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:

September 30, 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 October 31, 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
ATC	American Transmission Company LLC
ATC Holdco	ATC Holdco, LLC
Blount	Blount Station
CAVR	Clean Air Visibility Rule
Codification	Financial Accounting Standards Board Accounting Standards Codification
Columbia	Columbia Energy Center
Cooling degree days	Measure of the extent to which the average daily temperature is above 65 degrees Fahrenheit, which is considered an indicator of possible increased demand for energy to provide cooling
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

Riverside	Riverside Energy Center
ROE	Return on Equity
SCR	Selective Catalytic Reduction
SEC	Securities and Exchange Commission
SO2	Sulfur Dioxide
Stock Plan	Direct Stock Purchase and Dividend Reinvestment Plan of MGE Energy
UW	University of Wisconsin at Madison
VIE	Variable Interest Entity
WCCF	West Campus Cogeneration Facility
WEPCO	Wisconsin Electric Power Company, a subsidiary of WEC Energy Group, Inc.
Working capital	Current assets less current liabilities
WPL	Wisconsin Power and Light Company, a subsidiary of Alliant Energy Corporation
XBRL	eXtensible Business Reporting Language

5

Item 1. Financial Statements.

MGE Energy, Inc.

Consolidated Statements of Income (unaudited)

(In thousands, except per-share amounts)

		Three Months Ended				Nine Months Ended
		September 30,				September 30,
		2017		2016		2017		2016
Operating Revenues:
Electric revenues	$	120,761	$	119,147	$	321,540	$	313,452
Gas revenues		18,778		17,570		101,285		92,368
Total Operating Revenues		139,539		136,717		422,825		405,820
Operating Expenses:
Fuel for electric generation		15,829		20,505		39,938		47,567
Purchased power		15,984		9,167		48,058		38,698
Cost of gas sold		5,094		4,314		50,109		43,247
Other operations and maintenance		41,529		40,146		128,143		123,839
Depreciation and amortization		13,372		11,212		39,606		33,358
Other general taxes		4,730		4,846		14,509		14,841
Total Operating Expenses		96,538		90,190		320,363		301,550
Operating Income		43,001		46,527		102,462		104,270
Other income, net		3,939		2,105		9,004		6,726
Interest expense, net		(4,727)		(5,038)		(14,507)		(14,995)
Income before income taxes		42,213		43,594		96,959		96,001
Income tax provision		(15,584)		(15,714)		(35,487)		(34,943)
Net Income	$	26,629	$	27,880	$	61,472	$	61,058
Earnings Per Share of Common Stock
(basic and diluted)	$	0.77	$	0.80	$	1.77	$	1.76
Dividends per share of common stock	$	0.323	$	0.308	$	0.938	$	0.898
Weighted Average Shares Outstanding
(basic and diluted)		34,668		34,668		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				Nine Months Ended
		September 30,				September 30,
		2017		2016		2017		2016
Net Income	$	26,629	$	27,880	$	61,472	$	61,058
Other comprehensive income, net of tax:
Unrealized gain (loss) on available-for-sale
securities, net of tax (($40) and ($8), and ($127) and
$96, respectively)		60		11		189		(143)
Comprehensive Income	$	26,689	$	27,891	$	61,661	$	60,915
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)

		Nine Months Ended
		September 30,
		2017		2016
Operating Activities:
Net income	$	61,472	$	61,058
Items not affecting cash:
Depreciation and amortization		39,606		33,358
Deferred income taxes		4,810		15,041
Provision for doubtful receivables		650		583
Employee benefit plan cost		778		165
Equity earnings in ATC		(7,432)		(6,023)
Gain on sale of property		(1,581)		-
Other items		1,071		693
Changes in working capital items:
Decrease in current assets		18,161		33,740
Decrease in current liabilities		(17,615)		(3,147)
Dividends from ATC		6,142		4,214
Cash contributions to pension and other postretirement plans		(9,717)		(13,134)
Other noncurrent items, net		2,671		2,644
Cash Provided by Operating Activities		99,016		129,192
Investing Activities:
Capital expenditures		(66,286)		(62,273)
Capital contributions to investments		(6,863)		(2,036)
Proceeds from sale of property		2,399		-
Other		(364)		(310)
Cash Used for Investing Activities		(71,114)		(64,619)
Financing Activities:
Cash dividends paid on common stock		(32,502)		(31,115)
Repayment of long-term debt		(33,260)		(3,192)
Issuance of long-term debt		40,000		-
Proceeds from short-term debt		7,000		-
Other		(366)		(65)
Cash Used for Financing Activities		(19,128)		(34,372)
Change in cash and cash equivalents		8,774		30,201
Cash and cash equivalents at beginning of period		95,959		81,384
Cash and cash equivalents at end of period	$	104,733	$	111,585
Supplemental disclosures of cash flow information:
Significant noncash investing activities:
Accrued capital expenditures	$	12,469	$	10,603
The accompanying notes are an integral part of the unaudited consolidated financial statements.

7

MGE Energy, Inc.

Consolidated Balance Sheets (unaudited)

(In thousands)

		September 30,	December 31,
ASSETS		2017		2016
Current Assets:
Cash and cash equivalents	$	104,733	$	95,959
Accounts receivable, less reserves of $2,950 and $3,017, respectively		38,129		39,887
Other accounts receivable, less reserves of $372 and $426, respectively		7,588		8,530
Unbilled revenues		21,764		29,846
Materials and supplies, at average cost		21,835		18,561
Fossil fuel, at average cost		10,017		9,757
Stored natural gas, at average cost		14,758		12,819
Prepaid taxes		12,406		26,636
Regulatory assets - current		7,377		6,414
Assets held for sale		6,707		14,813
Other current assets		10,043		12,293
Total Current Assets		255,357		275,515
Regulatory assets		146,006		158,485
Pension and other postretirement benefit asset		3,471		2,020
Other deferred assets and other		6,311		6,691
Property, Plant, and Equipment:
Property, plant, and equipment, net		1,270,124		1,245,269
Construction work in progress		42,276		36,790
Total Property, Plant, and Equipment		1,312,400		1,282,059
Investments		86,455		76,290
Total Assets	$	1,810,000	$	1,801,060
LIABILITIES AND CAPITALIZATION
Current Liabilities:
Long-term debt due within one year	$	4,428	$	4,333
Short-term debt		7,000		-
Accounts payable		31,519		47,799
Accrued interest and taxes		4,750		5,495
Accrued payroll related items		9,981		11,892
Regulatory liabilities - current		6,353		6,910
Derivative liabilities		8,288		7,620
Other current liabilities		12,263		19,456
Total Current Liabilities		84,582		103,505
Other Credits:
Deferred income taxes		389,179		383,813
Investment tax credit - deferred		885		947
Regulatory liabilities		28,253		22,173
Accrued pension and other postretirement benefits		65,616		74,347
Derivative liabilities		34,890		42,970
Other deferred liabilities and other		63,942		66,426
Total Other Credits		582,765		590,676
Capitalization:
Common shareholders' equity		753,247		724,088
Long-term debt		389,406		382,791
Total Capitalization		1,142,653		1,106,879
Commitments and contingencies (see Footnote 7)
Total Liabilities and Capitalization	$	1,810,000	$	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							61,058				61,058
Other comprehensive loss									(143)		(143)
Common stock dividends declared
($0.898 per share)							(31,115)				(31,115)
Ending balance - September 30, 2016	34,668	$	34,668	$	316,268	$	369,108	$	214	$	720,258
2017
Beginning balance - December 31, 2016	34,668	$	34,668	$	316,268	$	372,950	$	202	$	724,088
Net income							61,472				61,472
Other comprehensive income									189		189
Common stock dividends declared
($0.938 per share)							(32,502)				(32,502)
Ending balance - September 30, 2017	34,668	$	34,668	$	316,268	$	401,920	$	391	$	753,247
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				Nine Months Ended
		September 30,				September 30,
		2017		2016		2017		2016
Operating Revenues:
Electric revenues	$	120,760	$	119,152	$	321,543	$	313,470
Gas revenues		18,779		17,576		101,294		92,390
Total Operating Revenues		139,539		136,728		422,837		405,860
Operating Expenses:
Fuel for electric generation		15,828		20,507		39,939		47,574
Purchased power		15,985		9,171		48,061		38,709
Cost of gas sold		5,094		4,320		50,117		43,269
Other operations and maintenance		41,327		40,003		127,355		123,117
Depreciation and amortization		13,372		11,212		39,606		33,334
Other general taxes		4,730		4,846		14,509		14,841
Income tax provision		14,059		14,934		32,080		32,488
Total Operating Expenses		110,395		104,993		351,667		333,332
Operating Income		29,144		31,735		71,170		72,528
Other Income and Deductions:
AFUDC - equity funds		310		253		875		777
Equity earnings in MGE Transco		-		1,451		-		5,451
Income tax provision		(663)		(606)		(754)		(2,315)
Other expense, net		1,488		(62)		1,301		(298)
Total Other Income and Deductions		1,135		1,036		1,422		3,615
Income before interest expense		30,279		32,771		72,592		76,143
Interest Expense:
Interest on long-term debt		4,995		5,079		15,051		15,284
Other interest, net		54		112		150		163
AFUDC - borrowed funds		(123)		(82)		(295)		(253)
Net Interest Expense		4,926		5,109		14,906		15,194
Net Income	$	25,353	$	27,662	$	57,686	$	60,949
Less: Net Income Attributable to Noncontrolling
Interest, net of tax		(5,439)		(5,695)		(16,224)		(17,899)
Net Income Attributable to MGE	$	19,914	$	21,967	$	41,462	$	43,050
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				Nine Months Ended
		September 30,				September 30,
		2017		2016		2017		2016
Net Income	$	25,353	$	27,662	$	57,686	$	60,949
Other comprehensive income, net of tax:
Unrealized (loss) gain on available-for-sale
securities, net of tax ($5 and ($5), and $26 and
$21, respectively)		(7)		8		(38)		(31)
Comprehensive Income	$	25,346	$	27,670	$	57,648	$	60,918
Less: Comprehensive Income Attributable to
Noncontrolling Interest, net of tax		(5,439)		(5,695)		(16,224)		(17,899)
Comprehensive Income Attributable to MGE	$	19,907	$	21,975	$	41,424	$	43,019
The accompanying notes are an integral part of the above unaudited consolidated financial statements.

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Madison Gas and Electric Company

Consolidated Statements of Cash Flows (unaudited)

(In thousands)

		Nine Months Ended
		September 30,
		2017		2016
Operating Activities:
Net income	$	57,686	$	60,949
Items not affecting cash:
Depreciation and amortization		39,606		33,334
Deferred income taxes		2,255		13,997
Provision for doubtful receivables		650		583
Employee benefit plan cost		778		165
Equity earnings in MGE Transco		-		(5,451)
Gain on sale of property		(1,581)		-
Other items		1,344		1,056
Changes in working capital items:
Decrease in current assets		17,536		32,557
Decrease in current liabilities		(16,670)		(1,783)
Dividends from MGE Transco		-		4,214
Cash contributions to pension and other postretirement plans		(9,717)		(13,134)
Other noncurrent items, net		2,479		2,472
Cash Provided by Operating Activities		94,366		128,959
Investing Activities:
Capital expenditures		(66,286)		(62,273)
Capital contributions to investments		-		(1,598)
Proceeds from sale of property		1,751		-
Other		(570)		(536)
Cash Used for Investing Activities		(65,105)		(64,407)
Financing Activities:
Cash dividends paid to parent by MGE		(35,000)		(40,000)
Distributions to parent from noncontrolling interest		(16,500)		(18,113)
Equity contribution received from noncontrolling interest		-		1,598
Repayment of long-term debt		(33,260)		(3,192)
Issuance of long-term debt		40,000		-
Proceeds from short-term debt		7,000		-
Other		(315)		(47)
Cash Used for Financing Activities		(38,075)		(59,754)
Change in cash and cash equivalents		(8,814)		4,798
Cash and cash equivalents at beginning of period		10,768		26,760
Cash and cash equivalents at end of period	$	1,954	$	31,558
Supplemental disclosures of cash flow information:
Significant noncash investing activities:
Accrued capital expenditures	$	12,469	$	10,603
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)

		September 30,	December 31,
ASSETS		2017		2016
Current Assets:
Cash and cash equivalents	$	1,954	$	10,768
Accounts receivable, less reserves of $2,950 and $3,017, respectively		38,129		39,887
Affiliate receivables		683		539
Other accounts receivable, less reserves of $372 and $426, respectively		7,529		6,363
Unbilled revenues		21,764		29,846
Materials and supplies, at average cost		21,835		18,561
Fossil fuel, at average cost		10,017		9,757
Stored natural gas, at average cost		14,758		12,819
Prepaid taxes		12,524		25,798
Regulatory assets - current		7,377		6,414
Assets held for sale		6,707		14,813
Other current assets		10,010		12,268
Total Current Assets		153,287		187,833
Affiliate receivable long-term		3,839		4,236
Regulatory assets		146,006		158,485
Pension and other postretirement benefit asset		3,471		2,020
Other deferred assets and other		4,066		4,353
Property, Plant, and Equipment:
Property, plant, and equipment, net		1,270,153		1,244,648
Construction work in progress		42,276		36,790
Total Property, Plant, and Equipment		1,312,429		1,281,438
Investments		423		487
Total Assets	$	1,623,521	$	1,638,852
LIABILITIES AND CAPITALIZATION
Current Liabilities:
Long-term debt due within one year	$	4,428	$	4,333
Short-term debt		7,000		-
Accounts payable		31,508		47,790
Accrued interest and taxes		5,717		5,440
Accrued payroll related items		9,981		11,892
Regulatory liabilities - current		6,353		6,910
Derivative liabilities		8,288		7,620
Other current liabilities		12,079		19,347
Total Current Liabilities		85,354		103,332
Other Credits:
Deferred income taxes		346,278		343,117
Investment tax credit - deferred		885		947
Regulatory liabilities		28,253		22,173
Accrued pension and other postretirement benefits		65,616		74,347
Derivative liabilities		34,890		42,970
Other deferred liabilities and other		63,942		66,426
Total Other Credits		539,864		549,980
Capitalization:
Common shareholder's equity		493,508		487,084
Noncontrolling interest		115,389		115,665
Total Equity		608,897		602,749
Long-term debt		389,406		382,791
Total Capitalization		998,303		985,540
Commitments and contingencies (see Footnote 7)
Total Liabilities and Capitalization	$	1,623,521	$	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							43,050				17,899		60,949
Other comprehensive loss									(31)				(31)
Cash dividends paid to parent
by MGE							(40,000)						(40,000)
Equity contribution received from
noncontrolling interest											1,598		1,598
Distributions to parent from
noncontrolling interest											(18,113)		(18,113)
Deconsolidation of
noncontrolling interest											(25,486)		(25,486)
Ending balance - September 30, 2016	17,348	$	17,348	$	192,417	$	294,938	$	(8)	$	116,206	$	620,901
2017
Beginning balance - Dec. 31, 2016	17,348	$	17,348	$	192,417	$	277,300	$	19	$	115,665	$	602,749
Net income							41,462				16,224		57,686
Other comprehensive loss									(38)				(38)
Cash dividends paid to parent
by MGE							(35,000)						(35,000)
Distributions to parent from
noncontrolling interest											(16,500)		(16,500)
Ending balance - September 30, 2017	17,348	$	17,348	$	192,417	$	283,762	$	(19)	$	115,389	$	608,897
The accompanying notes are an integral part of the above unaudited consolidated financial statements.

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

Notes to Consolidated Financial Statements (unaudited)

September 30, 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 (the 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 September 30, 2017, and for the three and nine 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 the 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 and nine months ended September 30, 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 stock option or stock award programs or 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 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.

On October 2, 2017, MGE issued $30 million of 3.11% senior unsecured notes due October 1, 2027. MGE will use the net proceeds from the sale of senior notes to cover capital expenditures and other corporate obligations. The long-term debt carries an interest rate of 3.11% per annum over its 10-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 and nine months ended September 30, 2017 and 2016, MGE Transco recorded the following:

		Three Months Ended				Nine Months Ended
		September 30,				September 30,
(In thousands)		2017		2016		2017		2016
Equity earnings from investment in ATC	$	2,338	$	2,023	$	7,432	$	6,023
Dividends from ATC(a)		2,070		1,486		4,070		4,214
Capital contributions to ATC		710		888		3,018		1,598

(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 September 30, 2017, and December 31, 2016, MGE Transco held a 3.6% ownership interest in ATC. At September 30, 2017, and December 31, 2016, MGEE Transco held a 4.4% and 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 and nine months ended September 30, 2017 and 2016, is as follows:

		Three Months Ended				Nine Months Ended
		September 30,				September 30,
(In thousands)		2017		2016		2017		2016
Operating revenues	$	171,123	$	158,126	$	522,402	$	476,591
Operating expenses		(85,063)		(80,271)		(250,116)		(241,034)
Other income, net		796		1,128		1,615		2,563
Interest expense, net		(28,273)		(24,624)		(81,188)		(73,714)
Earnings before members' income taxes	$	58,583	$	54,359	$	192,713	$	164,406

MGE receives transmission and other related services from ATC. During the three and nine months ended September 30, 2017, MGE recorded $7.3 million and $21.9 million, respectively, for transmission services received compared to $7.4 million and $22.1 million for the comparable periods in 2016. MGE also provides a variety of operational, maintenance, and project management services for ATC, which is reimbursed by ATC. As of September 30, 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.

MGE Energy's effective income tax rate for the three months ended September 30, 2017 and 2016, was 36.9% and 36.1%, respectively. MGE's effective income tax rate for the three months ended September 30, 2017 and 2016, was 36.7% and 36.0%, respectively. For both MGE Energy and MGE, the increase in the effective tax rate is due in part to lower estimated federal tax credits.

MGE Energy's effective income tax rate for the nine months ended September 30, 2017 and 2016, was 36.6% and 36.4%, respectively. MGE's effective income tax rate for the nine months ended September 30, 2017 and 2016, was 36.3% and 36.4%, respectively.

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 and nine months ended September 30, 2017 and 2016. A portion of the net periodic benefit cost is capitalized within the consolidated balance sheets.

		Three Months Ended				Nine Months Ended
		September 30,				September 30,
(In thousands)		2017		2016		2017		2016
Pension Benefits
Components of net periodic benefit cost:
Service cost	$	1,351	$	1,413	$	4,043	$	4,358
Interest cost		3,168		3,161		9,481		9,744
Expected return on assets		(5,762)		(5,724)		(17,244)		(17,646)
Amortization of:
Prior service (credit) cost		(4)		3		(12)		8
Actuarial loss		1,594		1,388		4,769		4,278
Net periodic benefit cost	$	347	$	241	$	1,037	$	742
Postretirement Benefits
Components of net periodic benefit cost:
Service cost	$	315	$	361	$	944	$	1,084
Interest cost		678		753		2,034		2,258
Expected return on assets		(722)		(787)		(2,165)		(2,360)
Amortization of:
Transition obligation		1		1		2		3
Prior service credit		(667)		(744)		(2,001)		(2,233)
Actuarial loss		190		178		570		533
Net periodic benefit credit	$	(205)	$	(238)	$	(616)	$	(715)

6.

Share-Based Compensation - MGE Energy and MGE.

Under MGE Energy's Director Incentive Plan and its 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 September 30, 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 and nine months ended September 30, 2017, MGE recorded $0.3 million and $1.0 million, respectively, in compensation expense as a result of awards under the plans compared to $0.2 million and $2.0 million for the comparable periods in 2016. In January 2017, cash payments of $2.0 million were distributed according to the terms of the awards granted earlier under the plans that had reached their payment dates. No forfeitures of units occurred during the three and nine months ended September 30, 2017 and 2016. At September 30, 2017, $5.1 million of outstanding awards are vested, and of this amount, no cash settlements have occurred.

7.

Commitments and Contingencies.

a.

Environmental - MGE Energy and MGE.

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 (the Clean Power Plan, or CPP). Implementation of the rule is expected to have a direct impact on existing coal and natural gas fired generating units, including possible changes in dispatch and additional operating costs. In May 2017, the EPA requested the U.S. Court of Appeals for the D.C. Circuit to put on hold, indefinitely, any ongoing challenges to the rules while the EPA reviews the rule and undertakes any potential rulemaking. In October 2017, the EPA published a proposed rule announcing the EPA's intention to repeal the CPP and has sought public comment on whether to replace the rule, and if so how. Given the pending legal proceedings, and the EPA's recent proposal, the nature and timing of any final requirements to control GHG emissions from existing fossil fuel-fired EGUs is subject to uncertainty. If a rule is implemented substantially in its present form, it is expected to have a material impact on MGE. MGE will continue to monitor developments with this proposed rule.

•

Federal and state air quality regulations impose restrictions on various emissions including emissions of sulfur dioxide (SO₂), nitrogen dioxide (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 were delayed following a request by the EPA. The EPA missed its regulatory deadline to

17

designate areas as attainment or nonattainment under the 2015 standard. MGE will continue to monitor the EPA's progress on attainment designations 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 uncertainties surrounding the ongoing implementation of Phase II of CSAPR and 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 the 2016 Annual Report on Form 10-K.

b.

Legal Matters - MGE Energy and MGE.

MGE is involved in various legal matters that are being defended and handled in the normal course of business. 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.

c.

Purchase Contracts - MGE Energy and MGE.

MGE has entered into various commodity supply, transportation, and storage contracts to meet its obligation to deliver electricity and natural gas to customers. Management expects to recover these costs in future customer rates. As of September 30, 2017, the future commitments related to these purchase contracts were as follows:

(In thousands)		2017		2018		2019		2020		2021		Thereafter
Coal(a)	$	6,402	$	19,685	$	13,497	$	3,445	$	-	$	-
Natural gas
Transportation & storage(b)		6,073		20,839		19,680		15,423		8,660		24,373
Supply(c)		11,243		11,817		-		-		-		-
	$	23,718	$	52,341	$	33,177	$	18,868	$	8,660	$	24,373

(a)

Total coal commitments for the Columbia and Elm Road Units, including transportation. Fuel procurement for MGE's jointly owned Columbia and Elm Road Units is handled by WPL and WEPCO, respectively, who are the operators of those facilities.

(b)

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

(c)

These commitments include market-based pricing.

d.

Other Commitments - MGE Energy.

In May 2017, MGE Energy entered into a subscription agreement to invest in a nonpublic venture capital fund. From time to time, this entity will require capital infusions from its investors. MGE Energy has committed to contribute $5 million in capital for such infusions. The timing of these infusions is dependent on the needs of the investee and is therefore uncertain at this time.

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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 on an annual basis and to increase rates for retail gas customers by 1.9% or $3.1 million on an annual basis. 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% based on a capital structure consisting of 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. MGE did not file 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. 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 July 2016, the PSCW issued a final order in the fuel rules proceedings requiring MGE to refund 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.

In July 2017, the PSCW issued a final order in the fuel rules proceedings requiring MGE to refund $6.0 million of additional fuel savings realized during 2015 and 2016 to its retail electric customers over a one-month period in October 2017.

As of September 30, 2017, MGE has deferred $3.3 million of 2017 fuel savings. The 2017 fuel savings 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 depending on whether the derivative is in a net loss or net gain position, respectively. The

19

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:

	September 30, 2017	December 31, 2016
Commodity derivative contracts	634,605 MWh	393,395 MWh
Commodity derivative contracts	7,924,500 Dth	4,195,000 Dth
FTRs	3,552 MW	2,251 MW
PPA	2,800 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 September 30, 2017, and December 31, 2016, the fair value of exchange traded derivatives and FTRs exceeded their cost basis by $0.9 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 September 30, 2017, and December 31, 2016, reflects a loss position of $43.1 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 September 30, 2017, and December 31, 2016, the receivable – margin account balance of $1.5 million and $1.3 million, respectively, is shown net of any collateral posted against derivative positions.

		Derivative		Derivative
(In thousands)		Assets		Liabilities	Balance Sheet Location
September 30, 2017
Commodity derivative contracts(a)	$	857	$	560	Other current assets(b)
Commodity derivative contracts(a)		112		122	Other deferred charges
FTRs		567		-	Other current assets
PPA		N/A		8,240	Derivative liability (current)
PPA		N/A		34,890	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)

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(a)

As of September 30, 2017, and December 31, 2016, no collateral was posted against and netted with derivative liability positions on the consolidated balance sheets.

(b)

As of September 30, 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
September 30, 2017
Commodity derivative contracts	$	969	$	(634)	$	-	$	335
FTRs		567		-		-		567
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
September 30, 2017
Commodity derivative contracts	$	682	$	(634)	$	-	$	48
PPA		43,130		-		-		43,130
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 September 30, 2017 and 2016, and the consolidated income statements for the three and nine months ended September 30, 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 September 30:
Balance at July 1,	$	45,316	$	618	$	50,521	$	659
Unrealized gain		(1,277)		-		(663)		-
Realized (loss) gain reclassified to a deferred account		(313)		313		17		(17)
Realized (loss) gain reclassified to income statement		(1,450)		(57)		(304)		46
Balance at September 30,	$	42,276	$	874	$	49,571	$	688
Nine Months Ended September 30:
Balance at January 1,	$	49,281	$	230	$	54,082	$	1,208
Unrealized (gain) loss		(3,698)		-		1,128		-
Realized (loss) gain reclassified to a deferred account		(935)		935		(1,417)		1,417
Realized loss reclassified to income statement		(2,372)		(291)		(4,222)		(1,937)
Balance at September 30,	$	42,276	$	874	$	49,571	$	688

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		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 September 30:
Commodity derivative contracts	$	362	$	18	$	45	$	-
FTRs		(224)		-		(703)		-
PPA		1,351		-		916		-
Nine Months Ended September 30:
Commodity derivative contracts	$	764	$	227	$	1,469	$	1,814
FTRs		(1,349)		-		(635)		-
PPA		3,021		-		3,511		-

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 September 30, 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 September 30, 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 September 30, 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 September 30, 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 September 30, 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:

		September 30, 2017				December 31, 2016
(In thousands)		Carrying Amount		Fair Value		Carrying Amount		Fair Value
MGE Energy
Assets:
Cash and cash equivalents	$	104,733	$	104,733	$	95,959	$	95,959
Liabilities:
Short-term debt - commercial paper		7,000		7,000		-		-
Long-term debt(a)		397,981		444,195		391,242		430,122
MGE
Assets:
Cash and cash equivalents	$	1,954	$	1,954	$	10,768	$	10,768
Liabilities:
Short-term debt - commercial paper		7,000		7,000		-		-
Long-term debt(a)		397,981		444,195		391,242		430,122
(a)   Includes long-term debt due within one year. Excludes debt issuance costs and unamortized discount of
$4.1 million at September 30, 2017, and December 31, 2016.

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 September 30, 2017
(In thousands)		Total		Level 1		Level 2		Level 3
MGE Energy
Assets:
Derivatives	$	1,536	$	673	$	-	$	863
Exchange-traded investments		816		816		-		-
Total Assets	$	2,352	$	1,489	$	-	$	863
Liabilities:
Derivatives	$	43,812	$	190	$	-	$	43,622
Deferred compensation		3,150		-		3,150		-
Total Liabilities	$	46,962	$	190	$	3,150	$	43,622
MGE
Assets:
Derivatives	$	1,536	$	673	$	-	$	863
Exchange-traded investments		78		78		-		-
Total Assets	$	1,614	$	751	$	-	$	863
Liabilities:
Derivatives	$	43,812	$	190	$	-	$	43,622
Deferred compensation		3,150		-		3,150		-
Total Liabilities	$	46,962	$	190	$	3,150	$	43,622

23

		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 nine months ended September 30, 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. 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.

24

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

	Model Input
Significant Unobservable Inputs	September 30, 2017	December 31, 2016
Basis adjustment:
On peak	92.4%	91.9%
Off peak	94.2%	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				Nine Months Ended
		September 30,				September 30,
(In thousands)		2017		2016		2017		2016
Beginning balance	$	(45,605)	$	(51,883)	$	(50,305)	$	(53,501)
Realized and unrealized gains (losses):
Included in regulatory liabilities		2,846		1,455		7,547		3,073
Included in other comprehensive income		-		-		-		-
Included in earnings		(1,478)		(278)		(2,614)		(4,250)
Included in current assets		(14)		-		(111)		-
Purchases		6,299		5,814		18,481		16,751
Sales		-		-		-		-
Issuances		-		-		-		-
Settlements		(4,807)		(5,537)		(15,757)		(12,502)
Transfers in and/or out of Level 3		-		-		-		-
Balance as of September 30,	$	(42,759)	$	(50,429)	$	(42,759)	$	(50,429)
Total gains (losses) included in earnings attributed to
the change in unrealized gains (losses) related to
assets and liabilities held at September 30,(b)	$	-	$	-	$	-	$	-

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

		Three Months Ended				Nine Months Ended
		September 30,				September 30,
(In thousands)		2017		2016		2017		2016
Purchased Power Expense	$	(1,460)	$	(278)	$	(2,377)	$	(4,250)
Cost of Gas Sold Expense		(18)		-		(237)		-
Total	$	(1,478)	$	(278)	$	(2,614)	$	(4,250)

(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 June 2017, the FERC approved the ownership transfer in Columbia, effective January 1, 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 and nine months ended September 30, 2017, MGE accrued $1.6 million and $6.7 million, respectively, of 2017 capital expenditures that MGE has forgone subject to the ownership transfer agreement. As of September 30, 2017, MGE classified $6.7 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 materially 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. 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.

26

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. As of September 30, 2017, MGE Energy had $0.4 million and MGE had less than $0.1 million of accumulated other comprehensive income related to equity investments within the scope of this standard.

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 September 30, 2017, and December 31, 2016, MGE Energy and MGE had $4.5 million and $5.1 million, respectively, of restricted cash classified within other current assets on the consolidated balance sheets.

27

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 (together, net benefit cost). This authoritative guidance will become effective January 1, 2018. 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. A practical expedient within the standard permits an employer to use the amounts disclosed in its pension and other postretirement benefit plan footnote for prior comparative periods as the estimation basis for applying the retrospective presentation requirements. MGE Energy and MGE have elected to apply the practical expedient. Operating income will decrease and other income will increase $6.6 million and $5.0 million for the years ended December 31, 2016 and 2015, respectively. The standard also only allows the service cost component to be eligible for capitalization prospectively from the effective date of the pronouncement (whereas under current GAAP, all components of net benefit cost are eligible for capitalization). MGE Energy and MGE are currently evaluating the impact of how the change in components of net benefit cost eligible for capitalization will affect our 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 the 2016 Annual Report on Form 10-K for additional discussion of each of these segments.

28

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 September 30, 2017
Operating revenues	$	120,649	$	18,778	$	112	$	-	$	-	$	-	$	139,539
Interdepartmental revenues		(110)		3,892		11,130		-		-		(14,912)		-
Total operating revenues		120,539		22,670		11,242		-		-		(14,912)		139,539
Depreciation and amortization		(9,256)		(2,258)		(1,858)		-		-		-		(13,372)
Other operating expenses		(78,886)		(18,940)		(50)		(9)		(193)		14,912		(83,166)
Operating income (loss)		32,397		1,472		9,334		(9)		(193)		-		43,001
Other income (deductions), net		1,440		358		-		2,258		(117)		-		3,939
Interest (expense) income, net		(2,760)		(795)		(1,371)		-		199		-		(4,727)
Income (loss) before taxes		31,077		1,035		7,963		2,249		(111)		-		42,213
Income tax (provision) benefit		(11,175)		(351)		(3,196)		(906)		44		-		(15,584)
Net income (loss)	$	19,902	$	684	$	4,767	$	1,343	$	(67)	$	-	$	26,629
Three Months Ended September 30, 2016
Operating revenues	$	118,933	$	17,570	$	214	$	-	$	-	$	-	$	136,717
Interdepartmental revenues		459		6,040		10,998		-		-		(17,497)		-
Total operating revenues		119,392		23,610		11,212		-		-		(17,497)		136,717
Depreciation and amortization		(7,332)		(2,047)		(1,833)		-		-		-		(11,212)
Other operating expenses		(77,010)		(19,292)		(33)		(13)		(127)		17,497		(78,978)
Operating income (loss)		35,050		2,271		9,346		(13)		(127)		-		46,527
Other income (deductions), net		178		13		-		2,023		(109)		-		2,105
Interest (expense) income, net		(2,855)		(818)		(1,436)		-		71		-		(5,038)
Income (loss) before taxes		32,373		1,466		7,910		2,010		(165)		-		43,594
Income tax (provision) benefit		(11,290)		(494)		(3,175)		(812)		57		-		(15,714)
Net income (loss)	$	21,083	$	972	$	4,735	$	1,198	$	(108)	$	-	$	27,880
Nine Months Ended September 30, 2017
Operating revenues	$	321,279	$	101,285	$	261	$	-	$	-	$	-	$	422,825
Interdepartmental revenues		(334)		11,708		33,307		-		-		(44,681)		-
Total operating revenues		320,945		112,993		33,568		-		-		(44,681)		422,825
Depreciation and amortization		(27,341)		(6,703)		(5,562)		-		-		-		(39,606)
Other operating expenses		(231,827)		(92,670)		(153)		(9)		(779)		44,681		(280,757)
Operating income (loss)		61,777		13,620		27,853		(9)		(779)		-		102,462
Other income (deductions), net		1,821		355		-		7,242		(414)		-		9,004
Interest (expense) income, net		(8,337)		(2,399)		(4,170)		-		399		-		(14,507)
Income (loss) before taxes		55,261		11,576		23,683		7,233		(794)		-		96,959
Income tax (provision) benefit		(18,753)		(4,576)		(9,505)		(2,909)		256		-		(35,487)
Net income (loss)	$	36,508	$	7,000	$	14,178	$	4,324	$	(538)	$	-	$	61,472
Nine Months Ended September 30, 2016
Operating revenues	$	312,470	$	92,368	$	982	$	-	$	-	$	-	$	405,820
Interdepartmental revenues		1,482		17,278		32,894		-		-		(51,654)		-
Total operating revenues		313,952		109,646		33,876		-		-		(51,654)		405,820
Depreciation and amortization		(21,754)		(6,043)		(5,537)		-		(24)		-		(33,358)
Other operating expenses		(230,680)		(88,328)		(115)		(17)		(706)		51,654		(268,192)
Operating income (loss)		61,518		15,275		28,224		(17)		(730)		-		104,270
Other income (deductions), net		492		(13)		-		6,023		224		-		6,726
Interest (expense) income, net		(8,421)		(2,425)		(4,348)		-		199		-		(14,995)
Income (loss) before taxes		53,589		12,837		23,876		6,006		(307)		-		96,001
Income tax (provision) benefit		(17,984)		(5,048)		(9,583)		(2,418)		90		-		(34,943)
Net income (loss)	$	35,605	$	7,789	$	14,293	$	3,588	$	(217)	$	-	$	61,058

29

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 September 30, 2017
Operating revenues	$	120,648	$	18,779	$	112	$	-	$	-	$	139,539
Interdepartmental revenues		(109)		3,891		11,130		-		(14,912)		-
Total operating revenues		120,539		22,670		11,242		-		(14,912)		139,539
Depreciation and amortization		(9,256)		(2,258)		(1,858)		-		-		(13,372)
Other operating expenses(a)		(89,544)		(19,145)		(3,246)		-		14,912		(97,023)
Operating income(a)		21,739		1,267		6,138		-		-		29,144
Other income, net(a)		923		212		-		-		-		1,135
Interest expense, net		(2,760)		(795)		(1,371)		-		-		(4,926)
Net income		19,902		684		4,767		-		-		25,353
Less: Net income attributable to
noncontrolling interest, net of tax		-		-		-		-		(5,439)		(5,439)
Net income attributable to MGE	$	19,902	$	684	$	4,767	$	-	$	(5,439)	$	19,914
Three Months Ended September 30, 2016
Operating revenues	$	118,938	$	17,576	$	214	$	-	$	-	$	136,728
Interdepartmental revenues		454		6,034		10,998		-		(17,486)		-
Total operating revenues		119,392		23,610		11,212		-		(17,486)		136,728
Depreciation and amortization		(7,332)		(2,047)		(1,833)		-		-		(11,212)
Other operating expenses(a)		(88,282)		(19,781)		(3,208)		4		17,486		(93,781)
Operating income(a)		23,778		1,782		6,171		4		-		31,735
Other income, net(a)		160		8		-		868		-		1,036
Interest expense, net		(2,855)		(818)		(1,436)		-		-		(5,109)
Net income		21,083		972		4,735		872		-		27,662
Less: Net income attributable to
noncontrolling interest, net of tax		-		-		-		-		(5,695)		(5,695)
Net income attributable to MGE	$	21,083	$	972	$	4,735	$	872	$	(5,695)	$	21,967
Nine Months Ended September 30, 2017
Operating revenues	$	321,282	$	101,294	$	261	$	-	$	-	$	422,837
Interdepartmental revenues		(337)		11,699		33,307		-		(44,669)		-
Total operating revenues		320,945		112,993		33,568		-		(44,669)		422,837
Depreciation and amortization		(27,341)		(6,703)		(5,562)		-		-		(39,606)
Other operating expenses(a)		(249,992)		(97,080)		(9,658)		-		44,669		(312,061)
Operating income(a)		43,612		9,210		18,348		-		-		71,170
Other income, net(a)		1,233		189		-		-		-		1,422
Interest expense, net		(8,337)		(2,399)		(4,170)		-		-		(14,906)
Net income		36,508		7,000		14,178		-		-		57,686
Less: Net income attributable to
noncontrolling interest, net of tax		-		-		-		-		(16,224)		(16,224)
Net income attributable to MGE	$	36,508	$	7,000	$	14,178	$	-	$	(16,224)	$	41,462
Nine Months Ended September 30, 2016
Operating revenues	$	312,488	$	92,390	$	982	$	-	$	-	$	405,860
Interdepartmental revenues		1,464		17,256		32,894		-		(51,614)		-
Total operating revenues		313,952		109,646		33,876		-		(51,614)		405,860
Depreciation and amortization		(21,754)		(6,043)		(5,537)		-		-		(33,334)
Other operating expenses(a)		(248,566)		(93,348)		(9,698)		-		51,614		(299,998)
Operating income(a)		43,632		10,255		18,641		-		-		72,528
Other income (deductions), net(a)		394		(41)		-		3,262		-		3,615
Interest expense, net		(8,421)		(2,425)		(4,348)		-		-		(15,194)
Net income		35,605		7,789		14,293		3,262		-		60,949
Less: Net income attributable to
noncontrolling interest, net of tax		-		-		-		-		(17,899)		(17,899)
Net income attributable to MGE	$	35,605	$	7,789	$	14,293	$	3,262	$	(17,899)	$	43,050
(a) Amounts are shown net of the related tax expense, consistent with the presentation on the MGE Consolidated Statement 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 further discussion.

30

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

General

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

·

Regulated electric utility operations, conducted through MGE,

·

Regulated gas utility operations, conducted through MGE,

·

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

·

Transmission investments, representing our equity investment in ATC and 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 MGE Energy's 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 continues to examine and pursue opportunities to reduce the proportion that coal generation represents in its generation mix, including the announced reduction in its ownership of Columbia. 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 September 30, 2017, MGE Energy's earnings were $26.6 million or $0.77 per share compared to $27.9 million or $0.80 per share for the same period in the prior year. MGE's earnings for the three months ended September 30, 2017, were $19.9 million compared to $22.0 million for the same period in the prior year.

For the nine months ended September 30, 2017, MGE Energy's earnings were $61.5 million or $1.77 per share compared to $61.1 million or $1.76 per share for the same period in the prior year. MGE's earnings for the nine months ended September 30, 2017, were $41.5 million compared to $43.1 million for the same period in the prior year.

31

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

		Three Months Ended				Nine Months Ended
(In thousands)		September 30,				September 30,
Business Segment:		2017		2016		2017		2016
Electric Utility	$	19,902	$	21,083	$	36,508	$	35,605
Gas Utility		684		972		7,000		7,789
Nonregulated Energy		4,767		4,735		14,178		14,293
Transmission Investments		1,343		1,198		4,324		3,588
All Other		(67)		(108)		(538)		(217)
Net Income	$	26,629	$	27,880	$	61,472	$	61,058

Our net income during the three and nine months ended September 30, 2017, compared to the same period in the prior year primarily reflects the effects of the following factors:

Electric Utility

For the three months ended, electric net income decreased primarily resulting from cooler weather. The average temperature in August 2017 was 67 degrees compared to 73 in August 2016. For the nine months ended, electric net income increased primarily related to efforts to manage the level of operating and maintenance costs.

Transmission Investments

Transmission investment income reflects our share of ATC's earnings and a favorable comparison to 2016, which included an expense reflecting ATC's establishment of a reserve covering its estimate of its refund liability associated with the return on equity complaint filed with FERC. See "Other Matters" below for additional information concerning ATC.

During the first nine months ended of 2017, the following events occurred:

2017 Rate Case Order: 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 on an annual basis and to increase rates for retail gas customers by 1.9% or $3.1 million on an annual basis. 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% based on a capital structure consisting of 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 September 30, 2017, MGE has deferred $3.3 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 long-term unsecured debt in January 2017. The debt carries 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:

2016 Annual Fuel Proceeding: In July 2017, the PSCW issued a final order in the fuel rules proceedings requiring MGE to refund $6.0 million of additional fuel savings realized during 2015 and 2016 to its retail electric customers over a one-month period in October 2017.

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 7.2% and 5.8% of our net income for the nine months ended September 30, 2017 and 2016, respectively, from our investment in ATC. See "Other Matters" below for additional information concerning ATC.

32

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 administrations may affect existing, 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 September 30, 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. In October 2017, the EPA published a proposed rule announcing the EPA's intention to repeal the CPP and has sought public comment on whether to replace the rule, and if so how. Given the pending legal proceedings, and the EPA's proposal, the nature and timing of any final requirements to control GHG emissions from existing fossil fuel-fired EGUs is subject to uncertainty. If a rule is implemented substantially in its present form, it is expected to have a material impact on MGE. MGE will continue to monitor developments with this proposed rule.

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 three and nine months ended September 30, 2017, MGE accrued $1.6 million and $6.7 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 September 30, 2017, and December 31, 2016, MGE classified $6.7 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 April 2017, MGE filed an application with the PSCW to seek approval to construct, own and operate a 66MW wind farm, consisting of 33 turbines, located near Saratoga, Iowa. If approved by the PSCW, construction of the project is expected to begin in early 2018, with an estimated capital cost of $107 million.

Forward Wind: In October 2017, MGE, along with two other utilities, entered into an agreement to purchase the Forward Wind Energy Center, which consists of 86 wind turbines located in Wisconsin with a total capacity of 129 MWs. The aggregate purchase price is approximately $174 million of which MGE's proportionate share is 12.8%, or approximately $23 million. MGE currently purchases 12.8% of the facility's energy output under a purchase power agreement. The transaction is subject to PSCW and FERC approvals and is expected to close in the spring of 2018.

Debt Issuance: In October 2017, MGE issued $30 million of long-term unsecured debt to cover capital expenditures and other corporate obligations. The debt carries an interest rate of 3.11% per annum, over its 10-year term. The covenants of this debt are substantially consistent with MGE's existing unsecured long-term debt.

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

33

Three Months Ended September 30, 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, except cooling degree days)		Three Months Ended September 30,				Three Months Ended September 30,
		2017		2016	% Change	2017	2016	% Change
Residential	$	39,905	$	40,120	(0.5)%	225,992	259,529	(12.9)%
Commercial		64,036		55,232	15.9 %	505,771	517,253	(2.2)%
Industrial		4,555		4,122	10.5 %	48,896	61,362	(20.3)%
Other-retail/municipal		10,459		9,091	15.0 %	119,979	114,097	5.2 %
Total retail		118,955		108,565	9.6 %	900,638	952,241	(5.4)%
Sales to the market		1,068		2,120	(49.6)%	27,581	52,278	(47.2)%
Deferral of fuel savings		-		8,194	(100.0)%	-	-	-  %
Adjustments to revenues		626		54	N/A%	-	-	-  %
Total	$	120,649	$	118,933	1.4 %	928,219	1,004,519	(7.6)%
Cooling degree days (normal 473)						398	570	(30.2)%

Electric operating revenues increased $1.7 million or 1.4% for the three months ended September 30, 2017, compared to the same period in 2016, due to the following:

(In millions)
Deferral of fuel savings/fuel credit	$	9.6
Adjustments to revenues		0.6
Volume		(5.9)
Sales to the market		(1.1)
Other		(0.8)
Rate changes		(0.7)
Total	$	1.7

·

Deferral of fuel savings/fuel credit. During the three months ended September 30, 2016, customers received a fuel credit on their bill related to accumulated fuel savings of $17.8 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.

·

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 September 30, 2017, there was a 20.3% decrease in industrial retail sales volumes compared to the same period in the prior year as a result of a large industrial customer relocating its operations out of state. During the three months ended September 30, 2017, there was a 12.9% decrease in residential sales volumes compared to the same period in the prior year driven by decreased customer demand due, at least in part, to less favorable weather conditions, as evidenced by the lower number of cooling degree days.

·

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 September 30, 2017, market volumes decreased compared to the same period in the prior year, reflecting decreased opportunities for sales and those sales were made at lower 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.

34

·

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

Rates charged to retail customers for the three months ended September 30, 2017, were 2.4% or $0.7 million lower than those charged during the same period in the prior year.

Electric fuel and purchased power

Electric fuel and purchased power costs reflect an increase in the volume of purchased power offset by a decrease in internal generation volumes 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 decreased $4.7 million during the three months ended September 30, 2017, compared to the same period in the prior year, due to the following:

(In millions)
Decrease in volume	$	(3.2)
Decrease in per-unit cost		(1.5)
Total	$	(4.7)

This decrease in expense reflects a 15.8% decrease in internal generation volume delivered to the system primarily as a result of decreased generation at WCCF based on market prices and an 8.4% decrease in per-unit cost of internal electric generation.

Purchased power

Purchased power expense increased $6.8 million during the three months ended September 30, 2017, compared to the same period in the prior year, due to the following:

(In millions)
Change in fuel rule adjustments, net of recoveries	$	5.0
Increase in volume		2.2
Decrease in per-unit cost		(0.4)
Total	$	6.8

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, with potential refunds associated with fuel savings increasing that expense and potential recovery of excess fuel costs decreasing that expense.

The increase in expense (before fuel rules adjustments) reflects a 17.4% increase in the volume of power purchased from third parties partially offset by a 2.5% decrease in the per-unit cost of purchased power.

Electric operating and maintenance expenses

For the three months ended September 30, 2017, electric operating and maintenance expenses increased $0.6 million, compared to the same period in the prior year. The following contributed to the net change:

(In millions)
Increased transmission costs	$	1.3
Increased customer accounts costs		0.5
Decreased production expenses		(0.5)
Decreased distribution expenses		(0.5)
Decreased administrative and general costs		(0.2)
Total	$	0.6

For the three months ended September 30, 2017, increased transmission costs are primarily due to an increase in transmission reliability enhancements.

35

Electric depreciation expense

Electric depreciation expense increased $1.9 million for the three months ended September 30, 2017, compared to the same period in the prior year as a result of new depreciation rates for Columbia, as approved by the PSCW.

Other electric income

Other electric income increased $1.3 million for the three months ended September 30, 2017, compared to the same period in the prior year, primarily due to the gain on sale of property assets.

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 September 30,				Three Months Ended September 30,
		2017		2016	% Change	2017	2016	% Change
Residential	$	12,121	$	11,440	6.0 %	5,841	5,468	6.8 %
Commercial/Industrial		5,622		5,043	11.5 %	8,847	8,488	4.2 %
Total retail		17,743		16,483	7.6 %	14,688	13,956	5.2 %
Gas transportation		944		997	(5.3)%	14,606	15,982	(8.6)%
Other revenues		91		90	1.1 %	-	-	-  %
Total	$	18,778	$	17,570	6.9 %	29,294	29,938	(2.2)%
Heating degree days (normal 158)						138	49	181.6 %
Average rate per therm of
retail customer	$	1.208	$	1.181	2.3 %

Gas revenues increased $1.2 million or 6.9% for the three months ended September 30, 2017, compared to the same period in 2016. These changes are related to the following factors:

(In millions)
Rate/PGA changes	$	0.9
Volume		0.3
Total	$	1.2

·

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 on an annual basis.

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 change net income.

The average retail rate per therm for the three months ended September 30, 2017, increased 2.3% compared to the same period in 2016, reflecting a $0.5 million increase in natural gas commodity costs (recovered through the PGA) and an increase in fixed rate charges.

·

Volume. For the three months ended September 30, 2017, retail gas deliveries increased 5.2% compared to the same period in the prior year.

Cost of gas sold

For the three months ended September 30, 2017, cost of gas sold increased $0.8 million compared to the same period in the prior year. The cost per therm of natural gas increased 10.5%, which resulted in $0.5 million of increased expense. The volume of gas purchased increased 6.9%, which resulted in $0.3 million of increased expense.

36

Gas operating and maintenance expenses

Gas operating and maintenance expenses increased by $0.7 million for the three months ended September 30, 2017, compared to the same period in 2016. The following contributed to the net change:

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

For the three months ended September 30, 2017, increased customer accounts costs are primarily related to technology improvements.

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 September 30, 2017 and 2016, net income at the nonregulated energy operations segment was $4.8 million and $4.7 million, respectively.

Transmission Investment Operations - MGE Energy and MGE

Transmission investment other income

For the three months ended September 30, 2017 and 2016, other income at the transmission investment segment was $2.3 million and $2.0 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 in this Report 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 September 30, 2017 and 2016, was 36.9% and 36.1%, respectively. MGE's effective income tax rate for the three months ended September 30, 2017 and 2016, was 36.7% and 36.0%, respectively. For both MGE Energy and MGE, the increase in the effective tax rate is due in part to lower estimated federal tax credits.

Noncontrolling Interest, Net of Tax - MGE

The noncontrolling interest, net of tax, reflects the accounting required for MGE Energy's interest in MGE Power Elm Road (the Elm Road Units) and MGE Power West Campus (WCCF). MGE Energy owns 100% of MGE Power Elm Road and MGE Power West Campus; however, due to the contractual agreements for these projects with MGE, the entities are considered VIEs with respect to MGE and their results are consolidated with those of MGE, the primary beneficiary of the VIEs. Also included in noncontrolling interest, net of tax, for the three months ended September 30, 2016, was MGE Energy's interest in MGE Transco, which holds our investment in ATC.

37

The following table shows MGE Energy's noncontrolling interest, net of tax, reflected on MGE's consolidated statement of income:

		Three Months Ended
		September 30,
(In millions)		2017		2016
MGE Power Elm Road	$	3.6	$	3.7
MGE Power West Campus		1.8		1.8
MGE Transco(a)		-		0.2

(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 in this Report for additional information.

Nine Months Ended September 30, 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, except cooling degree days)		Nine Months Ended September 30,				Nine Months Ended September 30,
		2017		2016	% Change	2017	2016	% Change
Residential	$	104,892	$	104,917	-%	601,310	641,551	(6.3)%
Commercial		168,921		161,056	4.9 %	1,389,036	1,420,769	(2.2)%
Industrial		13,286		13,381	(0.7)%	153,759	178,535	(13.9)%
Other-retail/municipal		29,141		26,498	10.0 %	315,692	296,093	6.6 %
Total retail		316,240		305,852	3.4 %	2,459,797	2,536,948	(3.0)%
Sales to the market		3,090		5,281	(41.5)%	80,273	161,217	(50.2)%
Deferral of fuel savings		-		1,125	(100.0)%	-	-	-  %
Adjustments to revenues		1,949		212	N/A%	-	-	-  %
Total	$	321,279	$	312,470	2.8 %	2,540,070	2,698,165	(5.9)%
Cooling degree days (normal 653)						570	771	(26.1)%

Electric operating revenues increased $8.8 million or 2.8% for the nine months ended September 30, 2017, compared to the same period in 2016, due to the following:

(In millions)
Deferral of fuel savings/fuel credit	$	20.7
Adjustments to revenue		1.8
Volume		(8.8)
Rate changes		(2.5)
Sales to the market		(2.2)
Other		(0.2)
Total	$	8.8

·

Deferral of fuel savings/fuel credit. During the nine months ended September 30, 2016, customers received a fuel credit on their bill related to accumulated fuel savings of $21.8 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.

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·

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 nine months ended September 30, 2017, there was a 13.9% decrease in industrial retail sales volumes compared to the same period in the prior year as a result of a large industrial customer relocating its operations out of state. During the nine months ended September 30, 2017, there was a 6.3% decrease in residential sales volumes compared to the same period in the prior year driven by decreased customer demand due, at least in part, to less favorable weather conditions, as evidenced by the lower number of cooling degree days.

·

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

Rates charged to retail customers for the nine months ended September 30, 2017, were 2.1% or $2.5 million lower than those charged during the same period in the prior year.

·

Sales to the market. Sales to the market represent wholesale sales made to third parties who are not ultimate users of the electricity. These sales may include spot market transactions on the markets operated by MISO and PJM. These sales may also include bilateral sales to other utilities or power marketers. Generating units are dispatched by MISO based on cost considerations as well as reliability of the system. Sales to the market typically occur when MGE has more generation and purchases online than are needed for its own system demand. The excess electricity is then sold to others in the market. For the nine months ended September 30, 2017, market volumes decreased compared to the same period in the prior year, reflecting decreased opportunities for sales and those sales were made at lower 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.

Electric fuel and purchased power

Electric fuel and purchased power costs reflect an increase in the volume of purchased power offset by a decrease in internal generation volumes 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 decreased $7.6 million during the nine months ended September 30, 2017, compared to the same period in the prior year, due to the following:

(In millions)
Decrease in volume	$	(6.0)
Decrease in per-unit cost		(1.6)
Total	$	(7.6)

This decrease in expense reflects a 13.0% decrease in internal generation volume delivered to the system primarily as a result of decreased generation at WCCF based on market prices and a 3.5% decrease in per-unit cost of internal electric generation.

Purchased power

Purchased power expense increased $9.4 million during the nine months ended September 30, 2017, compared to the same period in the prior year, due to the following:

(In millions)
Change in fuel rule adjustments, net of recoveries	$	8.4
Increase in volume		5.4
Decrease in per-unit cost		(4.4)
Total	$	9.4

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, with potential refunds associated with fuel savings increasing that expense and potential recovery of excess fuel costs decreasing that expense.

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The decrease in expense (before fuel rules adjustments) reflects a 12.2% increase in the volume of power purchased from third parties partially offset by a 9.0% decrease in the per-unit cost of purchased power.

Electric operating and maintenance expenses

Electric operating and maintenance expenses increased $2.5 million during the nine months ended September 30, 2017, compared to the same period in 2016. The following changes contributed to the net change:

(In millions)
Increased transmission costs	$	3.8
Increased customer accounts costs		1.7
Increased customer service costs		0.3
Decreased production expenses		(2.1)
Decreased administrative and general costs		(0.7)
Decreased distribution expenses		(0.5)
Total	$	2.5

For the nine months ended September 30, 2017, increased transmission costs are primarily due to an increase in transmission reliability enhancements and increased customer accounts costs are primarily related to technology improvements, partially offset by decreased production costs at Columbia and the Elm Road Units.

Electric depreciation expense

Electric depreciation expense increased $5.6 million for the nine months ended September 30, 2017, compared to the same period in the prior year as a result of new depreciation rates for Columbia, as approved by the PSCW.

Other electric income

Other electric income increased $1.3 million for the nine months ended September 30, 2017, compared to the same period in the prior year, primarily due to the gain on sale of property assets.

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)		Nine Months Ended September 30,				Nine Months Ended September 30,
		2017		2016	% Change	2017	2016	% Change
Residential	$	61,164	$	56,344	8.6 %	60,794	62,188	(2.2)%
Commercial/Industrial		36,512		32,324	13.0 %	58,865	58,812	0.1 %
Total retail		97,676		88,668	10.2 %	119,659	121,000	(1.1)%
Gas transportation		3,285		3,402	(3.4)%	50,828	53,957	(5.8)%
Other revenues		324		298	8.7 %	-	-	-  %
Total	$	101,285	$	92,368	9.7 %	170,487	174,957	(2.6)%
Heating degree days (normal 4,477)						4,025	4,135	(2.7)%
Average rate per therm of
retail customer	$	0.816	$	0.733	11.3 %

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Gas revenues increased $8.9 million or 9.7% for the nine months ended September 30, 2017, compared to the same period in 2016. These changes are related to the following factors:

(In millions)
Rate/PGA changes	$	9.5
Volume		(0.6)
Total	$	8.9

·

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 on an annual basis.

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 nine months ended September 30, 2017, increased 11.3% compared to the same period in 2016, reflecting a $7.2 million increase in natural gas commodity costs (recovered through the PGA) and an increase in fixed rate charges.

·

Volume. For the nine months ended September 30, 2017, retail gas deliveries decreased 1.1% compared to the same period in the prior year primarily resulting from unfavorable weather conditions.

Cost of gas sold

For the nine months ended September 30, 2017, cost of gas sold increased $6.9 million compared to the same period in the prior year. The cost per therm of natural gas increased 15.9%, which resulted in $6.9 million of increased expense.

Gas operating and maintenance expenses

Gas operating and maintenance expenses increased by $1.7 million for the nine months ended September 30, 2017, compared to the same period in 2016. The following changes contributed to the net change:

(In millions)
Increased customer account costs	$	1.7
Increased customer service costs		0.8
Decreased administrative and general costs		(0.8)
Total	$	1.7

For the nine months ended September 30, 2017, increased customer accounts costs are primarily related to technology improvements.

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 nine months ended September 30, 2017 and 2016, net income at the nonregulated energy operations segment was $14.2 million and $14.3 million, respectively.

Transmission Investment Operations - MGE Energy and MGE

Transmission investment other income

For the nine months ended September 30, 2017 and 2016, other income at the transmission investment segment was $7.2 million and $6.0 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 in this Report and "Other Matters" below for additional information concerning ATC and summarized financial information regarding ATC.

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Consolidated Income Taxes - MGE Energy and MGE

MGE Energy's effective income tax rate for the nine months ended September 30, 2017 and 2016, was 36.6% and 36.4%, respectively. MGE's effective income tax rate for the nine months ended September 30, 2017 and 2016, was 36.3% and 36.4%, respectively.

Noncontrolling Interest, Net of Tax - MGE

The noncontrolling interest, net of tax, reflects the accounting required for MGE Energy's interest in MGE Power Elm Road (the Elm Road Units) and MGE Power West Campus (WCCF). MGE Energy owns 100% of MGE Power Elm Road and MGE Power West Campus; however, due to the contractual agreements for these projects with MGE, the entities are considered VIEs with respect to MGE and their results are consolidated with those of MGE, the primary beneficiary of the VIEs. Also included in noncontrolling interest, net of tax, for the nine months ended September 30, 2016, 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:

		Nine Months Ended
		September 30,
(In millions)		2017		2016
MGE Power Elm Road	$	10.8	$	11.1
MGE Power West Campus		5.4		5.4
MGE Transco(a)		-		1.4

(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 in this Report 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 nine months ended September 30, 2017, except as noted below. 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.

Purchase Contracts - MGE Energy and MGE

See Footnote 7.c. of Notes to Consolidated Financial Statements in this Report for a description of commitments at September 30, 2017, that MGE Energy and MGE have entered with respect to various commodity supply and transportation contracts to meet their obligations to deliver electricity and natural gas to customers.

Other Commitments - MGE Energy

In May 2017, MGE Energy entered a subscription agreement to invest in a nonpublic venture capital fund. From time to time, this entity will require capital infusions from its investors. MGE Energy has committed to contribute $5 million in capital for such infusions. The timing of these infusions is dependent on the needs of the investee and is therefore uncertain at this time.

Long-term Debt - MGE Energy and MGE

MGE issued $40 million of 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. In October 2017, MGE also issued an additional $30 million of long-term unsecured debt to cover capital expenditures and other corporate obligations. See Footnote 2 of the Notes to Consolidated Financial Statements in this Report for further discussion of these debt issuances.

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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. See "Credit Facilities" under Part II, Item 7, Management's Discussion and Analysis of Financial Condition and Results of Operations – Liquidity and Capital Resources in MGE Energy's and MGE's 2016 Annual Report on Form 10-K for information regarding MGE Energy's and MGE's credit facilities.

Cash Flows

The following summarizes cash flows for MGE Energy and MGE during the nine months ended September 30, 2017 and 2016:

		MGE Energy				MGE
(In thousands)		2017		2016		2017		2016
Cash provided by/(used for):
Operating activities	$	99,016	$	129,192	$	94,366	$	128,959
Investing activities		(71,114)		(64,619)		(65,105)		(64,407)
Financing activities		(19,128)		(34,372)		(38,075)		(59,754)

Cash Provided by Operating Activities

MGE Energy

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

Cash provided by operating activities for the nine months ended September 30, 2017, was $99.0 million, a decrease of $30.2 million when compared to the same period in the prior year, primarily reflecting changes in working capital items between the periods.

MGE Energy's net income increased $0.4 million for the nine months ended September 30, 2017, when compared to the same period in the prior year.

In 2016, MGE received a $10.0 million refund from the IRS for the 2015 tax year. Excluding the 2016 refund, MGE Energy's federal and state taxes paid increased $10.2 million during the nine months ended September 30, 2017, when compared to the same period in the prior year.

Working capital accounts (excluding prepaid and accrued taxes) resulted in $13.9 million in cash used for operating activities for the nine months ended September 30, 2017, primarily due to decreased accounts payable and increased inventories, partially offset by decreased unbilled revenues, decreased other current assets, and increased other current liabilities.

Working capital accounts (excluding prepaid and accrued taxes) resulted in $7.6 million in cash provided by operating activities for the nine months ended September 30, 2016, primarily due to decreased inventories, decreased unbilled revenues, increased accounts payable, and increased other current liabilities, partially offset by increased receivables. The increase in current liabilities includes a fuel credit, that was approved in August 2015, of $6.3 million that customers received on their bill from January through September 2016 and a one-time fuel credit, approved in July 2016, of $15.5 million that customers received on their bill in September 2016.

A decrease in pension contribution resulted in an additional $3.4 million in cash provided by operating activities for the nine months ended September 30, 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 nine months ended September 30, 2017, was $94.4 million, a decrease of $34.6 million when compared to the same period in the prior year, primarily reflecting changes in working capital items between the periods.

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Net income decreased $3.3 million for the nine months ended September 30, 2017, when compared to the same period in the prior year.

In 2016, MGE received a $10.0 million refund from the IRS for the 2015 tax year. Excluding the 2016 refund, MGE Energy's federal and state taxes paid increased $10.2 million during the nine months ended September 30, 2017, when compared to the same period in the prior year.

Working capital accounts (excluding prepaid and accrued taxes) resulted in $13.6 million in cash used for operating activities for the nine months ended September 30, 2017, primarily due to decreased accounts payable and increased inventories, partially offset by decreased unbilled revenues, decreased other current assets, and increased other current liabilities.

Working capital accounts (excluding prepaid and accrued taxes) resulted in $7.7 million in cash provided by operating activities for the nine months ended September 30, 2016, primarily due to decreased inventories, decreased unbilled revenues, increased accounts payable, and increased other current liabilities, partially offset by increased receivables. The increase in current liabilities includes a fuel credit, that was approved in August 2015, of $6.3 million that customers received on their bill from January through September 2016 and a one-time fuel credit, approved in July 2016, of $15.5 million that customers received on their bill in September 2016.

A decrease in pension contribution resulted in an additional $3.4 million in cash provided by operating activities for the nine months ended September 30, 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 $6.5 million for the nine months ended September 30, 2017, when compared to the same period in the prior year.

Capital expenditures for the nine months ended September 30, 2017, were $66.3 million. This amount represents an increase of $4.0 million from the expenditures made in the same period in the prior year. This increase primarily reflects increased expenditures on electric distribution assets.

Capital contributions in ATC and other investments increased $4.8 million for the nine months ended September 30, 2017, when compared to the same period in the prior year.

MGE Energy received $2.4 million in proceeds from the sales of property for the nine months ended September 30, 2017.

MGE

MGE's cash used for investing activities increased $0.7 million for the nine months ended September 30, 2017, when compared to the same period in the prior year.

Capital expenditures for the nine months ended September 30, 2017, were $66.3 million. This amount represents an increase of $4.0 million from the expenditures made in the same period in the prior year. This increase primarily reflects increased expenditures on electric distribution assets.

Capital contributions in ATC and other investments decreased $1.6 million for the nine months ended September 30, 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 in this Report for further details.

MGE received $1.8 million in proceeds from the sales of property for the nine months ended September 30, 2017.

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Cash Used for Financing Activities

MGE Energy

Cash used for MGE Energy's financing activities was $19.1 million for the nine months ended September 30, 2017, a decrease of $15.2 million when compared to the same period in the prior year.

For the nine months ended September 30, 2017, dividends paid were $32.5 million compared to $31.1 million in the prior year. This increase was a result of a higher dividend per share ($0.938 vs. $0.898).

During the nine months ended September 30, 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.

For the nine months ended September 30, 2017, short-term borrowings were $7.0 million. There were no short term borrowings for the nine months ended September 30, 2016.

MGE

During the nine months ended September 30, 2017, cash used for MGE's financing activities was $38.1 million, a decrease of $21.7 million when compared to the same period in the prior year.

Dividends paid from MGE to MGE Energy were $35.0 million for the nine months ended September 30, 2017, compared to $40.0 for the nine months ended September 30, 2016.

Distributions to parent from noncontrolling interest, which represent distributions from MGE Power Elm Road and MGE Power West Campus to MGE Energy, were $16.5 million for the nine months ended September 30, 2017, compared to $18.1 million in the prior year.

For the nine months ended September 30, 2016, equity contributions received from noncontrolling interest, which represent contributions to MGE Transco, were $1.6 million. There were no equity contributions received from noncontrolling interest, which represent contributions to MGE Transco for the nine months ended September 30, 2017.

During the nine months ended September 30, 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.

For the nine months ended September 30, 2017, short-term borrowings were $7.0 million. There were no short term borrowings for the nine months ended September 30, 2016.

Capitalization Ratios

MGE Energy's capitalization ratios were as follows:

	MGE Energy
	September 30, 2017	December 31, 2016
Common shareholders' equity	65.3 %	65.2 %
Long-term debt(a)	34.1 %	34.8 %
Short-term debt	0.6 %	-%

(a)

Includes the current portion of long-term debt.

MGE Energy's and MGE's Capital Requirements

MGE Energy's and MGE's liquidity are primarily affected by their capital requirements. During the nine months ended September 30, 2017, capital expenditures for MGE Energy and MGE totaled $66.3 million, which included $63.9 million of capital expenditures for utility operations.

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Credit Ratings

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

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

Environmental Matters

The following discussion is limited to updates or developments in environmental matters that occurred during the nine months ended September 30, 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.

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. In October 2017, the EPA published a proposed rule announcing the EPA's intention to repeal the CPP and has sought public comment on whether to replace the rule, and if so how. Given the pending legal proceedings, and the EPA's proposal, the nature and timing of any final requirements to control GHG emissions from existing fossil fuel-fired EGUs is subject to uncertainty. If a rule is implemented substantially in its present form, it is expected to have a material impact on MGE. MGE will continue to monitor developments with this proposed rule.

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 in the beginning of 2018. 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 expense of $0.7 million for the three months ended September 30, 2016, and a pre-tax expense of $0.2 million and $1.8 million for the nine months ended September 30, 2017 and 2016, respectively, recorded by ATC for this matter representing its estimate of its refund liability. There was not a pre-tax expense for the three months ended September 30, 2017. We derived approximately 7.2% and 5.8% of our net income for the nine months ended September 30, 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 in this Report 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 in this Report 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 September 30, 2017, the fair value of these instruments exceeded their cost basis by $0.9 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 agreement also allows MGE an option to extend the contract after that 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 September 30, 2017, reflects a loss position of $43.1 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 September 30, 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.

48

Item 4. Controls and Procedures.

During the third 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 September 30, 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 September 30, 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.

49

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 in this Report 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*
July 1-31, 2017	23,072	$	64.34	-	-
August 1-31, 2017	9,975		65.54	-	-
September 1-30, 2017	49,666		65.21	-	-
Total	82,713	$	65.01	-	-

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

Item 4. Mine Safety Disclosures.

Not applicable to MGE Energy and MGE.

Item 6. Exhibits.

12

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

Certifications Pursuant to Rule 13a-14(a) and 15d-14(a) of the Securities and Exchange Act of 1934 as to the Quarterly Report on Form 10-Q for the quarter ended September 30, 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

50

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 September 30, 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

51

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: November 3, 2017	/s/ Jeffrey M. Keebler
	Jeffrey M. Keebler President and Chief Executive Officer (Duly Authorized Officer)
Date: November 3, 2017	/s/ Jeffrey C. Newman
	Jeffrey C. Newman Executive Vice President, Chief Financial Officer, Secretary and Treasurer (Chief Financial and Accounting Officer)

52

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: November 3, 2017	/s/ Jeffrey M. Keebler
	Jeffrey M. Keebler President and Chief Executive Officer (Duly Authorized Officer)
Date: November 3, 2017	/s/ Jeffrey C. Newman
	Jeffrey C. Newman Executive Vice President, Chief Financial Officer, Secretary and Treasurer (Chief Financial and Accounting Officer)

53

EX-12

EXHIBIT 12

Madison Gas and Electric Company

Ratio of Earnings to Fixed Charges

Nine Months Ended September 30, 2017

(In thousands)

Earnings
Net income before minority interest	$57,686
Amortization of capitalized interest	396
Federal and state income taxes	32,834
Fixed charges	15,701
Total Earnings as Defined	$106,617
Fixed Charges
Interest expense on long-term debt and other	$14,252
Interest on rentals*	500
Amortization of debt issuance costs	654
AFUDC - borrowed funds	295
Total Fixed Charges	$15,701
Ratio of Earnings to Fixed Charges	6.79X

*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: November 3, 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: November 3, 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:November 3, 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: November 3, 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 September 30, 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: November 3, 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 September 30, 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: November 3, 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 September 30, 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: November 3, 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 September 30, 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: November 3, 2017

XML

Document and Entity Information - shares	9 Months Ended
	Sep. 30, 2017	Oct. 31, 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	Sep. 30, 2017
Amendment Flag	false
Trading Symbol	MGEE
Document Fiscal Year Focus	2017
Document Fiscal Period Focus	Q3
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		9 Months Ended
	Sep. 30, 2017	Sep. 30, 2016	Sep. 30, 2017	Sep. 30, 2016
Operating Revenues:
Electric revenues	$ 120,761	$ 119,147	$ 321,540	$ 313,452
Gas revenues	18,778	17,570	101,285	92,368
Total Operating Revenues	139,539	136,717	422,825	405,820
Operating Expenses:
Fuel for electric generation	15,829	20,505	39,938	47,567
Purchased power	15,984	9,167	48,058	38,698
Cost of gas sold	5,094	4,314	50,109	43,247
Other operations and maintenance	41,529	40,146	128,143	123,839
Depreciation and amortization	13,372	11,212	39,606	33,358
Other general taxes	4,730	4,846	14,509	14,841
Total Operating Expenses	96,538	90,190	320,363	301,550
Operating Income	43,001	46,527	102,462	104,270
Other income, net	3,939	2,105	9,004	6,726
Interest expense, net	(4,727)	(5,038)	(14,507)	(14,995)
Income before income taxes	42,213	43,594	96,959	96,001
Income tax provision	(15,584)	(15,714)	(35,487)	(34,943)
Net Income	$ 26,629	$ 27,880	$ 61,472	$ 61,058
Earnings Per Share of Common Stock (basic and diluted)	$ 0.77	$ 0.80	$ 1.77	$ 1.76
Dividends per share of common stock	$ 0.323	$ 0.308	$ 0.938	$ 0.898
Weighted Average Shares Outstanding (basic and diluted)	34,668	34,668	34,668	34,668

XML

Madison Gas and Electric Company Consolidated Statements of Income (Unaudited) - USD ($) $ in Thousands		3 Months Ended		9 Months Ended
		Sep. 30, 2017	Sep. 30, 2016	Sep. 30, 2017	Sep. 30, 2016
Operating Revenues:
Electric revenues		$ 120,761	$ 119,147	$ 321,540	$ 313,452
Gas revenues		18,778	17,570	101,285	92,368
Total Operating Revenues		139,539	136,717	422,825	405,820
Operating Expenses:
Fuel for electric generation		15,829	20,505	39,938	47,567
Purchased power		15,984	9,167	48,058	38,698
Cost of gas sold		5,094	4,314	50,109	43,247
Other operations and maintenance		41,529	40,146	128,143	123,839
Depreciation and amortization		13,372	11,212	39,606	33,358
Other general taxes		4,730	4,846	14,509	14,841
Total Operating Expenses		96,538	90,190	320,363	301,550
Operating Income		43,001	46,527	102,462	104,270
Other Income and Deductions:
Equity earnings in MGE Transco		2,338	2,023	7,432	6,023
Total Other Income and Deductions		3,939	2,105	9,004	6,726
Interest Expense:
Net Interest Expense		4,727	5,038	14,507	14,995
Net Income		26,629	27,880	61,472	61,058
MGE [Member]
Operating Revenues:
Electric revenues		120,760	119,152	321,543	313,470
Gas revenues		18,779	17,576	101,294	92,390
Total Operating Revenues		139,539	136,728	422,837	405,860
Operating Expenses:
Fuel for electric generation		15,828	20,507	39,939	47,574
Purchased power		15,985	9,171	48,061	38,709
Cost of gas sold		5,094	4,320	50,117	43,269
Other operations and maintenance		41,327	40,003	127,355	123,117
Depreciation and amortization		13,372	11,212	39,606	33,334
Other general taxes		4,730	4,846	14,509	14,841
Income tax provision		14,059	14,934	32,080	32,488
Total Operating Expenses		110,395	104,993	351,667	333,332
Operating Income	[1]	29,144	31,735	71,170	72,528
Other Income and Deductions:
AFUDC - equity funds		310	253	875	777
Equity earnings in MGE Transco		0	1,451	0	5,451
Income tax provision		(663)	(606)	(754)	(2,315)
Other expense, net		1,488	(62)	1,301	(298)
Total Other Income and Deductions	[1]	1,135	1,036	1,422	3,615
Income before interest expense		30,279	32,771	72,592	76,143
Interest Expense:
Interest on long-term debt		4,995	5,079	15,051	15,284
Other interest, net		54	112	150	163
AFUDC - borrowed funds		(123)	(82)	(295)	(253)
Net Interest Expense		4,926	5,109	14,906	15,194
Net Income Including Noncontrolling Interest		25,353	27,662	57,686	60,949
Less Net Income Attributable to Noncontrolling Interest, net of tax		(5,439)	(5,695)	(16,224)	(17,899)
Net Income		$ 19,914	$ 21,967	$ 41,462	$ 43,050

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

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MGE Energy Inc Consolidated Statements of Comprehensive Income (Unaudited) - USD ($) $ in Thousands	3 Months Ended		9 Months Ended
	Sep. 30, 2017	Sep. 30, 2016	Sep. 30, 2017	Sep. 30, 2016
Comprehensive Income [Abstract]
Net Income	$ 26,629	$ 27,880	$ 61,472	$ 61,058
Other comprehensive income, net of tax:
Unrealized gain (loss) on available-for-sale securities, net of tax	60	11	189	(143)
Comprehensive Income	$ 26,689	$ 27,891	$ 61,661	$ 60,915

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Madison Gas and Electric Company Consolidated Statements of Comprehensive Income (Unaudited) - USD ($) $ in Thousands	3 Months Ended		9 Months Ended
	Sep. 30, 2017	Sep. 30, 2016	Sep. 30, 2017	Sep. 30, 2016
Other comprehensive income, net of tax:
Unrealized gain (loss) on available-for-sale securities, net of tax	$ 60	$ 11	$ 189	$ (143)
Comprehensive Income	26,689	27,891	61,661	60,915
MGE [Member]
Net Income	25,353	27,662	57,686	60,949
Other comprehensive income, net of tax:
Unrealized gain (loss) on available-for-sale securities, net of tax	(7)	8	(38)	(31)
Total comprehensive income including noncontrolling interest	25,346	27,670	57,648	60,918
Less: Comprehensive income attributable to Noncontrolling Interest, net of tax	(5,439)	(5,695)	(16,224)	(17,899)
Comprehensive Income	$ 19,907	$ 21,975	$ 41,424	$ 43,019

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Consolidated Statements of Comprehensive Income (Unaudited) (Parantheticals) - USD ($) $ in Thousands	3 Months Ended		9 Months Ended
	Sep. 30, 2017	Sep. 30, 2016	Sep. 30, 2017	Sep. 30, 2016
Unrealized gain (loss) on available-for-sale securities, tax expense (benefit)	$ 40	$ 8	$ 127	$ (96)
MGE [Member]
Unrealized gain (loss) on available-for-sale securities, tax expense (benefit)	$ (5)	$ 5	$ (26)	$ (21)

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MGE Energy Inc Consolidated Statements of Cash Flows (Unaudited) - USD ($) $ in Thousands	9 Months Ended
	Sep. 30, 2017	Sep. 30, 2016
Operating Activities:
Net Income	$ 61,472	$ 61,058
Items not affecting cash:
Depreciation and amortization	39,606	33,358
Deferred income taxes	4,810	15,041
Provision for doubtful receivables	650	583
Employee benefit plan cost	778	165
Equity earnings in ATC	(7,432)	(6,023)
Gain on sale of property	(1,581)	0
Other items	1,071	693
Changes in working capital items:
Decrease in current assets	18,161	33,740
Decrease in current liabilities	(17,615)	(3,147)
Dividends from ATC	6,142	4,214
Cash contributions to pension and other postretirement plans	(9,717)	(13,134)
Other noncurrent items, net	2,671	2,644
Cash Provided by Operating Activities	99,016	129,192
Investing Activities:
Capital expenditures	(66,286)	(62,273)
Capital contributions to investments	(6,863)	(2,036)
Proceeds from sale of property	2,399	0
Other	(364)	(310)
Cash Used for Investing Activities	(71,114)	(64,619)
Financing Activities:
Cash dividends paid on common stock	(32,502)	(31,115)
Repayment of long-term debt	(33,260)	(3,192)
Issuance of long-term debt	40,000	0
Proceeds from short-term debt	7,000	0
Other	(366)	(65)
Cash Used for Financing Activities	(19,128)	(34,372)
Change in cash and cash equivalents	8,774	30,201
Cash and cash equivalents at beginning of period	95,959	81,384
Cash and cash equivalents at end of period	104,733	111,585
Significant noncash investing activities:
Accrued capital expenditures	$ 12,469	$ 10,603

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Madison Gas and Electric Company Consolidated Statements of Cash Flows (Unaudited) - USD ($) $ in Thousands	9 Months Ended
	Sep. 30, 2017	Sep. 30, 2016
Items not affecting cash:
Depreciation and amortization	$ 39,606	$ 33,358
Deferred income taxes	4,810	15,041
Provision for doubtful receivables	650	583
Employee benefit plan cost	778	165
Equity earnings in MGE Transco	(7,432)	(6,023)
Gain on sale of property	(1,581)	0
Other items	1,071	693
Changes in working capital items:
Decrease in current assets	18,161	33,740
Decrease in current liabilities	(17,615)	(3,147)
Dividends from MGE Transco	6,142	4,214
Cash contributions to pension and other postretirement plans	(9,717)	(13,134)
Other noncurrent items, net	2,671	2,644
Cash Provided by Operating Activities	99,016	129,192
Investing Activities:
Capital expenditures	(66,286)	(62,273)
Capital contributions to investments	(6,863)	(2,036)
Proceeds from sale of property	2,399	0
Other	(364)	(310)
Cash Used for Investing Activities	(71,114)	(64,619)
Financing Activities:
Repayment of long-term debt	(33,260)	(3,192)
Issuance of long-term debt	40,000	0
Proceeds from short-term debt	7,000	0
Other	(366)	(65)
Cash Used for Financing Activities	(19,128)	(34,372)
Change in cash and cash equivalents	8,774	30,201
Cash and cash equivalents at beginning of period	95,959	81,384
Cash and cash equivalents at end of period	104,733	111,585
Significant noncash investing activities:
Accrued capital expenditures	12,469	10,603
MGE [Member]
Operating Activities:
Net Income	57,686	60,949
Items not affecting cash:
Depreciation and amortization	39,606	33,334
Deferred income taxes	2,255	13,997
Provision for doubtful receivables	650	583
Employee benefit plan cost	778	165
Equity earnings in MGE Transco	0	(5,451)
Gain on sale of property	(1,581)	0
Other items	1,344	1,056
Changes in working capital items:
Decrease in current assets	17,536	32,557
Decrease in current liabilities	(16,670)	(1,783)
Dividends from MGE Transco	0	4,214
Cash contributions to pension and other postretirement plans	(9,717)	(13,134)
Other noncurrent items, net	2,479	2,472
Cash Provided by Operating Activities	94,366	128,959
Investing Activities:
Capital expenditures	(66,286)	(62,273)
Capital contributions to investments	0	(1,598)
Proceeds from sale of property	1,751	0
Other	(570)	(536)
Cash Used for Investing Activities	(65,105)	(64,407)
Financing Activities:
Cash dividends paid to parent by MGE	(35,000)	(40,000)
Distributions to parent from noncontrolling interest	(16,500)	(18,113)
Equity contribution received by noncontrolling interest	0	1,598
Repayment of long-term debt	(33,260)	(3,192)
Issuance of long-term debt	40,000	0
Proceeds from short-term debt	7,000	0
Other	(315)	(47)
Cash Used for Financing Activities	(38,075)	(59,754)
Change in cash and cash equivalents	(8,814)	4,798
Cash and cash equivalents at beginning of period	10,768	26,760
Cash and cash equivalents at end of period	1,954	31,558
Significant noncash investing activities:
Accrued capital expenditures	$ 12,469	$ 10,603

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Consolidated Balance Sheets (Unaudited) - USD ($) $ in Thousands	Sep. 30, 2017	Dec. 31, 2016
Current Assets:
Cash and cash equivalents	$ 104,733	$ 95,959
Accounts receivable, less reserves	38,129	39,887
Other accounts receivables, less reserves	7,588	8,530
Unbilled revenues	21,764	29,846
Materials and supplies, at average cost	21,835	18,561
Fossil fuel, at average cost	10,017	9,757
Stored natural gas, at average cost	14,758	12,819
Prepaid taxes	12,406	26,636
Regulatory assets - current	7,377	6,414
Assets held for sale	6,707	14,813
Other current assets	10,043	12,293
Total Current Assets	255,357	275,515
Regulatory assets	146,006	158,485
Pension and other postretirement benefit asset	3,471	2,020
Other deferred assets and other	6,311	6,691
Property, Plant, and Equipment:
Property, plant, and equipment, net	1,270,124	1,245,269
Construction work in progress	42,276	36,790
Total Property, Plant, and Equipment	1,312,400	1,282,059
Investments	86,455	76,290
Total Assets	1,810,000	1,801,060
Current Liabilities:
Long-term debt due within one year	4,428	4,333
Short-term debt	7,000	0
Accounts payable	31,519	47,799
Accrued interest and taxes	4,750	5,495
Accrued payroll related items	9,981	11,892
Regulatory liabilities - current	6,353	6,910
Derivative liabilities	8,288	7,620
Other current liabilities	12,263	19,456
Total Current Liabilities	84,582	103,505
Other Credits:
Deferred income taxes	389,179	383,813
Investment tax credit - deferred	885	947
Regulatory liabilities	28,253	22,173
Accrued pension and other postretirement benefits	65,616	74,347
Derivative liabilities	34,890	42,970
Other deferred liabilities and other	63,942	66,426
Total Other Credits	582,765	590,676
Capitalization:
Common shareholders equity	753,247	724,088
Long-term debt	389,406	382,791
Total Capitalization	1,142,653	1,106,879
Commitments and contingencies (see Footnote 7)
Total Liabilities and Capitalization	1,810,000	1,801,060
MGE [Member]
Current Assets:
Cash and cash equivalents	1,954	10,768
Accounts receivable, less reserves	38,129	39,887
Affiliate receivables	683	539
Other accounts receivables, less reserves	7,529	6,363
Unbilled revenues	21,764	29,846
Materials and supplies, at average cost	21,835	18,561
Fossil fuel, at average cost	10,017	9,757
Stored natural gas, at average cost	14,758	12,819
Prepaid taxes	12,524	25,798
Regulatory assets - current	7,377	6,414
Assets held for sale	6,707	14,813
Other current assets	10,010	12,268
Total Current Assets	153,287	187,833
Affiliate receivable long-term	3,839	4,236
Regulatory assets	146,006	158,485
Pension and other postretirement benefit asset	3,471	2,020
Other deferred assets and other	4,066	4,353
Property, Plant, and Equipment:
Property, plant, and equipment, net	1,270,153	1,244,648
Construction work in progress	42,276	36,790
Total Property, Plant, and Equipment	1,312,429	1,281,438
Investments	423	487
Total Assets	1,623,521	1,638,852
Current Liabilities:
Long-term debt due within one year	4,428	4,333
Short-term debt	7,000	0
Accounts payable	31,508	47,790
Accrued interest and taxes	5,717	5,440
Accrued payroll related items	9,981	11,892
Regulatory liabilities - current	6,353	6,910
Derivative liabilities	8,288	7,620
Other current liabilities	12,079	19,347
Total Current Liabilities	85,354	103,332
Other Credits:
Deferred income taxes	346,278	343,117
Investment tax credit - deferred	885	947
Regulatory liabilities	28,253	22,173
Accrued pension and other postretirement benefits	65,616	74,347
Derivative liabilities	34,890	42,970
Other deferred liabilities and other	63,942	66,426
Total Other Credits	539,864	549,980
Capitalization:
Common shareholders equity	493,508	487,084
Noncontrolling interest	115,389	115,665
Total Equity	608,897	602,749
Long-term debt	389,406	382,791
Total Capitalization	998,303	985,540
Commitments and contingencies (see Footnote 7)
Total Liabilities and Capitalization	$ 1,623,521	$ 1,638,852

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Consolidated Balance Sheets (Unaudited) (Parentheticals) - USD ($) $ in Thousands	Sep. 30, 2017	Dec. 31, 2016
Receivables, Net
Reserve for uncollectible accounts receivable	$ 2,950	$ 3,017
Reserve for uncollectible other accounts receivable	372	426
MGE [Member]
Receivables, Net
Reserve for uncollectible accounts receivable	2,950	3,017
Reserve for uncollectible other accounts receivable	$ 372	$ 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	61,058			61,058
Other comprehensive income (loss)	(143)				(143)
Common stock dividends declared	(31,115)			(31,115)
Ending balance, shares at Sep. 30, 2016		34,668
Ending balance, value at Sep. 30, 2016	720,258	$ 34,668	316,268	369,108	214
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	61,472			61,472
Other comprehensive income (loss)	189				189
Common stock dividends declared	(32,502)			(32,502)
Ending balance, shares at Sep. 30, 2017		34,668
Ending balance, value at Sep. 30, 2017	$ 753,247	$ 34,668	$ 316,268	$ 401,920	$ 391

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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		60,949				43,050			17,899
Other comprehensive income (loss)	$ (143)	(31)					$ (143)	(31)
Cash dividends paid to parent by MGE		(40,000)				(40,000)
Equity contribution received by noncontrolling interest		1,598							1,598
Distributions to parent from noncontrolling interest		(18,113)							(18,113)
Deconsolidation of noncontrolling interest		(25,486)							(25,486)
Ending balance, shares at Sep. 30, 2016			34,668	17,348
Ending balance, value at Sep. 30, 2016		620,901		$ 17,348	192,417	294,938		(8)	116,206
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		57,686				41,462			16,224
Other comprehensive income (loss)	$ 189	(38)					$ 189	(38)
Cash dividends paid to parent by MGE		(35,000)				(35,000)
Distributions to parent from noncontrolling interest		(16,500)							(16,500)
Ending balance, shares at Sep. 30, 2017			34,668	17,348
Ending balance, value at Sep. 30, 2017		$ 608,897		$ 17,348	$ 192,417	$ 283,762		$ (19)	$ 115,389

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Consolidated Statements of Common Equity (Unaudited) (Parentheticals) - $ / shares	3 Months Ended		9 Months Ended
	Sep. 30, 2017	Sep. 30, 2016	Sep. 30, 2017	Sep. 30, 2016
Consolidated Statements of Common Equity
Dividends per share of common stock	$ 0.323	$ 0.308	$ 0.938	$ 0.898

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Basis of Presentation

9 Months Ended

Sep. 30, 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 (the 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 September 30,2017, and for the three and nine 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 the2016 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

9 Months Ended

Sep. 30, 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 and nine months endedSeptember 30,2017 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 stock option or stock award programs or 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 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.

On October 2, 2017, MGE issued $30 million of 3.11% senior unsecured notes due October 1, 2027. MGE will use the net proceeds from the sale of senior notes to cover capital expenditures and other corporate obligations. The long-term debt carries an interest rate of 3.11% per annum over its 10-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

9 Months Ended

Sep. 30, 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 and nine months endedSeptember 30,2017 and 2016, MGE Transco recorded the following:

		Three Months Ended				Nine Months Ended
		September 30,				September 30,
(In thousands)		2017		2016		2017		2016
Equity earnings from investment in ATC	$	2,338	$	2,023	$	7,432	$	6,023
Dividends from ATC(a)		2,070		1,486		4,070		4,214
Capital contributions to ATC		710		888		3,018		1,598

(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.

AtSeptember 30,2017, and December 31, 2016, MGE Transco held a 3.6% ownership interest in ATC.AtSeptember 30,2017, and December 31, 2016, MGEE Transco held a 4.4% and 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 and nine months endedSeptember 30,2017 and 2016, is as follows:

		Three Months Ended				Nine Months Ended
		September 30,				September 30,
(In thousands)		2017		2016		2017		2016
Operating revenues	$	171,123	$	158,126	$	522,402	$	476,591
Operating expenses		(85,063)		(80,271)		(250,116)		(241,034)
Other income, net		796		1,128		1,615		2,563
Interest expense, net		(28,273)		(24,624)		(81,188)		(73,714)
Earnings before members' income taxes	$	58,583	$	54,359	$	192,713	$	164,406

MGE receives transmission and other related services from ATC. During the three and nine months endedSeptember 30,2017, MGE recorded $7.3 million and $21.9 million, respectively, for transmission services received compared to $7.4 million and $22.1 million for the comparable periods in 2016. MGE also provides a variety of operational, maintenance, and project management services for ATC, which is reimbursed by ATC. As of September 30,2017 and December 31, 2016, MGE had a receivable due from ATC of $0.1 million.

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Taxes

9 Months Ended

Sep. 30, 2017

Income Tax Disclosure [Abstract]

Taxes

Taxes - MGE Energy and MGE.

MGE Energy's effective income tax rate for the three months endedSeptember 30,2017 and 2016, was 36.9% and 36.1%, respectively. MGE's effective income tax rate for the three months endedSeptember 30,2017 and 2016, was 36.7% and 36.0%, respectively. For both MGE Energy and MGE, the increase in the effective tax rate is due in part to lower estimated federal tax credits.

MGE Energy's effective income tax rate for the nine months endedSeptember 30,2017 and 2016, was 36.6% and 36.4%, respectively. MGE's effective income tax rate for the nine months endedSeptember 30,2017 and 2016, was 36.3% and 36.4%, respectively.

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Pension and Other Postretirement Plans

9 Months Ended

Sep. 30, 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 and nine months endedSeptember 30,2017 and 2016. A portion of the net periodic benefit cost is capitalized within the consolidated balance sheets.

		Three Months Ended				Nine Months Ended
		September 30,				September 30,
(In thousands)		2017		2016		2017		2016
Pension Benefits
Components of net periodic benefit cost:
Service cost	$	1,351	$	1,413	$	4,043	$	4,358
Interest cost		3,168		3,161		9,481		9,744
Expected return on assets		(5,762)		(5,724)		(17,244)		(17,646)
Amortization of:
Prior service (credit) cost		(4)		3		(12)		8
Actuarial loss		1,594		1,388		4,769		4,278
Net periodic benefit cost	$	347	$	241	$	1,037	$	742
Postretirement Benefits
Components of net periodic benefit cost:
Service cost	$	315	$	361	$	944	$	1,084
Interest cost		678		753		2,034		2,258
Expected return on assets		(722)		(787)		(2,165)		(2,360)
Amortization of:
Transition obligation		1		1		2		3
Prior service credit		(667)		(744)		(2,001)		(2,233)
Actuarial loss		190		178		570		533
Net periodic benefit credit	$	(205)	$	(238)	$	(616)	$	(715)

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Share-Based Compensation

9 Months Ended

Sep. 30, 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 its 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 atSeptember 30,2017, 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 and nine months endedSeptember 30,2017, MGE recorded $0.3 million and $1.0 million, respectively, in compensation expense as a result of awards under the plans compared to $0.2 million and $2.0 million for the comparable periods in 2016. In January 2017, cash payments of $2.0 million were distributed according to the terms of the awards granted earlier under the plans that had reached their payment dates. No forfeitures of units occurred during the three and nine months endedSeptember 30,2017 and 2016. At September 30,2017, $5.1 million of outstanding awards are vested, and of this amount, no cash settlements have occurred.

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Commitments and Contingencies

9 Months Ended

Sep. 30, 2017

Commitments and Contingencies Disclosure [Abstract]

Commitments and Contingencies

Commitments and Contingencies.

a. Environmental - MGE Energy and MGE.

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 (the Clean Power Plan, or CPP). Implementation of the rule is expected to have a direct impact on existing coal and natural gas fired generating units, including possible changes in dispatch and additional operating costs. In May 2017, the EPA requested the U.S. Court of Appeals for the D.C. Circuit to put on hold, indefinitely, any ongoing challenges to the rules while the EPA reviews the rule and undertakes any potential rulemaking. In October 2017, the EPA published a proposed rule announcing the EPA's intention to repeal the CPPand has sought public comment on whether to replace the rule, and if so how. Given the pending legal proceedings, and the EPA's recent proposal, the nature and timing of any final requirements to control GHG emissions from existing fossil fuel-fired EGUs is subject to uncertainty. If a rule is implemented substantially in its present form, it is expected to have a material impact on MGE. MGE will continue to monitor developments with this proposed rule.

•Federal and state air quality regulations impose restrictions on various emissions including emissions of sulfur dioxide (SO₂), nitrogen dioxide (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 were delayed following a request by the EPA. The EPA missed its regulatory deadline to designate areas as attainment or nonattainment under the 2015 standard. MGE will continue to monitor the EPA's progress on attainment designations 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 uncertainties surrounding the ongoing implementation of Phase II of CSAPR and 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 the 2016 Annual Report on Form 10-K.

b. Legal Matters - MGE Energy and MGE.

MGE is involved in various legal matters that are being defended and handled in the normal course of business. 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.

c. Purchase Contracts - MGE Energy and MGE.

MGE has entered into various commodity supply, transportation, and storage contracts to meet its obligation to deliver electricity and natural gas to customers. Management expects to recover these costs in future customer rates. As of September 30,2017, the future commitments related to these purchase contracts were as follows:

(In thousands)		2017		2018		2019		2020		2021		Thereafter
Coal(a)	$	6,402	$	19,685	$	13,497	$	3,445	$	-	$	-
Natural gas
Transportation & storage(b)		6,073		20,839		19,680		15,423		8,660		24,373
Supply(c)		11,243		11,817		-		-		-		-
	$	23,718	$	52,341	$	33,177	$	18,868	$	8,660	$	24,373

(a) Total coal commitments for the Columbia and Elm Road Units, including transportation. Fuel procurement for MGE's jointly owned Columbia and Elm Road Units is handled by WPL and WEPCO, respectively, who are the operators of those facilities.

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

(c)These commitments include market-based pricing.

d.Other Commitments - MGE Energy.

InMay 2017, MGE Energy entered into a subscription agreement to invest in a nonpublic venture capital fund. From time to time, this entity will require capital infusions from its investors. MGE Energy has committed to contribute $5million in capital for such infusions. The timing of these infusions is dependent on the needs of the investee and is therefore uncertain at this time.

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Rate Matters

9 Months Ended

Sep. 30, 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 on an annual basis and to increase rates for retail gas customers by 1.9% or $3.1million on an annual basis. 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% based on a capital structure consisting of 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. MGE did not file 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. 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 July 2016, the PSCW issued a final order in the fuel rules proceedings requiring MGE to refund 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.

In July 2017, the PSCW issued a final order in the fuel rules proceedings requiring MGE to refund $6.0million of additional fuel savings realized during 2015 and 2016 to its retail electric customers over a one-month period in October 2017.

As of September 30,2017, MGE has deferred $3.3 million of 2017 fuel savings. The 2017 fuel savings 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

9 Months Ended

Sep. 30, 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 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 depending on whether the derivative is in a net loss or net gain position, respectively. 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:

	September 30, 2017	December 31, 2016
Commodity derivative contracts	634,605 MWh	393,395 MWh
Commodity derivative contracts	7,924,500 Dth	4,195,000 Dth
FTRs	3,552 MW	2,251 MW
PPA	2,800 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 September 30,2017, and December 31, 2016, the fair value of exchange traded derivatives and FTRs exceeded their cost basis by $0.9 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 September 30,2017, and December 31, 2016, reflects a loss position of $43.1 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 September 30,2017, and December 31, 2016, the receivable – margin account balance of $1.5million and $1.3 million, respectively, is shown net of any collateral posted against derivative positions.

		Derivative		Derivative
(In thousands)		Assets		Liabilities	Balance Sheet Location
September 30, 2017
Commodity derivative contracts(a)	$	857	$	560	Other current assets(b)
Commodity derivative contracts(a)		112		122	Other deferred charges
FTRs		567		-	Other current assets
PPA		N/A		8,240	Derivative liability (current)
PPA		N/A		34,890	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 September 30,2017, and December 31, 2016, no collateral was posted against and netted with derivative liability positions on the consolidated balance sheets.

(b)As of September 30,2017, $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
September 30, 2017
Commodity derivative contracts	$	969	$	(634)	$	-	$	335
FTRs		567		-		-		567
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
September 30, 2017
Commodity derivative contracts	$	682	$	(634)	$	-	$	48
PPA		43,130		-		-		43,130
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 September 30,2017 and 2016, and the consolidated income statements for the three and nine months endedSeptember 30,2017 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 September 30:
Balance at July 1,	$	45,316	$	618	$	50,521	$	659
Unrealized gain		(1,277)		-		(663)		-
Realized (loss) gain reclassified to a deferred account		(313)		313		17		(17)
Realized (loss) gain reclassified to income statement		(1,450)		(57)		(304)		46
Balance at September 30,	$	42,276	$	874	$	49,571	$	688
Nine Months Ended September 30:
Balance at January 1,	$	49,281	$	230	$	54,082	$	1,208
Unrealized (gain) loss		(3,698)		-		1,128		-
Realized (loss) gain reclassified to a deferred account		(935)		935		(1,417)		1,417
Realized loss reclassified to income statement		(2,372)		(291)		(4,222)		(1,937)
Balance at September 30,	$	42,276	$	874	$	49,571	$	688

		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 September 30:
Commodity derivative contracts	$	362	$	18	$	45	$	-
FTRs		(224)		-		(703)		-
PPA		1,351		-		916		-
Nine Months Ended September 30:
Commodity derivative contracts	$	764	$	227	$	1,469	$	1,814
FTRs		(1,349)		-		(635)		-
PPA		3,021		-		3,511		-

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 September 30,2017, 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 September 30,2017, 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 September 30,2017,no counterparties have defaulted.

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Fair Value of Financial Instruments

9 Months Ended

Sep. 30, 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 September 30,2017, 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 September 30,2017, 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:

		September 30, 2017				December 31, 2016
(In thousands)		Carrying Amount		Fair Value		Carrying Amount		Fair Value
MGE Energy
Assets:
Cash and cash equivalents	$	104,733	$	104,733	$	95,959	$	95,959
Liabilities:
Short-term debt - commercial paper		7,000		7,000		-		-
Long-term debt(a)		397,981		444,195		391,242		430,122
MGE
Assets:
Cash and cash equivalents	$	1,954	$	1,954	$	10,768	$	10,768
Liabilities:
Short-term debt - commercial paper		7,000		7,000		-		-
Long-term debt(a)		397,981		444,195		391,242		430,122
(a) Includes long-term debt due within one year. Excludes debt issuance costs and unamortized discount of
$4.1 million at September 30, 2017, and December 31, 2016.

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 September 30, 2017
(In thousands)		Total		Level 1		Level 2		Level 3
MGE Energy
Assets:
Derivatives	$	1,536	$	673	$	-	$	863
Exchange-traded investments		816		816		-		-
Total Assets	$	2,352	$	1,489	$	-	$	863
Liabilities:
Derivatives	$	43,812	$	190	$	-	$	43,622
Deferred compensation		3,150		-		3,150		-
Total Liabilities	$	46,962	$	190	$	3,150	$	43,622
MGE
Assets:
Derivatives	$	1,536	$	673	$	-	$	863
Exchange-traded investments		78		78		-		-
Total Assets	$	1,614	$	751	$	-	$	863
Liabilities:
Derivatives	$	43,812	$	190	$	-	$	43,622
Deferred compensation		3,150		-		3,150		-
Total Liabilities	$	46,962	$	190	$	3,150	$	43,622

		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 nine months endedSeptember 30,2017.

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. 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	September 30, 2017	December 31, 2016
Basis adjustment:
On peak	92.4%	91.9%
Off peak	94.2%	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				Nine Months Ended
		September 30,				September 30,
(In thousands)		2017		2016		2017		2016
Beginning balance	$	(45,605)	$	(51,883)	$	(50,305)	$	(53,501)
Realized and unrealized gains (losses):
Included in regulatory liabilities		2,846		1,455		7,547		3,073
Included in other comprehensive income		-		-		-		-
Included in earnings		(1,478)		(278)		(2,614)		(4,250)
Included in current assets		(14)		-		(111)		-
Purchases		6,299		5,814		18,481		16,751
Sales		-		-		-		-
Issuances		-		-		-		-
Settlements		(4,807)		(5,537)		(15,757)		(12,502)
Transfers in and/or out of Level 3		-		-		-		-
Balance as of September 30,	$	(42,759)	$	(50,429)	$	(42,759)	$	(50,429)
Total gains (losses) included in earnings attributed to
the change in unrealized gains (losses) related to
assets and liabilities held at September 30,(b)	$	-	$	-	$	-	$	-

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

		Three Months Ended				Nine Months Ended
		September 30,				September 30,
(In thousands)		2017		2016		2017		2016
Purchased Power Expense	$	(1,460)	$	(278)	$	(2,377)	$	(4,250)
Cost of Gas Sold Expense		(18)		-		(237)		-
Total	$	(1,478)	$	(278)	$	(2,614)	$	(4,250)

(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

9 Months Ended

Sep. 30, 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 June 2017, the FERC approved the ownership transfer in Columbia, effective January 1, 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 and nine months endedSeptember 30,2017, MGE accrued $1.6million and $6.7 million, respectively, of 2017 capital expenditures that MGE has forgone subject to the ownership transfer agreement. As of September 30,2017, MGE classified $6.7 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

9 Months Ended

Sep. 30, 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 materially 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.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. As of September 30, 2017, MGE Energy had $0.4 million and MGE had less than $0.1 million of accumulated other comprehensive income related to equity investments within the scope of this standard.

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 September 30, 2017, and December 31, 2016, MGE Energy and MGE had$4.5 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 (together, net benefit cost). This authoritative guidance will become effective January 1, 2018. 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. A practical expedient within the standard permits an employer to use the amounts disclosed in its pension and other postretirement benefit plan footnote for prior comparative periods as the estimation basis for applying the retrospective presentation requirements. MGE Energy and MGE have elected to apply the practical expedient. Operating income will decrease and other income will increase $6.6 million and $5.0 millionfor the years ended December 31, 2016 and 2015, respectively. The standard also only allows the service cost component to be eligible for capitalization prospectively from the effective date of the pronouncement (whereas under current GAAP, all components of net benefit cost are eligible for capitalization). MGE Energy and MGE are currently evaluating the impact of how the change in components of net benefit cost eligible for capitalization will affect our financial statements.

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Segment Information

9 Months Ended

Sep. 30, 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 the2016 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 September 30, 2017
Operating revenues	$	120,649	$	18,778	$	112	$	-	$	-	$	-	$	139,539
Interdepartmental revenues		(110)		3,892		11,130		-		-		(14,912)		-
Total operating revenues		120,539		22,670		11,242		-		-		(14,912)		139,539
Depreciation and amortization		(9,256)		(2,258)		(1,858)		-		-		-		(13,372)
Other operating expenses		(78,886)		(18,940)		(50)		(9)		(193)		14,912		(83,166)
Operating income (loss)		32,397		1,472		9,334		(9)		(193)		-		43,001
Other income (deductions), net		1,440		358		-		2,258		(117)		-		3,939
Interest (expense) income, net		(2,760)		(795)		(1,371)		-		199		-		(4,727)
Income (loss) before taxes		31,077		1,035		7,963		2,249		(111)		-		42,213
Income tax (provision) benefit		(11,175)		(351)		(3,196)		(906)		44		-		(15,584)
Net income (loss)	$	19,902	$	684	$	4,767	$	1,343	$	(67)	$	-	$	26,629
Three Months Ended September 30, 2016
Operating revenues	$	118,933	$	17,570	$	214	$	-	$	-	$	-	$	136,717
Interdepartmental revenues		459		6,040		10,998		-		-		(17,497)		-
Total operating revenues		119,392		23,610		11,212		-		-		(17,497)		136,717
Depreciation and amortization		(7,332)		(2,047)		(1,833)		-		-		-		(11,212)
Other operating expenses		(77,010)		(19,292)		(33)		(13)		(127)		17,497		(78,978)
Operating income (loss)		35,050		2,271		9,346		(13)		(127)		-		46,527
Other income (deductions), net		178		13		-		2,023		(109)		-		2,105
Interest (expense) income, net		(2,855)		(818)		(1,436)		-		71		-		(5,038)
Income (loss) before taxes		32,373		1,466		7,910		2,010		(165)		-		43,594
Income tax (provision) benefit		(11,290)		(494)		(3,175)		(812)		57		-		(15,714)
Net income (loss)	$	21,083	$	972	$	4,735	$	1,198	$	(108)	$	-	$	27,880
Nine Months Ended September 30, 2017
Operating revenues	$	321,279	$	101,285	$	261	$	-	$	-	$	-	$	422,825
Interdepartmental revenues		(334)		11,708		33,307		-		-		(44,681)		-
Total operating revenues		320,945		112,993		33,568		-		-		(44,681)		422,825
Depreciation and amortization		(27,341)		(6,703)		(5,562)		-		-		-		(39,606)
Other operating expenses		(231,827)		(92,670)		(153)		(9)		(779)		44,681		(280,757)
Operating income (loss)		61,777		13,620		27,853		(9)		(779)		-		102,462
Other income (deductions), net		1,821		355		-		7,242		(414)		-		9,004
Interest (expense) income, net		(8,337)		(2,399)		(4,170)		-		399		-		(14,507)
Income (loss) before taxes		55,261		11,576		23,683		7,233		(794)		-		96,959
Income tax (provision) benefit		(18,753)		(4,576)		(9,505)		(2,909)		256		-		(35,487)
Net income (loss)	$	36,508	$	7,000	$	14,178	$	4,324	$	(538)	$	-	$	61,472
Nine Months Ended September 30, 2016
Operating revenues	$	312,470	$	92,368	$	982	$	-	$	-	$	-	$	405,820
Interdepartmental revenues		1,482		17,278		32,894		-		-		(51,654)		-
Total operating revenues		313,952		109,646		33,876		-		-		(51,654)		405,820
Depreciation and amortization		(21,754)		(6,043)		(5,537)		-		(24)		-		(33,358)
Other operating expenses		(230,680)		(88,328)		(115)		(17)		(706)		51,654		(268,192)
Operating income (loss)		61,518		15,275		28,224		(17)		(730)		-		104,270
Other income (deductions), net		492		(13)		-		6,023		224		-		6,726
Interest (expense) income, net		(8,421)		(2,425)		(4,348)		-		199		-		(14,995)
Income (loss) before taxes		53,589		12,837		23,876		6,006		(307)		-		96,001
Income tax (provision) benefit		(17,984)		(5,048)		(9,583)		(2,418)		90		-		(34,943)
Net income (loss)	$	35,605	$	7,789	$	14,293	$	3,588	$	(217)	$	-	$	61,058

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 September 30, 2017
Operating revenues	$	120,648	$	18,779	$	112	$	-	$	-	$	139,539
Interdepartmental revenues		(109)		3,891		11,130		-		(14,912)		-
Total operating revenues		120,539		22,670		11,242		-		(14,912)		139,539
Depreciation and amortization		(9,256)		(2,258)		(1,858)		-		-		(13,372)
Other operating expenses(a)		(89,544)		(19,145)		(3,246)		-		14,912		(97,023)
Operating income(a)		21,739		1,267		6,138		-		-		29,144
Other income, net(a)		923		212		-		-		-		1,135
Interest expense, net		(2,760)		(795)		(1,371)		-		-		(4,926)
Net income		19,902		684		4,767		-		-		25,353
Less: Net income attributable to
noncontrolling interest, net of tax		-		-		-		-		(5,439)		(5,439)
Net income attributable to MGE	$	19,902	$	684	$	4,767	$	-	$	(5,439)	$	19,914
Three Months Ended September 30, 2016
Operating revenues	$	118,938	$	17,576	$	214	$	-	$	-	$	136,728
Interdepartmental revenues		454		6,034		10,998		-		(17,486)		-
Total operating revenues		119,392		23,610		11,212		-		(17,486)		136,728
Depreciation and amortization		(7,332)		(2,047)		(1,833)		-		-		(11,212)
Other operating expenses(a)		(88,282)		(19,781)		(3,208)		4		17,486		(93,781)
Operating income(a)		23,778		1,782		6,171		4		-		31,735
Other income, net(a)		160		8		-		868		-		1,036
Interest expense, net		(2,855)		(818)		(1,436)		-		-		(5,109)
Net income		21,083		972		4,735		872		-		27,662
Less: Net income attributable to
noncontrolling interest, net of tax		-		-		-		-		(5,695)		(5,695)
Net income attributable to MGE	$	21,083	$	972	$	4,735	$	872	$	(5,695)	$	21,967
Nine Months Ended September 30, 2017
Operating revenues	$	321,282	$	101,294	$	261	$	-	$	-	$	422,837
Interdepartmental revenues		(337)		11,699		33,307		-		(44,669)		-
Total operating revenues		320,945		112,993		33,568		-		(44,669)		422,837
Depreciation and amortization		(27,341)		(6,703)		(5,562)		-		-		(39,606)
Other operating expenses(a)		(249,992)		(97,080)		(9,658)		-		44,669		(312,061)
Operating income(a)		43,612		9,210		18,348		-		-		71,170
Other income, net(a)		1,233		189		-		-		-		1,422
Interest expense, net		(8,337)		(2,399)		(4,170)		-		-		(14,906)
Net income		36,508		7,000		14,178		-		-		57,686
Less: Net income attributable to
noncontrolling interest, net of tax		-		-		-		-		(16,224)		(16,224)
Net income attributable to MGE	$	36,508	$	7,000	$	14,178	$	-	$	(16,224)	$	41,462
Nine Months Ended September 30, 2016
Operating revenues	$	312,488	$	92,390	$	982	$	-	$	-	$	405,860
Interdepartmental revenues		1,464		17,256		32,894		-		(51,614)		-
Total operating revenues		313,952		109,646		33,876		-		(51,614)		405,860
Depreciation and amortization		(21,754)		(6,043)		(5,537)		-		-		(33,334)
Other operating expenses(a)		(248,566)		(93,348)		(9,698)		-		51,614		(299,998)
Operating income(a)		43,632		10,255		18,641		-		-		72,528
Other income (deductions), net(a)		394		(41)		-		3,262		-		3,615
Interest expense, net		(8,421)		(2,425)		(4,348)		-		-		(15,194)
Net income		35,605		7,789		14,293		3,262		-		60,949
Less: Net income attributable to
noncontrolling interest, net of tax		-		-		-		-		(17,899)		(17,899)
Net income attributable to MGE	$	35,605	$	7,789	$	14,293	$	3,262	$	(17,899)	$	43,050
(a) Amounts are shown net of the related tax expense, consistent with the presentation on the MGE Consolidated Statement 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 further discussion.

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Significant Accounting Policies (Policies)

9 Months Ended

Sep. 30, 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 its 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 atSeptember 30,2017, 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 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 depending on whether the derivative is in a net loss or net gain position, respectively. 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 September 30,2017, 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 September 30,2017, 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. 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	September 30, 2017	December 31, 2016
Basis adjustment:
On peak	92.4%	91.9%
Off peak	94.2%	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 materially 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.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. As of September 30, 2017, MGE Energy had $0.4 million and MGE had less than $0.1 million of accumulated other comprehensive income related to equity investments within the scope of this standard.

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 September 30, 2017, and December 31, 2016, MGE Energy and MGE had$4.5 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 (together, net benefit cost). This authoritative guidance will become effective January 1, 2018. 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. A practical expedient within the standard permits an employer to use the amounts disclosed in its pension and other postretirement benefit plan footnote for prior comparative periods as the estimation basis for applying the retrospective presentation requirements. MGE Energy and MGE have elected to apply the practical expedient. Operating income will decrease and other income will increase $6.6 million and $5.0 millionfor the years ended December 31, 2016 and 2015, respectively. The standard also only allows the service cost component to be eligible for capitalization prospectively from the effective date of the pronouncement (whereas under current GAAP, all components of net benefit cost are eligible for capitalization). MGE Energy and MGE are currently evaluating the impact of how the change in components of net benefit cost eligible for capitalization will affect our financial statements.

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Investment in ATC and ATC Holdco (Tables)

9 Months Ended

Sep. 30, 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 and nine months endedSeptember 30,2017 and 2016, MGE Transco recorded the following:

		Three Months Ended				Nine Months Ended
		September 30,				September 30,
(In thousands)		2017		2016		2017		2016
Equity earnings from investment in ATC	$	2,338	$	2,023	$	7,432	$	6,023
Dividends from ATC(a)		2,070		1,486		4,070		4,214
Capital contributions to ATC		710		888		3,018		1,598

(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 and nine months endedSeptember 30,2017 and 2016, is as follows:

		Three Months Ended				Nine Months Ended
		September 30,				September 30,
(In thousands)		2017		2016		2017		2016
Operating revenues	$	171,123	$	158,126	$	522,402	$	476,591
Operating expenses		(85,063)		(80,271)		(250,116)		(241,034)
Other income, net		796		1,128		1,615		2,563
Interest expense, net		(28,273)		(24,624)		(81,188)		(73,714)
Earnings before members' income taxes	$	58,583	$	54,359	$	192,713	$	164,406

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Pension and Other Postretirement Plans (Tables)

9 Months Ended

Sep. 30, 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 and nine months endedSeptember 30,2017 and 2016. A portion of the net periodic benefit cost is capitalized within the consolidated balance sheets.

		Three Months Ended				Nine Months Ended
		September 30,				September 30,
(In thousands)		2017		2016		2017		2016
Pension Benefits
Components of net periodic benefit cost:
Service cost	$	1,351	$	1,413	$	4,043	$	4,358
Interest cost		3,168		3,161		9,481		9,744
Expected return on assets		(5,762)		(5,724)		(17,244)		(17,646)
Amortization of:
Prior service (credit) cost		(4)		3		(12)		8
Actuarial loss		1,594		1,388		4,769		4,278
Net periodic benefit cost	$	347	$	241	$	1,037	$	742
Postretirement Benefits
Components of net periodic benefit cost:
Service cost	$	315	$	361	$	944	$	1,084
Interest cost		678		753		2,034		2,258
Expected return on assets		(722)		(787)		(2,165)		(2,360)
Amortization of:
Transition obligation		1		1		2		3
Prior service credit		(667)		(744)		(2,001)		(2,233)
Actuarial loss		190		178		570		533
Net periodic benefit credit	$	(205)	$	(238)	$	(616)	$	(715)

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Commitments and Contingencies (Tables)

9 Months Ended

Sep. 30, 2017

Commitments and Contingencies Disclosure [Abstract]

Purchase Contracts, Fiscal Year Maturity Schedule

(In thousands)		2017		2018		2019		2020		2021		Thereafter
Coal(a)	$	6,402	$	19,685	$	13,497	$	3,445	$	-	$	-
Natural gas
Transportation & storage(b)		6,073		20,839		19,680		15,423		8,660		24,373
Supply(c)		11,243		11,817		-		-		-		-
	$	23,718	$	52,341	$	33,177	$	18,868	$	8,660	$	24,373

(a) Total coal commitments for the Columbia and Elm Road Units, including transportation. Fuel procurement for MGE's jointly owned Columbia and Elm Road Units is handled by WPL and WEPCO, respectively, who are the operators of those facilities.

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

(c)These commitments include market-based pricing.

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Derivative and Hedging Instruments (Tables)

9 Months Ended

Sep. 30, 2017

Derivative Instruments and Hedging Activities Disclosure [Abstract]

Gross Notional Volume of Open Derivatives

The gross notional volume of open derivatives is as follows:

	September 30, 2017	December 31, 2016
Commodity derivative contracts	634,605 MWh	393,395 MWh
Commodity derivative contracts	7,924,500 Dth	4,195,000 Dth
FTRs	3,552 MW	2,251 MW
PPA	2,800 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 September 30,2017, and December 31, 2016, the receivable – margin account balance of $1.5million and $1.3 million, respectively, is shown net of any collateral posted against derivative positions.

		Derivative		Derivative
(In thousands)		Assets		Liabilities	Balance Sheet Location
September 30, 2017
Commodity derivative contracts(a)	$	857	$	560	Other current assets(b)
Commodity derivative contracts(a)		112		122	Other deferred charges
FTRs		567		-	Other current assets
PPA		N/A		8,240	Derivative liability (current)
PPA		N/A		34,890	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 September 30,2017, and December 31, 2016, no collateral was posted against and netted with derivative liability positions on the consolidated balance sheets.

(b)As of September 30,2017, $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
September 30, 2017
Commodity derivative contracts	$	969	$	(634)	$	-	$	335
FTRs		567		-		-		567
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
September 30, 2017
Commodity derivative contracts	$	682	$	(634)	$	-	$	48
PPA		43,130		-		-		43,130
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 September 30,2017 and 2016, and the consolidated income statements for the three and nine months endedSeptember 30,2017 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 September 30:
Balance at July 1,	$	45,316	$	618	$	50,521	$	659
Unrealized gain		(1,277)		-		(663)		-
Realized (loss) gain reclassified to a deferred account		(313)		313		17		(17)
Realized (loss) gain reclassified to income statement		(1,450)		(57)		(304)		46
Balance at September 30,	$	42,276	$	874	$	49,571	$	688
Nine Months Ended September 30:
Balance at January 1,	$	49,281	$	230	$	54,082	$	1,208
Unrealized (gain) loss		(3,698)		-		1,128		-
Realized (loss) gain reclassified to a deferred account		(935)		935		(1,417)		1,417
Realized loss reclassified to income statement		(2,372)		(291)		(4,222)		(1,937)
Balance at September 30,	$	42,276	$	874	$	49,571	$	688

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 September 30:
Commodity derivative contracts	$	362	$	18	$	45	$	-
FTRs		(224)		-		(703)		-
PPA		1,351		-		916		-
Nine Months Ended September 30:
Commodity derivative contracts	$	764	$	227	$	1,469	$	1,814
FTRs		(1,349)		-		(635)		-
PPA		3,021		-		3,511		-

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Fair Value of Financial Instruments (Tables)

9 Months Ended

Sep. 30, 2017

Fair Value Disclosures [Abstract]

Estimated Fair Market Value of Financial Instruments

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

		September 30, 2017				December 31, 2016
(In thousands)		Carrying Amount		Fair Value		Carrying Amount		Fair Value
MGE Energy
Assets:
Cash and cash equivalents	$	104,733	$	104,733	$	95,959	$	95,959
Liabilities:
Short-term debt - commercial paper		7,000		7,000		-		-
Long-term debt(a)		397,981		444,195		391,242		430,122
MGE
Assets:
Cash and cash equivalents	$	1,954	$	1,954	$	10,768	$	10,768
Liabilities:
Short-term debt - commercial paper		7,000		7,000		-		-
Long-term debt(a)		397,981		444,195		391,242		430,122
(a) Includes long-term debt due within one year. Excludes debt issuance costs and unamortized discount of
$4.1 million at September 30, 2017, and December 31, 2016.

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 September 30, 2017
(In thousands)		Total		Level 1		Level 2		Level 3
MGE Energy
Assets:
Derivatives	$	1,536	$	673	$	-	$	863
Exchange-traded investments		816		816		-		-
Total Assets	$	2,352	$	1,489	$	-	$	863
Liabilities:
Derivatives	$	43,812	$	190	$	-	$	43,622
Deferred compensation		3,150		-		3,150		-
Total Liabilities	$	46,962	$	190	$	3,150	$	43,622
MGE
Assets:
Derivatives	$	1,536	$	673	$	-	$	863
Exchange-traded investments		78		78		-		-
Total Assets	$	1,614	$	751	$	-	$	863
Liabilities:
Derivatives	$	43,812	$	190	$	-	$	43,622
Deferred compensation		3,150		-		3,150		-
Total Liabilities	$	46,962	$	190	$	3,150	$	43,622

		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	September 30, 2017	December 31, 2016
Basis adjustment:
On peak	92.4%	91.9%
Off peak	94.2%	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				Nine Months Ended
		September 30,				September 30,
(In thousands)		2017		2016		2017		2016
Beginning balance	$	(45,605)	$	(51,883)	$	(50,305)	$	(53,501)
Realized and unrealized gains (losses):
Included in regulatory liabilities		2,846		1,455		7,547		3,073
Included in other comprehensive income		-		-		-		-
Included in earnings		(1,478)		(278)		(2,614)		(4,250)
Included in current assets		(14)		-		(111)		-
Purchases		6,299		5,814		18,481		16,751
Sales		-		-		-		-
Issuances		-		-		-		-
Settlements		(4,807)		(5,537)		(15,757)		(12,502)
Transfers in and/or out of Level 3		-		-		-		-
Balance as of September 30,	$	(42,759)	$	(50,429)	$	(42,759)	$	(50,429)
Total gains (losses) included in earnings attributed to
the change in unrealized gains (losses) related to
assets and liabilities held at September 30,(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 losses included in income for Level 3 assets and liabilities measured at fair value on a recurring basis (b).

		Three Months Ended				Nine Months Ended
		September 30,				September 30,
(In thousands)		2017		2016		2017		2016
Purchased Power Expense	$	(1,460)	$	(278)	$	(2,377)	$	(4,250)
Cost of Gas Sold Expense		(18)		-		(237)		-
Total	$	(1,478)	$	(278)	$	(2,614)	$	(4,250)

(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)

9 Months Ended

Sep. 30, 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		Nonregulated Energy		Transmission Investment		All Others		Consolidation/ Elimination Entries		Consolidated Total
Three Months Ended September 30, 2017
Operating revenues	$	120,649	$	18,778	$	112	$	-	$	-	$	-	$	139,539
Interdepartmental revenues		(110)		3,892		11,130		-		-		(14,912)		-
Total operating revenues		120,539		22,670		11,242		-		-		(14,912)		139,539
Depreciation and amortization		(9,256)		(2,258)		(1,858)		-		-		-		(13,372)
Other operating expenses		(78,886)		(18,940)		(50)		(9)		(193)		14,912		(83,166)
Operating income (loss)		32,397		1,472		9,334		(9)		(193)		-		43,001
Other income (deductions), net		1,440		358		-		2,258		(117)		-		3,939
Interest (expense) income, net		(2,760)		(795)		(1,371)		-		199		-		(4,727)
Income (loss) before taxes		31,077		1,035		7,963		2,249		(111)		-		42,213
Income tax (provision) benefit		(11,175)		(351)		(3,196)		(906)		44		-		(15,584)
Net income (loss)	$	19,902	$	684	$	4,767	$	1,343	$	(67)	$	-	$	26,629
Three Months Ended September 30, 2016
Operating revenues	$	118,933	$	17,570	$	214	$	-	$	-	$	-	$	136,717
Interdepartmental revenues		459		6,040		10,998		-		-		(17,497)		-
Total operating revenues		119,392		23,610		11,212		-		-		(17,497)		136,717
Depreciation and amortization		(7,332)		(2,047)		(1,833)		-		-		-		(11,212)
Other operating expenses		(77,010)		(19,292)		(33)		(13)		(127)		17,497		(78,978)
Operating income (loss)		35,050		2,271		9,346		(13)		(127)		-		46,527
Other income (deductions), net		178		13		-		2,023		(109)		-		2,105
Interest (expense) income, net		(2,855)		(818)		(1,436)		-		71		-		(5,038)
Income (loss) before taxes		32,373		1,466		7,910		2,010		(165)		-		43,594
Income tax (provision) benefit		(11,290)		(494)		(3,175)		(812)		57		-		(15,714)
Net income (loss)	$	21,083	$	972	$	4,735	$	1,198	$	(108)	$	-	$	27,880
Nine Months Ended September 30, 2017
Operating revenues	$	321,279	$	101,285	$	261	$	-	$	-	$	-	$	422,825
Interdepartmental revenues		(334)		11,708		33,307		-		-		(44,681)		-
Total operating revenues		320,945		112,993		33,568		-		-		(44,681)		422,825
Depreciation and amortization		(27,341)		(6,703)		(5,562)		-		-		-		(39,606)
Other operating expenses		(231,827)		(92,670)		(153)		(9)		(779)		44,681		(280,757)
Operating income (loss)		61,777		13,620		27,853		(9)		(779)		-		102,462
Other income (deductions), net		1,821		355		-		7,242		(414)		-		9,004
Interest (expense) income, net		(8,337)		(2,399)		(4,170)		-		399		-		(14,507)
Income (loss) before taxes		55,261		11,576		23,683		7,233		(794)		-		96,959
Income tax (provision) benefit		(18,753)		(4,576)		(9,505)		(2,909)		256		-		(35,487)
Net income (loss)	$	36,508	$	7,000	$	14,178	$	4,324	$	(538)	$	-	$	61,472
Nine Months Ended September 30, 2016
Operating revenues	$	312,470	$	92,368	$	982	$	-	$	-	$	-	$	405,820
Interdepartmental revenues		1,482		17,278		32,894		-		-		(51,654)		-
Total operating revenues		313,952		109,646		33,876		-		-		(51,654)		405,820
Depreciation and amortization		(21,754)		(6,043)		(5,537)		-		(24)		-		(33,358)
Other operating expenses		(230,680)		(88,328)		(115)		(17)		(706)		51,654		(268,192)
Operating income (loss)		61,518		15,275		28,224		(17)		(730)		-		104,270
Other income (deductions), net		492		(13)		-		6,023		224		-		6,726
Interest (expense) income, net		(8,421)		(2,425)		(4,348)		-		199		-		(14,995)
Income (loss) before taxes		53,589		12,837		23,876		6,006		(307)		-		96,001
Income tax (provision) benefit		(17,984)		(5,048)		(9,583)		(2,418)		90		-		(34,943)
Net income (loss)	$	35,605	$	7,789	$	14,293	$	3,588	$	(217)	$	-	$	61,058

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 September 30, 2017
Operating revenues	$	120,648	$	18,779	$	112	$	-	$	-	$	139,539
Interdepartmental revenues		(109)		3,891		11,130		-		(14,912)		-
Total operating revenues		120,539		22,670		11,242		-		(14,912)		139,539
Depreciation and amortization		(9,256)		(2,258)		(1,858)		-		-		(13,372)
Other operating expenses(a)		(89,544)		(19,145)		(3,246)		-		14,912		(97,023)
Operating income(a)		21,739		1,267		6,138		-		-		29,144
Other income, net(a)		923		212		-		-		-		1,135
Interest expense, net		(2,760)		(795)		(1,371)		-		-		(4,926)
Net income		19,902		684		4,767		-		-		25,353
Less: Net income attributable to
noncontrolling interest, net of tax		-		-		-		-		(5,439)		(5,439)
Net income attributable to MGE	$	19,902	$	684	$	4,767	$	-	$	(5,439)	$	19,914
Three Months Ended September 30, 2016
Operating revenues	$	118,938	$	17,576	$	214	$	-	$	-	$	136,728
Interdepartmental revenues		454		6,034		10,998		-		(17,486)		-
Total operating revenues		119,392		23,610		11,212		-		(17,486)		136,728
Depreciation and amortization		(7,332)		(2,047)		(1,833)		-		-		(11,212)
Other operating expenses(a)		(88,282)		(19,781)		(3,208)		4		17,486		(93,781)
Operating income(a)		23,778		1,782		6,171		4		-		31,735
Other income, net(a)		160		8		-		868		-		1,036
Interest expense, net		(2,855)		(818)		(1,436)		-		-		(5,109)
Net income		21,083		972		4,735		872		-		27,662
Less: Net income attributable to
noncontrolling interest, net of tax		-		-		-		-		(5,695)		(5,695)
Net income attributable to MGE	$	21,083	$	972	$	4,735	$	872	$	(5,695)	$	21,967
Nine Months Ended September 30, 2017
Operating revenues	$	321,282	$	101,294	$	261	$	-	$	-	$	422,837
Interdepartmental revenues		(337)		11,699		33,307		-		(44,669)		-
Total operating revenues		320,945		112,993		33,568		-		(44,669)		422,837
Depreciation and amortization		(27,341)		(6,703)		(5,562)		-		-		(39,606)
Other operating expenses(a)		(249,992)		(97,080)		(9,658)		-		44,669		(312,061)
Operating income(a)		43,612		9,210		18,348		-		-		71,170
Other income, net(a)		1,233		189		-		-		-		1,422
Interest expense, net		(8,337)		(2,399)		(4,170)		-		-		(14,906)
Net income		36,508		7,000		14,178		-		-		57,686
Less: Net income attributable to
noncontrolling interest, net of tax		-		-		-		-		(16,224)		(16,224)
Net income attributable to MGE	$	36,508	$	7,000	$	14,178	$	-	$	(16,224)	$	41,462
Nine Months Ended September 30, 2016
Operating revenues	$	312,488	$	92,390	$	982	$	-	$	-	$	405,860
Interdepartmental revenues		1,464		17,256		32,894		-		(51,614)		-
Total operating revenues		313,952		109,646		33,876		-		(51,614)		405,860
Depreciation and amortization		(21,754)		(6,043)		(5,537)		-		-		(33,334)
Other operating expenses(a)		(248,566)		(93,348)		(9,698)		-		51,614		(299,998)
Operating income(a)		43,632		10,255		18,641		-		-		72,528
Other income (deductions), net(a)		394		(41)		-		3,262		-		3,615
Interest expense, net		(8,421)		(2,425)		(4,348)		-		-		(15,194)
Net income		35,605		7,789		14,293		3,262		-		60,949
Less: Net income attributable to
noncontrolling interest, net of tax		-		-		-		-		(17,899)		(17,899)
Net income attributable to MGE	$	35,605	$	7,789	$	14,293	$	3,262	$	(17,899)	$	43,050
(a) Amounts are shown net of the related tax expense, consistent with the presentation on the MGE Consolidated Statement 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 further discussion.

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Equity and Financing Arrangements (Details) - USD ($)			3 Months Ended		9 Months Ended
	Oct. 02, 2017	Jan. 13, 2017	Sep. 30, 2017	Sep. 30, 2016	Sep. 30, 2017	Sep. 30, 2016
Common Stock [Abstract]
Common stock issued during period			0	0	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
Future Debt Issuance, 3.11% due 2027 | Subsequent Event [Member]
Debt Instrument [Line Items]
Long-term debt, gross	$ 30,000,000
Interest rate	3.11%
Term	10 years

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Investment in ATC and ATC Holdco (Details-1) - USD ($) $ in Thousands		3 Months Ended		9 Months Ended
	Dec. 01, 2016	Sep. 30, 2017	Sep. 30, 2016	Sep. 30, 2017		Sep. 30, 2016	Dec. 31, 2016
Schedule Of Equity Method Investments [Line Items]
Equity earnings from investment in ATC		$ 2,338	$ 2,023	$ 7,432		$ 6,023
Dividends from ATC		2,070	1,486	6,142		4,214
Capital contributions to investments		710	888	6,863		2,036
MGE Energy [Member]
Schedule Of Equity Method Investments [Line Items]
Dividend in kind to parent	$ 15,800
MGE Transco [Member] | ATC [Member]
Schedule Of Equity Method Investments [Line Items]
Equity earnings from investment in ATC		2,338	2,023	7,432		6,023
Dividends from ATC		2,070	1,486	4,070	[1]	4,214
Capital contributions to investments		$ 710	888	$ 3,018		1,598
Ownership interest in equity-method investee		3.60%		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	$ 1,451	$ 0		5,451
Dividends from ATC				0		4,214
Capital contributions to investments				$ 0		$ 1,598
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		4.40%		4.40%			4.00%

[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		9 Months Ended
	Sep. 30, 2017	Sep. 30, 2016	Sep. 30, 2017	Sep. 30, 2016	Dec. 31, 2016
ATC [Member]
Schedule Of Equity Method Investments [Line Items]
Operating revenues	$ 171,123	$ 158,126	$ 522,402	$ 476,591
Operating expenses	(85,063)	(80,271)	(250,116)	(241,034)
Other income, net	796	1,128	1,615	2,563
Interest expense, net	(28,273)	(24,624)	(81,188)	(73,714)
Earnings before members' income taxes	58,583	54,359	192,713	164,406
ATC [Member]
Related Party Transaction [Line Items]
Related party expenses	7,300	$ 7,400	21,900	$ 22,100
Due from related parties	$ 100		$ 100		$ 100

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Taxes (Details)	3 Months Ended		9 Months Ended
	Sep. 30, 2017	Sep. 30, 2016	Sep. 30, 2017	Sep. 30, 2016
Income Tax Disclosure [Line Items]
Effective income tax rate	36.90%	36.10%	36.60%	36.40%
MGE [Member]
Income Tax Disclosure [Line Items]
Effective income tax rate	36.70%	36.00%	36.30%	36.40%

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Pension and Other Postretirement Plans (Details) - USD ($) $ in Thousands	3 Months Ended		9 Months Ended
	Sep. 30, 2017	Sep. 30, 2016	Sep. 30, 2017	Sep. 30, 2016
Pension Benefits [Member]
Components of net periodic benefit cost:
Service cost	$ 1,351	$ 1,413	$ 4,043	$ 4,358
Interest cost	3,168	3,161	9,481	9,744
Expected return on assets	(5,762)	(5,724)	(17,244)	(17,646)
Amortization of:
Prior service (credit) cost	(4)	3	(12)	8
Actuarial loss	1,594	1,388	4,769	4,278
Net periodic benefit cost (credit)	347	241	1,037	742
Postretirement Benefits [Member]
Components of net periodic benefit cost:
Service cost	315	361	944	1,084
Interest cost	678	753	2,034	2,258
Expected return on assets	(722)	(787)	(2,165)	(2,360)
Amortization of:
Transition obligation	1	1	2	3
Prior service (credit) cost	(667)	(744)	(2,001)	(2,233)
Actuarial loss	190	178	570	533
Net periodic benefit cost (credit)	$ (205)	$ (238)	$ (616)	$ (715)

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Share Based Compensation (Details) - Performance Units [Member] - USD ($) $ in Millions	1 Months Ended		3 Months Ended		9 Months Ended
	Mar. 31, 2017	Jan. 31, 2017	Sep. 30, 2017	Sep. 30, 2016	Sep. 30, 2017	Sep. 30, 2016
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Compensation expense			$ 0.3	$ 0.2	$ 1.0	$ 2.0
Cash payments distributed related to awards previously granted and now payable		$ 2.0
Awards forfeited during period, value			$ 0.0	$ 0.0	$ 0.0	$ 0.0
Awards forfeited during period, units			0	0	0	0
Outstanding awards vested during period					$ 5.1
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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Commitments and Contingencies (Details-1)	Sep. 30, 2017 USD ($)
Operating expense purchase contracts [Abstract]
Purchase obligation, 2017	$ 23,718,000
Purchase obligation, 2018	52,341,000
Purchase obligation, 2019	33,177,000
Purchase obligation, 2020	18,868,000
Purchase obligation, 2021	8,660,000
Purchase obligation, Thereafter	24,373,000
Coal [Member]
Operating expense purchase contracts [Abstract]
Purchase obligation, 2017	6,402,000	[1]
Purchase obligation, 2018	19,685,000	[1]
Purchase obligation, 2019	13,497,000	[1]
Purchase obligation, 2020	3,445,000	[1]
Purchase obligation, 2021	0	[1]
Purchase obligation, Thereafter	0	[1]
Natural Gas, Transportation and Storage [Member]
Operating expense purchase contracts [Abstract]
Purchase obligation, 2017	6,073,000	[2]
Purchase obligation, 2018	20,839,000	[2]
Purchase obligation, 2019	19,680,000	[2]
Purchase obligation, 2020	15,423,000	[2]
Purchase obligation, 2021	8,660,000	[2]
Purchase obligation, Thereafter	24,373,000	[2]
Natual Gas, Supply [Member]
Operating expense purchase contracts [Abstract]
Purchase obligation, 2017	11,243,000	[3]
Purchase obligation, 2018	11,817,000	[3]
Purchase obligation, 2019	0	[3]
Purchase obligation, 2020	0	[3]
Purchase obligation, 2021	0	[3]
Purchase obligation, Thereafter	0	[3]
MGE Energy [Member] | Investments in Non Public Entities, Capital Infusions [Member]
Other Commitments [Line Items]
Other commitment, initial agreed upon commitment total	$ 5,000,000

[1] Total coal commitments for the Columbia and Elm Road Units, including transportation. Fuel procurement for MGE's jointly owned Columbia and Elm Road Units is handled by WPL and WEPCO, respectively, who are the operators of those facilities.

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

[3] These commitments include market-based pricing.

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Rate Matters (Details) - PSCW [Member] - MGE [Member] - USD ($)	1 Months Ended	4 Months Ended	9 Months Ended	12 Months Ended
	Sep. 30, 2016	Dec. 31, 2015	Sep. 30, 2017	Dec. 31, 2016	Jul. 31, 2017
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			$ 3,300,000
Fuel Rules Credit ($0.00256/kWh), 2015/2016 [Member]
Fuel Rules [Abstract]
Electric fuel credit (per kWh)		$ 0.00256		$ 0.00256
Return of electric fuel credit, total		$ 2,600,000		$ 8,300,000
Fuel Rules Refund, 2015/2016 [Member]
Fuel Rules [Abstract]
Electric fuel credit ($)					$ 6,000,000
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		9 Months Ended		12 Months Ended
		Sep. 30, 2017 USD ($) Dth MWh MW		Dec. 31, 2016 USD ($) Dth MWh MW	Jun. 30, 2017 USD ($)	Sep. 30, 2016 USD ($)	Jun. 30, 2016 USD ($)	Dec. 31, 2015 USD ($)
Derivative fair values [Abstract]
Receivable, margin account balance, net of collateral posted against derivative positions		$ 1,500		$ 1,300
Other Current Assets [Member]
Derivative fair values [Abstract]
Derivative fair value, net		874		230	$ 618	$ 688	$ 659	$ 1,208
Commodity Contracts And Financial Transimission Rights [Member]
Derivative fair values [Abstract]
Derivative fair value, net		$ 900		$ 1,300
Commodity Derivative Contracts [Member]
Gross Notional Volume of Open Derivatives
Notional amount, energy measure (in MWh) | MWh		634,605		393,395
Notional amount, decatherm measure (in Dth) | Dth		7,924,500		4,195,000
Derivative fair values [Abstract]
Asset Derivatives, fair value, gross basis		$ 969		$ 1,384
Liability Derivatives, fair value, gross basis		682		218
Commodity Derivative Contracts [Member] | Other Current Assets [Member]
Derivative fair values [Abstract]
Asset Derivatives, fair value, gross basis	[1]	857		1,227
Liability Derivatives, fair value, gross basis	[1]	560	[2]	164
Derivative, right to reclaim collateral (receivable)		0		0
Commodity Derivative Contracts [Member] | Other Deferred Charges [Member]
Derivative fair values [Abstract]
Asset Derivatives, fair value, gross basis	[1]	112		157
Liability Derivatives, fair value, gross basis	[1]	122		54
Derivative, right to reclaim collateral (receivable)		0		$ 0
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		3,552		2,251
Derivative fair values [Abstract]
Asset Derivatives, fair value, gross basis		$ 567		$ 143
Financial Transmission Rights [Member] | Other Current Assets [Member]
Derivative fair values [Abstract]
Asset Derivatives, fair value, gross basis		567		143
Liability Derivatives, fair value, gross basis		$ 0		$ 0
PPA [Member]
Gross Notional Volume of Open Derivatives
Notional amount, power measure (in MW) | MW		2,800		3,250
Derivative fair values [Abstract]
Derivative fair value, net		$ (43,100)		$ (50,600)
Liability Derivatives, fair value, gross basis		43,130		50,590
PPA [Member] | Derivative Liability (Current) [Member]
Derivative fair values [Abstract]
Liability Derivatives, fair value, gross basis		8,240		7,620
PPA [Member] | Derivative Liability (Long-term) [Member]
Derivative fair values [Abstract]
Liability Derivatives, fair value, gross basis		$ 34,890		$ 42,970

[1] As of September 30, 2017 , and December 31, 2016 , no collateral was posted against and netted with derivative liability positions on the consolidated balance sheets.

[2] As of September 30, 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	Sep. 30, 2017	Dec. 31, 2016
Commodity Derivative Contracts [Member]
Offsetting Assets [Line Items]
Gross amounts	$ 969	$ 1,384
Gross amounts offset in balance sheet	(634)	(218)
Collateral posted against derivative positions	0	0
Net amount presented in balance sheet	335	1,166
Financial Transmission Rights [Member]
Offsetting Assets [Line Items]
Gross amounts	567	143
Gross amounts offset in balance sheet	0	0
Collateral posted against derivative positions	0	0
Net amount presented in balance sheet	$ 567	$ 143

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Derivative and Hedging Instruments (Details-3) - USD ($) $ in Thousands	Sep. 30, 2017	Dec. 31, 2016
Commodity Derivative Contracts [Member]
Offsetting Liabilities [Line Items]
Gross amounts	$ 682	$ 218
Gross amounts offset in balance sheet	(634)	(218)
Collateral posted against derivative positions	0	0
Net amount presented in balance sheet	48	0
Purchased Power Agreement [Member]
Offsetting Liabilities [Line Items]
Gross amounts	43,130	50,590
Gross amounts offset in balance sheet	0	0
Collateral posted against derivative positions	0	0
Net amount presented in balance sheet	$ 43,130	$ 50,590

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Derivative and Hedging Instruments (Details-4) - USD ($) $ in Thousands	3 Months Ended		9 Months Ended
	Sep. 30, 2017	Sep. 30, 2016	Sep. 30, 2017	Sep. 30, 2016
Current and Long-Term Regulatory Asset [Member]
Change In Derivative Fair Value [Roll Forward]
Beginning balance,	$ 45,316	$ 50,521	$ 49,281	$ 54,082
Unrealized (gain) loss	(1,277)	(663)	(3,698)	1,128
Realized (loss) gain reclassified to a deferred account	(313)	17	(935)	(1,417)
Realized (loss) gain reclassified to income statement	(1,450)	(304)	(2,372)	(4,222)
Ending balance,	42,276	49,571	42,276	49,571
Other Current Assets [Member]
Change In Derivative Fair Value [Roll Forward]
Beginning balance,	618	659	230	1,208
Unrealized (gain) loss	0	0	0	0
Realized (loss) gain reclassified to a deferred account	313	(17)	935	1,417
Realized (loss) gain reclassified to income statement	(57)	46	(291)	(1,937)
Ending balance,	$ 874	$ 688	$ 874	$ 688

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Derivative and Hedging Instruments (Details-5) $ in Thousands	3 Months Ended		9 Months Ended
	Sep. 30, 2017 USD ($) counterparty	Sep. 30, 2016 USD ($)	Sep. 30, 2017 USD ($) counterparty	Sep. 30, 2016 USD ($)	Dec. 31, 2016 USD ($)
Counterparties in net liability position or default [Abstract]
Derivative, net liability position of counterparties (less than $0.1 million)	$ 100		$ 100		$ 0
Number of counterparties in default | counterparty	0		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	$ 362	$ 45	$ 764	$ 1,469
Commodity Derivative Contracts [Member] | Cost Of Gas Sold Expense [Member]
Realized losses (gains) on income statement [Line Items]
Realized losses (gains) on income statement	18	0	227	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	(224)	(703)	(1,349)	(635)
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	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		20,000
Maximum collateral that may be required to be posted	40,000		40,000
Collateral posted	0		0
Purchased Power Agreement [Member] | Fuel For Electric Generation Purchased Power [Member]
Realized losses (gains) on income statement [Line Items]
Realized losses (gains) on income statement	1,351	916	3,021	3,511
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	$ 0	$ 0

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Fair Value of Financial Instruments (Details-1) - USD ($) $ in Thousands		Sep. 30, 2017	Dec. 31, 2016
Fair Value Measurement [Domain]
Liabilities:
Unamortized discount and debt issuance costs, net		$ 4,100	$ 4,100
Carrying Amount [Member]
Assets:
Cash and cash equivalents		104,733	95,959
Liabilities:
Short-term debt - commercial paper		7,000	0
Long-term debt	[1]	397,981	391,242
Fair Value [Member]
Assets:
Cash and cash equivalents		104,733	95,959
Liabilities:
Short-term debt - commercial paper		7,000	0
Long-term debt	[1]	444,195	430,122
MGE [Member] | Fair Value Measurement [Domain]
Liabilities:
Unamortized discount and debt issuance costs, net		4,100	4,100
MGE [Member] | Carrying Amount [Member]
Assets:
Cash and cash equivalents		1,954	10,768
Liabilities:
Short-term debt - commercial paper		7,000	0
Long-term debt	[1]	397,981	391,242
MGE [Member] | Fair Value [Member]
Assets:
Cash and cash equivalents		1,954	10,768
Liabilities:
Short-term debt - commercial paper		7,000	0
Long-term debt	[1]	$ 444,195	$ 430,122

[1] Includes long-term debt due within one year. Excludes debt issuance costs and unamortized discount of $4.1 million at September 30, 2017, and December 31, 2016.

XML

Fair Value of Financial Instruments (Details-2) - Recurring [Member] - USD ($) $ in Thousands	Sep. 30, 2017	Dec. 31, 2016
Assets:
Derivatives	$ 1,536	$ 1,527
Total Assets	2,352	2,027
Liabilities:
Derivatives	43,812	50,808
Deferred compensation	3,150	3,039
Total liabilities	46,962	53,847
Exchange Traded [Member]
Assets:
Available-for-sale securities	816	500
Level 1 [Member]
Assets:
Derivatives	673	1,041
Total Assets	1,489	1,541
Liabilities:
Derivatives	190	16
Deferred compensation	0	0
Total liabilities	190	16
Level 1 [Member] | Exchange Traded [Member]
Assets:
Available-for-sale securities	816	500
Level 2 [Member]
Assets:
Derivatives	0	0
Total Assets	0	0
Liabilities:
Derivatives	0	0
Deferred compensation	3,150	3,039
Total liabilities	3,150	3,039
Level 2 [Member] | Exchange Traded [Member]
Assets:
Available-for-sale securities	0	0
Level 3 [Member]
Assets:
Derivatives	863	486
Total Assets	863	486
Liabilities:
Derivatives	43,622	50,792
Deferred compensation	0	0
Total liabilities	43,622	50,792
Level 3 [Member] | Exchange Traded [Member]
Assets:
Available-for-sale securities	0	0
MGE [Member]
Assets:
Derivatives	1,536	1,527
Total Assets	1,614	1,670
Liabilities:
Derivatives	43,812	50,808
Deferred compensation	3,150	3,039
Total liabilities	46,962	53,847
MGE [Member] | Exchange Traded [Member]
Assets:
Available-for-sale securities	78	143
MGE [Member] | Level 1 [Member]
Assets:
Derivatives	673	1,041
Total Assets	751	1,184
Liabilities:
Derivatives	190	16
Deferred compensation	0	0
Total liabilities	190	16
MGE [Member] | Level 1 [Member] | Exchange Traded [Member]
Assets:
Available-for-sale securities	78	143
MGE [Member] | Level 2 [Member]
Assets:
Derivatives	0	0
Total Assets	0	0
Liabilities:
Derivatives	0	0
Deferred compensation	3,150	3,039
Total liabilities	3,150	3,039
MGE [Member] | Level 2 [Member] | Exchange Traded [Member]
Assets:
Available-for-sale securities	0	0
MGE [Member] | Level 3 [Member]
Assets:
Derivatives	863	486
Total Assets	863	486
Liabilities:
Derivatives	43,622	50,792
Deferred compensation	0	0
Total liabilities	43,622	50,792
MGE [Member] | Level 3 [Member] | Exchange Traded [Member]
Assets:
Available-for-sale securities	$ 0	$ 0

XML

Fair Value of Financial Instruments (Details-3)	9 Months Ended	12 Months Ended
	Sep. 30, 2017	Dec. 31, 2016
Basis adjustment:
Basis adjustment - on peak	92.40%	91.90%
Basis adjustment - off peak	94.20%	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%

XML

Fair Value of Financial Instruments (Details-4) - USD ($) $ in Thousands	3 Months Ended		9 Months Ended
	Sep. 30, 2017	Sep. 30, 2016	Sep. 30, 2017	Sep. 30, 2016
Fair Value, Net Derivative Asset (Liability) Measured on Recurring Basis, Unobservable Input Reconciliation [Roll Forward]
Beginning balance,	$ (45,605)	$ (51,883)	$ (50,305)	$ (53,501)
Realized and unrealized gains (losses):
Included in regulatory liabilities	2,846	1,455	7,547	3,073
Included in other comprehensive income	0	0	0	0
Included in earnings	(1,478)	(278)	(2,614)	(4,250)
Included in current assets	(14)	0	(111)	0
Purchases	6,299	5,814	18,481	16,751
Sales	0	0	0	0
Issuances	0	0	0	0
Settlements	(4,807)	(5,537)	(15,757)	(12,502)
Transfers in and/or out of level 3	0	0	0	0
Ending balance,	(42,759)	(50,429)	(42,759)	(50,429)
Total gains (losses) included in earnings attributed to the change in unrealized gains (losses) related to assets and liabilities	0	0	0	0
Purchased Power Expense [Member]
Realized and unrealized gains (losses):
Included in earnings	(1,460)	(278)	(2,377)	(4,250)
Cost Of Gas Sold Expense [Member]
Realized and unrealized gains (losses):
Included in earnings	$ (18)	$ 0	$ (237)	$ 0

XML

Joint Plant Ownership (Details) - USD ($) $ in Thousands	3 Months Ended	9 Months Ended		12 Months Ended
	Sep. 30, 2017	Sep. 30, 2017	Sep. 30, 2016	Dec. 31, 2016	Jan. 01, 2017
Jointly Owned Utility Plant Interests [Line Items]
Assets held for sale	$ 6,707	$ 6,707		$ 14,813
Accrued capital expenditures		12,469	$ 10,603
MGE [Member]
Jointly Owned Utility Plant Interests [Line Items]
Assets held for sale	6,707	6,707		$ 14,813
Accrued capital expenditures		12,469	$ 10,603
Columbia Units [Member] | MGE [Member]
Jointly Owned Utility Plant Interests [Line Items]
Jointly Owned Utility Plant, Proportionate Ownership Share				22.00%	20.40%
Assets held for sale	6,700	6,700		$ 14,800
Accrued capital expenditures	$ 1,600	$ 6,700		$ 14,800

XML

Adoption of Accounting Principles and Recently Issued Accounting Pronouncements (Details-1) - USD ($) $ in Thousands	Sep. 30, 2017	Dec. 31, 2016	Dec. 31, 2015
Accounting Standards Update 2016-18 - Restricted Cash [Member]
Adoption of Accounting Principles and Recently Issued Accounting Pronouncements [Line Items]
Restricted cash	$ 4,500	$ 5,100
Accounting Standards Update 2016-01 - Restricted Cash [Member]
Adoption of Accounting Principles and Recently Issued Accounting Pronouncements [Line Items]
Accumulated other comprehensive income (loss)	391
Accounting Standards Update 2016-01 - Restricted Cash [Member] | MGE [Member]
Adoption of Accounting Principles and Recently Issued Accounting Pronouncements [Line Items]
Accumulated other comprehensive income (loss)	$ (19)
Accounting Standards Update 2017-07 - Restricted Cash [Member]
Adoption of Accounting Principles and Recently Issued Accounting Pronouncements [Line Items]
Cumulative effect of new accounting guidance, retained earnings		$ 6,600	$ 5,000

XML

Segment Information (Details) - USD ($) $ in Thousands		3 Months Ended		9 Months Ended
		Sep. 30, 2017	Sep. 30, 2016	Sep. 30, 2017	Sep. 30, 2016
Segment Reporting Information [Line Items]
Operating revenues		$ 139,539	$ 136,717	$ 422,825	$ 405,820
Depreciation and amortization		(13,372)	(11,212)	(39,606)	(33,358)
Other operating expenses		(83,166)	(78,978)	(280,757)	(268,192)
Operating income (loss)		43,001	46,527	102,462	104,270
Other income (deductions), net		3,939	2,105	9,004	6,726
Interest (expense) income, net		(4,727)	(5,038)	(14,507)	(14,995)
Income before income taxes		42,213	43,594	96,959	96,001
Income tax (provision) benefit		(15,584)	(15,714)	(35,487)	(34,943)
Net Income (Loss)		26,629	27,880	61,472	61,058
Electric [Member]
Segment Reporting Information [Line Items]
Operating revenues		120,649	118,933	321,279	312,470
Gas [Member]
Segment Reporting Information [Line Items]
Operating revenues		18,778	17,570	101,285	92,368
Non Regulated Energy [Member]
Segment Reporting Information [Line Items]
Operating revenues		112	214	261	982
Transmission Investment [Member]
Segment Reporting Information [Line Items]
Operating revenues		0	0	0	0
All Others [Member]
Segment Reporting Information [Line Items]
Operating revenues		0	0	0	0
Operating Segments [Member]
Segment Reporting Information [Line Items]
Operating revenues		139,539	136,717	422,825	405,820
Operating Segments [Member] | Electric [Member]
Segment Reporting Information [Line Items]
Operating revenues		120,539	119,392	320,945	313,952
Depreciation and amortization		(9,256)	(7,332)	(27,341)	(21,754)
Other operating expenses		(78,886)	(77,010)	(231,827)	(230,680)
Operating income (loss)		32,397	35,050	61,777	61,518
Other income (deductions), net		1,440	178	1,821	492
Interest (expense) income, net		(2,760)	(2,855)	(8,337)	(8,421)
Income before income taxes		31,077	32,373	55,261	53,589
Income tax (provision) benefit		(11,175)	(11,290)	(18,753)	(17,984)
Net Income (Loss)		19,902	21,083	36,508	35,605
Operating Segments [Member] | Gas [Member]
Segment Reporting Information [Line Items]
Operating revenues		22,670	23,610	112,993	109,646
Depreciation and amortization		(2,258)	(2,047)	(6,703)	(6,043)
Other operating expenses		(18,940)	(19,292)	(92,670)	(88,328)
Operating income (loss)		1,472	2,271	13,620	15,275
Other income (deductions), net		358	13	355	(13)
Interest (expense) income, net		(795)	(818)	(2,399)	(2,425)
Income before income taxes		1,035	1,466	11,576	12,837
Income tax (provision) benefit		(351)	(494)	(4,576)	(5,048)
Net Income (Loss)		684	972	7,000	7,789
Operating Segments [Member] | Non Regulated Energy [Member]
Segment Reporting Information [Line Items]
Operating revenues		11,242	11,212	33,568	33,876
Depreciation and amortization		(1,858)	(1,833)	(5,562)	(5,537)
Other operating expenses		(50)	(33)	(153)	(115)
Operating income (loss)		9,334	9,346	27,853	28,224
Other income (deductions), net		0	0	0	0
Interest (expense) income, net		(1,371)	(1,436)	(4,170)	(4,348)
Income before income taxes		7,963	7,910	23,683	23,876
Income tax (provision) benefit		(3,196)	(3,175)	(9,505)	(9,583)
Net Income (Loss)		4,767	4,735	14,178	14,293
Operating Segments [Member] | Transmission Investment [Member]
Segment Reporting Information [Line Items]
Operating revenues		0	0	0	0
Depreciation and amortization		0	0	0	0
Other operating expenses		(9)	(13)	(9)	(17)
Operating income (loss)		(9)	(13)	(9)	(17)
Other income (deductions), net		2,258	2,023	7,242	6,023
Interest (expense) income, net		0	0	0	0
Income before income taxes		2,249	2,010	7,233	6,006
Income tax (provision) benefit		(906)	(812)	(2,909)	(2,418)
Net Income (Loss)		1,343	1,198	4,324	3,588
Operating Segments [Member] | All Others [Member]
Segment Reporting Information [Line Items]
Operating revenues		0	0	0	0
Depreciation and amortization		0	0	0	(24)
Other operating expenses		(193)	(127)	(779)	(706)
Operating income (loss)		(193)	(127)	(779)	(730)
Other income (deductions), net		(117)	(109)	(414)	224
Interest (expense) income, net		199	71	399	199
Income before income taxes		(111)	(165)	(794)	(307)
Income tax (provision) benefit		44	57	256	90
Net Income (Loss)		(67)	(108)	(538)	(217)
Consolidation Elimination Entries [Member]
Segment Reporting Information [Line Items]
Operating revenues		(14,912)	(17,497)	(44,681)	(51,654)
Depreciation and amortization		0	0	0	0
Other operating expenses		14,912	17,497	44,681	51,654
Operating income (loss)		0	0	0	0
Other income (deductions), net		0	0	0	0
Interest (expense) income, net		0	0	0	0
Income before income taxes		0	0	0	0
Income tax (provision) benefit		0	0	0	0
Net Income (Loss)		0	0	0	0
Consolidation Elimination Entries [Member] | Electric [Member]
Segment Reporting Information [Line Items]
Operating revenues		(110)	459	(334)	1,482
Consolidation Elimination Entries [Member] | Gas [Member]
Segment Reporting Information [Line Items]
Operating revenues		3,892	6,040	11,708	17,278
Consolidation Elimination Entries [Member] | Non Regulated Energy [Member]
Segment Reporting Information [Line Items]
Operating revenues		11,130	10,998	33,307	32,894
Consolidation Elimination Entries [Member] | Transmission Investment [Member]
Segment Reporting Information [Line Items]
Operating revenues		0	0	0	0
Consolidation Elimination Entries [Member] | All Others [Member]
Segment Reporting Information [Line Items]
Operating revenues		0	0	0	0
MGE [Member]
Segment Reporting Information [Line Items]
Operating revenues		139,539	136,728	422,837	405,860
Depreciation and amortization		(13,372)	(11,212)	(39,606)	(33,334)
Other operating expenses	[1]	(97,023)	(93,781)	(312,061)	(299,998)
Operating income (loss)	[1]	29,144	31,735	71,170	72,528
Other income (deductions), net	[1]	1,135	1,036	1,422	3,615
Interest (expense) income, net		(4,926)	(5,109)	(14,906)	(15,194)
Net Income Including Noncontrolling Interest		25,353	27,662	57,686	60,949
Less Net Income Attributable to Noncontrolling Interest, net of tax		(5,439)	(5,695)	(16,224)	(17,899)
Net Income (Loss)		19,914	21,967	41,462	43,050
MGE [Member] | Electric [Member]
Segment Reporting Information [Line Items]
Operating revenues		120,648	118,938	321,282	312,488
MGE [Member] | Gas [Member]
Segment Reporting Information [Line Items]
Operating revenues		18,779	17,576	101,294	92,390
MGE [Member] | Non Regulated Energy [Member]
Segment Reporting Information [Line Items]
Operating revenues		112	214	261	982
MGE [Member] | Transmission Investment [Member]
Segment Reporting Information [Line Items]
Operating revenues	[2]	0	0	0	0
MGE [Member] | Operating Segments [Member]
Segment Reporting Information [Line Items]
Operating revenues		139,539	136,728	422,837	405,860
MGE [Member] | Operating Segments [Member] | Electric [Member]
Segment Reporting Information [Line Items]
Operating revenues		120,539	119,392	320,945	313,952
Depreciation and amortization		(9,256)	(7,332)	(27,341)	(21,754)
Other operating expenses	[1]	(89,544)	(88,282)	(249,992)	(248,566)
Operating income (loss)	[1]	21,739	23,778	43,612	43,632
Other income (deductions), net	[1]	923	160	1,233	394
Interest (expense) income, net		(2,760)	(2,855)	(8,337)	(8,421)
Net Income Including Noncontrolling Interest		19,902	21,083	36,508	35,605
Less Net Income Attributable to Noncontrolling Interest, net of tax		0	0	0	0
Net Income (Loss)		19,902	21,083	36,508	35,605
MGE [Member] | Operating Segments [Member] | Gas [Member]
Segment Reporting Information [Line Items]
Operating revenues		22,670	23,610	112,993	109,646
Depreciation and amortization		(2,258)	(2,047)	(6,703)	(6,043)
Other operating expenses	[1]	(19,145)	(19,781)	(97,080)	(93,348)
Operating income (loss)	[1]	1,267	1,782	9,210	10,255
Other income (deductions), net	[1]	212	8	189	(41)
Interest (expense) income, net		(795)	(818)	(2,399)	(2,425)
Net Income Including Noncontrolling Interest		684	972	7,000	7,789
Less Net Income Attributable to Noncontrolling Interest, net of tax		0	0	0	0
Net Income (Loss)		684	972	7,000	7,789
MGE [Member] | Operating Segments [Member] | Non Regulated Energy [Member]
Segment Reporting Information [Line Items]
Operating revenues		11,242	11,212	33,568	33,876
Depreciation and amortization		(1,858)	(1,833)	(5,562)	(5,537)
Other operating expenses	[1]	(3,246)	(3,208)	(9,658)	(9,698)
Operating income (loss)	[1]	6,138	6,171	18,348	18,641
Other income (deductions), net	[1]	0	0	0	0
Interest (expense) income, net		(1,371)	(1,436)	(4,170)	(4,348)
Net Income Including Noncontrolling Interest		4,767	4,735	14,178	14,293
Less Net Income Attributable to Noncontrolling Interest, net of tax		0	0	0	0
Net Income (Loss)		4,767	4,735	14,178	14,293
MGE [Member] | Operating Segments [Member] | Transmission Investment [Member]
Segment Reporting Information [Line Items]
Operating revenues	[2]	0	0	0	0
Depreciation and amortization	[2]	0	0	0	0
Other operating expenses	[1],[2]	0	4	0	0
Operating income (loss)	[1],[2]	0	4	0	0
Other income (deductions), net	[1],[2]	0	868	0	3,262
Interest (expense) income, net	[2]	0	0	0	0
Net Income Including Noncontrolling Interest	[2]	0	872	0	3,262
Less Net Income Attributable to Noncontrolling Interest, net of tax	[2]	0	0	0	0
Net Income (Loss)	[2]	0	872	0	3,262
MGE [Member] | Consolidation Elimination Entries [Member]
Segment Reporting Information [Line Items]
Operating revenues		(14,912)	(17,486)	(44,669)	(51,614)
Depreciation and amortization		0	0	0	0
Other operating expenses	[1]	14,912	17,486	44,669	51,614
Operating income (loss)	[1]	0	0	0	0
Other income (deductions), net	[1]	0	0	0	0
Interest (expense) income, net		0	0	0	0
Net Income Including Noncontrolling Interest		0	0	0	0
Less Net Income Attributable to Noncontrolling Interest, net of tax		(5,439)	(5,695)	(16,224)	(17,899)
Net Income (Loss)		(5,439)	(5,695)	(16,224)	(17,899)
MGE [Member] | Consolidation Elimination Entries [Member] | Electric [Member]
Segment Reporting Information [Line Items]
Operating revenues		(109)	454	(337)	1,464
MGE [Member] | Consolidation Elimination Entries [Member] | Gas [Member]
Segment Reporting Information [Line Items]
Operating revenues		3,891	6,034	11,699	17,256
MGE [Member] | Consolidation Elimination Entries [Member] | Non Regulated Energy [Member]
Segment Reporting Information [Line Items]
Operating revenues		11,130	10,998	33,307	32,894
MGE [Member] | Consolidation Elimination Entries [Member] | Transmission Investment [Member]
Segment Reporting Information [Line Items]
Operating revenues	[2]	$ 0	$ 0	$ 0	$ 0

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