7,849		2,478		(503)		-		30,467
Income tax (provision) benefit		(3,454)		(3,704)		(3,151)		(997)		139		-		(11,167)
Net income (loss)	$	7,953	$	5,532	$	4,698	$	1,481	$	(364)	$	-	$	19,300
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 income (deductions), 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

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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(b)		Consolidation/ Elimination Entries		Consolidated Total
Three Months Ended March 31, 2017
Operating revenues	$	98,328	$	58,435	$	73	$	-	$	-	$	156,836
Interdepartmental revenues		(109)		4,385		11,070		-		(15,346)		-
Total operating revenues		98,219		62,820		11,143		-		(15,346)		156,836
Depreciation and amortization		(8,900)		(2,213)		(1,846)		-		-		(12,959)
Other operating expenses(a)		(78,746)		(54,271)		(3,192)		-		15,346		(120,863)
Operating income(a)		10,573		6,336		6,105		-		-		23,014
Other income (deductions), net(a)		156		(5)		-		-		-		151
Interest expense, net		(2,776)		(799)		(1,407)		-		-		(4,982)
Net income		7,953		5,532		4,698		-		-		18,183
Less: Net income attributable to
noncontrolling interest, net of tax		-		-		-		-		(5,389)		(5,389)
Net income attributable to MGE	$	7,953	$	5,532	$	4,698	$	-	$	(5,389)	$	12,794
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(a)		(77,879)		(51,091)		(3,287)		(1)		16,514		(115,744)
Operating income (loss)(a)		8,622		5,862		6,296		(1)		-		20,779
Other income (deductions), net(a)		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
(a) Amounts are shown net of the related tax expense, consistent with the presentation on the MGE Consolidated Statements of Income.
(b) As of July 31, 2016, MGE no longer consolidates MGE Energy's proportionate share of equity earnings in MGE Transco.
See Footnote 3 for additional information.

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

General

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

·

Regulated electric utility operations, conducted through MGE,

·

Regulated gas utility operations, conducted through MGE,

·

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

·

Transmission investments, representing our equity investment in ATC and ATC Holdco, 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 149,000 customers in Dane County, Wisconsin, including the city of Madison, and purchases and distributes natural gas to approximately 154,000 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 2016 Annual Report on Form 10-K.

For the three months ended March 31, 2017, MGE Energy's earnings were $19.3 million or $0.56 per share compared to $17.0 million or $0.49 per share for the same period in the prior year. MGE's earnings for the three months ended March 31, 2017, were $12.8 million compared to $10.9 million for the same period in the prior year.

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

		Three Months Ended
(In thousands)		March 31,
Business Segment:		2017		2016
Electric Utility	$	7,953	$	5,992
Gas Utility		5,532		5,037
Nonregulated Energy		4,698		4,833
Transmission Investments		1,481		1,335
All Other		(364)		(169)
Net Income	$	19,300	$	17,028

Our net income during the three months ended March 31, 2017, compared to the same period in the prior year primarily reflects the effects of the following factors:

·

Electric net income increased primarily related to lower fuel costs and savings from ongoing efforts to manage operating and maintenance costs.

During the first three months of 2017, the following events occurred:

2017 Rate Case Filing: On December 15, 2016, the PSCW authorized MGE, effective January 1, 2017, to decrease 2017 rates for retail electric customers by 0.8% or $3.3 million and to increase rates for retail gas customers by 1.9% or $3.1 million. The decrease in retail electric rates reflects declining fuel and purchased power costs. The increase in retail gas rates covers costs associated with MGE's natural gas system infrastructure improvements. The authorized return on common stock equity for 2017 is 9.8% on 57.2% common equity. The PSCW also approved MGE's request to extend the current accounting treatment for transmission related costs through 2018.

Deferred Fuel Costs: As of March 31, 2017, MGE has deferred $1.1 million of 2017 fuel savings. These costs will be subject to the PSCW's annual review of 2017 fuel costs, expected to be completed in 2018.

Debt Issuance: MGE issued $40 million of new long-term unsecured debt in January 2017. The new debt will carry an interest rate of 3.76% per annum over its 35-year term. The proceeds of this debt financing were used to refinance $30 million of medium-term notes, which matured in January 2017, and assist with the financing of additional capital expenditures. The covenants of this debt are substantially consistent with MGE's existing unsecured long-term debt.

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

ATC Return on Equity: Several parties have filed complaints with the FERC seeking to reduce the 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 8.0% and 7.8% of our net income for the three months ended March 31, 2017 and 2016 respectively, from our investment in ATC. See "Other Matters" below for additional information concerning ATC.

Environmental Initiatives: There are proposed legislative 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. At present, it is unclear how the changes in the Presidential and EPA administration may affect pending or new legislative or rulemaking proposals or regulatory initiatives. 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 43% of our electric generating capacity as of March 31, 2017. 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 October 2015, the EPA finalized its Clean Power Plan (CPP) rule with an effective date of 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. 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. Given the pending legal proceedings, 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.

30

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. MGE and WPL have negotiated an amendment to the existing Columbia joint operating agreement, effective January 1, 2017, under which MGE will reduce its obligation to pay certain capital expenditures (other than SCR-related expenditures) at Columbia prior to the expected in-service date of the Riverside gas-fired generating plant in exchange for a proportional reduction in MGE's ownership in Columbia. On January 1 of each year, beginning in 2017 and ending June 1, 2020, the ownership percentage will be adjusted, through a partial sale, based on the amount of capital expenditures foregone. During the three months ended March 31, 2017, MGE accrued $2.3 million of 2017 capital expenditures that MGE has forgone as part of the ownership transfer agreement with WPL. During 2016, MGE accrued $14.8 million of 2016 capital expenditures forgone. As of March 31, 2017, and December 31, 2016, MGE classified $2.3 million and $14.8 million, respectively, of Columbia assets as held-for-sale on the consolidated balance sheets. In January 2017, MGE reduced its ownership interest in Columbia from 22.0% to 20.4% through the partial sale of plant assets to WPL. By June 2020, MGE's ownership in Columbia is forecasted to be approximately 19%.

Saratoga Wind Farm: In February 2017, MGE filed with the PSCW a letter notifying the commission of MGE's intent to seek approval to construct, own and operate a 66MW wind farm, consisting of 33 turbines, located near Saratoga, Iowa. MGE filed its formal application with the PSCW in April 2017. If approved, construction of the project is expected to begin in early 2018, with an estimated capital cost of $107 million.

Financing Plans: MGE plans to issue an additional $30 million of new long-term debt during 2017 to cover capital expenditures and other corporate obligations.

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

Three Months Ended March 31, 2017 and 2016

Electric Utility Operations - MGE Energy and MGE

Electric sales and revenues

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

		Revenues				Sales (kWh)
(In thousands)		Three Months Ended March 31,				Three Months Ended March 31,
		2017		2016	% Change	2017	2016	% Change
Residential	$	33,353	$	33,304	0.1 %	197,674	201,090	(1.7)%
Commercial		50,164		50,497	(0.7)%	433,389	442,319	(2.0)%
Industrial		4,215		4,404	(4.3)%	51,765	57,222	(9.5)%
Other-retail/municipal		9,021		8,238	9.5 %	92,087	84,949	8.4 %
Total retail		96,753		96,443	0.3 %	774,915	785,580	(1.4)%
Sales to the market		972		142	N/A%	35,862	10,619	N/A%
Deferral of fuel savings		-		(3,581)	(100.0)%	-	-	-  %
Adjustments to revenues		599		204	N/A%	-	-	-  %
Total	$	98,324	$	93,208	5.5 %	810,777	796,199	1.8 %

Electric operating revenues increased $5.1 million or 5.5% for the three months ended March 31, 2017, compared to the same period in 2016, due to the following:

(In millions)
Deferral of fuel savings/fuel credit	$	5.5
Sales to the market		0.8
Other		0.7
Adjustments to revenues		0.5
Volume		(1.2)
Rate changes		(1.2)
Total	$	5.1

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·

Deferral of fuel savings/fuel credit. During the three months ended March 31, 2016, customers received a fuel credit on their bill related to the fuel savings of $1.9 million, which decreased electric revenues in the prior year. In January 2016, the PSCW lowered MGE's 2016 fuel rules monitored costs, which were deferred in revenue in the prior period, as a result of continued lower projected fuel costs in 2016.

·

Sales to the market. Sales to the market represent wholesale sales made to third parties who are not ultimate users of the electricity. These sales may include spot market transactions on the markets operated by MISO and PJM. These sales may also include bilateral sales to other utilities or power marketers. Generating units are dispatched by MISO based on cost considerations as well as reliability of the system. Sales to the market typically occur when MGE has more generation and purchases online than are needed for its own system demand. The excess electricity is then sold to others in the market. For the three months ended March 31, 2017, market volumes increased compared to the same period in the prior year, reflecting increased opportunities for sales and those sales were made at higher market prices. The revenue generated from these sales is included in fuel rules monitored costs. See fuel rules discussion in Footnote 8.b. of the Notes to the Consolidated Financial Statements.

·

Adjustments to revenue. 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.

·

Volume. During the three months ended March 31, 2017, there was a 1.4% decrease in retail sales volumes compared to the same period in the prior year.

·

Rate Changes. Rates charged to retail customers for the three months ended March 31, 2017, were 2.3% or $1.2 million lower than those charged during the same period in the prior year.

In December 2016, the PSCW authorized MGE to decrease 2017 rates for retail electric customers by 0.8% or $3.3 million.

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, increased purchased power expense. These items are explained below.

Fuel for electric generation

The expense for fuel for internal electric generation increased $0.2 million during the three months ended March 31, 2017, compared to the same period in the prior year, due to the following:

(In millions)
Increase in volume	$	0.5
Decrease in per-unit cost		(0.3)
Total	$	0.2

This increase in expense reflects a 4.3% increase in internal generation volume delivered to the system primarily as a result of increased generation at Columbia and the Elm Road Units based on market prices, partially offset by a 2.6% decrease in per-unit cost of internal electric generation.

Purchased power

Purchased power expense increased $0.7 million during the three months ended March 31, 2017, compared to the same period in the prior year, due to the following:

(In millions)
Change in fuel rule adjustments, net of recoveries	$	3.1
Decrease in per-unit cost		(2.2)
Decrease in volume		(0.2)
Total	$	0.7

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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.

The decrease in expense (before fuel rules adjustments) reflects a 13.3% decrease in the per-unit cost of purchased power and a 1.3% decrease in the volume of power purchased from third parties.

Electric operating and maintenance expenses

For the three months ended March 31, 2017, electric operating and maintenance expenses were flat, compared to the same period in the prior year. The following contributed to the net change:

(In millions)
Increased transmission costs	$	1.2
Increased customer accounts costs		0.3
Decreased production expenses		(1.2)
Decreased administrative and general costs		(0.3)
Total	$	-

For the three months ended March 31, 2017, increased transmission costs are primarily due to an increase in transmission reliability enhancements, offset by decreased production costs at Columbia and the Elm Road Units.

Electric depreciation expense

Electric depreciation expense increased $1.7 million for the three months ended March 31, 2017, compared to the same period in the prior year as a result of new depreciation rates for Columbia, as approved by the PSCW.

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,
		2017		2016	% Change	2017	2016	% Change
Residential	$	33,903	$	31,250	8.5 %	43,038	43,575	(1.2)%
Commercial/Industrial		23,048		21,108	9.2 %	37,176	37,355	(0.5)%
Total retail		56,951		52,358	8.8 %	80,214	80,930	(0.9)%
Gas transportation		1,350		1,356	(0.4)%	21,035	21,453	(1.9)%
Other revenues		125		123	1.6 %	-	-	-  %
Total	$	58,426	$	53,837	8.5 %	101,249	102,383	(1.1)%
Heating degree days (normal 3,506)						3,130	3,258	(3.9)%
Average rate per therm of
retail customer	$	0.710	$	0.647	9.7 %

Gas revenues increased $4.6 million or 8.5% for the three months ended March 31, 2017, compared to the same period in 2016. These changes are related to the following factors:

(In millions)
Rate/PGA changes	$	5.0
Volume		(0.4)
Total	$	4.6

·

Rate/PGA changes. In December 2016, the PSCW authorized MGE to increase 2017 rates for retail gas customers by 1.9% or $3.1 million.

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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, 2017, increased 9.7% compared to the same period in 2016, reflecting a $3.6 million increase in natural gas commodity costs (recovered through the PGA) and an increase in fixed rate charges.

·

Volume. For the three months ended March 31, 2017, retail gas deliveries decreased 0.9% compared to the same period in the prior year.

Cost of gas sold

For the three months ended March 31, 2017, cost of gas sold increased $3.3 million compared to the same period in the prior year. The cost per therm of natural gas increased 10.3%, which resulted in $3.4 million of increased expense. The volume of gas purchased decreased 0.2%, which resulted in $0.1 million of decreased expense.

Gas operating and maintenance expenses

Gas operating and maintenance expenses decreased by $0.1 million for the three months ended March 31, 2017, compared to the same period in 2016. The following contributed to the net change:

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

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, 2017 and 2016, net income at the nonregulated energy operations segment was $4.7 million and $4.8 million, respectively.

Transmission Investment Operations - MGE Energy and MGE

Transmission investment other income

For the three months ended March 31, 2017 and 2016, other income at the transmission investment segment was $2.5 million and $2.2 million, respectively. The transmission investment segment holds our interest in ATC and ATC Holdco, and its income reflects our equity in the earnings of the investments. ATC Holdco was formed in December 2016. In the near term, it is expected that ATC Holdco will be pursuing transmission development opportunities that typically have long development and investment lead times before becoming operational. 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, 2017 and 2016, was 36.7% and 36.9%, respectively. MGE's effective income tax rate for the three months ended March 31, 2017 and 2016, was 36.2% and 36.8%, respectively. For both MGE Energy and MGE, the decrease in the effective tax rate is due in part to a higher estimated domestic manufacturing deduction and higher estimated AFUDC equity earnings in 2017. In addition, MGE's effective income tax rate decreased as a result of the transfer of its ownership interest in MGE Transco.

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

34

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)		2017		2016
MGE Power Elm Road	$	3.6	$	3.8
MGE Power West Campus		1.8		1.8
MGE Transco(a)		-		0.7

(a)

MGE Transco holds an ownership interest in ATC. In July 2016, MGE's ownership interest in MGE Transco declined below a majority, resulting in MGE Energy's investment in MGE Transco being deconsolidated from MGE's consolidated financial statements. In December 2016, MGE's ownership interest in MGE Transco was transferred to MGE Energy. See Footnote 3 of the Notes to Consolidated Financial Statements for additional information.

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, 2017. Further discussion of the contractual obligations and commercial commitments is included in Footnote 17 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 2016 Annual Report on Form 10-K.

Long-term Debt - MGE Energy and MGE

MGE issued $40 million of new long-term unsecured debt in January 2017. The proceeds of this debt financing were used to refinance $30 million of medium-term notes, which matured in January 2017, and assist with the financing of additional capital expenditures. See Footnote 2 of the Notes to Consolidated Financial Statements for further discussion.

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, 2017 and 2016:

		MGE Energy				MGE
(In thousands)		2017		2016		2017		2016
Cash provided by/(used for):
Operating activities	$	42,287	$	43,729	$	40,545	$	43,322
Investing activities		(18,515)		(16,496)		(16,346)		(16,247)
Financing activities		(2,029)		(11,286)		(11,869)		(17,026)

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.

35

Cash provided by operating activities for the three months ended March 31, 2017, was $42.3 million, a decrease of $1.4 million when compared to the same period in the prior year.

MGE Energy's net income increased $2.3 million for the three months ended March 31, 2017, when compared to the same period in the prior year.

Working capital accounts (excluding prepaid and accrued taxes) resulted in $1.0 million in cash provided by operating activities for the three months ended March 31, 2017, primarily due to decreased gas inventories, decreased unbilled revenues, and decreased current assets, partially offset by decreased accounts payable and decreased accrued payroll.

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 included 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.

A decrease in pension contribution resulted in an additional $4.0 million in cash provided by operating activities for the three months ended March 31, 2017, when compared to the same period in the prior year. Pension contributions reflect amounts required by law and discretionary amounts.

MGE

Cash provided by operating activities for the three months ended March 31, 2017, was $40.5 million, a decrease of $2.8 million when compared to the same period in the prior year.

Net income increased $1.0 million for the three months ended March 31, 2017, when compared to the same period in the prior year.

Working capital accounts (excluding prepaid and accrued taxes) resulted in $0.8 million in cash provided by operating activities for the three months ended March 31, 2017, primarily due to decreased gas inventories, decreased unbilled revenues, and decreased other current assets, partially offset by decreased accounts payable and decreased accrued payroll.

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 included 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.

A decrease in pension contribution resulted in an additional $4.0 million in cash provided by operating activities for the three months ended March 31, 2017, when compared to the same period in the prior year. Pension contributions reflect amounts required by law and discretionary amounts.

Cash Used for Investing Activities

MGE Energy

MGE Energy's cash used for investing activities increased $2.0 million for the three months ended March 31, 2017, when compared to the same period in the prior year.

Capital expenditures for the three months ended March 31, 2017, were $16.1 million. This amount represents an increase of $0.5 million from the expenditures made in the same period in the prior year. This increase primarily reflects increased expenditures on gas distribution assets.

Capital contributions in ATC and other investments increased $2.3 million for the three months ended March 31, 2017, when compared to the same period in the prior year.

36

MGE

MGE's cash used for investing activities increased $0.1 million for the three months ended March 31, 2017, when compared to the same period in the prior year.

Capital expenditures for the three months ended March 31, 2017, were $16.1 million. This amount represents an increase of $0.5 million from the expenditures made in the same period in the prior year. This increase primarily reflects increased expenditures on gas distribution assets.

Capital contributions in ATC and other investments decreased $0.5 million for the three months ended March 31, 2017, when compared to the same period in the prior year. In December 2016, MGE transferred its ownership interest to MGE Energy. See Footnote 3 of the Notes to Consolidated Financial Statements for further details.

Cash Used for Financing Activities

MGE Energy

Cash used for MGE Energy's financing activities was $2.0 million for the three months ended March 31, 2017, compared to $11.3 million of cash used for MGE Energy's financing activities for the same period in the prior year.

For the three months ended March 31, 2017, dividends paid were $10.7 million compared to $10.2 million in the prior year. This increase was a result of a higher dividend per share ($0.308 vs. $0.295).

During the three months ended March 31, 2017, MGE issued $40.0 million of senior unsecured notes, which was used to refinance $30.0 million of medium-term notes and assist with financing additional capital expenditures.

MGE

During the three months ended March 31, 2017, cash used for MGE's financing activities was $11.9 million compared to $17.0 million of cash used for MGE's financing activities for the same period in the prior year.

Dividends paid from MGE to MGE Energy were $15.0 million for the three months ended March 31, 2017, compared to $10.0 million in the prior year.

Distributions to parent from noncontrolling interest, which represent distributions from MGE Power Elm Road and MGE Power West Campus to MGE Energy, were $5.5 million for the three months ended March 31, 2017, compared to $6.5 million in the prior year.

For the three months ended March 31, 2016, equity contributions received from noncontrolling interest, which represent contributions to MGE Transco, were $0.5 million. There were no equity contributions received from noncontrolling interest, which represent contributions to MGE Transco for the three months ended March 31, 2017.

During the three months ended March 31, 2017, MGE issued $40.0 million of senior unsecured notes, which was used to refinance $30.0 million of medium-term notes and assist with financing additional capital expenditures.

Capitalization Ratios

MGE Energy's capitalization ratios were as follows:

	MGE Energy
	March 31, 2017	December 31, 2016
Common shareholders' equity	64.9 %	65.2 %
Long-term debt(a)	35.1 %	34.8 %

(a)

Includes the current portion of long-term debt.

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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, 2017, capital expenditures for MGE Energy and MGE totaled $16.1 million, which included $15.6 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

There were no material updates or developments in environmental matters that occurred during the three months ended March 31, 2017. Further discussion of environmental matters is included in MGE Energy's and MGE's 2016 Annual Report on Form 10-K and Footnote 7.a. of Notes to Consolidated Financial Statements in this Report.

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 alleged 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. At the time, MISO's base ROE was 12.38% and ATC's base ROE was 12.2%. In February 2015, a second complaint was filed for the period February 2015 through May 2015 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. In June 2016, an administrative law judge issued an initial decision for the second complaint that would reduce the transmission owner's base ROE to 9.7%. The initial decision will be reviewed by FERC. It is anticipated FERC will issue an order on this issue by mid-2017. On September 28, 2016, FERC issued an order on the first complaint, for the period November 2013 through February 2015, reducing the base ROE to 10.32%. This base ROE also became effective September 28, 2016, and will apply to future periods until FERC rules in the second complaint, at which time the base ROE ordered by FERC in the second complaint will prospectively become the authorized base ROE.

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.

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 reflects a pre-tax charge of $0.1 million and $0.3 million for the three months ended March 31, 2017 and 2016, respectively, recorded by ATC for this matter representing its estimate of its refund liability. We derived approximately 8.0% and 7.8% of our net income for the three months ended March 31, 2017 and 2016, respectively, from our investment in ATC.

Adoption of Accounting Principles and Recently Issued Accounting Pronouncements

See Footnote 12 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 in the following year and is then reflected 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 2017, fuel and purchased power costs included in MGE's base fuel rates are $101.9 million. See Footnote 8.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, 2017, the fair value of these instruments exceeded their cost basis by $0.6 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, 2017, reflects a loss position of $48.6 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, 2017, 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, 2016, 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 2017, 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, MGE Energy does not control or manage certain of its unconsolidated entities and thus, its access and ability to apply its procedures to those entities is more limited than is the case for its consolidated subsidiaries.

As of March 31, 2017, 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, 2017, 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, 2017	17,000	$	63.55	-	-
February 1-28, 2017	32,036		63.18	-	-
March 1-31, 2017	53,753		62.52	-	-
Total	102,789	$	62.90	-	-

*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

MGE Energy, Inc. 2006 Performance Unit Plan, as amended

10.2

MGE Energy, Inc. 2013 Director Incentive Plan, as amended

12

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

Certifications Pursuant to Rule 13a-14(a) and 15d-14(a) of the Securities and Exchange Act of 1934 as to the Quarterly Report on Form 10-Q for the quarter ended March 31, 2017, filed by the following officers for the following companies:

31.1

Filed by Jeffrey M. Keebler for MGE Energy, Inc.

31.2

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

31.3

Filed by Jeffrey M. Keebler for Madison Gas and Electric Company

31.4

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

42

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, 2017, filed by the following officers for the following companies:

32.1

Filed by Jeffrey M. Keebler for MGE Energy, Inc.

32.2

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

32.3

Filed by Jeffrey M. Keebler 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

43

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, 2017	/s/ Jeffrey M. Keebler
	Jeffrey M. Keebler President and Chief Executive Officer (Duly Authorized Officer)
Date: May 5, 2017	/s/ Jeffrey C. Newman
	Jeffrey C. Newman Executive Vice President, Chief Financial Officer, Secretary and Treasurer (Chief Financial and Accounting Officer)

44

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, 2017	/s/ Jeffrey M. Keebler
	Jeffrey M. Keebler President and Chief Executive Officer (Duly Authorized Officer)
Date: May 5, 2017	/s/ Jeffrey C. Newman
	Jeffrey C. Newman Executive Vice President, Chief Financial Officer, Secretary and Treasurer (Chief Financial and Accounting Officer)

45

EX-10

Exhibit 10.1

MGE ENERGY, INC.

2006 PERFORMANCE UNIT PLAN¹

___________________

¹ As amended.  Reflects amendments adopted on March 18, 2011, February 25, 2015, and February 17, 2017.

MGE ENERGY, INC.

2006 PERFORMANCE UNIT PLAN

1.

Purpose; Effective Date

The purpose of the 2006 Performance Unit Plan (the “Plan”) of MGE Energy, Inc. and its subsidiaries and affiliates (the “Company”) is to attract, retain and motivate key employees by providing those employees incentives and reward for performance at the Company.  This Plan is effective January 1, 2007, the first date on which any Awards (as defined below) were issued under the Plan, and amends and restates in its entirety the version of the Plan originally adopted by the Company on December 29, 2006.  Capitalized terms not defined herein shall have the meanings ascribed to them in Section 2 below.

2.

Definitions

The following terms used in the Plan shall have the meanings set forth below:

“Administrator” means the person or persons, if any, to whom the Committee has delegated authority to administer the Plan.

“Award” means an award of Performance Units made to a Participant.

“Award Agreement” means a written agreement setting forth the terms and conditions of the

Award made under the Plan.

“Board” means the Company's Board of Directors.

“Cause” means "cause" as defined in the Participant's employment agreement, or in the absence of such definition, shall mean the Participant's:  (i) continued failure to obey reasonable instructions of the person(s) to whom the Participant reports; (ii) continued neglect of duties and responsibilities; (iii) willful misconduct or other actions in bad faith which are to the Company's detriment; (iv) breach of any material covenant with the Company by which employee is bound, including without limitation, any confidentiality, intellectual property or non-solicitation agreements with the Company (including without limitation the provisions contained herein), or (v) violation of any provision of the Company's written code of conduct.

“Committee” means the Compensation Committee appointed by the Board to administer the Plan pursuant to the provisions of Section 3 of the Plan.

“Disability” means the definition of Disability in the Company's Long-Term Disability Plan, or in the absence of such a definition, the Participant's inability, due to mental or physical incapacity, to substantially perform the duties of the Participant's employment for 180 consecutive days, and which impairment is determined to be total and permanent by a physician selected by Company or its insurers and reasonably acceptable to the Participant or the Participant's legal representative.

“Dividend Equivalent” means a right, granted under this Plan, to receive the cash equivalent of all or a specified portion of the dividends declared and paid with respect to one share of the Company’s Stock during the Vesting Period which applies to an award of Performance Units.  The Dividend Equivalent amount shall be calculated based upon the dividend rate in effect on the last day of the Vesting Period that applies to an award of Performance Units.  Dividend Equivalents shall not be deemed reinvested in the Company’s Stock, and shall be paid to the Participants on the appropriate Settlement Date.

“Fair Market Value” means the fair market value of Stock as determined in good faith by the Committee or under procedures established by the Committee.  Unless otherwise determined by the Committee, the Fair Market Value of Stock shall be the officially-quoted closing selling price of the stock or if no selling price is quoted the bid price on the NASDAQ or other principal stock exchange or market on which Stock is traded on the day immediately preceding the day as of which such value is being determined or, if there is no sale on that day, then on the last previous day on which a sale was reported.

“Grant Date” means the date upon which an award of Performance Units are granted to a Participant.

“Performance Period” means any relevant period designated by the Committee with respect to any Award.

“Performance Unit” or “Unit” means a right granted to a Participant to receive a cash settlement equal to the Unit Value, as determined by the Committee.

“Plan” means this MGE 2006 Performance Unit Plan.

“Retirement” means any normal (or approved early retirement) by a Participant pursuant to the terms of any pension, profit sharing or 401(k) plan, or Company policy applicable to a Participant on the Termination Date.

“Settlement Date” means the date upon which cash is paid to a Participant in full settlement of vested Performance Units for which the relevant Vesting Period has been completed.  The Committee shall ensure that the Settlement Date occurs within 90 days following the completion of the relevant Vesting Period.

“Stock” means the Company's common stock, par value $1.00 per share as traded on the NASDAQ or other principal stock exchange or market on which Stock is traded.

“Termination Date” means, with respect to a Participant, the final date of the Participant's employment with the Company.

“Unit Value” means, as calculated on the measurement date, the sum of (i) the Fair Market Value of the Company's Stock, plus (ii) an amount equal to the aggregate value of all Dividend Equivalents declared on the Stock during the relevant Vesting Period.

“Vesting Period” means the duration of time ending on December 31 of a calendar year over which a Performance Award becomes 100% vested.

3.

Administration

3.1

Committee Authority.  Unless otherwise determined by the Board and subject to the provisions of the Plan, the Committee, and the Administrator (subject to the Committee's ability to restrict the Administrator) shall have the authority and full discretionary power to:  (i) establish eligible Participants, and make Awards; (ii) determine the size of Awards as specified herein; (iii) administer, construe and interpret the Plan; (iv) prescribe, amend and rescind rules and regulations, agreements, terms, and notices hereunder (but not unilateral modifications to existing awards without the Participant's written consent); and (v) make all other determinations necessary or advisable in its discretion for the administration of the Plan.  Any actions of the Committee with respect to the Plan shall be conclusive and binding upon all persons interested in the Plan.  The Committee and Administrator may each appoint agents and delegate authority as advisable to administer the Plan.

3.2

Administrator.  An Administrator may be appointed by, shall remain in office at the will of, and may be removed with or without reason by, the Committee.  The Administrator may resign at any time.  The Administrator shall not be entitled to act on or decide any matter relating solely to himself or herself or any of his or her rights or benefits under the Plan.  The Administrator shall not receive any special compensation for serving in his or her capacity as Administrator but shall be reimbursed for any reasonable expenses incurred in connection therewith.  No bond or other security need be required of the Administrator in any jurisdiction.

3.3

Limitation of Liability.  In the exercise of authority under the Plan, each Committee member (or Administrator) shall be entitled in good faith to rely or act upon any report or other information furnished to him or her by any employee of the Company, the Company's independent certified public accountants, or any executive compensation consultant, legal counsel, or other professional retained by the Company to assist in the administration of the Plan.  No Committee member, Administrator, or executive shall be personally liable to the Company or to any participant in the Plan for any action, determination, or interpretation taken or made in good faith with respect to the administration of this Plan, and each such person shall be fully indemnified and the Company and the participants in the Plan waive their rights with respect to any such liability.

4.

Participation

Participants must be Company employees to be eligible to participate in the Plan (“Participants”).  The Committee shall have sole discretion to designate eligible employees who may participate in the Plan, which shall be determined based on a Participant's performance against goals established by the Committee and the CEO for the immediately preceding year.  Participation in this Plan in one Performance Period neither guarantees nor precludes participation in any subsequent Performance Period.

5.

Performance Awards

5.1

General.  Awards may be granted on the terms and conditions set forth in this Section 5.  In addition, the Committee may impose on any Award or the exercise thereof, at the date of grant or thereafter, such additional terms and conditions, not inconsistent with the provisions of the Plan, as the Committee shall determine, including terms requiring forfeiture of Awards in the event of termination of employment or service by the Participant and terms permitting a Participant to make elections relating to his or her Award.  The Committee shall retain full power and discretion with respect to any term or condition of an Award that is not mandatory under the

Plan.  The Committee shall require the payment of lawful consideration for an Award to the extent necessary to satisfy the requirements of applicable corporate law of the State of Wisconsin.

5.2

Limitation on Size of Awards.  Awards shall be targeted for each Performance Period to a percentage of a Participant's base salary, as determined separately by the Committee for each Participant using the Fair Market Value of the Company's Stock on the Grant Date.  With respect to Awards for any Performance Period, the maximum Award made to any Participant shall not exceed 60% of that Participant's base salary, as measured on the Grant Date.

5.3

Award Agreements.  The Committee may grant an Award to a Participant with respect to any Performance Period.  Each Award shall be evidenced by an Award Agreement signed by the Participant and an authorized Company representative.  Each Award shall be subject to the terms and conditions of the Plan and to such other terms and conditions as may be established by the Committee in the Agreements.

5.4

Performance Unit Vesting.  Unless otherwise determined in the Award Agreement, Performance Units shall vest according to the following schedule:

Years

Vesting

1

    0%

2

    0%

3

  60%

4

  80%

5

100%

5.5

Settlement of Performance Awards; Other Terms.  Performance Awards shall be settled in a cash lump sum within 90 days following completion of the relevant Vested Period.  Vested awards shall not be settled until the conclusion of the full Vesting Period to which such award relates.

6.

Termination Events

Unless otherwise provided in the applicable Award Agreement, the following shall apply to all Performance Units held by a Participant upon any termination of employment with the Company.

6.1

Death, Disability or Retirement.  If a Participant's employment with the Company is terminated due to the Participant's death, Disability or Retirement, the Participant shall receive an additional year of vesting credit with respect to the Units, and all vested Units shall be settled in accordance with the Plan on the appropriate Settlement Date following the conclusion of the full Vesting Period.  Specifically, such a Participant shall receive, as applicable, (i) if the Participant's Termination Date occurs prior to December 31 of a calendar year, vesting credit with respect to such calendar year or (ii) if the Participant's Termination Date occurs on December 31 of a calendar year, vesting credit with respect to the calendar year immediately following the calendar year which includes such Termination Date.

6.2

Voluntarily by the Participant or by Company without Cause.  If the Participant voluntarily terminates employment with the Company or the Company terminates the Participant without Cause, in either case prior to the conclusion of the full Vesting Period, all unvested Units (determined as of the Termination Date) shall be immediately forfeited and all of the

Participant's vested Units shall be settled in accordance with the Plan on the appropriate Settlement Date following conclusion of the full Vesting Period.

6.3

Termination by Company for Cause.  If the Participant's employment with the Company is terminated for Cause, all vested and unvested Units shall be immediately forfeited without settlement or payment of value.  

7.

Change in Control

The Committee may set forth in any Award Agreement the effect, if any, that a change in control or other, similar transaction shall have on any awards granted under this Plan.

8.

Restrictive Covenants

8.1

Non-disclosure.   No Participant shall disclose to anyone, without the Company's prior written consent (except in good faith in the ordinary course of business to a person who will be advised by the Participant to keep such information confidential) or make use of any Confidential Information (as defined below), except in the performance of the Participant's duties on the Company's behalf or when required to do so by legal process, any governmental agency having supervisory authority over the Company's business, or any administrative or legislative body (including a Committee thereof) that requires the Participant to divulge, disclose or make accessible such information.  In the event that the Participant is so required, he or she shall give the Company prompt written notice to allow the Company the opportunity to object to or otherwise resist such order.  “Confidential Information” shall mean (i) all information concerning the Company's business of a confidential or proprietary nature relating to any of its assets, product development, pricing, customers, suppliers, trade secrets, owners, investors, finances, transactions (present and contemplated) and business plans and strategies, and (ii) information regarding the names, titles, status, compensation, benefits and other proprietary employment-related aspects of the Company's employees and employment practices, provided that "Confidential Information" does not include information that is or properly becomes part of the public domain.

8.2

Return of the Company Materials.  Upon any termination of employment or service, each Participant agrees to deliver any documents, notes, drawings, specifications, computer software, data and other materials of any nature pertaining to any Confidential Information.in the Participant's possession or over which the Participant has control, and will not take any of the foregoing, or any reproduction of any of the foregoing, that is embodied in any tangible medium of expression, provided that the foregoing shall not prohibit a Participant from retaining his or her personal phone directories and rolodexes.

9.

Forfeiture

9.1

Forfeiture of Performance Award Settlement and Repayment.   Unless otherwise determined by the Committee, upon a violation by the Participant of any of the restrictive covenants contained in Section 8 (excluding unintentional or non­material violations of Section 8.2) (each a “Forfeiture Event”), the Participant shall forfeit his or her entitlement to any payment pursuant to this Plan and shall be obligated to repay to the Company, in cash, within five business days after demand is made therefore by the Company, all amounts paid to the Participant by the Company pursuant to this Plan within 12 months of the date of such Forfeiture Event.

9.2

Committee Discretion.  The Committee may, in its discretion , waive in whole or in part the Company's right to forfeiture under this Section, but no such waiver shall be effective unless evidenced in writing.

10.

Claims; Arbitration

10.1

Claims.  Any individual who makes a claim for benefits under the Plan shall file the claim in writing with the Committee.  Written notice of the disposition of the claim shall be delivered to the claimant within 60 days after filing.  If the claim is denied, the reasons shall be set forth in a statement delivered to the claimant.  Thereafter the claimant may request arbitration in accordance with Section 10.2.  The filing of a claim in accordance with this Section 10.1 shall be a condition precedent to the prosecution of any dispute.

10.2

Arbitration.  Any dispute between the Company and an individual claiming a benefit under the Plan that is not resolved between the Company and the claimant shall, if either party wishes to further pursue resolution of the dispute, be submitted to binding arbitration in accordance with the rules of Commercial Arbitration of the American Arbitration Association.  Any such arbitration shall take place in Madison, Wisconsin.  The arbitrator shall be a person experienced in employment and compensation of corporate business executives who is mutually acceptable to the Company and the claimant.   If an arbitrator cannot be agreed upon within 15 days after a dispute is submitted to arbitration, the parties shall each select one representative who is not and has never been associated with the Company or the Board, and who is not and never has been associated with the claimant, and these two representatives shall choose a neutral arbitrator with the qualifications described above.  If the representatives cannot reach agreement, one arbitrator with the qualifications described above shall be selected by the Madison, Wisconsin office of the American Arbitration Association.   All actions and proceedings under this Section 10 shall be kept confidential and neither party shall divulge any part thereof to third parties without the prior written consent of the other party.   Each party to an arbitration under this Section 10 shall pay his or her own expenses, including without limitation, fees of counsel, and each of the parties shall bear one-half of the fees and costs of the arbitrators.

11.

Miscellaneous

11.1

No Employment or Equityholder Rights.  Neither the Plan nor any Performance Awards granted under the Plan shall give any Participant a right to remain employed by the Company.  The Company reserves the right to terminate the employment or service of any Participant at any time, and for any reason, subject to applicable laws, employee manuals (as may be revised from time to time) and any employment or other agreement.  No Participant shall have any rights of an equityholder of the Company thereof as a result of the grant of an Award or otherwise under the Plan.

11.2

Withholding Taxes.  The Company shall withhold from the settlement of any Performance Units under this Plan any amount of withholding taxes due in respect of settlement of such Performance Units in cash.

11.3

Governing Law.  All questions pertaining to the validity, construction and administration of the Plan and the Agreements shall be determined in accordance with the laws of the State of Wisconsin without regard to conflicts of law principles.

11.4

Unfunded Plan.  The Plan is intended to constitute an "unfunded" plan for incentive and deferred compensation.  With respect to any amount payable to a Participant under the Plan, nothing contained in the Plan (or in any Award Agreement or other documents related thereto), nor the creation or adoption of the Plan, the grant of any award, or the taking of any other action pursuant to the provisions of the Plan shall give any such Participant any rights that are greater than those of a general creditor of the Company; provided, however, that the Committee may authorize the creation of trusts or make other arrangements to meet the Company's obligations under the Plan, which trusts or other arrangements shall be consistent with the "unfunded" status of the Plan unless the Committee otherwise determines with the consent of each affected Participant.

11.5

Severability.  In case any provision of this Plan shall be held illegal or invalid, such illegality or invalidity shall be construed and enforced as if said illegal or invalid provision had never been inserted herein and shall not affect the remaining provisions of this Plan, but shall be fully severable, and the Plan shall be construed and enforced as if any such illegal or invalid provision were not a part hereof.

11.6

Adjustments.  In the event of any cash infusion, capital raising transaction, reorganization, recapitalization, stock split, stock dividend, merger, consolidation, split-up, spin-off or any other similar change in the structure of the Company, the Committee reserves the right to make such equitable adjustment, if any, as it may deem appropriate, in its sole and absolute discretion, in the determination of the value of the Performance Units as described herein.

11.7

Setoff.  The Company may, to the extent permitted by law, deduct from and set off against its obligations to a Participant from time to time, (including without limitation amounts payable in connection with an Award, as wages or benefits or other form of compensation), any amounts that the Participant owes to the Company for any reason whatsoever.  A Participant shall remain liable for any portion of the Participant's obligation not satisfied by such setoff.  By accepting an Award granted hereunder, a Participant agrees to any deduction or setoff under this Section 11.7.

11.8

Transferability and Alienation.  Except insofar as may otherwise be required by law, no amount payable at any time under the Plan shall be subject in any manner to alienation by anticipation, sale, transfer, assignment, bankruptcy, pledge, attachment, charge, or encumbrance of any kind, nor in any manner be subject to the debts or liabilities of any person, and any attempt to so alienate or subject any such amount, whether presently or thereafter payable, shall be void.   If any person shall attempt to, or shall, alienate, sell, transfer, assign, pledge, attach, charge, or otherwise encumber any amount payable under the Plan, or any part thereof, or if by reason of his bankruptcy or other event happening at any such time such amount would be made subject to his debts or liabilities or would otherwise not be enjoyed by him, then the Committee, if it so elects, may direct that such amount be withheld and that the same or any part thereof be paid or applied to or for the benefit of such person, his or her spouse, children or other dependents, or any of a Participant's heirs, in such manner and proportion as the Committee may deem proper.

11.9

Notices.  All notices or other communications made or given pursuant to this Plan shall be in writing and shall be sufficiently made or given if hand­delivered or mailed by certified mail addressed to any Participant at the address contained in the records of the Company or to the Company at its principal office.

11.10

Amendment; Termination.  The Board may, without the consent of the Participants under the Plan, at any time terminate the Plan entirely, and at any time or from time to time amend or modify the Plan, provided that no such action shall adversely affect any Award previously granted without the Participant's consent.

11.11

Expenses.  All expenses and costs incurred in connection with the operation of the Plan shall be borne by the Company.

11.12

Other Plans.  The adoption of this Plan shall not affect any other compensation or incentive plans in effect for the Company.  Nothing in this Plan shall be construed to limit the right of the Company to establish, alter or terminate any other forms of incentives, benefits or compensation for employees.

11.13

Headings.  The headings in the Plan are for reference purposes only and shall not affect the meaning or interpretation of the Plan.

11.14

Section 409A Compliance.  This Plan is intended to comply with the provisions of Section 409A of the Internal Revenue Code of 1986, as amended (the “Code”), and shall be interpreted and construed accordingly.  The Company shall have the discretion and authority to amend this Plan 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 Plan.  By accepting an Award under this Plan, the Participant agrees that no provision of this Plan or any communications related to this Plan shall be interpreted as guaranteeing the tax consequences or treatment of any amounts payable to the Participant under this Plan.

EX-10

Exhibit 10.2

MGE ENERGY, INC.

2013 DIRECTOR INCENTIVE PLAN¹

____________

¹ As amended.  Reflects amendment adopted February 17, 2017.

MGE ENERGY, INC.

2013 DIRECTOR INCENTIVE PLAN

1.

Purpose; Effective Date

The purpose of the 2013 Director Incentive Plan (the “Plan”) of MGE Energy, Inc. (the “Company”) is to align the interests of the Company’s shareholders and the recipients of Awards (as defined below) under this Plan by increasing the interest of such recipients in the Company’s growth and success.  This Plan is effective December 20, 2013.  Capitalized terms not defined herein shall have the meanings ascribed to them in Section 2 below.

2.

Definitions

The following terms used in the Plan shall have the meanings set forth below:

“Administrator” means the person or persons, if any, to whom the Committee has delegated authority to administer the Plan.

“Award” means an award of Units made to a Participant.

“Award Agreement” means a written agreement setting forth the terms and conditions of an Award made under the Plan.

“Board” means the Company’s Board of Directors.

“Committee” means the Compensation Committee appointed by the Board to administer the Plan pursuant to the provisions of Section 3 of the Plan.

“Director” means any non-employee member of the Company’s Board from time to time.

"Disability” means the Participant’s inability, due to mental or physical incapacity, to substantially perform the duties of the Participant’s service on the Board for 180 consecutive days, and which impairment is determined to be total and permanent by a physician selected by Company and reasonably acceptable to the Participant or the Participant’s legal representative.

“Dividend Equivalent” means a right, granted under this Plan, to receive the cash equivalent of all of the dividends declared and paid with respect to one share of the Company’s Stock during the Vesting Period that applies to an Award.  The Dividend Equivalent amount shall be calculated based upon the dividend rate in effect on the last day of the Vesting Period that applies to an award of Units.  Dividend Equivalents shall not be deemed reinvested in the Company’s Stock, and shall be paid to the Participants on the appropriate Settlement Date.

“Fair Market Value” means the fair market value of Stock as determined in good faith by the Committee or under procedures established by the Committee.  Unless otherwise determined by the Committee, the Fair Market Value of Stock shall be the officially-quoted closing selling price of the stock, or if no selling price is quoted the bid price, on the Nasdaq Stock Market or other principal stock exchange or market on which Stock is traded on the day immediately preceding the day as of which such value is being determined or, if there is no sale on that day, then on the last previous day on which a sale was reported.

“Grant Date” means the date upon which an Award is granted to a Participant.

“Participant” shall have the meaning assigned to that term in Section 4.

“Plan” means this MGE Energy, Inc. 2013 Director Incentive Plan.

“Retirement” means a Participant’s retirement from the Board (i) in accordance with the guidelines regarding Board member selection and retirement approved from time to time by the Board or (ii) as recognized and permitted as such by the Board.

“Settlement Date” means the date upon which cash is paid to a Participant in full settlement of vested Units for which the relevant Vesting Period has been completed.  The Committee shall ensure that the Settlement Date occurs no later than March 15th of the calendar year following the calendar year in which completion of the relevant Vesting Period occurs.

“Stock” means the Company’s common stock, par value $1.00 per share as traded on the Nasdaq Stock Market or other principal stock exchange or market on which such common stock is traded.

“Termination” means a Participant ceasing to be a Director.

“Termination Date” means, with respect to a Participant, the final date of the Participant’s service as a Director.

“Unit” means a right granted to a Participant to receive a cash settlement equal to the Unit Value, as determined by the Committee.

“Unit Value” means, as calculated on the measurement date, the sum of (i) the Fair Market Value of the Company’s Stock, plus (ii) an amount equal to the aggregate value of all Dividend Equivalents declared on the Stock during the relevant Vesting Period.

“Vesting Period” means the duration of time ending on December 31 of a calendar year over which an Award becomes 100% vested.

3.

Administration

3.1

Committee Authority.  Unless otherwise determined by the Board and subject to the provisions of the Plan, the Committee and the Administrator (subject to the Committee’s ability to restrict the Administrator) shall have the authority and full discretionary power to:  (i) designate eligible Participants, and make Awards; (ii) determine the size of Awards as specified herein; (iii) administer, construe and interpret the Plan; (iv) prescribe, amend and rescind rules and regulations, agreements, terms, and notices hereunder (but not unilateral modifications to existing Awards without the affected Participant’s written consent); and (v) make all other determinations necessary

or advisable in its discretion for the administration of the Plan.  Any actions of the Committee with respect to the Plan shall be conclusive and binding upon all persons interested in the Plan.  The Committee and Administrator may each appoint agents and delegate authority as advisable to administer the Plan.

3.2

Administrator.  An Administrator may be appointed by, shall remain in office at the will of, and may be removed with or without reason by, the Committee.  The Administrator may resign at any time.  The Administrator shall not be entitled to act on or decide any matter relating solely to himself or herself or any of his or her rights or benefits under the Plan.  The Administrator shall not receive any special compensation for serving in his or her capacity as Administrator but shall be reimbursed for any reasonable expenses incurred in connection therewith.  No bond or other security need be required of the Administrator in any jurisdiction.

3.3

Limitation of Liability.  In the exercise of authority under the Plan, each Committee member (or Administrator) shall be entitled in good faith to rely or act upon any report or other information furnished to him or her by any employee of the Company, the Company’s independent certified public accountants, or any executive compensation consultant, legal counsel, or other professional retained by the Company to assist in the administration of the Plan.  No Committee member, Administrator, or executive shall be personally liable to the Company or to any participant in the Plan for any action, determination, or interpretation taken or made in good faith with respect to the administration of this Plan, and each such person shall be fully indemnified by the Company and the Company and the participants in the Plan waive their rights with respect to any such liability.

4.

Participation

An individual must be a Director to be eligible to participate in the Plan (“Participants”).  

5.

Awards

5.1

General.  Awards may be granted on the terms and conditions set forth in this Section 5.  In addition, the Committee may impose on any Award or the exercise thereof, at the date of grant or thereafter, such additional terms and conditions, not inconsistent with the provisions of the Plan, as the Committee shall determine, including terms requiring forfeiture of Awards in the event of a Participant’s Termination.  The Committee shall retain full power and discretion with respect to any term or condition of an Award that is not mandatory under the Plan.  

5.2

Award Agreements.  Each Award shall be evidenced by an Award Agreement signed by the Participant and an authorized Company representative.  Each Award shall be subject to the terms and conditions of the Plan and to such other terms and conditions as may be established by the Committee in the Award Agreements.

5.3

Unit Vesting.  Unless otherwise determined in the Award Agreement, Units shall vest according to the following schedule:

Year

Vesting

  1

33-1/3%   

  2

33-1/3%

  3

33-1/3%

5.4

 Settlement of Units;  Other Terms.  Units shall be settled based on their Unit Value in a cash lump sum no later than March 15th of the calendar year following the calendar year in which completion of the relevant Vested Period occurs.  Vested Awards shall not be settled until the conclusion of the full Vesting Period to which such Award relates.

6.

Termination Events

 Unless otherwise provided in the applicable Award Agreement, the following shall apply to all Units held by a Participant upon any Termination.

6.1

Death, Disability or Retirement.  If a Participant's Termination is due to the Participant’s death, Disability or Retirement, all unvested Units (determined as of the Termination Date) shall become immediately vested and all of the Participant’s Units shall be settled in accordance with the Plan on the appropriate Settlement Date following conclusion of the full Vesting Period.

6.2

Termination For Any Other Reason.  If the Participant’s Termination is not due to the Participant’s death, Disability or Retirement, all unvested Units (determined as of the Termination Date) shall be immediately forfeited and all of the Participant’s vested Units shall be settled in accordance with the Plan on the appropriate Settlement Date following conclusion of the full Vesting Period.

7.

Change in Control

 The Committee may set forth in any Award Agreement the effect, if any, that a change in control or other, similar transaction shall have on any awards granted under this Plan.

8.

Claims; Arbitration

8.1

 Claims.  Any individual who makes a claim for benefits under the Plan shall file the claim in writing with the Committee.  Written notice of the disposition of the claim shall be delivered to the claimant within 60 days after filing.  If the claim is denied, the general reasons shall be set forth in a statement delivered to the claimant.  Thereafter, the claimant may request arbitration in accordance with Section 8.2.  The filing of a claim in accordance with this Section 8.1 shall be a condition precedent to the prosecution of any dispute.

8.2

Arbitration.  Any dispute between the Company and an individual claiming a benefit under the Plan that is not resolved between the Company and the claimant shall, if either party wishes to pursue further resolution of the dispute, be submitted to binding arbitration in accordance with the rules of Commercial Arbitration of the American Arbitration Association.  Any such arbitration shall take place in Madison, Wisconsin.  The arbitrator shall be a person experienced in employment and compensation of corporate business executives who is mutually acceptable to the Company and the claimant.  If an arbitrator cannot be agreed upon within 15 days after a dispute is submitted to arbitration, the parties shall each select one representative who is not and has never been associated with the Company or the Board, and who is not and never has been associated with the claimant, and these two representatives shall choose a neutral arbitrator with the qualifications described above.  If the representatives cannot reach agreement, one arbitrator with the qualifications described above shall be selected by the Madison, Wisconsin office of the American Arbitration Association.  All actions and proceedings under this Section 8 shall be kept confidential and neither party shall divulge any part thereof to third parties without the prior written consent of the other party.  Each party to an arbitration under this Section 8 shall pay his or her own expenses,

including without limitation, fees of counsel, and each of the parties shall bear one-half of the fees and costs of the arbitrators.

9.

Miscellaneous

9.1

No Service or Equityholder Rights.  Neither the Plan nor any Awards granted under the Plan shall give any Participant a right to remain in the service of the Board.  No Participant shall have any rights of an equityholder of the Company thereof as a result of the grant of an Award or otherwise under the Plan.

9.2

Withholding Taxes.  The Company shall withhold from the settlement of any Units under this Plan any amount of withholding taxes due in respect of settlement of such Units in cash.

9.3

Governing Law.  All questions pertaining to the validity, construction and administration of the Plan and the Agreements shall be determined in accordance with the laws of the State of Wisconsin without regard to conflicts of law principles.

9.4

Unfunded Plan.  The Plan is intended to constitute an “unfunded” plan for incentive and deferred compensation.  With respect to any amount payable to a Participant under the Plan, nothing contained in the Plan (or in any Award Agreement or other documents related thereto), nor the creation or adoption of the Plan, the grant of any award, or the taking of any other action pursuant to the provisions of the Plan shall give any such Participant any rights that are greater than those of a general creditor of the Company; provided, however, that the Committee may authorize the creation of trusts or make other arrangements to meet the Company’s obligations under the Plan, which trusts or other arrangements shall be consistent with the “unfunded” status of the Plan unless the Committee otherwise determines with the consent of each affected Participant.

9.5

Severability.  In case any provision of this Plan shall be held illegal or invalid, such illegality or invalidity shall be construed and enforced as if said illegal or invalid provision had never been inserted herein and shall not affect the remaining provisions of this Plan, but shall be fully severable, and the Plan shall be construed and enforced as if any such illegal or invalid provision were not a part hereof.

9.6

Adjustments.  In the event of any cash infusion, capital raising transaction, reorganization, recapitalization, stock split, stock dividend, merger, consolidation, split-up, spin-off or any other similar change in the structure of the Company, the Committee reserves the right to make such equitable adjustment, if any, as it may deem appropriate, in its sole and absolute discretion, in the determination of the value of the Units as described herein.

9.7

Setoff.  The Company may, to the extent permitted by law, deduct from and set off against its obligations to a Participant from time to time, any amounts that the Participant owes to the Company for any reason whatsoever.  A Participant shall remain liable for any portion of the Participant’s obligation not satisfied by such setoff.  By accepting an Award granted hereunder, a Participant agrees to any deduction or setoff under this Section 9.7.  

9.8

Transferability and Alienation.  Except insofar as may otherwise be required by law, no amount payable at any time under the Plan shall be subject in any manner to alienation by anticipation, sale, transfer, assignment, bankruptcy, pledge, attachment, charge, or encumbrance of any kind, nor in any manner be subject to the debts or liabilities of any person, and any attempt to so alienate or subject any such amount, whether presently or thereafter payable, shall be void.  If

any person shall attempt to, or shall, alienate, sell, transfer, assign, pledge, attach, charge, or otherwise encumber any amount payable under the Plan, or any part thereof, or if by reason of his or her bankruptcy or other event happening at any such time such amount would be made subject to his or her debts or liabilities or would otherwise not be enjoyed by him or her, then the Committee, if it so elects, may direct that such amount be withheld and that the same or any part thereof be paid or applied to or for the benefit of such person, his or her spouse, children or other dependents, or any of a Participant’s heirs, in such manner and proportion as the Committee may deem proper.

9.9

Notices.  All notices or other communications made or given pursuant to this Plan shall be in writing and shall be sufficiently made or given if hand-delivered or mailed by certified mail addressed to any Participant at the address contained in the records of the Company or to the Company at its principal office.

9.10

Amendment; Termination.  The Board may, without the consent of the Participants under the Plan, at any time terminate the Plan entirely, and at any time or from time to time amend or modify the Plan, provided that no such action shall adversely affect any Award previously granted without the Participant’s consent.

9.11

Expenses.  All expenses and costs incurred in connection with the operation of the Plan shall be borne by the Company.

9.12

Other Plans.  The adoption of this Plan shall not affect any other compensation or incentive plans in effect for the Company’s Directors.  Nothing in this Plan shall be construed to limit the right of the Company to establish, alter or terminate any other forms of incentives, benefits or compensation for Directors.

9.13

Headings.  The headings in the Plan are for reference purposes only and shall not affect the meaning or interpretation of the Plan.

9.14

Section 409A Compliance.  This Plan is intended to be excepted from or comply with, as applicable, the provisions of Section 409A of the Internal Revenue Code of 1986, as amended (the “Code”), and shall be interpreted and construed accordingly.  The Company shall have the discretion and authority to amend this Plan 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 Plan.  By accepting an Award under this Plan, the Participant agrees that no provision of this Plan or any communications related to this Plan shall be interpreted as guaranteeing the tax consequences or treatment of any amounts payable to the Participant under this Plan.

EX-12

EXHIBIT 12

Madison Gas and Electric Company

Ratio of Earnings to Fixed Charges

Three Months Ended March 31, 2017

(In thousands)

Earnings
Net income before minority interest	$18,183
Amortization of capitalized interest	132
Federal and state income taxes	10,309
Fixed charges	5,241
Total Earnings as Defined	$33,865
Fixed Charges
Interest expense on long-term debt and other	$4,764
Interest on rentals*	167
Amortization of debt issuance costs	218
AFUDC - borrowed funds	92
Total Fixed Charges	$5,241
Ratio of Earnings to Fixed Charges	6.46X

*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, Jeffrey M. Keebler, 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 M. Keebler

Jeffrey M. Keebler

President and Chief Executive Officer

Date: May 5, 2017

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

Executive Vice President, Chief Financial Officer,

Secretary and Treasurer

Date: May 5, 2017

EX-31

EXHIBIT 31.3

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

I, Jeffrey M. Keebler, 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 M. Keebler

Jeffrey M. Keebler

President and Chief Executive Officer

Date:May 5, 2017

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

Executive Vice President, Chief Financial Officer,

Secretary and Treasurer

Date: May 5, 2017

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, 2017, as filed with the Securities and Exchange Commission on the date hereof ("the Report"), I, Jeffrey M. Keebler, 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/ Jeffrey M. Keebler

Jeffrey M. Keebler

President and Chief Executive Officer

Date: May 5, 2017

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, 2017, 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

Executive Vice President, Chief Financial Officer,

Secretary and Treasurer

Date: May 5, 2017

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, 2017, as filed with the Securities and Exchange Commission on the date hereof ("the Report"), I, Jeffrey M. Keebler, 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/ Jeffrey M. Keebler

Jeffrey M. Keebler

President and Chief Executive Officer

Date: May 5, 2017

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, 2017, 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

Executive Vice President, Chief Financial Officer,

Secretary and Treasurer

Date: May 5, 2017

XML

Document and Entity Information - shares	3 Months Ended
	Mar. 31, 2017	Apr. 30, 2017
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, 2017
Amendment Flag	false
Trading Symbol	MGEE
Document Fiscal Year Focus	2017
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, 2017	Mar. 31, 2016
Operating Revenues:
Electric revenues	$ 98,397	$ 93,690
Gas revenues	58,426	53,837
Total Operating Revenues	156,823	147,527
Operating Expenses:
Fuel for electric generation	12,199	12,013
Purchased power	15,354	14,670
Cost of gas sold	35,784	32,523
Other operations and maintenance	42,690	42,730
Depreciation and amortization	12,959	11,032
Other general taxes	4,927	5,028
Total Operating Expenses	123,913	117,996
Operating Income	32,910	29,531
Other income, net	2,451	2,442
Interest expense, net	(4,894)	(5,000)
Income before income taxes	30,467	26,973
Income tax provision	(11,167)	(9,945)
Net Income	$ 19,300	$ 17,028
Earnings Per Share of Common Stock (basic and diluted)	$ 0.56	$ 0.49
Dividends per share of common stock	$ 0.308	$ 0.295
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, 2017	Mar. 31, 2016
Operating Revenues:
Electric revenues		$ 98,397	$ 93,690
Gas revenues		58,426	53,837
Total Operating Revenues		156,823	147,527
Operating Expenses:
Fuel for electric generation		12,199	12,013
Purchased power		15,354	14,670
Cost of gas sold		35,784	32,523
Other operations and maintenance		42,690	42,730
Depreciation and amortization		12,959	11,032
Other general taxes		4,927	5,028
Total Operating Expenses		123,913	117,996
Operating Income		32,910	29,531
Other Income and Deductions:
Equity earnings in MGE Transco		2,608	2,233
Total Other Income and Deductions		2,451	2,442
Interest Expense:
Net Interest Expense		4,894	5,000
Net Income		19,300	17,028
MGE [Member]
Operating Revenues:
Electric revenues		98,401	93,696
Gas revenues		58,435	53,847
Total Operating Revenues		156,836	147,543
Operating Expenses:
Fuel for electric generation		12,201	12,016
Purchased power		15,356	14,674
Cost of gas sold		35,793	32,534
Other operations and maintenance		42,321	42,402
Depreciation and amortization		12,959	11,020
Other general taxes		4,927	5,028
Income tax provision		10,265	9,090
Total Operating Expenses		133,822	126,764
Operating Income	[1]	23,014	20,779
Other Income and Deductions:
AFUDC - equity funds		271	261
Equity earnings in MGE Transco		0	2,233
Income tax provision		(44)	(942)
Other expense, net		(76)	(73)
Total Other Income and Deductions	[1]	151	1,479
Income before interest expense		23,165	22,258
Interest Expense:
Interest on long-term debt		5,043	5,109
Other interest, net		31	37
AFUDC - borrowed funds		(92)	(85)
Net Interest Expense		4,982	5,061
Net Income Including Noncontrolling Interest		18,183	17,197
Less Net Income Attributable to Noncontrolling Interest, net of tax		(5,389)	(6,252)
Net Income		$ 12,794	$ 10,945

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

XML

MGE Energy Inc Consolidated Statements of Comprehensive Income (Unaudited) - USD ($) $ in Thousands	3 Months Ended
	Mar. 31, 2017	Mar. 31, 2016
Comprehensive Income [Abstract]
Net Income	$ 19,300	$ 17,028
Other comprehensive income, net of tax:
Unrealized gain (loss) on available-for-sale securities, net of tax	97	(164)
Comprehensive Income	$ 19,397	$ 16,864

XML

Madison Gas and Electric Company Consolidated Statements of Comprehensive Income (Unaudited) - USD ($) $ in Thousands	3 Months Ended
	Mar. 31, 2017	Mar. 31, 2016
Other comprehensive income, net of tax:
Unrealized gain (loss) on available-for-sale securities, net of tax	$ 97	$ (164)
Comprehensive Income	19,397	16,864
MGE [Member]
Net Income	18,183	17,197
Other comprehensive income, net of tax:
Unrealized gain (loss) on available-for-sale securities, net of tax	(6)	(30)
Total comprehensive income including noncontrolling interest	18,177	17,167
Less: Comprehensive income attributable to Noncontrolling Interest, net of tax	(5,389)	(6,252)
Comprehensive Income	$ 12,788	$ 10,915

XML

Consolidated Statements of Comprehensive Income (Unaudited) (Parantheticals) - USD ($) $ in Thousands	3 Months Ended
	Mar. 31, 2017	Mar. 31, 2016
Unrealized gain (loss) on available-for-sale securities, tax expense (benefit)	$ 65	$ (110)
MGE [Member]
Unrealized gain (loss) on available-for-sale securities, tax expense (benefit)	$ (4)	$ (20)

XML

MGE Energy Inc Consolidated Statements of Cash Flows (Unaudited) - USD ($) $ in Thousands	3 Months Ended
	Mar. 31, 2017	Mar. 31, 2016
Operating Activities:
Net Income	$ 19,300	$ 17,028
Items not affecting cash:
Depreciation and amortization	12,959	11,032
Deferred income taxes	(3,732)	2,840
Provision for doubtful receivables	254	592
Employee benefit plan cost (credit)	202	(57)
Equity earnings in ATC	(2,608)	(2,233)
Other items	609	86
Changes in working capital items:
Decrease in current assets	28,191	22,311
(Decrease) increase in current liabilities	(9,318)	1,487
Dividends from ATC	2,072	865
Cash contributions to pension and other postretirement plans	(7,168)	(11,159)
Other noncurrent items, net	1,526	937
Cash Provided by Operating Activities	42,287	43,729
Investing Activities:
Capital expenditures	(16,117)	(15,642)
Capital contributions to investments	(2,939)	(671)
Other	541	(183)
Cash Used for Investing Activities	(18,515)	(16,496)
Financing Activities:
Cash dividends paid on common stock	(10,660)	(10,227)
Repayment of long-term debt	(31,080)	(1,059)
Issuance of long-term debt	40,000	0
Other	(289)	0
Cash Used for Financing Activities	(2,029)	(11,286)
Change in cash and cash equivalents	21,743	15,947
Cash and cash equivalents at beginning of period	95,959	81,384
Cash and cash equivalents at end of period	117,702	97,331
Significant noncash investing activities:
Accrued capital expenditures	$ 6,804	$ 6,587

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Madison Gas and Electric Company Consolidated Statements of Cash Flows (Unaudited) - USD ($) $ in Thousands	3 Months Ended
	Mar. 31, 2017	Mar. 31, 2016
Items not affecting cash:
Depreciation and amortization	$ 12,959	$ 11,032
Deferred income taxes	(3,732)	2,840
Provision for doubtful receivables	254	592
Employee benefit plan cost (credit)	202	(57)
Equity earnings in MGE Transco	(2,608)	(2,233)
Other items	609	86
Changes in working capital items:
Decrease in current assets	28,191	22,311
(Decrease) increase in current liabilities	(9,318)	1,487
Dividends from MGE Transco	2,072	865
Cash contributions to pension and other postretirement plans	(7,168)	(11,159)
Other noncurrent items, net	1,526	937
Cash Provided by Operating Activities	42,287	43,729
Investing Activities:
Capital expenditures	(16,117)	(15,642)
Capital contributions to investments	(2,939)	(671)
Other	541	(183)
Cash Used for Investing Activities	(18,515)	(16,496)
Financing Activities:
Repayment of long-term debt	(31,080)	(1,059)
Issuance of long-term debt	40,000	0
Other	(289)	0
Cash Used for Financing Activities	(2,029)	(11,286)
Change in cash and cash equivalents	21,743	15,947
Cash and cash equivalents at beginning of period	95,959	81,384
Cash and cash equivalents at end of period	117,702	97,331
Significant noncash investing activities:
Accrued capital expenditures	6,804	6,587
MGE [Member]
Operating Activities:
Net Income	18,183	17,197
Items not affecting cash:
Depreciation and amortization	12,959	11,020
Deferred income taxes	(4,242)	2,502
Provision for doubtful receivables	254	592
Employee benefit plan cost (credit)	202	(57)
Equity earnings in MGE Transco	0	(2,233)
Other items	658	112
Changes in working capital items:
Decrease in current assets	27,233	22,053
(Decrease) increase in current liabilities	(9,022)	1,524
Dividends from MGE Transco	0	865
Cash contributions to pension and other postretirement plans	(7,168)	(11,159)
Other noncurrent items, net	1,488	906
Cash Provided by Operating Activities	40,545	43,322
Investing Activities:
Capital expenditures	(16,117)	(15,642)
Capital contributions to investments	0	(533)
Other	(229)	(72)
Cash Used for Investing Activities	(16,346)	(16,247)
Financing Activities:
Cash dividends paid to parent by MGE	(15,000)	(10,000)
Distributions to parent from noncontrolling interest	(5,500)	(6,500)
Equity contribution received by noncontrolling interest	0	533
Repayment of long-term debt	(31,080)	(1,059)
Issuance of long-term debt	40,000	0
Other	(289)	0
Cash Used for Financing Activities	(11,869)	(17,026)
Change in cash and cash equivalents	12,330	10,049
Cash and cash equivalents at beginning of period	10,768	26,760
Cash and cash equivalents at end of period	23,098	36,809
Significant noncash investing activities:
Accrued capital expenditures	$ 6,804	$ 6,587

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Consolidated Balance Sheets (Unaudited) - USD ($) $ in Thousands	Mar. 31, 2017	Dec. 31, 2016
Current Assets:
Cash and cash equivalents	$ 117,702	$ 95,959
Accounts receivable, less reserves	39,750	39,887
Other accounts receivables, less reserves	5,896	8,530
Unbilled revenues	25,335	29,846
Materials and supplies, at average cost	19,668	18,561
Fossil fuel, at average cost	8,827	9,757
Stored natural gas, at average cost	4,710	12,819
Prepaid taxes	12,468	26,636
Regulatory assets - current	7,581	6,414
Assets held for sale	2,338	14,813
Other current assets	9,819	12,293
Total Current Assets	254,094	275,515
Regulatory assets	153,126	158,485
Pension and other postretirement benefit asset	2,568	2,020
Other deferred assets and other	6,489	6,691
Property, Plant, and Equipment:
Property, plant, and equipment, net	1,249,648	1,245,269
Construction work in progress	37,588	36,790
Total Property, Plant, and Equipment	1,287,236	1,282,059
Investments	81,806	76,290
Total Assets	1,785,319	1,801,060
Current Liabilities:
Long-term debt due within one year	4,381	4,333
Accounts payable	36,865	47,799
Accrued interest and taxes	8,254	5,495
Accrued payroll related items	7,848	11,892
Regulatory liabilities - current	11,658	6,910
Derivative liabilities	8,259	7,620
Other current liabilities	6,249	19,456
Total Current Liabilities	83,514	103,505
Other Credits:
Deferred income taxes	380,276	383,813
Investment tax credit - deferred	927	947
Regulatory liabilities	23,266	22,173
Accrued pension and other postretirement benefits	67,481	74,347
Derivative liabilities	40,430	42,970
Other deferred liabilities and other	65,131	66,426
Total Other Credits	577,511	590,676
Capitalization:
Common shareholders equity	732,825	724,088
Long-term debt	391,469	382,791
Total Capitalization	1,124,294	1,106,879
Commitments and contingencies (see Footnote 7)
Total Liabilities and Capitalization	1,785,319	1,801,060
MGE [Member]
Current Assets:
Cash and cash equivalents	23,098	10,768
Accounts receivable, less reserves	39,750	39,887
Affiliate receivables	1,149	539
Other accounts receivables, less reserves	5,796	6,363
Unbilled revenues	25,335	29,846
Materials and supplies, at average cost	19,668	18,561
Fossil fuel, at average cost	8,827	9,757
Stored natural gas, at average cost	4,710	12,819
Prepaid taxes	12,449	25,798
Regulatory assets - current	7,581	6,414
Assets held for sale	2,338	14,813
Other current assets	9,805	12,268
Total Current Assets	160,506	187,833
Affiliate receivable long-term	4,104	4,236
Regulatory assets	153,126	158,485
Pension and other postretirement benefit asset	2,568	2,020
Other deferred assets and other	4,200	4,353
Property, Plant, and Equipment:
Property, plant, and equipment, net	1,249,676	1,244,648
Construction work in progress	37,588	36,790
Total Property, Plant, and Equipment	1,287,264	1,281,438
Investments	476	487
Total Assets	1,612,244	1,638,852
Current Liabilities:
Long-term debt due within one year	4,381	4,333
Accounts payable	36,865	47,790
Accrued interest and taxes	8,598	5,440
Accrued payroll related items	7,848	11,892
Regulatory liabilities - current	11,658	6,910
Derivative liabilities	8,259	7,620
Other current liabilities	6,028	19,347
Total Current Liabilities	83,637	103,332
Other Credits:
Deferred income taxes	339,477	343,117
Investment tax credit - deferred	927	947
Regulatory liabilities	23,266	22,173
Accrued pension and other postretirement benefits	67,481	74,347
Derivative liabilities	40,430	42,970
Other deferred liabilities and other	65,131	66,426
Total Other Credits	536,712	549,980
Capitalization:
Common shareholders equity	484,872	487,084
Noncontrolling interest	115,554	115,665
Total Equity	600,426	602,749
Long-term debt	391,469	382,791
Total Capitalization	991,895	985,540
Commitments and contingencies (see Footnote 7)
Total Liabilities and Capitalization	$ 1,612,244	$ 1,638,852

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Consolidated Balance Sheets (Unaudited) (Parentheticals) - USD ($) $ in Thousands	Mar. 31, 2017	Dec. 31, 2016
Receivables, Net
Reserve for uncollectible accounts receivable	$ 2,963	$ 3,017
Reserve for uncollectible other accounts receivable	419	426
MGE [Member]
Receivables, Net
Reserve for uncollectible accounts receivable	2,963	3,017
Reserve for uncollectible other accounts receivable	$ 419	$ 426

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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/(Loss) [Member]
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 income (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
Beginning balance, shares at Dec. 31, 2016		34,668
Beginning balance, value at Dec. 31, 2016	724,088	$ 34,668	316,268	372,950	202
Increase (Decrease) In Stockholders' Equity [Roll Forward]
Net Income	19,300			19,300
Other comprehensive income (loss)	97				97
Common stock dividends declared	(10,660)			(10,660)
Ending balance, shares at Mar. 31, 2017		34,668
Ending balance, value at Mar. 31, 2017	$ 732,825	$ 34,668	$ 316,268	$ 381,590	$ 299

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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] 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, 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 income (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
Beginning balance, shares at Dec. 31, 2016			34,668	17,348
Beginning balance, value at Dec. 31, 2016		602,749		$ 17,348	192,417	277,300		19	115,665
Increase (Decrease) In Stockholders' Equity [Roll Forward]
Net Income		18,183				12,794			5,389
Other comprehensive income (loss)	$ 97	(6)					$ 97	(6)
Cash dividends paid to parent by MGE		(15,000)				(15,000)
Distributions to parent from noncontrolling interest		(5,500)							(5,500)
Ending balance, shares at Mar. 31, 2017			34,668	17,348
Ending balance, value at Mar. 31, 2017		$ 600,426		$ 17,348	$ 192,417	$ 275,094		$ 13	$ 115,554

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Consolidated Statements of Common Equity (Unaudited) (Parentheticals) - $ / shares	3 Months Ended
	Mar. 31, 2017	Mar. 31, 2016
Consolidated Statements of Common Equity
Dividends per share of common stock	$ 0.308	$ 0.295

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Basis of Presentation

3 Months Ended

Mar. 31, 2017

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 2016 Annual Report on Form 10-K.

Prior to December 1, 2016, MGE Transco was jointly owned by MGE Energy and MGE.MGE's ownership interest in MGE Transco declined below a majority in July 2016. As a result of the change in majority ownership in MGE Transco in July 2016, MGE deconsolidated MGE Energy's proportionate share of the equity in MGE Transco. The change in consolidation was applied prospectively by reducing its investment and noncontrolling interest on MGE's consolidated financial statements.On December 1, 2016, MGE's ownership interest in MGE Transco was transferred to MGE Energy. See Footnote 3 for further discussion.

The accompanying consolidated financial statements as of March 31,2017, 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 2016 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 54 through 104 of the 2016 Annual Report on Form 10-K.

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Equity and Financing Arrangements

3 Months Ended

Mar. 31, 2017

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 31,2017 and 2016, MGE Energy did not issue any new shares of common stock under the Stock Plan.

b. Dilutive Shares Calculation.

MGE Energy does not have any dilutive securities.

c. Long-term Debt- MGE Energy and MGE.

On January 13, 2017, MGE issued $40 million of 3.76% senior unsecured notes due January 15, 2052. MGE used the net proceeds from the sale of senior notes to refinance $30 million of medium-term notes, which matured in January 2017, and assist with the financing of additional capital expenditures. The new, unsecured long-term debt carries an interest rate of 3.76% per annum over its 35-year term. The covenants of this debt are substantially consistent with MGE's existing unsecured long-term debt.

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Investment in ATC and ATC Holdco

3 Months Ended

Mar. 31, 2017

Equity Method Investments and Joint Ventures [Abstract]

Investment in ATC and ATC Holdco

Investment in ATC and ATC Holdco - 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, as of December 1, 2016, is owned solely by MGE Energy. ATC Holdco was formed by several members of ATC, including MGE Energy, to pursue electric transmission development and investments outside of Wisconsin. The ownership interest in ATC Holdco is held by MGEE Transco, a wholly-owned subsidiary of MGE Energy.

MGE Transco and MGEE Transco have accounted for their investment in ATC and ATC Holdco, respectively, under the equity method of accounting.Equity earnings from investments are recorded as "Other income" on MGE Energy's consolidated statements of income. For the three months endedMarch 31,2017 and 2016, MGE Transco recorded the following:

		Three Months Ended
		March 31,
(In thousands)		2017		2016
Equity earnings from investment in ATC	$	2,608	$	2,233
Dividends from ATC(a)		-		865
Capital contributions to ATC		1,420		533

(a)As of December 31, 2016, MGE Transco recorded a $2.1 million receivable from ATC for a cash dividend received in January 2017.

ATC Holdco's activities commenced in late December 2016 and had an immaterial impact on results of operations, cash flows, and financial condition.

AtMarch 31,2017, and December 31, 2016, MGE Transco held a 3.6% ownership interest in ATC, and MGEE Transco held a 4.0% ownership interest in ATC Holdco, respectively.

In June 2016, the PSCW required MGE to transfer its interest in ATC to MGE Energy, which was to be completed by December 31, 2022. The requirement arose in the context of requests for regulatory approvals by several owners of ATC in connection with a reorganization of ATC. MGE's ownership interest in ATC, held through MGE Transco, was transferred net of deferred tax liabilities to MGE Energy by way of a dividend in kind of $15.8 million as of December 1, 2016. As a result of the transfer, MGE's ownership interest in MGE Transco was completely eliminated in favor of MGE Energy. The change had no effect on MGE Energy's consolidated financial statements.

ATC's summarized financial data for the three months endedMarch 31,2017 and 2016, is as follows:

		Three Months Ended
		March 31,
(In thousands)		2017		2016
Operating revenues	$	174,669	$	164,240
Operating expenses		(82,388)		(79,065)
Other income, net		207		127
Interest expense, net		(26,616)		(24,208)
Earnings before members' income taxes	$	65,872	$	61,094

MGE receives transmission and other related services from ATC. During the three months endedMarch 31,2017, MGE recorded $9.2 million for transmission services received compared to $9.7 million for the comparable period in 2016. MGE also provides a variety of operational, maintenance, and project management services for ATC, which is reimbursed by ATC. As of March 31,2017 and December 31, 2016, MGE had a receivable due from ATC of $0.1 million.

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Taxes

3 Months Ended

Mar. 31, 2017

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 31,2017 and 2016, was 36.7% and 36.9%, respectively. MGE's effective income tax rate for thethree months endedMarch 31,2017 and 2016, was 36.2% and 36.8%, respectively. For both MGE Energy and MGE, the decrease in the effective tax rate is due in part to a higher estimated domestic manufacturing deduction and higher estimated AFUDC equity earnings in 2017. In addition, MGE's effective income tax rate decreased as a result of the transfer of its ownership interest in MGE Transco.

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Pension and Other Postretirement Plans

3 Months Ended

Mar. 31, 2017

Compensation and Retirement Disclosure [Abstract]

Pension and Other Postretirement Plans

Pension and Other Postretirement Plans - MGE Energy and MGE.

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

The following table presents the components of net periodic benefit costs recognized for the three months endedMarch 31,2017 and 2016. A portion of the net periodic benefit cost is capitalized within the consolidated balance sheets.

		Three Months Ended
		March 31,
(In thousands)		2017		2016
Pension Benefits
Components of net periodic benefit cost:
Service cost	$	1,332	$	1,381
Interest cost		3,119		3,089
Expected return on assets		(5,742)		(5,593)
Amortization of:
Prior service (credit) cost		(4)		2
Actuarial loss		1,464		1,356
Net periodic benefit cost	$	169	$	235
Postretirement Benefits
Components of net periodic benefit cost:
Service cost	$	206	$	324
Interest cost		444		674
Expected return on assets		(472)		(705)
Amortization of:
Transition obligation		-		1
Prior service credit		(436)		(667)
Actuarial loss		129		159
Net periodic benefit (credit) cost	$	(129)	$	(214)

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Share-Based Compensation

3 Months Ended

Mar. 31, 2017

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

Share-Based Compensation

Share-Based Compensation - MGE Energy and MGE.

Under MGE Energy'sDirector Incentive Plan and Performance Unit Plan, non-employee directorsand 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 January 2017, 4,032units were granted under the Director Incentive Plan and are subject to a three-year graded vesting schedule. In March 2017, 14,704 units were granted under the Performance Unit Plan and are subject to a five-year graded vesting schedule. On the grant date, MGE Energy and MGE measure the cost of the director or 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 31,2017, 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 under the Performance Unit Plan, 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.

During the three months endedMarch 31,2017, MGE recorded $0.5 million in compensation expense as a result of awards under the plans compared to $1.3 million for the comparable period in 2016. In January 2017, cash payments of $2.0 million were distributed relating to awards that were granted under the plans. No forfeitures of units occurred during the three months endedMarch 31,2017 and 2016. At March 31,2017, $5.4 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, 2017

Commitments and Contingencies Disclosure [Abstract]

Commitments and Contingencies

Commitments and Contingencies - MGE Energy and MGE.

a. Environmental.

MGE Energy and MGE are subject to frequently changing local, state, and federal regulations concerning air quality, water quality, land use, threatened and endangered species, hazardous materials handling, and solid waste disposal. These regulations affect the manner in which they conduct their operations, the costs of those operations, as well as capital and operating expenditures. Several of these environmental rules are subject to legal challenges, reconsideration and/or other uncertainties. 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. Management believes compliance costs will be recovered in future rates based on previous treatment of environmental compliance projects. These initiatives, proposed rules, and court challenges include:

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

• The EPA's cooling water intake rules, which require cooling water intake structures at electric power plants, such as our WCCF, Blount, and Columbia 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.

• Greenhouse Gas (GHG) reduction guidelines and approval criteria established under the Clean Air Act for states to use in developing plans to control GHG emissions from existing fossil fuel-fired electric generating units (EGUs) and systems. 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. Given the pending legal proceedings, 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.

• Federal and state air quality regulations impose restrictions on various emissions including emissions of sulfur dioxide (SO₂), nitrogen dioxides (NO₂), and other pollutants, and may require permits for operation of emission sources.

• The EPA's rule to regulate ambient levels of a pollutant through the Ozone National Ambient Air Quality Standards (NAAQS). 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. Oral arguments in this case are scheduled to begin in mid-2017. MGE will continue to monitor the EPA's progress on attainment designations and related litigation to assess potential impacts at our facilities, particularly our Elm Road Units.

• Rules regulating nitrogen oxide (NO_x) and SO₂ emissions including the Cross State Air Pollution Rule (CSAPR) and Clean Air Visibility Rule (CAVR). At this time, regulatory obligations, compliance strategies, and costs remain uncertain due to the continued legal challenges surrounding CSAPR and CAVR.

• The EPA's Coal Combustion Residuals Rule, which regulates coal ash 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. Review of our Elm Road Units 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.

The matters in the bullet points above are discussed further in Footnote 17.c. in the Financial Statements of MGE Energy's and MGE's 2016 Annual Report on Form 10-K.

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. MGE does not expect the resolution of these matters to have a material adverse effect on its consolidated results of operations, financial condition, or cash flows.

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Rate Matters

3 Months Ended

Mar. 31, 2017

Regulated Operations [Abstract]

Rate Matters

Rate Matters - MGE Energy and MGE.

a. Rate Proceedings.

In December 2016, the PSCW authorized MGE, effective January 1, 2017, to decrease 2017 rates for retail electric customers by 0.8% or $3.3million and to increase rates for retail gas customers by 1.9% or $3.1million. The decrease in retail electric rates is attributable to declining fuel and purchased power costs. The increase in retail gas rates covers costs associated with MGE's natural gas system infrastructure improvements. The authorized return on common stock equity for 2017 is 9.8% on 57.2% common equity. The PSCW also approved MGE's request to extend the current accounting treatment for transmission related costs through 2018. This accounting treatment allows MGE to reflect any differential between transmission costs reflected in rates and actual costs incurred in its next rate case filing.

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.

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 in the following year and is then reflected 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 continued throughout 2016. The fuel credit established a mechanism to return $10.9million of fuel savings to electric customers as a bill credit. MGE returned $2.6million of electric fuel-related savings to customers through bill credits during the period from September 1, 2015, through December 31, 2015. MGE returned $8.3million of electric fuel-related savings during the year ended December 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. Also, in March 2016, MGE filed its 2015 fuel plan reconciliation application showing an overcollection of 2015 fuel rules monitored costs. In July 2016, the PSCW issued a final order stating that MGE shall refund $15.7million of additional fuel savings realized during 2015 and 2016 to its retail electric customers over a one-month period. In September 2016, MGE returned $15.5million to customers through bill credits.

As of March 31,2016, MGE had no deferred 2016 fuel savings that were in excess of the fuel savings included within the fuel credits referenced above. As of March 31,2017, MGE has deferred $1.1 million of 2017 fuel savings. These costs will be subject to the PSCW's annual review of 2017 fuel costs, expected to be completed in 2018.

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Derivative and Hedging Instruments

3 Months Ended

Mar. 31, 2017

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, the derivatives are recognizedin the consolidated balance sheets at fair value. MGE's financial 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, 2017	December 31, 2016
Commodity derivative contracts	415,165 MWh	393,395 MWh
Commodity derivative contracts	1,677,500 Dth	4,195,000 Dth
FTRs	920 MW	2,251 MW
PPA	3,100 MW	3,250 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 31,2017 and December 31, 2016, the fair value of exchange traded derivatives and FTRs exceeded their cost basis by $0.6 million and $1.3 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 31,2017, and December 31, 2016, reflects a loss position of $48.6 million and $50.6 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, instruments are netted with the same counterparty under a master netting agreement as well as the netting of collateral. As of March 31,2017 and December 31, 2016, thereceivable – margin account balance of $0.6million and $1.3 million, respectively, is shown net of any collateral posted against derivative positions.

		Derivative Assets		Derivative Liabilities
(In thousands)					Balance Sheet Location
March 31, 2017
Commodity derivative contracts(a)	$	640	$	165	Other current assets(b)
Commodity derivative contracts(a)		24		87	Other deferred charges
FTRs		155		-	Other current assets
PPA		N/A		8,210	Derivative liability (current)
PPA		N/A		40,430	Derivative liability (long-term)
December 31, 2016
Commodity derivative contracts(a)	$	1,227	$	164	Other current assets
Commodity derivative contracts(a)		157		54	Other deferred charges
FTRs		143		-	Other current assets
PPA		N/A		7,620	Derivative liability (current)
PPA		N/A		42,970	Derivative liability (long-term)

(a)As of March 31,2017, and December 31, 2016, no collateral was posted against and netted with derivative liability positions on the consolidated balance sheets.

(b)As of March 31,2017, $0.1 million was presented as current derivative liabilities on the consolidated balance sheets.

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, 2017
Commodity derivative contracts	$	664	$	(203)	$	-	$	461
FTRs		155		-		-		155
December 31, 2016
Commodity derivative contracts	$	1,384	$	(218)	$	-	$	1,166
FTRs		143		-		-		143

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, 2017
Commodity derivative contracts	$	252	$	(203)	$	-	$	49
PPA		48,640		-		-		48,640
December 31, 2016
Commodity derivative contracts	$	218	$	(218)	$	-	$	-
PPA		50,590		-		-		50,590

The following tables summarize the unrealized and realized gains (losses) related to the derivative instruments on the consolidated balance sheets at March 31,2017 and 2016, and the consolidated income statements for the three months endedMarch 31,2017 and 2016.

		2017				2016
(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,	$	49,281	$	230	$	54,082	$	1,208
Unrealized (gain) loss		(689)		-		6,371		-
Realized (loss) gain reclassified to a deferred account		(78)		78		(1,451)		1,451
Realized loss reclassified to income statement		(441)		(166)		(2,118)		(2,004)
Balance at March 31,	$	48,073	$	142	$	56,884	$	655

		Realized losses (gains)
		2017				2016
(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	$	385	$	146	$	1,007	$	1,814
FTRs		(685)		-		(68)		-
PPA		761		-		1,369		-

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 31,2017, 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 31,2017, certain counterparties were in a net liability position of less than $0.1 million.As ofDecember 31, 2016, no counterparties were in a net liability position.

Nonperformance of counterparties to the non-exchange traded derivatives could expose MGE to credit loss. However, MGE enters into transactions only with companies that meet or exceed strict credit guidelines, and it monitors these counterparties on an ongoing basis to mitigate nonperformance risk in its portfolio. As of March 31,2017,no counterparties have defaulted.

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Fair Value of Financial Instruments

3 Months Ended

Mar. 31, 2017

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 31,2017, and December 31, 2016, 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 oflong-term debt is based on quoted market prices for similar financial instruments at March 31,2017, and December 31, 2016. Since long-term debt is not traded in an active market, it is classified as Level 2.The estimated fair market values of financial instruments are as follows:

		March 31, 2017				December 31, 2016
(In thousands)		Carrying Amount		Fair Value		Carrying Amount		Fair Value
MGE Energy
Assets:
Cash and cash equivalents	$	117,702	$	117,702	$	95,959	$	95,959
Liabilities:
Long-term debt(a)		400,161		445,037		391,242		430,122
MGE
Assets:
Cash and cash equivalents	$	23,098	$	23,098	$	10,768	$	10,768
Liabilities:
Long-term debt(a)		400,161		445,037		391,242		430,122
(a) Includes long-term debt due within one year. Excludes debt issuance costs and unamortized discount of
$4.3 million and $4.1 million at March 31, 2017, and December 31, 2016, respectively.

b. Recurring Fair Value Measurements.

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

		Fair Value as of March 31, 2017
(In thousands)		Total		Level 1		Level 2		Level 3
MGE Energy
Assets:
Derivatives	$	819	$	341	$	-	$	478
Exchange-traded investments		662		662		-		-
Total Assets	$	1,481	$	1,003	$	-	$	478
Liabilities:
Derivatives	$	48,892	$	60	$	-	$	48,832
Deferred compensation		3,014		-		3,014		-
Total Liabilities	$	51,906	$	60	$	3,014	$	48,832
MGE
Assets:
Derivatives	$	819	$	341	$	-	$	478
Exchange-traded investments		132		132		-		-
Total Assets	$	951	$	473	$	-	$	478
Liabilities:
Derivatives	$	48,892	$	60	$	-	$	48,832
Deferred compensation		3,014		-		3,014		-
Total Liabilities	$	51,906	$	60	$	3,014	$	48,832

		Fair Value as of December 31, 2016
(In thousands)		Total		Level 1		Level 2		Level 3
MGE Energy
Assets:
Derivatives	$	1,527	$	1,041	$	-	$	486
Exchange-traded investments		500		500		-		-
Total Assets	$	2,027	$	1,541	$	-	$	486
Liabilities:
Derivatives	$	50,808	$	16	$	-	$	50,792
Deferred compensation		3,039		-		3,039		-
Total Liabilities	$	53,847	$	16	$	3,039	$	50,792
MGE
Assets:
Derivatives	$	1,527	$	1,041	$	-	$	486
Exchange-traded investments		143		143		-		-
Total Assets	$	1,670	$	1,184	$	-	$	486
Liabilities:
Derivatives	$	50,808	$	16	$	-	$	50,792
Deferred compensation		3,039		-		3,039		-
Total Liabilities	$	53,847	$	16	$	3,039	$	50,792

No transfers were made in or out of Level 1 or Level 2 for the three months endedMarch 31,2017.

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

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

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

	Model Input
Significant Unobservable Inputs	March 31, 2017	December 31, 2016
Basis adjustment:
On peak	92.2%	91.9%
Off peak	94.0%	93.4%
Counterparty fuel mix:
Internal generation	55% - 75%	55% - 75%
Purchased power	45% - 25%	45% - 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. 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 commodity derivative assets and liabilities measured at fair value on a recurring basis.

		Three Months Ended
		March 31,
(In thousands)		2017		2016
Beginning balance	$	(50,306)	$	(53,501)
Realized and unrealized gains (losses):
Included in regulatory (assets) liabilities		1,953		(3,600)
Included in other comprehensive income		-		-
Included in earnings		(586)		(2,163)
Included in current assets		125		-
Purchases		5,996		5,301
Sales		-		-
Issuances		-		-
Settlements		(5,536)		(3,138)
Transfers in and/or out of Level 3		-		-
Balance as of March 31,	$	(48,354)	$	(57,101)
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 (b).

		Three Months Ended
		March 31,
(In thousands)		2017		2016
Purchased Power Expense	$	(431)	$	(2,163)
Cost of Gas Sold Expense		(155)		-
Total	$	(586)	$	(2,163)

(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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Joint Plant Ownership

3 Months Ended

Mar. 31, 2017

Regulated Operations [Abstract]

Joint Plant Ownership

Joint Plant Ownership - MGE Energy and MGE.

Columbia.

In 2016, MGE and WPL negotiated an amendment to the existing Columbia joint operating agreement, that has been approved by the PSCW, under which MGE will have the option to reduce its obligation to pay certain capital expenditures (other than SCR-related expenditures) at Columbia in exchange for a proportional reduction in MGE's ownership in Columbia. On January 1 of each year, beginning in 2017 and ending June 1, 2020, the ownership percentage will be adjusted, through a partial sale, based on the amount of capital expenditures foregone. In December 2016, MGE jointly filed a request with the co-owners of Columbia for FERC approval of the amendment to the Columbia joint operating agreement, effective January 1, 2017. MGE currently expects to receive FERC's decision on the amendment in 2017.

During 2016, MGE accrued $14.8 million of 2016 capital expenditures that MGE has forgone as part of the ownership transfer agreement with WPL. As of December 31, 2016, MGE classified $14.8 million of Columbia assets as held-for-sale on the consolidated balance sheets. In January 2017, MGE reduced its ownership interest in Columbia from 22.0% to 20.4% through the partial sale of plant assets to WPL.

During three months endedMarch 31,2017, MGE accrued $2.3 million of 2017 capital expenditures that MGE has forgone subject to the ownership transfer agreement. As of March 31,2017, MGE classified $2.3 million of Columbia assets as held-for-sale on the consolidated balance sheets. The assets recognized as held-for-sale are subject to a partial sale of plant assets to WPL, expected to occur in January 2018.

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Adoption of Accounting Principles and Recently Issued Accounting Pronouncements

3 Months Ended

Mar. 31, 2017

New Accounting Pronouncements and Changes in Accounting Principles [Abstract]

New Accounting Pronouncements

Adoption of Accounting Principles and Recently Issued 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. The new standard establishes a five step model for recognizing and measuring revenue from contracts with customers and replaces existing guidance on revenue recognition. The objective of the new standard is to provide a single, comprehensive revenue recognition model for all contracts with customers to improve comparability within industries, across industries and across capital markets. The underlying principle is that an entity will recognize revenue to depict the transfer of goods or services to customers at an amount that the entity expects to be entitled to in exchange for those goods or services.

MGE Energy and MGE have been assessing the impact of this guidance on revenue streams within the scope of the new standard. All retail electric and gas revenues are tariff rates approved by the PSCW. Based on our evaluation of the new standard, retail revenues will be recognized within the period in which utility service is provided to the customer and the performance obligation is fulfilled, consistent with our current revenue recognition model. Electric revenues for sales to the market represent wholesale sales made to third parties who are not ultimate users of the electricity. These sales may also include bilateral sales to other utilities or power marketers. Revenues for sales to the market will be recognized when the sale is completed within the market operated by MISO, similar to the recognition under our current revenue recognition model. In addition, revenues from the transportation of gas will continue to be recognized upon the performance of services for the respective customer. Based on our assessment of the new standard, revenue recognition for retail revenues, sales to the market, and transportation of gas will be consistent with our current revenue recognition model. However, additional disclosures regarding the nature, amount, timing, and uncertainty of these revenue streams and related cash flows arising from contracts with customers will be required as a result of the new standard.

The Power and Utilities Task Force of the AICPA is formulating a utility industry-specific interpretation of the guidance regarding the collectability threshold of probable within the new standard. The collectability criterion could impact the timing of revenue recognition for uncollectible accounts. Management continues to analyze newly-released interpretative guidance and assess the related impacts to the current revenue recognition model.

This authoritative guidance will become effective January 1, 2018, and MGE Energy and MGE anticipate adopting the standard upon the effective date. Adoption of this standard is permitted under one of two methods: the full retrospective method or the modified retrospective method. MGE Energy and MGE are continuing to assess the permitted implementation methods and the impact on our financial statements.

b. 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, and will require equity investments to be measured at fair value with changes in fair value recognized in net income rather than in other comprehensive income. As a result of this guidance, MGE Energy and MGE will no longer have any other comprehensive income related to equity investments. This standard will be applied using a modified retrospective approach, with a cumulative effect adjustment recorded to opening retained earnings as of the beginning of all prior periods presented.

c. Leases.

In February 2016, the FASB issued authoritative guidance within the Codification's Leases topic that provides guidance on the classification, recognition, measurement, and disclosure of leases. The new leasing standard establishes that a lease conveys the right to control the use of identified property, plant, or equipment for a period of time in exchange for consideration. Under the new guidance, lessees will be required to recognize all leases with terms greater than one year, including operating leases, on the consolidated balance sheet by recording a right-of-use asset and lease liability. Prior to the authoritative guidance, only capital leases were recognized on the balance sheet by lessees. The new accounting guidance as applied by lessors is materially consistent from that applied under current GAAP.

Management has begun utilizing a bottoms-up approach to analyze the impact of the standard on our lease portfolio. MGE Energy and MGE have been reviewing current accounting policies and procedures to identify potential differences in accounting treatment that would result from applying the requirements of the new standard to our existing lease portfolio. In addition, we are identifying appropriate changes to our business processes, systems, and controls to support recognition and disclosure requirements under the new standard. This authoritative guidance will become effective January 1, 2019, with early adoption permitted. MGE Energy and MGE anticipate adopting the standard upon the effective date. The new leasing standard requires entities to recognize and measure leases at the beginning of the earliest comparative period presented using a modified retrospective approach. MGE Energy and MGE are currently assessing the impact this pronouncement will have on our financial statements.

d. Restricted Cash.

In November 2016, the FASB issued authoritative guidance within the Codification's Statement of Cash Flows topic that provides guidance on the classification and presentation of changes in restricted cash within the statement of cash flows. The new standard was issued to eliminate a current diversity in practice for the accounting treatment of restricted cash. Under the new guidance, reporting entities will be required to explain the changes in the total of restricted and unrestricted cash and cash equivalents when reconciling the beginning and ending balances on the statement of cash flows. Prior to the authoritative guidance, changes in restricted cash were presented as either cash flows from operating, investing, or financing activities within the statement of cash flows, as appropriate based on the nature of the restriction. Also under the new standard, reporting entities will be required to provide a reconciliation from the balance sheet to the statement of cash flows and disclose the nature of the restrictions of cash. This authoritative guidance will become effective January 1, 2018. Upon the effective date, MGE Energy and MGE will change the presentation of restricted cash to reflect this change in accounting guidance. MGE Energy and MGE will also retrospectively apply the guidance to all prior periods presented. As of March 31, 2017, and December 31, 2016, MGE Energy and MGE had $4.3 million and $5.1 million, respectively, of restricted cash classified within other current assets on the consolidated balance sheets.

e.Pension and Other Postretirement Benefits.

In March 2017, the FASB issued authoritative guidance within the Compensation – Retirement Benefits topic that provides guidance on the presentation of net periodic pension cost and net periodic postretirement benefit cost. Under the new guidance, the service cost component of net benefit costis required to be recorded in the same line item or items as other compensation costs arising from services rendered by the pertinent employees during the period. The other components of net benefit cost are required to be presented in the income statement separately from the service cost component and outside of income from operations. The standard also only allows the service cost component to be eligible for capitalization when applicable.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.

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Segment Information

3 Months Ended

Mar. 31, 2017

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 2016 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, 2017
Operating revenues	$	98,324	$	58,426	$	73	$	-	$	-	$	-	$	156,823
Interdepartmental revenues		(105)		4,394		11,070		-		-		(15,359)		-
Total operating revenues		98,219		62,820		11,143		-		-		(15,359)		156,823
Depreciation and amortization		(8,900)		(2,213)		(1,846)		-		-		-		(12,959)
Other operating expenses		(75,326)		(50,577)		(41)		-		(369)		15,359		(110,954)
Operating income (loss)		13,993		10,030		9,256		-		(369)		-		32,910
Other income (deductions), net		190		5		-		2,478		(222)		-		2,451
Interest (expense) income, net		(2,776)		(799)		(1,407)		-		88		-		(4,894)
Income (loss) before taxes		11,407		9,236		7,849		2,478		(503)		-		30,467
Income tax (provision) benefit		(3,454)		(3,704)		(3,151)		(997)		139		-		(11,167)
Net income (loss)	$	7,953	$	5,532	$	4,698	$	1,481	$	(364)	$	-	$	19,300
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 income (deductions), 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

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

(In thousands)MGE		Electric		Gas		Non-regulated Energy		Transmission Investment(b)		Consolidation/ Elimination Entries		Consolidated Total
Three Months Ended March 31, 2017
Operating revenues	$	98,328	$	58,435	$	73	$	-	$	-	$	156,836
Interdepartmental revenues		(109)		4,385		11,070		-		(15,346)		-
Total operating revenues		98,219		62,820		11,143		-		(15,346)		156,836
Depreciation and amortization		(8,900)		(2,213)		(1,846)		-		-		(12,959)
Other operating expenses(a)		(78,746)		(54,271)		(3,192)		-		15,346		(120,863)
Operating income(a)		10,573		6,336		6,105		-		-		23,014
Other income (deductions), net(a)		156		(5)		-		-		-		151
Interest expense, net		(2,776)		(799)		(1,407)		-		-		(4,982)
Net income		7,953		5,532		4,698		-		-		18,183
Less: Net income attributable to
noncontrolling interest, net of tax		-		-		-		-		(5,389)		(5,389)
Net income attributable to MGE	$	7,953	$	5,532	$	4,698	$	-	$	(5,389)	$	12,794
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(a)		(77,879)		(51,091)		(3,287)		(1)		16,514		(115,744)
Operating income (loss)(a)		8,622		5,862		6,296		(1)		-		20,779
Other income (deductions), net(a)		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
(a) Amounts are shown net of the related tax expense, consistent with the presentation on the MGE Consolidated Statements of Income.
(b) As of July 31, 2016, MGE no longer consolidates MGE Energy's proportionate share of equity earnings in MGE Transco.
See Footnote 3 for additional information.

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Significant Accounting Policies (Policies)

3 Months Ended

Mar. 31, 2017

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 and ATC Holdco

MGE Transco and MGEE Transco have accounted for their investment in ATC and ATC Holdco, respectively, under the equity method of accounting.

Share-based Compensation

Under MGE Energy'sDirector Incentive Plan and Performance Unit Plan, non-employee directorsand 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 January 2017, 4,032units were granted under the Director Incentive Plan and are subject to a three-year graded vesting schedule. In March 2017, 14,704 units were granted under the Performance Unit Plan and are subject to a five-year graded vesting schedule. On the grant date, MGE Energy and MGE measure the cost of the director or 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 31,2017, 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 under the Performance Unit Plan, 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.

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 in the following year and is then reflected 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.

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, the derivatives are recognizedin the consolidated balance sheets at fair value. MGE's financial 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, instruments are netted with the same counterparty under a master netting agreement as well as the netting of collateral.

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 31,2017, and December 31, 2016, 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 oflong-term debt is based on quoted market prices for similar financial instruments at March 31,2017, and December 31, 2016. 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 9) was valued using an internally-developed pricing model and therefore is classified as Level 3. The model projects future market energy prices and compares those prices to the projected power costs to be incurred under the contract. Inputs to the model require significant management judgment and estimation. Future energy prices are based on a forward power pricing curve using exchange-traded contracts in the electric futures market, where such exchange-traded contracts exist, and upon calculations based on forward gas prices, where such exchange-traded contracts do not exist. A basis adjustment is applied to the market energy price to reflect the price differential between the market price delivery point and the counterparty delivery point. The historical relationship between the delivery points is reviewed and a discount (below 100%) or premium (above 100%) is derived. This comparison is done for both peak times when demand is high and off peak times when demand is low. If the basis adjustment is lowered, the fair value measurement will decrease, and if the basis adjustment is increased, the fair value measurement will increase.

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

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

	Model Input
Significant Unobservable Inputs	March 31, 2017	December 31, 2016
Basis adjustment:
On peak	92.2%	91.9%
Off peak	94.0%	93.4%
Counterparty fuel mix:
Internal generation	55% - 75%	55% - 75%
Purchased power	45% - 25%	45% - 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. 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

Adoption of Accounting Principles and Recently Issued 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. The new standard establishes a five step model for recognizing and measuring revenue from contracts with customers and replaces existing guidance on revenue recognition. The objective of the new standard is to provide a single, comprehensive revenue recognition model for all contracts with customers to improve comparability within industries, across industries and across capital markets. The underlying principle is that an entity will recognize revenue to depict the transfer of goods or services to customers at an amount that the entity expects to be entitled to in exchange for those goods or services.

MGE Energy and MGE have been assessing the impact of this guidance on revenue streams within the scope of the new standard. All retail electric and gas revenues are tariff rates approved by the PSCW. Based on our evaluation of the new standard, retail revenues will be recognized within the period in which utility service is provided to the customer and the performance obligation is fulfilled, consistent with our current revenue recognition model. Electric revenues for sales to the market represent wholesale sales made to third parties who are not ultimate users of the electricity. These sales may also include bilateral sales to other utilities or power marketers. Revenues for sales to the market will be recognized when the sale is completed within the market operated by MISO, similar to the recognition under our current revenue recognition model. In addition, revenues from the transportation of gas will continue to be recognized upon the performance of services for the respective customer. Based on our assessment of the new standard, revenue recognition for retail revenues, sales to the market, and transportation of gas will be consistent with our current revenue recognition model. However, additional disclosures regarding the nature, amount, timing, and uncertainty of these revenue streams and related cash flows arising from contracts with customers will be required as a result of the new standard.

The Power and Utilities Task Force of the AICPA is formulating a utility industry-specific interpretation of the guidance regarding the collectability threshold of probable within the new standard. The collectability criterion could impact the timing of revenue recognition for uncollectible accounts. Management continues to analyze newly-released interpretative guidance and assess the related impacts to the current revenue recognition model.

This authoritative guidance will become effective January 1, 2018, and MGE Energy and MGE anticipate adopting the standard upon the effective date. Adoption of this standard is permitted under one of two methods: the full retrospective method or the modified retrospective method. MGE Energy and MGE are continuing to assess the permitted implementation methods and the impact on our financial statements.

b. 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, and will require equity investments to be measured at fair value with changes in fair value recognized in net income rather than in other comprehensive income. As a result of this guidance, MGE Energy and MGE will no longer have any other comprehensive income related to equity investments. This standard will be applied using a modified retrospective approach, with a cumulative effect adjustment recorded to opening retained earnings as of the beginning of all prior periods presented.

c. Leases.

In February 2016, the FASB issued authoritative guidance within the Codification's Leases topic that provides guidance on the classification, recognition, measurement, and disclosure of leases. The new leasing standard establishes that a lease conveys the right to control the use of identified property, plant, or equipment for a period of time in exchange for consideration. Under the new guidance, lessees will be required to recognize all leases with terms greater than one year, including operating leases, on the consolidated balance sheet by recording a right-of-use asset and lease liability. Prior to the authoritative guidance, only capital leases were recognized on the balance sheet by lessees. The new accounting guidance as applied by lessors is materially consistent from that applied under current GAAP.

Management has begun utilizing a bottoms-up approach to analyze the impact of the standard on our lease portfolio. MGE Energy and MGE have been reviewing current accounting policies and procedures to identify potential differences in accounting treatment that would result from applying the requirements of the new standard to our existing lease portfolio. In addition, we are identifying appropriate changes to our business processes, systems, and controls to support recognition and disclosure requirements under the new standard. This authoritative guidance will become effective January 1, 2019, with early adoption permitted. MGE Energy and MGE anticipate adopting the standard upon the effective date. The new leasing standard requires entities to recognize and measure leases at the beginning of the earliest comparative period presented using a modified retrospective approach. MGE Energy and MGE are currently assessing the impact this pronouncement will have on our financial statements.

d. Restricted Cash.

In November 2016, the FASB issued authoritative guidance within the Codification's Statement of Cash Flows topic that provides guidance on the classification and presentation of changes in restricted cash within the statement of cash flows. The new standard was issued to eliminate a current diversity in practice for the accounting treatment of restricted cash. Under the new guidance, reporting entities will be required to explain the changes in the total of restricted and unrestricted cash and cash equivalents when reconciling the beginning and ending balances on the statement of cash flows. Prior to the authoritative guidance, changes in restricted cash were presented as either cash flows from operating, investing, or financing activities within the statement of cash flows, as appropriate based on the nature of the restriction. Also under the new standard, reporting entities will be required to provide a reconciliation from the balance sheet to the statement of cash flows and disclose the nature of the restrictions of cash. This authoritative guidance will become effective January 1, 2018. Upon the effective date, MGE Energy and MGE will change the presentation of restricted cash to reflect this change in accounting guidance. MGE Energy and MGE will also retrospectively apply the guidance to all prior periods presented. As of March 31, 2017, and December 31, 2016, MGE Energy and MGE had $4.3 million and $5.1 million, respectively, of restricted cash classified within other current assets on the consolidated balance sheets.

e.Pension and Other Postretirement Benefits.

In March 2017, the FASB issued authoritative guidance within the Compensation – Retirement Benefits topic that provides guidance on the presentation of net periodic pension cost and net periodic postretirement benefit cost. Under the new guidance, the service cost component of net benefit costis required to be recorded in the same line item or items as other compensation costs arising from services rendered by the pertinent employees during the period. The other components of net benefit cost are required to be presented in the income statement separately from the service cost component and outside of income from operations. The standard also only allows the service cost component to be eligible for capitalization when applicable.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.

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Investment in ATC and ATC Holdco (Tables)

3 Months Ended

Mar. 31, 2017

Equity Method Investments and Joint Ventures [Abstract]

Equity Method Investments Financial Data

MGE Transco and MGEE Transco have accounted for their investment in ATC and ATC Holdco, respectively, under the equity method of accounting.Equity earnings from investments are recorded as "Other income" on MGE Energy's consolidated statements of income. For the three months endedMarch 31,2017 and 2016, MGE Transco recorded the following:

		Three Months Ended
		March 31,
(In thousands)		2017		2016
Equity earnings from investment in ATC	$	2,608	$	2,233
Dividends from ATC(a)		-		865
Capital contributions to ATC		1,420		533

(a)As of December 31, 2016, MGE Transco recorded a $2.1 million receivable from ATC for a cash dividend received in January 2017.

ATC's summarized financial data for the three months endedMarch 31,2017 and 2016, is as follows:

		Three Months Ended
		March 31,
(In thousands)		2017		2016
Operating revenues	$	174,669	$	164,240
Operating expenses		(82,388)		(79,065)
Other income, net		207		127
Interest expense, net		(26,616)		(24,208)
Earnings before members' income taxes	$	65,872	$	61,094

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Pension and Other Postretirement Plans (Tables)

3 Months Ended

Mar. 31, 2017

Compensation and Retirement Disclosure [Abstract]

Schedule of Net Periodic Benefit Costs

The following table presents the components of net periodic benefit costs recognized for the three months endedMarch 31,2017 and 2016. A portion of the net periodic benefit cost is capitalized within the consolidated balance sheets.

		Three Months Ended
		March 31,
(In thousands)		2017		2016
Pension Benefits
Components of net periodic benefit cost:
Service cost	$	1,332	$	1,381
Interest cost		3,119		3,089
Expected return on assets		(5,742)		(5,593)
Amortization of:
Prior service (credit) cost		(4)		2
Actuarial loss		1,464		1,356
Net periodic benefit cost	$	169	$	235
Postretirement Benefits
Components of net periodic benefit cost:
Service cost	$	206	$	324
Interest cost		444		674
Expected return on assets		(472)		(705)
Amortization of:
Transition obligation		-		1
Prior service credit		(436)		(667)
Actuarial loss		129		159
Net periodic benefit (credit) cost	$	(129)	$	(214)

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Derivative and Hedging Instruments (Tables)

3 Months Ended

Mar. 31, 2017

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, 2017	December 31, 2016
Commodity derivative contracts	415,165 MWh	393,395 MWh
Commodity derivative contracts	1,677,500 Dth	4,195,000 Dth
FTRs	920 MW	2,251 MW
PPA	3,100 MW	3,250 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, instruments are netted with the same counterparty under a master netting agreement as well as the netting of collateral. As of March 31,2017 and December 31, 2016, thereceivable – margin account balance of $0.6million and $1.3 million, respectively, is shown net of any collateral posted against derivative positions.

		Derivative Assets		Derivative Liabilities
(In thousands)					Balance Sheet Location
March 31, 2017
Commodity derivative contracts(a)	$	640	$	165	Other current assets(b)
Commodity derivative contracts(a)		24		87	Other deferred charges
FTRs		155		-	Other current assets
PPA		N/A		8,210	Derivative liability (current)
PPA		N/A		40,430	Derivative liability (long-term)
December 31, 2016
Commodity derivative contracts(a)	$	1,227	$	164	Other current assets
Commodity derivative contracts(a)		157		54	Other deferred charges
FTRs		143		-	Other current assets
PPA		N/A		7,620	Derivative liability (current)
PPA		N/A		42,970	Derivative liability (long-term)

(a)As of March 31,2017, and December 31, 2016, no collateral was posted against and netted with derivative liability positions on the consolidated balance sheets.

(b)As of March 31,2017, $0.1 million was presented as current derivative liabilities on the consolidated balance sheets.

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 Sheets
March 31, 2017
Commodity derivative contracts	$	664	$	(203)	$	-	$	461
FTRs		155		-		-		155
December 31, 2016
Commodity derivative contracts	$	1,384	$	(218)	$	-	$	1,166
FTRs		143		-		-		143

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, 2017
Commodity derivative contracts	$	252	$	(203)	$	-	$	49
PPA		48,640		-		-		48,640
December 31, 2016
Commodity derivative contracts	$	218	$	(218)	$	-	$	-
PPA		50,590		-		-		50,590

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 31,2017 and 2016, and the consolidated income statements for the three months endedMarch 31,2017 and 2016.

		2017				2016
(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,	$	49,281	$	230	$	54,082	$	1,208
Unrealized (gain) loss		(689)		-		6,371		-
Realized (loss) gain reclassified to a deferred account		(78)		78		(1,451)		1,451
Realized loss reclassified to income statement		(441)		(166)		(2,118)		(2,004)
Balance at March 31,	$	48,073	$	142	$	56,884	$	655

Derivative Gains and Losses in Income Statement

		Realized losses (gains)
		2017				2016
(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	$	385	$	146	$	1,007	$	1,814
FTRs		(685)		-		(68)		-
PPA		761		-		1,369		-

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Fair Value of Financial Instruments (Tables)

3 Months Ended

Mar. 31, 2017

Fair Value Disclosures [Abstract]

Estimated Fair Market Value of Financial Instruments

The estimated fair market values of financial instruments are as follows:

		March 31, 2017				December 31, 2016
(In thousands)		Carrying Amount		Fair Value		Carrying Amount		Fair Value
MGE Energy
Assets:
Cash and cash equivalents	$	117,702	$	117,702	$	95,959	$	95,959
Liabilities:
Long-term debt(a)		400,161		445,037		391,242		430,122
MGE
Assets:
Cash and cash equivalents	$	23,098	$	23,098	$	10,768	$	10,768
Liabilities:
Long-term debt(a)		400,161		445,037		391,242		430,122
(a) Includes long-term debt due within one year. Excludes debt issuance costs and unamortized discount of
$4.3 million and $4.1 million at March 31, 2017, and December 31, 2016, respectively.

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.

		Fair Value as of March 31, 2017
(In thousands)		Total		Level 1		Level 2		Level 3
MGE Energy
Assets:
Derivatives	$	819	$	341	$	-	$	478
Exchange-traded investments		662		662		-		-
Total Assets	$	1,481	$	1,003	$	-	$	478
Liabilities:
Derivatives	$	48,892	$	60	$	-	$	48,832
Deferred compensation		3,014		-		3,014		-
Total Liabilities	$	51,906	$	60	$	3,014	$	48,832
MGE
Assets:
Derivatives	$	819	$	341	$	-	$	478
Exchange-traded investments		132		132		-		-
Total Assets	$	951	$	473	$	-	$	478
Liabilities:
Derivatives	$	48,892	$	60	$	-	$	48,832
Deferred compensation		3,014		-		3,014		-
Total Liabilities	$	51,906	$	60	$	3,014	$	48,832

		Fair Value as of December 31, 2016
(In thousands)		Total		Level 1		Level 2		Level 3
MGE Energy
Assets:
Derivatives	$	1,527	$	1,041	$	-	$	486
Exchange-traded investments		500		500		-		-
Total Assets	$	2,027	$	1,541	$	-	$	486
Liabilities:
Derivatives	$	50,808	$	16	$	-	$	50,792
Deferred compensation		3,039		-		3,039		-
Total Liabilities	$	53,847	$	16	$	3,039	$	50,792
MGE
Assets:
Derivatives	$	1,527	$	1,041	$	-	$	486
Exchange-traded investments		143		143		-		-
Total Assets	$	1,670	$	1,184	$	-	$	486
Liabilities:
Derivatives	$	50,808	$	16	$	-	$	50,792
Deferred compensation		3,039		-		3,039		-
Total Liabilities	$	53,847	$	16	$	3,039	$	50,792

Significant Unobservable Inputs

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

	Model Input
Significant Unobservable Inputs	March 31, 2017	December 31, 2016
Basis adjustment:
On peak	92.2%	91.9%
Off peak	94.0%	93.4%
Counterparty fuel mix:
Internal generation	55% - 75%	55% - 75%
Purchased power	45% - 25%	45% - 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 commodity derivative assets and liabilities measured at fair value on a recurring basis.

		Three Months Ended
		March 31,
(In thousands)		2017		2016
Beginning balance	$	(50,306)	$	(53,501)
Realized and unrealized gains (losses):
Included in regulatory (assets) liabilities		1,953		(3,600)
Included in other comprehensive income		-		-
Included in earnings		(586)		(2,163)
Included in current assets		125		-
Purchases		5,996		5,301
Sales		-		-
Issuances		-		-
Settlements		(5,536)		(3,138)
Transfers in and/or out of Level 3		-		-
Balance as of March 31,	$	(48,354)	$	(57,101)
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 (b).

		Three Months Ended
		March 31,
(In thousands)		2017		2016
Purchased Power Expense	$	(431)	$	(2,163)
Cost of Gas Sold Expense		(155)		-
Total	$	(586)	$	(2,163)

(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, 2017

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, 2017
Operating revenues	$	98,324	$	58,426	$	73	$	-	$	-	$	-	$	156,823
Interdepartmental revenues		(105)		4,394		11,070		-		-		(15,359)		-
Total operating revenues		98,219		62,820		11,143		-		-		(15,359)		156,823
Depreciation and amortization		(8,900)		(2,213)		(1,846)		-		-		-		(12,959)
Other operating expenses		(75,326)		(50,577)		(41)		-		(369)		15,359		(110,954)
Operating income (loss)		13,993		10,030		9,256		-		(369)		-		32,910
Other income (deductions), net		190		5		-		2,478		(222)		-		2,451
Interest (expense) income, net		(2,776)		(799)		(1,407)		-		88		-		(4,894)
Income (loss) before taxes		11,407		9,236		7,849		2,478		(503)		-		30,467
Income tax (provision) benefit		(3,454)		(3,704)		(3,151)		(997)		139		-		(11,167)
Net income (loss)	$	7,953	$	5,532	$	4,698	$	1,481	$	(364)	$	-	$	19,300
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 income (deductions), 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

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

(In thousands)MGE		Electric		Gas		Non-regulated Energy		Transmission Investment(b)		Consolidation/ Elimination Entries		Consolidated Total
Three Months Ended March 31, 2017
Operating revenues	$	98,328	$	58,435	$	73	$	-	$	-	$	156,836
Interdepartmental revenues		(109)		4,385		11,070		-		(15,346)		-
Total operating revenues		98,219		62,820		11,143		-		(15,346)		156,836
Depreciation and amortization		(8,900)		(2,213)		(1,846)		-		-		(12,959)
Other operating expenses(a)		(78,746)		(54,271)		(3,192)		-		15,346		(120,863)
Operating income(a)		10,573		6,336		6,105		-		-		23,014
Other income (deductions), net(a)		156		(5)		-		-		-		151
Interest expense, net		(2,776)		(799)		(1,407)		-		-		(4,982)
Net income		7,953		5,532		4,698		-		-		18,183
Less: Net income attributable to
noncontrolling interest, net of tax		-		-		-		-		(5,389)		(5,389)
Net income attributable to MGE	$	7,953	$	5,532	$	4,698	$	-	$	(5,389)	$	12,794
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(a)		(77,879)		(51,091)		(3,287)		(1)		16,514		(115,744)
Operating income (loss)(a)		8,622		5,862		6,296		(1)		-		20,779
Other income (deductions), net(a)		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
(a) Amounts are shown net of the related tax expense, consistent with the presentation on the MGE Consolidated Statements of Income.
(b) As of July 31, 2016, MGE no longer consolidates MGE Energy's proportionate share of equity earnings in MGE Transco.
See Footnote 3 for additional information.

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Equity and Financing Arrangements (Details) - USD ($)		3 Months Ended
	Jan. 13, 2017	Mar. 31, 2017	Mar. 31, 2016
Common Stock [Abstract]
Common stock issued during period		0	0
Dilutive Shares Calculation [Abstract]
Dilutive securities		$ 0
Medium-Term Notes, 5.26% due 2017
Debt Instrument [Line Items]
Long-term debt, gross	$ 30,000,000
Senior Notes, 3.76% due 2052
Debt Instrument [Line Items]
Long-term debt, gross	$ 40,000,000
Interest rate	3.76%
Term	35 years

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Investment in ATC and ATC Holdco (Details-1) - USD ($) $ in Thousands		3 Months Ended
	Dec. 01, 2016	Mar. 31, 2017		Mar. 31, 2016	Dec. 31, 2016
Schedule Of Equity Method Investments [Line Items]
Equity earnings from investment in ATC		$ 2,608		$ 2,233
Dividends from ATC		2,072		865
Capital contributions to ATC		2,939		671
MGE Transco [Member] | ATC [Member]
Schedule Of Equity Method Investments [Line Items]
Equity earnings from investment in ATC		2,608		2,233
Dividends from ATC		0	[1]	865
Capital contributions to ATC		$ 1,420		533
Ownership interest in equity-method investee		3.60%			3.60%
Dividend receivable from ATC					$ 2,100
MGE [Member]
Schedule Of Equity Method Investments [Line Items]
Equity earnings from investment in ATC		$ 0		2,233
Dividends from ATC		0		865
Capital contributions to ATC		$ 0		$ 533
Dividend in kind to parent	$ 15,800
MGEE Transco [Member] | ATC Holdco [Member]
Schedule Of Equity Method Investments [Line Items]
Ownership interest in equity-method investee		4.00%			4.00%
MGE Energy [Member]
Schedule Of Equity Method Investments [Line Items]
Dividend in kind to parent	$ (15,800)

[1] As of December 31, 2016, MGE Transco recorded a $2.1 million receivable from ATC for a cash dividend received in January 2017.

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Investment in ATC and ATC Holdco (Details-2) - USD ($) $ in Thousands	3 Months Ended
	Mar. 31, 2017	Mar. 31, 2016	Dec. 31, 2016
ATC [Member]
Schedule Of Equity Method Investments [Line Items]
Operating revenues	$ 174,669	$ 164,240
Operating expenses	(82,388)	(79,065)
Other income, net	207	127
Interest expense, net	(26,616)	(24,208)
Earnings before members' income taxes	65,872	61,094
ATC [Member]
Related Party Transaction [Line Items]
Related party expenses	9,200	$ 9,700
Due from related parties	$ 100		$ 100

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Taxes (Details)	3 Months Ended
	Mar. 31, 2017	Mar. 31, 2016
Income Tax Disclosure [Line Items]
Effective income tax rate	36.70%	36.90%
MGE [Member]
Income Tax Disclosure [Line Items]
Effective income tax rate	36.20%	36.80%

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Pension and Other Postretirement Plans (Details) - USD ($) $ in Thousands	3 Months Ended
	Mar. 31, 2017	Mar. 31, 2016
Pension Benefits [Member]
Components of net periodic benefit cost:
Service cost	$ 1,332	$ 1,381
Interest cost	3,119	3,089
Expected return on assets	(5,742)	(5,593)
Amortization of:
Prior service cost (credit)	(4)	2
Actuarial loss	1,464	1,356
Net periodic benefit cost (credit)	169	235
Postretirement Benefits [Member]
Components of net periodic benefit cost:
Service cost	206	324
Interest cost	444	674
Expected return on assets	(472)	(705)
Amortization of:
Transition obligation	0	1
Prior service cost (credit)	(436)	(667)
Actuarial loss	129	159
Net periodic benefit cost (credit)	$ (129)	$ (214)

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Share Based Compensation (Details) - Performance Units [Member] - USD ($) $ in Millions	1 Months Ended		3 Months Ended
	Mar. 31, 2017	Jan. 31, 2017	Mar. 31, 2017	Mar. 31, 2016
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Compensation expense			$ 0.5	$ 1.3
Cash payments distributed related to awards previously granted and now payable		$ 2.0
Awards forfeited during period, value			$ 0.0	$ 0.0
Awards forfeited during period, units			0	0
Outstanding awards vested during period			$ 5.4
Director Incentive Agreement [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Awards granted during period (in units)		4,032
Award vesting period			3 years
Performance Unit Plan [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Awards granted during period (in units)	14,704
Award vesting period			5 years

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Rate Matters (Details) - PSCW [Member] - MGE [Member] - USD ($)	1 Months Ended	3 Months Ended	4 Months Ended	12 Months Ended
	Sep. 30, 2016	Mar. 31, 2017	Dec. 31, 2015	Dec. 31, 2016	Jul. 31, 2016	Mar. 31, 2016	Jan. 31, 2016	Aug. 31, 2015
Rate Proceedings [Abstract]
Authorized return on equity, percentage		9.80%
Approved equity capital structure, percentage		57.20%
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%
Deferred fuel rules monitored costs		$ 1,100,000				$ 0
Electric Fuel Monitored Costs, 2016 [Member]
Fuel Rules [Abstract]
Change in fuel rules monitored costs							$ (14,800,000)
Fuel Rules Credit ($0.00256/kWh), 2015/2016 [Member]
Fuel Rules [Abstract]
Electric fuel credit (per kWh)			$ 0.00256	$ 0.00256
Electric fuel credit ($)								$ 10,900,000
Return of electric fuel credit, total			$ 2,600,000	$ 8,300,000
Fuel Rules Refund, 2015/2016 [Member] | Electric Fuel Monitored Costs, 2016 [Member]
Fuel Rules [Abstract]
Electric fuel credit ($)					$ 15,700,000
Return of electric fuel credit, total	$ 15,500,000
Electric Rate Proceeding [Member]
Rate Proceedings [Abstract]
Authorized rate increase (decrease), percentage		(0.80%)		0.00%
Authorized rate increase (decrease), amount		$ (3,300,000)		$ 0
Gas Rate Proceeding [Member]
Rate Proceedings [Abstract]
Authorized rate increase (decrease), percentage		1.90%		0.00%
Authorized rate increase (decrease), amount		$ 3,100,000		$ 0

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Derivative and Hedging Instruments (Details-1) $ in Thousands		3 Months Ended		12 Months Ended
		Mar. 31, 2017 USD ($) Dth MWh MW		Dec. 31, 2016 USD ($) Dth MWh MW	Mar. 31, 2016 USD ($)	Dec. 31, 2015 USD ($)
Derivative fair values [Abstract]
Derivative, right to reclaim collateral (receivable)		$ 0		$ 0
Receivable, margin account balance, net of collateral posted against derivative positions		600		1,300
Other Current Assets [Member]
Derivative fair values [Abstract]
Derivative fair value, net		142		230	$ 655	$ 1,208
Commodity Contracts And Financial Transimission Rights [Member]
Derivative fair values [Abstract]
Derivative fair value, net		$ 600		$ 1,300
Commodity Derivative Contracts [Member]
Gross Notional Volume of Open Derivatives
Notional amount, energy measure (in MWh) | MWh		415,165		393,395
Notional amount, decatherm measure (in Dth) | Dth		1,677,500		4,195,000
Derivative fair values [Abstract]
Asset Derivatives, fair value, gross basis		$ 664		$ 1,384
Liability Derivatives, fair value, gross basis		252		218
Commodity Derivative Contracts [Member] | Other Current Assets [Member]
Derivative fair values [Abstract]
Asset Derivatives, fair value, gross basis	[1]	640		1,227
Liability Derivatives, fair value, gross basis	[1]	165	[2]	164
Commodity Derivative Contracts [Member] | Other Deferred Charges [Member]
Derivative fair values [Abstract]
Asset Derivatives, fair value, gross basis	[1]	24		157
Liability Derivatives, fair value, gross basis	[1]	87		$ 54
Commodity Derivative Contracts [Member] | Derivative Liability (Current) [Member]
Derivative fair values [Abstract]
Liability Derivatives, fair value, gross basis		$ 100
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		920		2,251
Derivative fair values [Abstract]
Asset Derivatives, fair value, gross basis		$ 155		$ 143
Financial Transmission Rights [Member] | Other Current Assets [Member]
Derivative fair values [Abstract]
Asset Derivatives, fair value, gross basis		155		143
Liability Derivatives, fair value, gross basis		$ 0		$ 0
PPA [Member]
Gross Notional Volume of Open Derivatives
Notional amount, power measure (in MW) | MW		3,100		3,250
Derivative fair values [Abstract]
Derivative fair value, net		$ (48,600)		$ (50,600)
Liability Derivatives, fair value, gross basis		48,640		50,590
PPA [Member] | Derivative Liability (Current) [Member]
Derivative fair values [Abstract]
Liability Derivatives, fair value, gross basis		8,210		7,620
PPA [Member] | Derivative Liability (Long-term) [Member]
Derivative fair values [Abstract]
Liability Derivatives, fair value, gross basis		$ 40,430		$ 42,970

[1] As of March 31, 2017 , and December 31, 2016 , no collateral was posted against and netted with derivative liability positions on the consolidated balance sheets.

[2] As of March 31, 2017 , $0.1 million was presented as current derivative liabilities on the consolidated balance sheets.

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Derivative and Hedging Instruments (Details-2) - USD ($) $ in Thousands	Mar. 31, 2017	Dec. 31, 2016
Commodity Derivative Contracts [Member]
Offsetting Assets [Line Items]
Gross amounts	$ 664	$ 1,384
Gross amounts offset in balance sheet	(203)	(218)
Collateral posted against derivative positions	0	0
Net amount presented in balance sheet	461	1,166
Financial Transmission Rights [Member]
Offsetting Assets [Line Items]
Gross amounts	155	143
Gross amounts offset in balance sheet	0	0
Collateral posted against derivative positions	0	0
Net amount presented in balance sheet	$ 155	$ 143

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Derivative and Hedging Instruments (Details-3) - USD ($) $ in Thousands	Mar. 31, 2017	Dec. 31, 2016
Commodity Derivative Contracts [Member]
Offsetting Liabilities [Line Items]
Gross amounts	$ 252	$ 218
Gross amounts offset in balance sheet	(203)	(218)
Collateral posted against derivative positions	0	0
Net amount presented in balance sheet	49	0
Purchased Power Agreement [Member]
Offsetting Liabilities [Line Items]
Gross amounts	48,640	50,590
Gross amounts offset in balance sheet	0	0
Collateral posted against derivative positions	0	0
Net amount presented in balance sheet	$ 48,640	$ 50,590

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Derivative and Hedging Instruments (Details-4) - USD ($) $ in Thousands	3 Months Ended
	Mar. 31, 2017	Mar. 31, 2016
Current and Long-Term Regulatory Asset [Member]
Change In Derivative Fair Value [Roll Forward]
Beginning balance,	$ 49,281	$ 54,082
Unrealized (gain) loss	(689)	6,371
Realized (loss) gain reclassified to a deferred account	(78)	(1,451)
Realized loss reclassified to income statement	(441)	(2,118)
Ending balance,	48,073	56,884
Other Current Assets [Member]
Change In Derivative Fair Value [Roll Forward]
Beginning balance,	230	1,208
Unrealized (gain) loss	0	0
Realized (loss) gain reclassified to a deferred account	78	1,451
Realized loss reclassified to income statement	(166)	(2,004)
Ending balance,	$ 142	$ 655

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Derivative and Hedging Instruments (Details-5) $ in Thousands	3 Months Ended
	Mar. 31, 2017 USD ($) counterparty	Mar. 31, 2016 USD ($)	Dec. 31, 2016 USD ($)
Counterparties in net liability position or default [Abstract]
Derivative, net liability position of counterparties (less than $0.1 million)	$ 100		$ 0
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	$ 385	$ 1,007
Commodity Derivative Contracts [Member] | Cost Of Gas Sold Expense [Member]
Realized losses (gains) on income statement [Line Items]
Realized losses (gains) on income statement	146	1,814
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	(685)	(68)
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	761	1,369
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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Fair Value of Financial Instruments (Details-1) - USD ($) $ in Thousands		Mar. 31, 2017	Dec. 31, 2016
Fair Value Measurement [Domain]
Liabilities:
Unamortized discount and debt issuance costs, net		$ 4,300	$ 4,100
Carrying Amount [Member]
Assets:
Cash and cash equivalents		117,702	95,959
Liabilities:
Long-term debt	[1]	400,161	391,242
Fair Value [Member]
Assets:
Cash and cash equivalents		117,702	95,959
Liabilities:
Long-term debt	[1]	445,037	430,122
MGE [Member] | Fair Value Measurement [Domain]
Liabilities:
Unamortized discount and debt issuance costs, net		4,300	4,100
MGE [Member] | Carrying Amount [Member]
Assets:
Cash and cash equivalents		23,098	10,768
Liabilities:
Long-term debt	[1]	400,161	391,242
MGE [Member] | Fair Value [Member]
Assets:
Cash and cash equivalents		23,098	10,768
Liabilities:
Long-term debt	[1]	$ 445,037	$ 430,122

[1] Includes long-term debt due within one year. Excludes debt issuance costs and unamortized discount of $4.3 million and $4.1 million at March 31, 2017, and December 31, 2016, respectively.

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Fair Value of Financial Instruments (Details-2) - Recurring [Member] - USD ($) $ in Thousands	Mar. 31, 2017	Dec. 31, 2016
Assets:
Derivatives	$ 819	$ 1,527
Total Assets	1,481	2,027
Liabilities:
Derivatives	48,892	50,808
Deferred compensation	3,014	3,039
Total liabilities	51,906	53,847
Exchange Traded [Member]
Assets:
Available-for-sale securities	662	500
Level 1 [Member]
Assets:
Derivatives	341	1,041
Total Assets	1,003	1,541
Liabilities:
Derivatives	60	16
Deferred compensation	0	0
Total liabilities	60	16
Level 1 [Member] | Exchange Traded [Member]
Assets:
Available-for-sale securities	662	500
Level 2 [Member]
Assets:
Derivatives	0	0
Total Assets	0	0
Liabilities:
Derivatives	0	0
Deferred compensation	3,014	3,039
Total liabilities	3,014	3,039
Level 2 [Member] | Exchange Traded [Member]
Assets:
Available-for-sale securities	0	0
Level 3 [Member]
Assets:
Derivatives	478	486
Total Assets	478	486
Liabilities:
Derivatives	48,832	50,792
Deferred compensation	0	0
Total liabilities	48,832	50,792
Level 3 [Member] | Exchange Traded [Member]
Assets:
Available-for-sale securities	0	0
MGE [Member]
Assets:
Derivatives	819	1,527
Total Assets	951	1,670
Liabilities:
Derivatives	48,892	50,808
Deferred compensation	3,014	3,039
Total liabilities	51,906	53,847
MGE [Member] | Exchange Traded [Member]
Assets:
Available-for-sale securities	132	143
MGE [Member] | Level 1 [Member]
Assets:
Derivatives	341	1,041
Total Assets	473	1,184
Liabilities:
Derivatives	60	16
Deferred compensation	0	0
Total liabilities	60	16
MGE [Member] | Level 1 [Member] | Exchange Traded [Member]
Assets:
Available-for-sale securities	132	143
MGE [Member] | Level 2 [Member]
Assets:
Derivatives	0	0
Total Assets	0	0
Liabilities:
Derivatives	0	0
Deferred compensation	3,014	3,039
Total liabilities	3,014	3,039
MGE [Member] | Level 2 [Member] | Exchange Traded [Member]
Assets:
Available-for-sale securities	0	0
MGE [Member] | Level 3 [Member]
Assets:
Derivatives	478	486
Total Assets	478	486
Liabilities:
Derivatives	48,832	50,792
Deferred compensation	0	0
Total liabilities	48,832	50,792
MGE [Member] | Level 3 [Member] | Exchange Traded [Member]
Assets:
Available-for-sale securities	$ 0	$ 0

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Fair Value of Financial Instruments (Details-3)	3 Months Ended	12 Months Ended
	Mar. 31, 2017	Dec. 31, 2016
Basis adjustment:
Basis adjustment - on peak	92.20%	91.90%
Basis adjustment - off peak	94.00%	93.40%
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%	55.00%
Purchased power	25.00%	25.00%
Maximum [Member]
Counterparty fuel mix:
Internal generation	75.00%	75.00%
Purchased power	45.00%	45.00%

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Fair Value of Financial Instruments (Details-4) - USD ($) $ in Thousands		3 Months Ended
		Mar. 31, 2017	Mar. 31, 2016
Fair Value, Net Derivative Asset (Liability) Measured on Recurring Basis, Unobservable Input Reconciliation [Roll Forward]
Beginning balance,		$ (50,306)	$ (53,501)
Realized and unrealized gains (losses):
Included in regulatory (assets) liabilities		1,953	(3,600)
Included in other comprehensive income		0	0
Included in earnings	[1]	(586)	(2,163)
Included in current assets		125	0
Purchases		5,996	5,301
Sales		0	0
Issuances		0	0
Settlements		(5,536)	(3,138)
Transfers in and/or out of level 3		0	0
Ending balance,		(48,354)	(57,101)
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]	(431)	(2,163)
Cost Of Gas Sold Expense [Member]
Realized and unrealized gains (losses):
Included in earnings	[1]	$ (155)	$ 0

[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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Joint Plant Ownership (Details) - USD ($) $ in Thousands	Mar. 31, 2017	Jan. 01, 2017	Dec. 31, 2016
Jointly Owned Utility Plant Interests [Line Items]
Assets held for sale	$ 2,338		$ 14,813
MGE [Member]
Jointly Owned Utility Plant Interests [Line Items]
Assets held for sale	2,338		$ 14,813
Columbia Units [Member] | MGE [Member]
Jointly Owned Utility Plant Interests [Line Items]
Jointly Owned Utility Plant, Proportionate Ownership Share		20.40%	22.00%
Assets held for sale	$ 2,300		$ 14,800

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Adoption of Accounting Principles and Recently Issued Accounting Pronouncements (Details-1) - USD ($) $ in Millions	Mar. 31, 2017	Dec. 31, 2016
Accounting Standards Update 2016-18 - Restricted Cash [Member]
Adoption of Accounting Principles and Recently Issued Accounting Pronouncements [Line Items]
Restricted cash	$ 4.3	$ 5.1

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Segment Information (Details) - USD ($) $ in Thousands		3 Months Ended
		Mar. 31, 2017	Mar. 31, 2016
Segment Reporting Information [Line Items]
Operating revenues		$ 156,823	$ 147,527
Depreciation and amortization		(12,959)	(11,032)
Other operating expenses		(110,954)	(106,964)
Operating income (loss)		32,910	29,531
Other income (deductions), net		2,451	2,442
Interest (expense) income, net		(4,894)	(5,000)
Income before income taxes		30,467	26,973
Income tax (provision) benefit		(11,167)	(9,945)
Net Income (Loss)		19,300	17,028
Electric [Member]
Segment Reporting Information [Line Items]
Operating revenues		98,324	93,208
Gas [Member]
Segment Reporting Information [Line Items]
Operating revenues		58,426	53,837
Non Regulated Energy [Member]
Segment Reporting Information [Line Items]
Operating revenues		73	482
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		156,823	147,527
Operating Segments [Member] | Electric [Member]
Segment Reporting Information [Line Items]
Operating revenues		98,219	93,664
Depreciation and amortization		(8,900)	(7,163)
Other operating expenses		(75,326)	(75,379)
Operating income (loss)		13,993	11,122
Other income (deductions), net		190	196
Interest (expense) income, net		(2,776)	(2,790)
Income before income taxes		11,407	8,528
Income tax (provision) benefit		(3,454)	(2,536)
Net Income (Loss)		7,953	5,992
Operating Segments [Member] | Gas [Member]
Segment Reporting Information [Line Items]
Operating revenues		62,820	58,934
Depreciation and amortization		(2,213)	(1,981)
Other operating expenses		(50,577)	(47,741)
Operating income (loss)		10,030	9,212
Other income (deductions), net		5	(8)
Interest (expense) income, net		(799)	(808)
Income before income taxes		9,236	8,396
Income tax (provision) benefit		(3,704)	(3,359)
Net Income (Loss)		5,532	5,037
Operating Segments [Member] | Non Regulated Energy [Member]
Segment Reporting Information [Line Items]
Operating revenues		11,143	11,459
Depreciation and amortization		(1,846)	(1,876)
Other operating expenses		(41)	(47)
Operating income (loss)		9,256	9,536
Other income (deductions), net		0	0
Interest (expense) income, net		(1,407)	(1,463)
Income before income taxes		7,849	8,073
Income tax (provision) benefit		(3,151)	(3,240)
Net Income (Loss)		4,698	4,833
Operating Segments [Member] | Transmission Investment [Member]
Segment Reporting Information [Line Items]
Operating revenues		0	0
Depreciation and amortization		0	0
Other operating expenses		0	(1)
Operating income (loss)		0	(1)
Other income (deductions), net		2,478	2,233
Interest (expense) income, net		0	0
Income before income taxes		2,478	2,232
Income tax (provision) benefit		(997)	(897)
Net Income (Loss)		1,481	1,335
Operating Segments [Member] | All Others [Member]
Segment Reporting Information [Line Items]
Operating revenues		0	0
Depreciation and amortization		0	(12)
Other operating expenses		(369)	(326)
Operating income (loss)		(369)	(338)
Other income (deductions), net		(222)	21
Interest (expense) income, net		88	61
Income before income taxes		(503)	(256)
Income tax (provision) benefit		139	87
Net Income (Loss)		(364)	(169)
Consolidation Elimination Entries [Member]
Segment Reporting Information [Line Items]
Operating revenues		(15,359)	(16,530)
Depreciation and amortization		0	0
Other operating expenses		15,359	16,530
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		(105)	456
Consolidation Elimination Entries [Member] | Gas [Member]
Segment Reporting Information [Line Items]
Operating revenues		4,394	5,097
Consolidation Elimination Entries [Member] | Non Regulated Energy [Member]
Segment Reporting Information [Line Items]
Operating revenues		11,070	10,977
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		156,836	147,543
Depreciation and amortization		(12,959)	(11,020)
Other operating expenses	[1]	(120,863)	(115,744)
Operating income (loss)	[1]	23,014	20,779
Other income (deductions), net	[1]	151	1,479
Interest (expense) income, net		(4,982)	(5,061)
Net Income Including Noncontrolling Interest		18,183	17,197
Less Net Income Attributable to Noncontrolling Interest, net of tax		(5,389)	(6,252)
Net Income (Loss)		12,794	10,945
MGE [Member] | Electric [Member]
Segment Reporting Information [Line Items]
Operating revenues		98,328	93,214
MGE [Member] | Gas [Member]
Segment Reporting Information [Line Items]
Operating revenues		58,435	53,847
MGE [Member] | Non Regulated Energy [Member]
Segment Reporting Information [Line Items]
Operating revenues		73	482
MGE [Member] | Transmission Investment [Member]
Segment Reporting Information [Line Items]
Operating revenues	[2]	0	0
MGE [Member] | Operating Segments [Member]
Segment Reporting Information [Line Items]
Operating revenues		156,836	147,543
MGE [Member] | Operating Segments [Member] | Electric [Member]
Segment Reporting Information [Line Items]
Operating revenues		98,219	93,664
Depreciation and amortization		(8,900)	(7,163)
Other operating expenses	[1]	(78,746)	(77,879)
Operating income (loss)	[1]	10,573	8,622
Other income (deductions), net	[1]	156	160
Interest (expense) income, net		(2,776)	(2,790)
Net Income Including Noncontrolling Interest		7,953	5,992
Less Net Income Attributable to Noncontrolling Interest, net of tax		0	0
Net Income (Loss)		7,953	5,992
MGE [Member] | Operating Segments [Member] | Gas [Member]
Segment Reporting Information [Line Items]
Operating revenues		62,820	58,934
Depreciation and amortization		(2,213)	(1,981)
Other operating expenses	[1]	(54,271)	(51,091)
Operating income (loss)	[1]	6,336	5,862
Other income (deductions), net	[1]	(5)	(17)
Interest (expense) income, net		(799)	(808)
Net Income Including Noncontrolling Interest		5,532	5,037
Less Net Income Attributable to Noncontrolling Interest, net of tax		0	0
Net Income (Loss)		5,532	5,037
MGE [Member] | Operating Segments [Member] | Non Regulated Energy [Member]
Segment Reporting Information [Line Items]
Operating revenues		11,143	11,459
Depreciation and amortization		(1,846)	(1,876)
Other operating expenses	[1]	(3,192)	(3,287)
Operating income (loss)	[1]	6,105	6,296
Other income (deductions), net	[1]	0	0
Interest (expense) income, net		(1,407)	(1,463)
Net Income Including Noncontrolling Interest		4,698	4,833
Less Net Income Attributable to Noncontrolling Interest, net of tax		0	0
Net Income (Loss)		4,698	4,833
MGE [Member] | Operating Segments [Member] | Transmission Investment [Member]
Segment Reporting Information [Line Items]
Operating revenues	[2]	0	0
Depreciation and amortization	[2]	0	0
Other operating expenses	[1],[2]	0	(1)
Operating income (loss)	[1],[2]	0	(1)
Other income (deductions), net	[1],[2]	0	1,336
Interest (expense) income, net	[2]	0	0
Net Income Including Noncontrolling Interest	[2]	0	1,335
Less Net Income Attributable to Noncontrolling Interest, net of tax	[2]	0	0
Net Income (Loss)	[2]	0	1,335
MGE [Member] | Consolidation Elimination Entries [Member]
Segment Reporting Information [Line Items]
Operating revenues		(15,346)	(16,514)
Depreciation and amortization		0	0
Other operating expenses	[1]	15,346	16,514
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		(5,389)	(6,252)
Net Income (Loss)		(5,389)	(6,252)
MGE [Member] | Consolidation Elimination Entries [Member] | Electric [Member]
Segment Reporting Information [Line Items]
Operating revenues		(109)	450
MGE [Member] | Consolidation Elimination Entries [Member] | Gas [Member]
Segment Reporting Information [Line Items]
Operating revenues		4,385	5,087
MGE [Member] | Consolidation Elimination Entries [Member] | Non Regulated Energy [Member]
Segment Reporting Information [Line Items]
Operating revenues		11,070	10,977
MGE [Member] | Consolidation Elimination Entries [Member] | Transmission Investment [Member]
Segment Reporting Information [Line Items]
Operating revenues	[2]	$ 0	$ 0

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

[2] As of July 31, 2016, MGE no longer consolidates MGE Energy's proportionate share of equity earnings in MGE Transco. See Footnote 3 for additional information.