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, 2015

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

For the transition period from _______________ to _______________

Commission File No.	Name of Registrant, State of Incorporation, Address of Principal Executive Offices, and Telephone No.	IRS Employer Identification No.
000-49965	MGE Energy, Inc. (a Wisconsin Corporation) 133 South Blair Street Madison, Wisconsin 53788 (608) 252-7000 mgeenergy.com	39-2040501
000-1125	Madison Gas and Electric Company (a Wisconsin Corporation) 133 South Blair Street Madison, Wisconsin 53788 (608) 252-7000 mge.com	39-0444025

Indicate by check mark whether the registrants (1) have filed all reports required to be filed by Section 13 or 15(d) of the Securities Exchange Act of 1934 during the preceding 12 months (or for such shorter period that the registrant was required to file such reports), and (2) have been subject to such filing requirements for the past 90 days: Yes [X] No [ ]

Indicate by check mark whether the registrants have submitted electronically and posted on their corporate Web sites, if any, every Interactive Data File required to be submitted and posted pursuant to Rule 405 of Regulation S-T (§232.405 of this chapter) during the preceding 12 months (or for such shorter period that the registrants were required to submit and post such files):

Yes [X] No [ ]

Indicate by check mark whether the registrant is a large accelerated filer, an accelerated filer, a non-accelerated filer, or a smaller reporting company. See definitions of "large accelerated filer," "accelerated filer," and "smaller reporting company" in Rule 12b-2 of the Exchange Act.

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

Indicate by check mark whether the registrant is a shell company (as defined in Rule 12b-2 of the Exchange Act):

MGE Energy, Inc. and Madison Gas and Electric Company: Yes [ ] No [X]

Number of Shares Outstanding of Each Class of Common Stock as of October 31, 2015
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' 2014 Annual Report on Form 10-K: Item 1A. Risk Factors, Item 7. Management's Discussion and Analysis of Financial Condition and Results of Operations, as updated by Part I, Item 2. Management's Discussion and Analysis of Financial Condition and Results of Operations in this report, and Item 8. Financial Statements and Supplementary Data – Note 18, as updated by Part I, Item 1. Financial Statements – Note 8 in this report, and (b) other factors discussed herein and in other filings made by that registrant with the SEC.

Readers are cautioned not to place undue reliance on these forward-looking statements, which apply only as of the date of this report. MGE Energy and MGE undertake no obligation to release publicly any revision to these forward-looking statements to reflect events or circumstances after the date of this report, except as required by law.

Where to Find More Information

The public may read and copy any reports or other information that MGE Energy and MGE file with the SEC at the SEC's public reference room at 100 F Street, NE, Washington, D.C. 20549. The public may obtain information on the operation of the Public Reference Room by calling the SEC at 1-800-SEC-0330. These documents also are available to the public from commercial document retrieval services, the website maintained by the SEC at sec.gov, MGE Energy's website at mgeenergy.com, and MGE's website at mge.com. Copies may be obtained from our websites free of charge. Information contained on MGE Energy's and MGE's websites shall not be deemed incorporated into, or to be a part of, this report.

3

Definitions, Abbreviations, and Acronyms Used in the Text and Notes of this Report

Abbreviations, acronyms, and definitions used in the text and notes of this report are defined below.

MGE Energy and Subsidiaries:
CWDC	Central Wisconsin Development Corporation
MAGAEL	MAGAEL, LLC
MGE	Madison Gas and Electric Company
MGE Energy	MGE Energy, Inc.
MGE Power	MGE Power, LLC
MGE Power Elm Road	MGE Power Elm Road, LLC
MGE Power West Campus	MGE Power West Campus, LLC
MGE Services	MGE Services, LLC
MGE State Energy Services	MGE State Energy Services, LLC
MGE Transco	MGE Transco Investment, LLC
NGV Fueling Services	NGV Fueling Services, LLC
North Mendota	North Mendota Energy & Technology Park, LLC
Other Defined Terms:
AFUDC	Allowance for Funds Used During Construction
ARO	Asset Retirement Obligation
ATC	American Transmission Company LLC
BART	Best Available Retrofit Technology
Blount	Blount Station
CAA	Clean Air Act
CAIR	Clean Air Interstate Rule
CAVR	Clean Air Visibility Rule
CCR	Coal Combustion Residual
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
CSAPR	Cross-State Air Pollution Rule
CWA	Clean Water Act
Dth	Dekatherms, a quantity measure used in respect of natural gas
EGUs	Electric Generating Units
ELG	Effluent Limitations Guidelines
Elm Road Units	Elm Road Generating Station
EPA	United States Environmental Protection Agency
FASB	Financial Accounting Standards Board
FERC	Federal Energy Regulatory Commission
FTR	Financial Transmission Rights
GHG	Greenhouse Gas
Heating degree days (HDD)	Measure of the extent to which the average daily temperature is below 65 degrees Fahrenheit, which is considered an indicator of possible increased demand for energy to provide heating
IRS	Internal Revenue Service
kWh	Kilowatt-hour, a measure of electric energy produced
MATS	Mercury and Air Toxics Standards
MISO	Midcontinent Independent System Operator (a regional transmission organization)
MW	Megawatt, a measure of electric energy generating capacity
MWh	Megawatt-hour, a measure of electric energy produced
NAAQS	National Ambient Air Quality Standards
NOV	Notice of Violation
NOx	Nitrogen Oxides

4

PGA	Purchased Gas Adjustment clause, a regulatory mechanism used to reconcile natural gas costs recovered in rates to actual costs
PJM	PJM Interconnection, LLC (a regional transmission organization)
PM	Particulate Matter
PPA	Purchased Power Agreement
ppb	Parts Per Billion
PSCW	Public Service Commission of Wisconsin
ROE	Return on Equity
SCR	Selective Catalytic Reduction
SEC	Securities and Exchange Commission
SIP	State Implementation Plan
SO2	Sulfur Dioxide
the State	State of Wisconsin
Stock Plan	Direct Stock Purchase and Dividend Reinvestment Plan of MGE Energy
UW	University of Wisconsin at Madison
VIE	Variable Interest Entity
WCCF	West Campus Cogeneration Facility
WDNR	Wisconsin Department of Natural Resources
WEPCO	Wisconsin Electric Power Company
Working capital	Current assets less current liabilities
WPDES	Wisconsin Pollutant Discharge Elimination System
WPL	Wisconsin Power and Light Company
WPSC	Wisconsin Public Service Corporation
XBRL	eXtensible Business Reporting Language

5

Item 1. Financial Statements.

MGE Energy, Inc.

Consolidated Statements of Income (unaudited)

(In thousands, except per-share amounts)

		Three Months Ended				Nine Months Ended
		September 30,				September 30,
		2015		2014		2015		2014
Operating Revenues:
Regulated electric revenues	$	121,453	$	112,869	$	319,174	$	308,418
Regulated gas revenues		17,431		21,404		108,028		163,335
Nonregulated revenues		1,911		862		5,853		2,392
Total Operating Revenues		140,795		135,135		433,055		474,145
Operating Expenses:
Fuel for electric generation		17,055		9,838		41,624		35,836
Purchased power		18,484		21,303		62,614		58,779
Cost of gas sold		4,299		11,039		57,868		107,679
Other operations and maintenance		38,721		37,587		120,895		118,267
Depreciation and amortization		11,182		10,376		33,026		30,191
Other general taxes		4,877		4,872		14,951		14,861
Total Operating Expenses		94,618		95,015		330,978		365,613
Operating Income		46,177		40,120		102,077		108,532
Other income, net		2,564		2,636		7,115		10,736
Interest expense, net		(5,036)		(5,141)		(15,135)		(14,550)
Income before income taxes		43,705		37,615		94,057		104,718
Income tax provision		(15,351)		(14,286)		(33,946)		(39,585)
Net Income	$	28,354	$	23,329	$	60,111	$	65,133
Earnings Per Share of Common Stock
(basic and diluted)	$	0.82	$	0.67	$	1.73	$	1.88
Dividends per share of common stock	$	0.295	$	0.283	$	0.860	$	0.826
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,
		2015		2014		2015		2014
Net Income	$	28,354	$	23,329	$	60,111	$	65,133
Other comprehensive income, net of tax:
Unrealized (loss) gain on available-for-sale
securities, net of tax ($56 and ($63), and $120 and
($38), respectively)		(85)		95		(180)		56
Comprehensive Income	$	28,269	$	23,424	$	59,931	$	65,189
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,
		2015		2014
Operating Activities:
Net income	$	60,111	$	65,133
Items not affecting cash:
Depreciation and amortization		33,026		30,191
Deferred income taxes		7,370		24,376
Provision for doubtful receivables		(78)		1,001
Employee benefit plan expenses		2,500		(814)
Equity earnings in ATC		(6,568)		(7,306)
Other items		(154)		(843)
Changes in working capital items:
Decrease in current assets		39,034		13,318
Decrease in current liabilities		(18,231)		(7,515)
Dividend income from ATC		4,732		5,762
Cash contributions to pension and other postretirement plans		(12,460)		(2,449)
Other noncurrent items, net		13,373		118
Cash Provided by Operating Activities		122,655		120,972
Investing Activities:
Capital expenditures		(52,311)		(66,138)
Capital contributions to investments		(785)		(1,830)
Other		(85)		(1,265)
Cash Used for Investing Activities		(53,181)		(69,233)
Financing Activities:
Cash dividends paid on common stock		(29,816)		(28,634)
Repayment of long-term debt		(3,128)		(3,069)
Repayment of short-term debt		(7,000)		-
Other		(1,018)		(130)
Cash Used for Financing Activities		(40,962)		(31,833)
Change in cash and cash equivalents		28,512		19,906
Cash and cash equivalents at beginning of period		65,755		68,813
Cash and Cash Equivalents at End of Period	$	94,267	$	88,719
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		2015		2014
Current Assets:
Cash and cash equivalents	$	94,267	$	65,755
Accounts receivable, less reserves of $3,418 and $4,329, respectively		35,507		41,614
Other accounts receivable, less reserves of $702 and $420, respectively		6,549		7,610
Unbilled revenues		21,252		31,262
Materials and supplies, at average cost		19,258		17,121
Fossil fuel		14,195		8,098
Stored natural gas, at average cost		16,998		21,036
Prepaid taxes		14,507		38,910
Regulatory assets - current		9,331		8,360
Deferred income taxes - current		-		3,482
Other current assets		9,916		10,711
Total Current Assets		241,780		253,959
Regulatory assets		155,469		156,823
Other deferred assets and other		10,028		7,018
Property, Plant, and Equipment:
Property, plant, and equipment, net		1,207,520		1,189,077
Construction work in progress		25,015		19,029
Total Property, Plant, and Equipment		1,232,535		1,208,106
Investments		74,016		71,760
Total Assets	$	1,713,828	$	1,697,666
LIABILITIES AND CAPITALIZATION
Current Liabilities:
Long-term debt due within one year	$	4,245	$	4,182
Short-term debt		-		7,000
Accounts payable		35,854		41,655
Accrued interest and taxes		3,996		5,086
Accrued payroll related items		10,141		11,241
Deferred income taxes		945		-
Regulatory liabilities - current		4,376		-
Derivative liabilities		8,880		6,901
Other current liabilities		5,821		13,931
Total Current Liabilities		74,258		89,996
Other Credits:
Deferred income taxes		345,127		342,045
Investment tax credit - deferred		1,094		1,223
Regulatory liabilities		24,467		22,715
Accrued pension and other postretirement benefits		78,879		90,201
Derivative liabilities		48,070		46,560
Other deferred liabilities and other		60,476		50,269
Total Other Credits		558,113		553,013
Capitalization:
Common shareholders' equity		689,374		659,401
Long-term debt		392,083		395,256
Total Capitalization		1,081,457		1,054,657
Commitments and contingencies (see Footnote 8)		-		-
Total Liabilities and Capitalization	$	1,713,828	$	1,697,666
The accompanying notes are an integral part of the above unaudited consolidated financial statements.

8

MGE Energy, Inc.

Consolidated Statements of Common Equity (unaudited)

(In thousands, except per-share amounts)

									Accumulated
					Additional				Other
	Common Stock				Paid-in		Retained		Comprehensive
	Shares		Value		Capital		Earnings		Income		Total
2014
Beginning balance - December 31, 2013	34,668	$	34,668	$	316,268	$	266,197	$	377	$	617,510
Net income							65,133				65,133
Other comprehensive income (loss)									56		56
Common stock dividends declared
($0.826 per share)							(28,634)				(28,634)
Cash in lieu of fractional shares related
to stock split							(80)				(80)
Ending balance - September 30, 2014	34,668	$	34,668	$	316,268	$	302,616	$	433	$	653,985
2015
Beginning balance - December 31, 2014	34,668	$	34,668	$	316,268	$	308,007	$	458	$	659,401
Cumulative effect of new accounting
principle (see Footnote 4)							(142)				(142)
Beginning balance - Adjusted							307,865				659,259
Net income							60,111				60,111
Other comprehensive income (loss)									(180)		(180)
Common stock dividends declared
($0.860 per share)							(29,816)				(29,816)
Ending balance - September 30, 2015	34,668	$	34,668	$	316,268	$	338,160	$	278	$	689,374
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 September 30,				Nine Months Ended September 30,
		2015		2014		2015		2014
Operating Revenues:
Regulated electric revenues	$	121,460	$	112,875	$	319,191	$	308,435
Regulated gas revenues		17,435		21,410		108,039		163,351
Nonregulated revenues		1,911		862		5,853		2,392
Total Operating Revenues		140,806		135,147		433,083		474,178
Operating Expenses:
Fuel for electric generation		17,057		9,841		41,630		35,843
Purchased power		18,488		21,307		62,624		58,790
Cost of gas sold		4,302		11,045		57,879		107,695
Other operations and maintenance		38,561		37,309		120,269		117,593
Depreciation and amortization		11,170		10,364		32,991		30,156
Other general taxes		4,877		4,872		14,951		14,861
Income tax provision		14,401		13,338		31,218		36,180
Total Operating Expenses		108,856		108,076		361,562		401,118
Operating Income		31,950		27,071		71,521		73,060
Other Income and Deductions:
AFUDC - equity funds		206		255		501		3,306
Equity in earnings in ATC		2,398		2,423		6,568		7,306
Income tax provision		(977)		(984)		(2,763)		(3,390)
Other income, net		(73)		(111)		(288)		(351)
Total Other Income and Deductions		1,554		1,583		4,018		6,871
Income before interest expense		33,504		28,654		75,539		79,931
Interest Expense:
Interest on long-term debt		5,123		5,225		15,410		15,714
Other interest, net		37		44		52		52
AFUDC - borrowed funds		(67)		(84)		(163)		(1,090)
Net Interest Expense		5,093		5,185		15,299		14,676
Net Income	$	28,411	$	23,469	$	60,240	$	65,255
Less: Net Income Attributable to Noncontrolling
Interest, net of tax		(6,633)		(6,653)		(19,812)		(19,784)
Net Income Attributable to MGE	$	21,778	$	16,816	$	40,428	$	45,471
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 September 30,				Nine Months Ended September 30,
		2015		2014		2015		2014
Net Income	$	28,411	$	23,469	$	60,240	$	65,255
Other comprehensive income, net of tax:
Unrealized (loss) gain on available-for-sale
securities, net of tax ($19 and ($29), and $92 and
$36, respectively)		(28)		43		(137)		(54)
Comprehensive Income	$	28,383	$	23,512	$	60,103	$	65,201
Less: Comprehensive Income Attributable to
Noncontrolling Interest, net of tax		(6,633)		(6,653)		(19,812)		(19,784)
Comprehensive Income Attributable to MGE	$	21,750	$	16,859	$	40,291	$	45,417
The accompanying notes are an integral part of the above unaudited consolidated financial statements.

10

Madison Gas and Electric Company

Consolidated Statements of Cash Flows (unaudited)

(In thousands)

		Nine Months Ended
		September 30,
		2015		2014
Operating Activities:
Net income	$	60,240	$	65,255
Items not affecting cash:
Depreciation and amortization		32,991		30,156
Deferred income taxes		4,510		23,811
Provision for doubtful receivables		(78)		1,001
Employee benefit plan expenses		2,500		(814)
Equity earnings in ATC		(6,568)		(7,306)
Other items		234		(446)
Changes in working capital items:
Decrease in current assets		46,806		13,258
Decrease in current liabilities		(15,876)		(5,457)
Dividend income from ATC		4,732		5,762
Cash contributions to pension and other postretirement plans		(12,460)		(2,449)
Other noncurrent items, net		13,076		(24)
Cash Provided by Operating Activities		130,107		122,747
Investing Activities:
Capital expenditures		(52,311)		(66,138)
Capital contributions to investments		(533)		(1,420)
Other		(90)		(1,087)
Cash Used for Investing Activities		(52,934)		(68,645)
Financing Activities:
Cash dividends paid to parent by MGE		(20,000)		(26,500)
Distributions to parent from noncontrolling interest		(12,007)		(17,778)
Equity contribution received by noncontrolling interest		3,053		1,420
Repayment of long-term debt		(3,128)		(3,069)
Repayment of short-term debt		(7,000)		-
Other		(682)		-
Cash Used for Financing Activities		(39,764)		(45,927)
Change in cash and cash equivalents		37,409		8,175
Cash and cash equivalents at beginning of period		4,562		14,808
Cash and Cash Equivalents at End of Period	$	41,971	$	22,983
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		2015		2014
Current Assets:
Cash and cash equivalents	$	41,971	$	4,562
Accounts receivable, less reserves of $3,418 and $4,329, respectively		35,507		41,614
Affiliate receivables		602		7,112
Other accounts receivable, less reserves of $702 and $420, respectively		6,490		7,524
Unbilled revenues		21,252		31,262
Materials and supplies, at average cost		19,258		17,121
Fossil fuel		14,195		8,098
Stored natural gas, at average cost		16,997		21,035
Prepaid taxes		13,418		39,103
Regulatory assets - current		9,331		8,360
Deferred income taxes - current		-		1,271
Other current assets		9,881		10,683
Total Current Assets		188,902		197,745
Affiliate receivable long-term		4,898		5,295
Regulatory assets		155,469		156,823
Other deferred assets and other		7,908		4,977
Property, Plant, and Equipment:
Property, plant, and equipment, net		1,206,828		1,188,351
Construction work in progress		25,015		19,029
Total Property, Plant, and Equipment		1,231,843		1,207,380
Investments		70,533		68,402
Total Assets	$	1,659,553	$	1,640,622
LIABILITIES AND CAPITALIZATION
Current Liabilities:
Long-term debt due within one year	$	4,245	$	4,182
Short-term debt		-		7,000
Accounts payable		35,847		41,654
Accrued interest and taxes		3,950		5,039
Accrued payroll related items		10,141		11,241
Deferred income taxes		946		-
Regulatory liabilities - current		4,376		-
Derivative liabilities		8,880		6,901
Other current liabilities		5,600		11,350
Total Current Liabilities		73,985		87,367
Other Credits:
Deferred income taxes		337,233		334,773
Investment tax credit - deferred		1,094		1,223
Regulatory liabilities		24,467		22,715
Accrued pension and other postretirement benefits		78,879		90,201
Derivative liabilities		48,070		46,560
Other deferred liabilities and other		60,475		50,267
Total Other Credits		550,218		545,739
Capitalization:
Common shareholder's equity		506,720		486,571
Noncontrolling interest		136,547		125,689
Total Equity		643,267		612,260
Long-term debt		392,083		395,256
Total Capitalization		1,035,350		1,007,516
Commitments and contingencies (see Footnote 8)		-		-
Total Liabilities and Capitalization	$	1,659,553	$	1,640,622
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			Interest		Total
2014
Beginning balance - Dec. 31, 2013	17,348	$	17,348	$	192,417	$	247,534	$	192	$	118,963	$	576,454
Net income							45,471				19,784		65,255
Other comprehensive loss									(54)				(54)
Cash dividends paid to parent
by MGE							(26,500)						(26,500)
Equity contribution received by
noncontrolling interest											1,420		1,420
Distributions to parent from
noncontrolling interest											(17,778)		(17,778)
Ending balance - September 30, 2014	17,348	$	17,348	$	192,417	$	266,505	$	138	$	122,389	$	598,797
2015
Beginning balance - Dec. 31, 2014	17,348	$	17,348	$	192,417	$	276,662	$	144	$	125,689	$	612,260
Cumulative effect of new accounting
principle (see Footnote 4)							(142)						(142)
Beginning balance - Adjusted							276,520						612,118
Net income							40,428				19,812		60,240
Other comprehensive loss									(137)				(137)
Cash dividends paid to parent
by MGE							(20,000)						(20,000)
Equity contribution received by
noncontrolling interest											3,053		3,053
Distributions to parent from
noncontrolling interest											(12,007)		(12,007)
Ending balance - September 30, 2015	17,348	$	17,348	$	192,417	$	296,948	$	7	$	136,547	$	643,267
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, 2015

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 2014 Annual Report on Form 10-K.

The accompanying consolidated financial statements as of September 30, 2015, 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 MGE Energy's and MGE's 2014 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 52 through 101 of the 2014 Annual Report on Form 10-K.

2.

Equity and Financing Arrangements.

a.

Common Stock - MGE Energy.

MGE Energy sells shares of its common stock through its Stock Plan. Those shares may be newly issued shares or shares that MGE Energy has purchased in the open market for resale to participants in the Stock Plan. All sales under the Stock Plan are covered by a shelf registration statement that MGE Energy filed with the SEC. For both the nine months ended September 30, 2015 and 2014, MGE Energy did not issue any new shares of common stock under the Stock Plan.

b.

Dilutive Shares Calculation - MGE Energy.

MGE Energy does not hold any dilutive securities.

c.

Credit Facilities - MGE Energy and MGE.

On June 1, 2015, MGE Energy and MGE entered into new revolving credit agreements, and terminated their existing revolving credit agreements.

MGE Energy entered into a Credit Agreement with an aggregate commitment of $50 million (MGE Energy Credit Agreement) with various financial institutions, as lenders, and JPMorgan Chase Bank, N.A., as administrative agent. Also, MGE entered into two revolving credit agreements: a Credit Agreement with an aggregate commitment of $60 million (MGE JPM Credit Agreement) with various financial institutions, as lenders, and JPMorgan Chase Bank, N.A., as administrative agent, and a Credit Agreement with an aggregate commitment of $40 million (MGE USB Credit Agreement) with various financial institutions, as lenders, and U.S. Bank National Association, as administrative agent. The MGE Energy Credit Agreement, the MGE JPM Credit Agreement, and the MGE USB Credit Agreement are collectively referred to as the Credit Agreements. As of September 30, 2015, neither MGE Energy nor MGE had any borrowings outstanding under the Credit Agreements, and MGE had no commercial paper outstanding.

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The Credit Agreements have a term expiring on June 1, 2020. Borrowings under the Credit Agreements may bear interest at a rate based upon either a "floating rate" or a "Eurodollar Rate" adjusted for statutory reserve requirements, plus an adder based upon the credit ratings assigned to MGE's senior unsecured long-term debt securities. The "floating rate" is calculated on a daily basis as the highest of a prime rate, a Federal Funds effective rate plus 0.5% per annum, or a Eurodollar Rate for a one-month interest period plus 1%. The "floating rate" adder ranges from zero to 0.125%. The "Eurodollar Rate" is calculated as provided in the Credit Agreements. The "Eurodollar Rate" adder ranges from 0.625% to 1.125%.

3.

Investment in ATC - MGE Energy and MGE.

ATC owns and operates electric transmission facilities primarily in Wisconsin. MGE received an interest in ATC when it, like other Wisconsin electric utilities, contributed its electric transmission facilities to ATC as required by Wisconsin law. That interest is presently held by MGE Transco, which is jointly owned by MGE Energy and MGE.

MGE Transco has accounted for its investment in ATC under the equity method of accounting. For the nine months ended September 30, 2015 and 2014, MGE Transco recorded the following:

		Nine Months Ended September 30,
(In thousands)		2015		2014
Equity in earnings from investment in ATC	$	6,568	$	7,306
Dividends received from ATC		4,732		5,762
Capital contributions to ATC		533		1,420

MGE Transco's investment in ATC as of September 30, 2015, and December 31, 2014, was $70.0 million and $67.7 million, respectively. On October 30, 2015, MGE Transco made a $0.2 million capital contribution to ATC.

At September 30, 2015, MGE is the majority owner, and MGE Energy, the holding company, is the minority owner of MGE Transco. MGE Energy's proportionate share of the equity and net income of MGE Transco is classified within the MGE financial statements as noncontrolling interest.

ATC's summarized financial data for the three and nine months ended September 30, 2015 and 2014, is as follows:

		Three Months Ended September 30,				Nine Months Ended September 30,
(In thousands)		2015		2014		2015		2014
Operating revenues	$	164,515	$	163,643	$	482,043	$	486,970
Operating expenses		(78,059)		(76,561)		(238,336)		(229,589)
Other income, net		585		693		566		1,403
Interest expense, net		(23,655)		(22,204)		(72,310)		(66,442)
Earnings before members' income taxes	$	63,386	$	65,571	$	171,963	$	192,342

4.

Chattel Paper Agreements - MGE Energy and MGE.

MGE makes available to qualifying customers a financing program for the purchase and installation of energy-related equipment that will provide more efficient use of utility service at the customer's property. The energy-related equipment installed at the customer sites is used to secure the customer loans. MGE is a party to a chattel paper purchase agreement with a financial institution under which it can sell or finance an undivided interest with recourse, in up to $10.0 million of the financing program receivables, until July 31, 2016. The length of the MGE guarantee to the financial institution varies from one to ten years depending on the term of the underlying customer loan. The loan balances outstanding at September 30, 2015, approximate the fair value of the energy-related equipment acting as collateral. MGE accounts for these agreements as secured borrowings.

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Prior to the Transfers and Servicing Asset authoritative accounting guidance that became effective in 2015, these agreements were treated as off-balance sheet arrangements. Beginning January 1, 2015, these agreements are included as assets and liabilities in the consolidated balance sheet. As of September 30, 2015, assets (other accounts receivable and other deferred assets) and liabilities (accounts payable and other deferred liabilities) increased approximately $3.8 million as a cumulative result of the guidance. In addition, the cumulative effect of this guidance resulted in a $0.1 million reduction in retained earnings.

As of September 30, 2015, the remaining contractual maturities of the chattel paper agreements were as follows:

(In thousands)		2015		2016		2017		2018		Thereafter		Total
Repurchase-to-Maturity Transactions:
Loans	$	132	$	735	$	472	$	504	$	1,963	$	3,806

5.

Taxes - MGE Energy and MGE.

MGE Energy's effective income tax rates for the three and nine months ended September 30, 2015, were 35.1% and 36.1%, respectively, compared to 38.0% and 37.8% for the same periods in 2014. MGE's effective income tax rates for the three and nine months ended September 30, 2015, were 35.1% and 36.1%, respectively, compared to 37.9% and 37.8% for the same periods in 2014. The decrease in the effective tax rates is due in part to a higher domestic manufacturing deduction, offset by lower AFUDC equity earnings in 2015.

6.

Pension and Other Postretirement Plans - MGE Energy and MGE.

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

The following table presents the components of MGE Energy's and MGE's net periodic benefit costs recognized for the three and nine months ended September 30, 2015 and 2014. 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)		2015		2014		2015		2014
Pension Benefits
Components of net periodic (benefit) cost:
Service cost	$	1,878	$	1,536	$	5,715	$	4,609
Interest cost		3,594		3,367		10,936		10,102
Expected return on assets		(5,930)		(5,467)		(18,045)		(16,402)
Amortization of:
Prior service cost		6		51		18		152
Actuarial loss		1,393		180		4,240		539
Net periodic (benefit) cost	$	941	$	(333)	$	2,864	$	(1,000)
Postretirement Benefits
Components of net periodic (benefit) cost:
Service cost	$	194	$	241	$	580	$	722
Interest cost		392		564		1,176		1,691
Expected return on assets		(355)		(478)		(1,063)		(1,432)
Amortization of:
Transition obligation		-		1		1		2
Prior service benefit		(337)		(487)		(1,009)		(1,462)
Actuarial loss		133		28		397		86
Net periodic (benefit) cost	$	27	$	(131)	$	82	$	(393)

7.

Share-Based Compensation - MGE Energy and MGE.

Under MGE Energy's Performance Unit Plan, eligible employees may receive performance units that entitle the holder to receive a cash payment equal to the value of a designated number of shares of MGE Energy's common stock, plus dividend equivalent payments thereon, at the end of the set performance period.

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On February 20, 2015, 18,948 units were granted based on the MGE Energy closing stock price as of that date. Units are subject to a five-year graded vesting schedule. On the grant date, MGE Energy and MGE measure the cost of the employee services received in exchange for a performance unit award based on the current market value of MGE Energy common stock. The fair value of the awards has been subsequently re-measured at September 30, 2015, as required by applicable accounting standards. Changes in fair value have been recognized as compensation cost. Since this amount is re-measured quarterly throughout the vesting period, the compensation cost is subject to variability.

For nonretirement eligible employees, stock based compensation costs are accrued and recognized using the graded vesting method. Compensation cost for retirement eligible employees or employees that will become retirement eligible during the vesting schedule are recognized on an abridged horizon.

In December 2013, a Director Incentive Plan was approved for the non-employee members of the Board of Directors. This plan is similar to MGE Energy's Performance Unit Plan for eligible employees described above. Under the plan, a non-employee director can receive performance units that entitle the holder to receive a cash payment equal to the value of a designated number of shares of MGE Energy's common stock, plus dividend payments, at the end of the set performance period. The units are subject to a three-year graded vesting schedule. In January 2015, 3,794 units were granted. For accounting purposes, the awards will be measured similarly to the employee unit awards.

During the nine months ended September 30, 2015 and 2014, MGE recorded $0.4 million and $0.9 million, respectively, in compensation expense as a result of awards under the plans. In January 2015, cash payments of $1.3 million were distributed relating to awards that were granted in 2010. During the nine months ended September 30, 2015, MGE recorded a $0.2 million gain on 4,676 units forfeited. No forfeitures occurred during the nine months ended September 30, 2014. At September 30, 2015, $4.2 million of outstanding awards are vested, and of this amount no cash settlements have occurred.

8.

Commitments and Contingencies - MGE Energy and MGE.

a.

Environmental.

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

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

In September 2015, the EPA released its final rule setting Effluent Limitations Guidelines (ELG) for the steam electric power generating industry. The ELG rule establishes federal limits on the amount of metals and other pollutants that can be discharged in wastewater from new and existing steam electric generation plants. The ELG rule mostly covers pollutants that are captured by certain air pollution control and via wet ash handling systems at coal-burning power plants with units greater than 50 megawatt (MW) generation capacity. Although we are still reviewing the ELG rule, we anticipate that some equipment upgrades may be necessary at the Columbia and Elm Road plants to comply with the new discharge standards. The rule will go into effect in 2018 and will be applied to Wisconsin-based power plants as they renew their WPDES permits.

MGE cannot accurately estimate the costs associated with the ELG rule without a more thorough evaluation. However, management believes that any compliance costs will be recovered in future rates based on previous treatment of environmental compliance projects.

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

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

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

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

On August 3, 2015, the EPA finalized its Clean Power Plan rule setting guidelines for states to use in developing plans to control GHG emissions from existing fossil fuel-fired electric generating units (EGUs) and systems. When fully implemented in 2030, the Clean Power Plan is projected to reduce GHG emissions from this sector by 32 percent below 2005 levels. States are given up to three years to submit a plan to meet the reduction goals and are expected to meet interim goals starting in 2022 and the final goal in 2030. Implementation of the rule is expected to have a direct impact on coal and natural gas fired generating units, including possible changes in dispatch and additional operating costs.

On October 23, 2015, several states, including Wisconsin, and several state regulatory bodies filed a joint petition seeking to have the U.S. Court of Appeals for the District of Columbia Circuit stay the effectiveness of the Clean Power Plant rule, which would otherwise become effective on December 22, 2015, and seeking expedited review of the petitioners' challenges to the legality of the adoption of the rule.

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

National Ambient Air Quality Standards (NAAQS)

The EPA's NAAQS regulations have been developed to set ambient levels of six pollutants to protect sensitive populations (primary NAAQS) and the environment (secondary NAAQS) from the negative effects of exposure to these pollutants at higher levels. MGE is following developments for several NAAQS, including for particulate matter, nitrogen dioxide, sulfur dioxide, and ozone. Further discussion on sulfur dioxide and ozone NAAQS follows. For additional information on the NAAQS process, see Footnote 18.d. of Notes to Consolidated Financial Statements under Item 8, Financial Statements and Supplementary Data, of MGE Energy's and MGE's 2014 Annual Report on Form 10-K.

Sulfur Dioxide (SO₂) NAAQS

The EPA's new 1-hour SO₂ NAAQS has been in place since 2010 and initial attainment/nonattainment designations by states were due in 2013. However, the EPA was sued by environmental groups for not making these designations in a timely and proper manner. In March 2015, the EPA entered into a court-approved consent decree requiring 1-hour SO₂ attainment/nonattainment area designations to be completed in three phases extending out until 2020. In August 2015, the EPA published its data requirements rule that lays out expectations, designation process options, and timeframes for states and tribes to meet. Under this new rule, states must submit their first designation proposals in July 2016 for those areas that contain large stationary sources of SO₂ (sources that emit over a threshold mass of SO₂, and/or over a threshold emissions rate). These proposals must identify one of the following options for demonstrating attainment with the 1-hour SO₂ NAAQS: modeling of SO₂ emissions; monitoring of SO₂ emissions; or limiting large stationary sources to 2,000 ton per year of SO₂ emissions by January 13, 2017. The EPA must make final designation determinations for these areas between 2017 and 2020 depending on the area.

In March 2015, MGE's Columbia plant was identified in the Federal Register as meeting the criteria of a large stationary source of SO₂ (based on 2012 data). As such, the State of Wisconsin must submit an attainment/nonattainment area designation plan for Columbia County (the county in which the Columbia plant is located). Since the 2012 data was collected, Columbia has installed pollution control equipment that has lowered its total SO₂ emissions and its SO₂ emissions rate. However, we will not know with any certainty if Columbia County will be determined to be in attainment until the State of Wisconsin completes its attainment/nonattainment demonstration and the EPA approves it. The outcome of this designation may have an adverse effect on the operation of the Columbia plant. MGE will monitor and participate in developments with the Columbia County designation process. Management believes compliance costs will be recovered in future rates based on previous treatment of environmental compliance projects.

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Ozone NAAQS

In October 2015, the EPA revised the primary and secondary ozone NAAQS, lowering each to 70 ppb. Based on current ozone monitoring data, it appears that Milwaukee County (where our Elm Road Units are located) may not attain the lowered standards. Current ozone monitoring data suggests that Dane and Columbia Counties (where our WCCF/Blount and Columbia Units are located, respectively) will meet the new ozone NAAQS. Nonetheless, final attainment designations for these three counties will be based upon air monitoring data for years 2014-2016 and must be approved by EPA. Once these designations are complete, the State of Wisconsin will develop implementation plans for each county designated as nonattainment, which could affect plant operations within the nonattainment counties. These implementation plans are not expected to be finalized until 2017 at the earliest. MGE will continue to monitor developments, attainment designations, and state actions and implementation plans.

EPA's Cross-State Air Pollution Rule

In July 2011, the EPA finalized its Cross-State Air Pollution Rule (CSAPR) as a court-ordered replacement for its Clean Air Interstate Rule (CAIR) that had been remanded in 2008. CSAPR is an interstate air pollution transport rule designed to reduce ozone and fine particulate matter (PM2.5) air levels in areas that the EPA has determined are being affected by pollution from neighboring and upwind states.

CSAPR has been the subject of extensive litigation. That litigation had delayed implementation and created uncertainty, however, the most recent D.C. Circuit ruling clears the way for CSAPR to be fully implemented in Wisconsin. Some uncertainty remains as to the ozone season NO_x budget for Wisconsin. In late 2014, the EPA tolled CSAPR's original compliance deadlines by three years and MGE's affected facilities must now meet their Phase I reduction obligations in 2015 and Phase II in 2017. MGE anticipates meeting its CSAPR requirements at all of our affected facilities by applying reductions achieved from recent pollution control installations and early reduction efforts. We do not anticipate this rule to have a significant impact on MGE.

Clean Air Visibility Rule (CAVR)

Columbia may be subject to the best available retrofit technology (BART) regulations, a subsection of the EPA's Clean Air Visibility Rule (CAVR), which may require pollution control retrofits. Columbia's pollution control upgrades and the EPA's stance that compliance with the CSAPR equals compliance with BART should mean that Columbia will not need to do additional work to meet BART requirements. At this time, however, the BART regulatory obligations, compliance strategies, and costs remain uncertain due to the legal uncertainty surrounding CSAPR.

EPA's Coal Combustion Residuals Rule

In December 2014, the EPA finalized its Disposal of Coal Combustion Residuals from Electric Utilities (CCR) rule. The rule became effective on October 19, 2015. It provides that coal ash will be regulated as a solid waste, and defines what ash use activities would be considered generally exempt beneficial reuse of coal ash. The rule also regulates landfills, ash ponds, and other surface impoundments for coal combustion residuals by regulating their design, location, monitoring, and operation. Landfills and impoundments that cannot meet design criteria will need to formally close within defined timeframes.

The Columbia and Elm Road Units co-owners and plant operators are evaluating the final rule to determine what changes may be necessary at those facilities and the associated timeframes. We anticipate that some design and operational changes may need to be made at these facilities. Review of our Elm Road facility has indicated that the costs to comply with this rule are not expected to be significant. We are still evaluating the rule's full effects at Columbia, however, Columbia's operator has developed a preliminary implementation schedule for meeting the various deadlines spelled out in the rule. Management believes compliance costs will be recovered in future rates based on previous treatment of environmental compliance projects.

Columbia

Based upon current available information, compliance with various environmental requirements and initiatives is expected to result in significant additional operating and capital expenditures at Columbia as noted below.

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Columbia Clean Air Act Litigation

Columbia is a coal-fired generating station operated by WPL in which WPL, WPSC, and MGE have ownership interests. In December 2009, the EPA sent a Notice of Violation (NOV) to MGE as one of the co-owners of Columbia. The NOV alleged that WPL and the Columbia co-owners failed to comply with appropriate pre-construction review and permitting requirements and, as a result, violated the Prevention of Significant Deterioration program requirements, Title V Operating Permit requirements of the CAA, and the Wisconsin SIP. In April 2013, the EPA filed a lawsuit against the co-owners of Columbia asserting similar allegations. In September 2010 and April 2013, the Sierra Club filed civil lawsuits against WPL alleging violations of the CAA at Columbia and other Wisconsin facilities operated by WPL. In June 2013, the court approved and entered a consent decree entered by the EPA, Sierra Club, and the co-owners of Columbia to resolve these claims, while admitting no liability. One of the requirements of the consent decree requires installation of a SCR system at Columbia Unit 2 by December 31, 2018. Installation of the SCR has been approved by the PSCW. MGE's share of the projected cost for the SCR system is approximately $19-$29 million. In addition, the consent decree establishes emission rate limits for SO₂, NO_x, and particulate matter and annual plant-wide emission caps for SO₂ and NO_x. MGE intends to seek recovery in future rates of the costs associated with its compliance with the terms of the final consent decree and currently expects to recover any material compliance costs.

b.

Legal Matters.

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

c.

Purchase Contracts.

MGE Energy and MGE have entered into various commodity supply, transportation, and storage contracts to meet their obligations to deliver electricity and natural gas to customers. As of September 30, 2015, the future commitments related to these purchase contracts were as follows:

(In thousands)		2015		2016		2017		2018		2019
Coal(a)	$	6,211	$	21,639	$	10,664	$	6,560	$	3,850
Natural gas
Transportation & storage(b)		5,229		18,117		17,983		17,901		16,971
Supply(c)		10,704		11,127		-		-		-
	$	22,144	$	50,883	$	28,647	$	24,461	$	20,821

(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. If any minimum purchase obligations must be paid under these contracts, management believes these obligations would be considered costs of service and recoverable in rates.

(b)

MGE'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. Management expects to recover these costs in future customer rates.

d.

Asset Retirement Obligation.

MGE Energy and MGE are required to record a liability for the fair value of an ARO to be recognized in the period in which it is incurred if it can be reasonably estimated. The offsetting associated asset retirement costs are capitalized as a long-lived asset and depreciated over the asset's useful life. As of September 30, 2015, MGE recorded an obligation of $2.3 million for the fair value of its legal liability for asset retirement obligations (AROs) associated with the effect of the final Coal Combustion Residual Rule at Columbia. MGE has regulatory treatment and recognizes regulatory assets or liabilities for the timing differences between when we recover legal AROs in rates and when those costs would actually be recognized.

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9.

Derivative and Hedging Instruments - MGE Energy and MGE.

a.

Purpose.

As part of its regular operations, MGE enters into contracts, including options, swaps, futures, forwards, and other contractual commitments, to manage its exposure to commodity prices. To the extent that these contracts are derivatives, MGE assesses whether or not the normal purchases or normal sales exclusion applies. For contracts to which this exclusion cannot be applied, MGE Energy and MGE recognize such derivatives in the consolidated balance sheets at fair value. MGE's commodity derivative activities are conducted in accordance with its electric and gas risk management program, which is approved by the PSCW and limits the volume MGE can hedge with specific risk management strategies. The maximum length of time over which cash flows related to energy commodities can be hedged is four years. If the derivative qualifies for regulatory deferral, the derivatives are marked to fair value and are offset with a corresponding regulatory asset or liability. The deferred gain or loss is recognized in earnings in the delivery month applicable to the instrument. Gains and losses related to hedges qualifying for regulatory treatment are recoverable in gas rates through the PGA or in electric rates as a component of the fuel rules mechanism.

b.

Notional Amounts.

The gross notional volume of open derivatives is as follows:

	September 30, 2015	December 31, 2014
Commodity derivative contracts	343,560 MWh	448,000 MWh
Commodity derivative contracts	6,547,500 Dth	4,405,000 Dth
FTRs	3,286 MW	1,854 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, 2015, and December 31, 2014, the cost basis of exchange traded derivatives and FTRs exceeded their fair value by $0.4 million and $1.6 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, 2015, and December 31, 2014, reflects a loss position of $57.0 million and $53.4 million, respectively. The actual cost will be recognized in purchased power expense in the month of purchase.

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The following table summarizes the fair value of the derivative instruments on the consolidated balance sheets. All derivative instruments in this table are presented on a gross basis and are calculated prior to the netting of instruments with the same counterparty under a master netting agreement as well as the netting of collateral. For financial statement purposes, MGE Energy and MGE have netted instruments with the same counterparty under a master netting agreement as well as the netting of collateral. At September 30, 2015, MGE Energy and MGE had the right to reclaim collateral (a receivable) of $0.8 million.

	Asset Derivatives			Liability Derivatives
(In thousands)	Balance Sheet Location		Fair Value	Balance Sheet Location		Fair Value
September 30, 2015
Commodity derivative contracts	Other current assets	$	375	Derivative liability (current)	$	1,196
Commodity derivative contracts	Other deferred charges		65	Derivative liability (long-term)		62
FTRs	Other current assets		370	Derivative liability (current)		-
PPA	N/A		N/A	Derivative liability (current)		8,880
PPA	N/A		N/A	Derivative liability (long-term)		48,070
December 31, 2014
Commodity derivative contracts	Other current assets	$	130	Derivative liability (current)	$	2,262
Commodity derivative contracts	Other deferred charges		93	Derivative liability (long-term)		171
FTRs	Other current assets		642	Derivative liability (current)		-
PPA	N/A		N/A	Derivative liability (current)		6,870
PPA	N/A		N/A	Derivative liability (long-term)		46,560

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 sheet		Collateral posted against derivative positions		Net amount presented in balance sheet
September 30, 2015
Commodity derivative contracts	$	440	$	(431)	$	-	$	9
FTRs		370		-		-		370
December 31, 2014
Commodity derivative contracts	$	223	$	(223)	$	-	$	-
FTRs		642		-		-		642

Offsetting of Derivative Liabilities
(In thousands)		Gross amounts		Gross amounts offset in balance sheet		Collateral posted against derivative positions		Net amount presented in balance sheet
September 30, 2015
Commodity derivative contracts	$	1,258	$	(431)	$	(827)	$	-
PPA		56,950		-		-		56,950
December 31, 2014
Commodity derivative contracts	$	2,433	$	(223)	$	(2,179)	$	31
PPA		53,430		-		-		53,430

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The following tables summarize the unrealized and realized gains (losses) related to the derivative instruments on the consolidated balance sheets at September 30, 2015 and 2014, and the consolidated income statements for the three and nine months ended September 30, 2015 and 2014.

		2015				2014
(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,	$	56,048	$	455	$	48,853	$	676
Unrealized loss (gain)		4,036		-		5,329		-
Realized (loss) gain reclassified to a deferred
account		(408)		408		(314)		314
Realized (loss) gain reclassified to income
statement		(2,278)		(91)		(1,184)		(249)
Balance at September 30,	$	57,398	$	772	$	52,684	$	741
Nine Months Ended September 30:
Balance at January 1,	$	54,998	$	1,001	$	63,893	$	411
Unrealized loss (gain)		8,514		-		(18,090)		-
Realized (loss) gain reclassified to a deferred
account		(1,700)		1,700		1,120		(1,120)
Realized (loss) gain reclassified to income
statement		(4,414)		(1,929)		5,761		1,450
Balance at September 30,	$	57,398	$	772	$	52,684	$	741

		Realized losses (gains)
		2015				2014
(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	$	862	$	(17)	$	480	$	(18)
FTRs		(233)		-		(97)		-
PPA		1,757		-		1,068		-
Nine Months Ended September 30:
Commodity derivative contracts	$	1,860	$	1,742	$	(5,376)	$	(1,367)
FTRs		(607)		-		(929)		-
PPA		3,348		-		461		-

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, 2015, 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, 2015, and December 31, 2014, certain counterparties were in a net liability of less than $0.1 million.

Nonperformance of counterparties to the non-exchange traded derivatives could expose MGE to credit loss. However, MGE enters into transactions only with companies that meet or exceed strict credit guidelines, and it monitors these counterparties on an ongoing basis to mitigate nonperformance risk in its portfolio. As of September 30, 2015, no counterparties have defaulted.

23

10.

Rate Matters - MGE Energy and MGE.

a.

Rate Proceedings.

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

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

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

On July 26, 2013, the PSCW authorized MGE to freeze electric and natural gas rates at 2013 levels for 2014. The order authorized 100% AFUDC on the Columbia scrubber construction project and deferral of increased costs related to ATC and MISO network upgrade fees. As part of the rate freeze plan authorized by the PSCW, effective January 1, 2014, approximately $6.3 million associated with a 2012 fuel rule surplus credit was required to be refunded to customers and was amortized in 2014. The fuel credit accrued interest at MGE's weighted cost of capital. The authorized return on common stock equity was unchanged at 10.3%.

b.

Fuel Rules.

Fuel rules require the PSCW and Wisconsin utilities to defer electric fuel-related costs that fall outside a symmetrical cost tolerance band around the amount approved for a utility in its annual fuel proceedings. Any over/under recovery of the actual costs is determined on an annual basis and is adjusted in future billings to electric retail customers. The fuel rules bandwidth is currently set at plus or minus 2%. Under fuel rules, MGE would defer costs, less any excess revenues, if its actual electric fuel costs exceeded 102% of the electric fuel costs allowed in its latest rate order. Excess revenues are defined as revenues in the year in question that provide MGE with a greater return on common equity than authorized by the PSCW in MGE's latest rate order. Conversely, MGE is required to defer the benefit of lower costs if actual electric fuel costs were less than 98% of the electric fuel costs allowed in that order.

In August 2015, the PSCW approved on an interim basis MGE's application to implement a fuel credit associated with its fuel savings for 2015. The fuel credit established a mechanism to return the fuel savings to electric customers via a bill credit during the period from September 1, 2015, to December 31, 2015. The fuel credit was based on $5.9 million of actual fuel savings deferred through June 30, 2015. Approximately $2.7 million is expected to be returned to customers through December 31, 2015. The application further proposes a fuel credit to cover expected fuel savings for 2016 in the amount of approximately $5.0 million based on anticipated fuel costs. The actual fuel savings will depend upon the completion of the annual PSCW fuel cost audits for 2015 and 2016.

As of September 30, 2015, MGE has deferred $7.6 million of 2015 electric fuel-related savings that are outside the range authorized by the PSCW. In September 2015, MGE returned $0.7 million of total electric fuel-related savings on customer bills. As part of the rate freeze plan authorized by the PSCW for 2014, $4.7 million of the approximately $6.3 million associated with the 2012 fuel rule credit was amortized against purchased power expense during the nine months ended September 30, 2014.

24

c.

Purchased Gas Adjustment Clause.

MGE's natural gas rates are subject to a fuel adjustment clause designed to recover or refund the difference between the actual cost of purchased gas and the amount included in rates. Differences between the amounts billed to customers and the actual costs recoverable are deferred and recovered or refunded in future periods by means of prospective monthly adjustments to rates. At September 30, 2015, and December 31, 2014, MGE had over collected $1.1 million and $1.2 million, respectively, which was recorded in other current liabilities on the consolidated balance sheets.

11.

Fair Value of Financial Instruments - MGE Energy and MGE.

Fair value is defined as the price that would be received to sell an asset or would be paid to transfer a liability (an exit price) in the principal or most advantageous market for the asset or liability in an orderly transaction between market participants at the measurement date. The 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, 2015, and December 31, 2014, the carrying amount of cash, cash equivalents, and outstanding commercial paper approximates fair market value due to the short maturity of those investments and obligations. The estimated fair market value of MGE Energy's and MGE's long-term debt is based on quoted market prices for similar financial instruments at September 30, 2015, and December 31, 2014. Since long-term debt is not traded in an active market, it is classified as Level 2. The estimated fair market value of MGE Energy's and MGE's financial instruments are as follows:

		September 30, 2015				December 31, 2014
(In thousands)		Carrying Amount		Fair Value		Carrying Amount		Fair Value
MGE Energy
Assets:
Cash and cash equivalents	$	94,267	$	94,267	$	65,755	$	65,755
Liabilities:
Short-term debt - commercial paper		-		-		7,000		7,000
Long-term debt*		396,562		446,176		399,690		457,420
MGE
Assets:
Cash and cash equivalents	$	41,971	$	41,971	$	4,562	$	4,562
Liabilities:
Short-term debt - commercial paper		-		-		7,000		7,000
Long-term debt*		396,562		446,176		399,690		457,420
*Includes long-term debt due within one year.

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b.

Recurring Fair Value Measurements.

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

		Fair Value as of September 30, 2015
(In thousands)		Total		Level 1		Level 2		Level 3
MGE Energy
Assets:
Derivatives, net	$	379	$	-	$	-	$	379
Exchange-traded investments		627		627		-		-
Total Assets	$	1,006	$	627	$	-	$	379
Liabilities:
Derivatives, net(a)	$	57,777	$	316	$	-	$	57,461
Deferred compensation		3,160		-		3,160		-
Total Liabilities	$	60,937	$	316	$	3,160	$	57,461
MGE
Assets:
Derivatives, net	$	379	$	-	$	-	$	379
Exchange-traded investments		122		122		-		-
Total Assets	$	501	$	122	$	-	$	379
Liabilities:
Derivatives, net(a)	$	57,777	$	316	$	-	$	57,461
Deferred compensation		3,160		-		3,160		-
Total Liabilities	$	60,937	$	316	$	3,160	$	57,461

		Fair Value as of December 31, 2014
(In thousands)		Total		Level 1		Level 2		Level 3
MGE Energy
Assets:
Derivatives, net	$	642	$	-	$	-	$	642
Exchange-traded investments		927		927		-		-
Total Assets	$	1,569	$	927	$	-	$	642
Liabilities:
Derivatives, net(a)	$	55,640	$	1,012	$	-	$	54,628
Deferred compensation		2,832		-		2,832		-
Total Liabilities	$	58,472	$	1,012	$	2,832	$	54,628
MGE
Assets:
Derivatives, net	$	642	$	-	$	-	$	642
Exchange-traded investments		350		350		-		-
Total Assets	$	992	$	350	$	-	$	642
Liabilities:
Derivatives, net(a)	$	55,640	$	1,012	$	-	$	54,628
Deferred compensation		2,832		-		2,832		-
Total Liabilities	$	58,472	$	1,012	$	2,832	$	54,628

(a)

These amounts are shown gross and exclude $0.8 million and $2.2 million of collateral that was posted against derivative positions with counterparties as of September 30, 2015, and December 31, 2014, respectively.

No transfers were made in or out of Level 1 or Level 2 for the nine months ended September 30, 2015.

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

26

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

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

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

This model is prepared by members of MGE's Energy Accounting department. On a quarterly basis, management in the Energy Supply and Finance departments review the assumptions, inputs, and fair value measurements.

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

	Model Input
Significant Unobservable Inputs	September 30, 2015	December 31, 2014
Basis adjustment:
On peak	97.4%	98.1%
Off peak	95.4%	95.0%
Counterparty fuel mix:
Internal generation	60% - 75%	50% - 70%
Purchased power	40% - 25%	50% - 30%

The deferred compensation plan allows participants to defer certain cash compensation into a notional investment account. These amounts are included within other deferred liabilities in the consolidated balance sheets of MGE Energy and MGE. The notional investments earn interest based upon the semiannual rate of U.S. Treasury Bills having a 26 week maturity increased by 1% compounded monthly with a minimum annual rate of 7%, compounded monthly. The notional investments are based upon observable market data, however, since the deferred compensation obligations themselves are not exchanged in an active market, they are classified as Level 2.

27

The following table summarizes the changes in Level 3 assets and liabilities measured at fair value on a recurring basis for both MGE Energy and MGE.

		Three Months Ended				Nine Months Ended
		September 30,				September 30,
(In thousands)		2015		2014		2015		2014
Beginning balance	$	(56,194)	$	(49,349)	$	(53,986)	$	(64,628)
Realized and unrealized gains (losses):
Included in regulatory liabilities (assets)		(888)		(3,752)		(3,096)		11,528
Included in other comprehensive income		-		-		-		-
Included in earnings		(2,285)		(1,419)		(4,497)		5,837
Included in current assets		-		-		-		(89)
Purchases		6,364		6,371		17,497		19,900
Sales		-		-		34		(60)
Issuances		-		-		-		-
Settlements		(4,079)		(4,952)		(13,034)		(25,589)
Transfers in and/or out of Level 3		-		-		-		-
Balance as of September 30,	$	(57,082)	$	(53,101)	$	(57,082)	$	(53,101)
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 gains (losses) included in income for Level 3 assets and liabilities measured at fair value on a recurring basis for both MGE Energy and MGE (b).

		Three Months Ended				Nine Months Ended
		September 30,				September 30,
(In thousands)		2015		2014		2015		2014
Purchased Power Expense	$	(2,302)	$	(1,411)	$	(4,515)	$	5,845
Cost of Gas Sold Expense		17		(8)		18		(8)
Total	$	(2,285)	$	(1,419)	$	(4,497)	$	5,837

(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.

12.

New Accounting Pronouncements - MGE Energy and MGE.

a.

Transfers and Servicing Assets.

In June 2014, the FASB issued authoritative guidance within the Codification's Transfers and Servicing topic that provides guidance on the accounting and disclosures for repurchase-to-maturity transactions, securities lending transactions, and repurchase financings. This authoritative guidance became effective January 1, 2015. The authoritative guidance changed the accounting for the Chattel Paper program and required additional disclosures. Prior to adoption of the standard, Chattel Paper was treated as an off-balance sheet arrangement. See Footnote 4 for additional information.

b.

Revenue from Contracts with Customers.

In May 2014, the FASB issued authoritative guidance within the Codification's Revenue Recognition topic that provides guidance on the recognition, measurement, and disclosure of revenue from contracts with customers. This authoritative guidance was scheduled to become effective January 1, 2017. In July 2015, the FASB deferred the effective date to January 1, 2018. MGE Energy and MGE are currently assessing the impact this pronouncement will have on their financial statements.

28

c.

Consolidations.

In February 2015, the FASB issued authoritative guidance within the Codification's Consolidation topic that provides guidance on the evaluation of certain legal entities for consolidation purposes. This authoritative guidance will become effective January 1, 2016. The impact of this guidance on our financial statements is not expected to be material.

d.

Debt Issuance Costs.

In April 2015, the FASB issued authoritative guidance within the Codification's Interest topic that provides guidance on the presentation of debt issuance costs in financial statements. This authoritative guidance will become effective January 1, 2016. The authoritative guidance changes the presentation of debt issuance costs on the balance sheet from an asset to a direct deduction from the related debt liability. The impact of this guidance on our financial statements is not expected to be material.

e.

Cloud Computing Arrangements.

In April 2015, the FASB issued authoritative guidance within the Codification's Software topic that provides guidance on the accounting treatment of cloud computer arrangements. This authoritative guidance will become effective January 1, 2016. The authoritative guidance provides criteria for determining whether a cloud computing arrangement contains a software license that should be accounted for as internal-use software. The impact of this guidance on our financial statements is not expected to be material.

f.

Inventory Measurement.

In July 2015, the FASB issued authoritative guidance within the Codification's Inventory topic that provides guidance on the subsequent measurement of inventory. This authoritative guidance will become effective January 1, 2017. The authoritative guidance changes the subsequent measurement of inventory from the lower of cost or market to the lower of cost or net realizable value. MGE Energy and MGE are currently assessing the impact this pronouncement will have on their financial statements.

13.

Segment Information - MGE Energy and MGE.

MGE Energy operates in the following business segments: electric utility, gas utility, nonregulated energy, transmission investment, and all other. See MGE Energy's and MGE's 2014 Annual Report on Form 10-K for additional discussion of each of these segments.

29

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

(In thousands) MGE Energy		Electric		Gas		Non- Regulated Energy		Transmission Investment		All Others		Consolidation/ Elimination Entries		Consolidated Total
Three Months Ended September 30, 2015
Operating revenues	$	121,453	$	17,431	$	1,911	$	-	$	-	$	-	$	140,795
Interdepartmental revenues		163		3,855		9,866		-		-		(13,884)		-
Total operating revenues		121,616		21,286		11,777		-		-		(13,884)		140,795
Depreciation and amortization		(7,584)		(1,714)		(1,872)		-		(12)		-		(11,182)
Other operating expenses		(80,202)		(16,906)		(36)		(15)		(161)		13,884		(83,436)
Operating income (loss)		33,830		2,666		9,869		(15)		(173)		-		46,177
Other (deductions) income, net		141		(7)		-		2,397		33		-		2,564
Interest (expense) income, net		(2,798)		(804)		(1,491)		-		57		-		(5,036)
Income (loss) before taxes		31,173		1,855		8,378		2,382		(83)		-		43,705
Income tax (provision) benefit		(10,321)		(732)		(3,362)		(962)		26		-		(15,351)
Net income (loss)	$	20,852	$	1,123	$	5,016	$	1,420	$	(57)	$	-	$	28,354
Three Months Ended September 30, 2014
Operating revenues	$	112,869	$	21,404	$	862	$	-	$	-	$	-	$	135,135
Interdepartmental revenues		156		1,614		10,674		-		-		(12,444)		-
Total operating revenues		113,025		23,018		11,536		-		-		(12,444)		135,135
Depreciation and amortization		(6,931)		(1,575)		(1,858)		-		(12)		-		(10,376)
Other operating expenses		(74,573)		(22,199)		(35)		-		(276)		12,444		(84,639)
Operating income (loss)		31,521		(756)		9,643		-		(288)		-		40,120
Other income, net		136		8		-		2,423		69		-		2,636
Interest (expense) income, net		(2,832)		(808)		(1,545)		-		44		-		(5,141)
Income (loss) before taxes		28,825		(1,556)		8,098		2,423		(175)		-		37,615
Income tax (provision) benefit		(10,758)		651		(3,251)		(963)		35		-		(14,286)
Net income (loss)	$	18,067	$	(905)	$	4,847	$	1,460	$	(140)	$	-	$	23,329
Nine Months Ended September 30, 2015
Operating revenues	$	319,174	$	108,028	$	5,853	$	-	$	-	$	-	$	433,055
Interdepartmental revenues		400		8,871		29,566		-		-		(38,837)		-
Total operating revenues		319,574		116,899		35,419		-		-		(38,837)		433,055
Depreciation and amortization		(22,372)		(5,018)		(5,601)		-		(35)		-		(33,026)
Other operating expenses		(239,963)		(96,063)		(122)		(15)		(626)		38,837		(297,952)
Operating income (loss)		57,239		15,818		29,696		(15)		(661)		-		102,077
Other (deductions) income, net		247		(33)		-		6,568		333		-		7,115
Interest (expense) income, net		(8,385)		(2,398)		(4,516)		-		164		-		(15,135)
Income (loss) before taxes		49,101		13,387		25,180		6,553		(164)		-		94,057
Income tax (provision) benefit		(15,868)		(5,370)		(10,106)		(2,637)		35		-		(33,946)
Net income (loss)	$	33,233	$	8,017	$	15,074	$	3,916	$	(129)	$	-	$	60,111
Nine Months Ended September 30, 2014
Operating revenues	$	308,418	$	163,335	$	2,392	$	-	$	-	$	-	$	474,145
Interdepartmental revenues		401		7,130		32,017		-		-		(39,548)		-
Total operating revenues		308,819		170,465		34,409		-		-		(39,548)		474,145
Depreciation and amortization		(19,909)		(4,700)		(5,547)		-		(35)		-		(30,191)
Other operating expenses		(229,286)		(144,907)		(105)		-		(672)		39,548		(335,422)
Operating income (loss)		59,624		20,858		28,757		-		(707)		-		108,532
Other (deductions) income, net		2,999		(44)		-		7,306		475		-		10,736
Interest (expense) income, net		(7,571)		(2,429)		(4,676)		-		126		-		(14,550)
Income (loss) before taxes		55,052		18,385		24,081		7,306		(106)		-		104,718
Income tax provision		(19,602)		(7,378)		(9,665)		(2,924)		(16)		-		(39,585)
Net income (loss)	$	35,450	$	11,007	$	14,416	$	4,382	$	(122)	$	-	$	65,133

30

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

(In thousands) MGE		Electric		Gas		Non-Regulated Energy		Transmission Investment		Consolidation/ Elimination Entries		Consolidated Total
Three Months Ended September 30, 2015
Operating revenues	$	121,460	$	17,435	$	1,911	$	-	$	-	$	140,806
Interdepartmental revenues		156		3,851		9,866		-		(13,873)		-
Total operating revenues		121,616		21,286		11,777		-		(13,873)		140,806
Depreciation and amortization		(7,584)		(1,714)		(1,872)		-		-		(11,170)
Other operating expenses*		(90,511)		(17,635)		(3,398)		(15)		13,873		(97,686)
Operating income (loss)*		23,521		1,937		6,507		(15)		-		31,950
Other (deductions) income, net*		129		(10)		-		1,435		-		1,554
Interest expense, net		(2,798)		(804)		(1,491)		-		-		(5,093)
Net income		20,852		1,123		5,016		1,420		-		28,411
Less: Net income attributable to
noncontrolling interest, net of tax		-		-		-		-		(6,633)		(6,633)
Net income attributable to MGE	$	20,852	$	1,123	$	5,016	$	1,420	$	(6,633)	$	21,778
Three Months Ended September 30, 2014
Operating revenues	$	112,875	$	21,410	$	862	$	-	$	-	$	135,147
Interdepartmental revenues		150		1,608		10,674		-		(12,432)		-
Total operating revenues		113,025		23,018		11,536		-		(12,432)		135,147
Depreciation and amortization		(6,931)		(1,575)		(1,858)		-		-		(10,364)
Other operating expenses*		(85,314)		(21,544)		(3,286)		-		12,432		(97,712)
Operating income (loss)*		20,780		(101)		6,392		-		-		27,071
Other income, net*		119		4		-		1,460		-		1,583
Interest expense, net		(2,832)		(808)		(1,545)		-		-		(5,185)
Net income (loss)		18,067		(905)		4,847		1,460		-		23,469
Less: Net income attributable to
noncontrolling interest, net of tax		-		-		-		-		(6,653)		(6,653)
Net income (loss) attributable to MGE	$	18,067	$	(905)	$	4,847	$	1,460	$	(6,653)	$	16,816
Nine Months Ended September 30, 2015
Operating revenues	$	319,191	$	108,039	$	5,853	$	-	$	-	$	433,083
Interdepartmental revenues		383		8,860		29,566		-		(38,809)		-
Total operating revenues		319,574		116,899		35,419		-		(38,809)		433,083
Depreciation and amortization		(22,372)		(5,018)		(5,601)		-		-		(32,991)
Other operating expenses*		(255,732)		(101,405)		(10,228)		(15)		38,809		(328,571)
Operating income (loss)*		41,470		10,476		19,590		(15)		-		71,521
Other (deductions) income, net*		148		(61)		-		3,931		-		4,018
Interest expense, net		(8,385)		(2,398)		(4,516)		-		-		(15,299)
Net income		33,233		8,017		15,074		3,916		-		60,240
Less: Net income attributable to
noncontrolling interest, net of tax		-		-		-		-		(19,812)		(19,812)
Net income attributable to MGE	$	33,233	$	8,017	$	15,074	$	3,916	$	(19,812)	$	40,428
Nine Months Ended September 30, 2014
Operating revenues	$	308,435	$	163,351	$	2,392	$	-	$	-	$	474,178
Interdepartmental revenues		384		7,114		32,017		-		(39,515)		-
Total operating revenues		308,819		170,465		34,409		-		(39,515)		474,178
Depreciation and amortization		(19,909)		(4,700)		(5,547)		-		-		(30,156)
Other operating expenses*		(248,525)		(152,182)		(9,770)		-		39,515		(370,962)
Operating income (loss)*		40,385		13,583		19,092		-		-		73,060
Other (deductions) income, net*		2,636		(147)		-		4,382		-		6,871
Interest expense, net		(7,571)		(2,429)		(4,676)		-		-		(14,676)
Net income		35,450		11,007		14,416		4,382		-		65,255
Less: Net income attributable to
noncontrolling interest, net of tax		-		-		-		-		(19,784)		(19,784)
Net income attributable to MGE	$	35,450	$	11,007	$	14,416	$	4,382	$	(19,784)	$	45,471
*Amounts are shown net of the related tax expense, consistent with the presentation on the MGE Consolidated Statement of Income.

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

General

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

·

Regulated electric utility operations, conducted through MGE,

·

Regulated gas utility operations, conducted through MGE,

·

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

·

Transmission investments, representing our equity investment in ATC, and

·

All other, which includes corporate operations and services.

Our principal subsidiary is MGE, which generates and distributes electric energy, distributes natural gas, and represents a majority portion of our assets, liabilities, revenues, and expenses. MGE generates and distributes electricity to approximately 143,000 customers in Dane County, Wisconsin, including the city of Madison, and purchases and distributes natural gas to approximately 149,000 customers in the Wisconsin counties of Columbia, Crawford, Dane, Iowa, Juneau, Monroe, and Vernon.

Our nonregulated energy operations own interests in electric generating capacity that is leased to MGE. The ownership/leasing structure was adopted under applicable state regulatory guidelines for MGE's participation in these generation facilities, consisting principally of a stable return on the equity investment in the new generation facilities over the term of the related leases. The nonregulated energy operations include an ownership interest in two coal-fired generating units in Oak Creek, Wisconsin and a partial ownership of a cogeneration project on the UW-Madison campus. A third party operates the units in Oak Creek, and MGE operates the cogeneration project. Due to the nature of MGE's participation in these facilities, the results of our nonregulated operations are also consolidated into MGE's consolidated financial position and results of operations under applicable accounting standards.

Executive Overview

Our primary focus today and for the foreseeable future is our core utility customers at MGE as well as creating long-term value for our shareholders. MGE continues to face the challenge of providing its customers with reliable power at competitive prices. MGE meets this challenge by investing in more efficient generation projects, including renewable energy sources. MGE will continue to focus on growing earnings while controlling operating and fuel costs. MGE maintains safe and efficient operations in addition to providing customer value. We believe it is critical to maintain a strong credit standing consistent with financial strength in MGE as well as the parent company in order to accomplish these goals.

We earn our revenue and generate cash from operations by providing electric and natural gas utility services, including electric power generation and electric power and gas distribution. The earnings and cash flows from the utility business are sensitive to various external factors, including:

·

Weather, and its impact on customer sales,

·

Economic conditions, including current business activity and employment and their impact on customer demand,

·

Regulation and regulatory issues, and their impact on the timing and recovery of costs,

·

Energy commodity prices, including natural gas prices,

·

Equity price risk pertaining to pension related assets,

·

Credit market conditions, including interest rates and our debt credit rating,

·

Environmental laws and regulations, including adopted and pending environmental rule changes,

and other factors listed in "Item 1A. Risk Factors" in our 2014 Annual Report on Form 10-K.

For the three months ended September 30, 2015, MGE Energy's earnings were $28.4 million or $0.82 per share compared to $23.3 million or $0.67 per share for the same period in the prior year. MGE's earnings for the three months ended September 30, 2015, were $21.8 million compared to $16.8 million for the same period in the prior year.

For the nine months ended September 30, 2015, MGE Energy's earnings were $60.1 million or $1.73 per share compared to $65.1 million or $1.88 per share for the same period in the prior year. MGE's earnings for the nine months ended September 30, 2015, were $40.4 million compared to $45.5 million for the same period in the prior year.

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

		Three Months Ended				Nine Months Ended
(In thousands)		September 30,				September 30,
Business Segment:		2015		2014		2015		2014
Electric Utility	$	20,852	$	18,067	$	33,233	$	35,450
Gas Utility		1,123		(905)		8,017		11,007
Nonregulated Energy		5,016		4,847		15,074		14,416
Transmission Investments		1,420		1,460		3,916		4,382
All Other		(57)		(140)		(129)		(122)
Net Income	$	28,354	$	23,329	$	60,111	$	65,133

Our net income during the three months ended September 30, 2015, compared to the same period in the prior year primarily reflects the effects of the following factors:

·

Electric net income increased due to a 3.7% increase in electric retail sales reflecting higher customer demand. Cooling degree days (a measure for determining the impact of weather during the cooling season) increased by 30.2% for the quarter compared to the prior year. The average temperature in September 2015 was 67.3 degrees compared to 60.9 degrees in the prior year.

·

Gas net income increased primarily related to rate design changes that became effective in 2015. The rate design changes are expected to make gas revenues less dependent upon usage as more of the costs are recovered in a fixed customer charge. As a consequence, revenues in the first and fourth quarters, when usage is higher, are expected to be lower than in past years; and revenues in the second and third quarters, when usage is lower, are expected to be higher than in past years.

Our net income during the nine months ended September 30, 2015, primarily reflects the effects of the following factors:

·

Electric net income decreased due to lower AFUDC and higher depreciation expense primarily related to the Columbia environment project being placed in service in April (Unit 2) and July 2014 (Unit 1). The decrease was offset by a 0.3% increase in electric retail sales as the result of a 7.3% increase in cooling degree days during the second and third quarter of 2015 compared to the same period in the prior year.

·

Gas net income decreased due to a 26.6% decrease in gas retail sales reflecting lower customer demand compared to the demand resulting from the extremely cold weather experienced in 2014. Heating degree days (a measure for determining the impact of weather during the heating season) decreased by 11.2% compared to the prior year. The average temperature in January 2015 was 20.1 degrees compared to 11.5 degrees in the prior year. Rate design changes that became effective in 2015 increased gas revenue by $8.1 million. The rate design changes are expected to make gas revenues less dependent upon usage as more of the costs are recovered in a fixed customer charge. As a consequence, revenues in the first and fourth quarters, when usage is higher, are expected to be lower than in past years; and revenues in the second and third quarters, when usage is lower, are expected to be higher than in past years.

During the first nine months of 2015, the following events occurred:

2015 Rate Filing: In December 2014, the PSCW authorized MGE to increase 2015 rates for retail electric customers by 3.8% and to decrease rates for gas customers by 2.0%. The increase in retail electric rates covers costs associated with the construction of emission-reduction equipment at Columbia, improvements and reliability of the state's electric transmission system, fuel and purchased power related to coal delivery costs, partially offset by lower cost as a result of market conditions for pension and postretirement benefit costs.

The PSCW approved changes to customer rates and rate design for gas service. Gas rate design consists of a fixed monthly customer charge and a variable charge tied to actual usage, in addition to the separate charge for natural gas commodity costs (PGA). The change shifted more of the rate recovery to the monthly charge, reflecting the related fixed costs of providing gas services, and reduced the variable usage-based charge. Thus, gas net income is expected to be more evenly distributed during the year and less sensitive to weather. A similar, but much smaller rate design shift was also approved for electric rates.

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

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

2016 Annual Fuel Proceeding: In August 2015, the PSCW approved on an interim basis MGE's application to implement a fuel credit associated with its fuel savings for 2015. The fuel credit established a mechanism to return the fuel savings to electric customers via a bill credit during the period from September 1, 2015, to December 31, 2015. The fuel credit was based on $5.9 million of actual fuel savings deferred through June 30, 2015. Approximately $2.7 million is expected to be returned to customers through December 31, 2015. The application further proposes a fuel credit to cover expected fuel savings for 2016 in the amount of approximately $5.0 million based on anticipated fuel costs. The actual fuel savings will depend upon the completion of the annual PSCW fuel cost audits for 2015 and 2016.

Loss of Industrial Customer: In November 2015, a large industrial customer announced its intention to relocate its operations out of state and to close its manufacturing facilities within our service territory. That closure is expected to occur in early 2017. While we expect that our rate request for 2017, which would be filed during 2016, would address the effects of the closure, there could be some impact on our electric revenues during 2016 if the customer's operations are curtailed as a result of the impending closure.

Environmental Initiatives: There are proposed legislation, rules, and initiatives involving matters related to air emissions, water effluent, hazardous materials, and greenhouse gases, all of which affect generation plant capital expenditures and operating costs as well as future operational planning. Such legislation and rulemaking could significantly affect the costs of owning and operating fossil-fueled generating plants, such as Columbia and the Elm Road Units, from which we derive approximately 44% of our electric generating capacity. We would expect to seek and receive recovery of any such costs in rates; however, it is difficult to estimate the amount of such costs due to the uncertainty as to the timing and form of the legislation and rules, and the scope and time of the recovery of costs in rates, which may lag the incurrence of those costs.

EPA's Clean Power Plan: On August 3, 2015, the EPA finalized its Clean Power Plan rule setting guidelines 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 coal-based generating units, including possible changes in dispatch and additional operating costs. MGE is currently evaluating the rule and its requirements; however, compliance with the rule's requirements, including the yet-to-be-developed state implementation plan, is expected to have a material impact on MGE.

Pension and Other Postretirement Benefit Costs: Costs for pension and other postretirement benefits are affected by actual investment returns on the assets held for those benefits and by the discount rate, which is sensitive to interest rates, used to calculate those benefits. Interest rates and investment returns have experienced volatility since the end of the year which could affect the value of the pension and postretirement benefit obligations. The changes in the discount rates and value of plan assets are not expected to have an impact on the income statement for 2015. However, these changes may affect benefit costs in future years. MGE expects changes in the cost for employee benefit plans will be factored into future rate actions.

ATC Return on Equity: Several parties have filed a complaint with FERC seeking to reduce the base return on equity (ROE) of MISO and numerous other MISO transmission owners, including ATC, "due to changes in the capital markets." The complaint alleges that the MISO ROE should not exceed 9.15%, the equity components of hypothetical capital structures should be restricted to 50%, and the relevant incentive ROE adders should be discontinued. FERC denied the portion of the complaint seeking to restrict the use of capital structures that include more than 50% common equity and also denied the portion of the complaint requesting the termination of the incentive ROE adders used by certain transmission owners. MISO's base ROE is 12.38%, and ATC's base ROE is 12.2%. FERC ordered formal hearing proceedings to begin, and an initial decision in the complaint is expected by November 30, 2015. ATC provided MGE its 2015 earnings reflecting an adjustment for this matter representing ATC's estimate of its potential refund liability. We derived approximately 6.4% of our net income for the nine months ended September 30, 2015, from our investment in ATC.

34

General Economic Conditions: Economic conditions both inside and outside our service area are expected to continue to affect the level of demand for our utility services and may affect the collection of our accounts receivable and the creditworthiness of counterparties with whom we do business. We have in place lines of credit aggregating $150 million for MGE Energy (including MGE) and $100 million for MGE to address our liquidity needs. As of September 30, 2015, there were no borrowings outstanding under MGE Energy's or MGE's lines of credit.

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

Three Months Ended September 30, 2015 and 2014

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,
		2015		2014	% Change	2015	2014	% Change
Residential	$	40,584	$	37,455	8.4 %	234,421	217,677	7.7 %
Commercial		64,240		60,127	6.8 %	507,033	488,310	3.8 %
Industrial		5,793		5,513	5.1 %	66,150	65,145	1.5 %
Other-retail/municipal		11,217		10,958	2.4 %	114,728	118,311	(3.0)%
Total retail		121,834		114,053	6.8 %	922,332	889,443	3.7 %
Sales to the market		737		179	N/A%	19,712	508	N/A%
Adjustments to revenues		(1,118)		(1,363)	18.0 %	-	-	-  %
Total	$	121,453	$	112,869	7.6 %	942,044	889,951	5.9 %
Cooling degree days (normal 478)						504	387	30.2 %

Electric operating revenues increased $8.6 million or 7.6% for the three months ended September 30, 2015, compared to the same period in 2014, due to the following:

(In millions)
Rate changes	$	4.3
Volume		4.2
Sales to the market		0.6
Other revenues		0.2
Fuel credit		(0.7)
Total	$	8.6

·

Rate changes. Rates charged to retail customers for the three months ended September 30, 2015, were 3.6% or $4.3 million higher than those charged during the same period in the prior year.

In December 2014, the PSCW authorized MGE to increase 2015 rates for retail electric customers by 3.8% or $15.4 million. See "2015 Rate Filing" under "Executive Overview" for more information.

·

Volume. During the three months ended September 30, 2015, there was a 3.7% increase in total retail sales volumes compared to the same period in the prior year driven by higher customer demand due, at least in part, to more favorable weather conditions, as evidenced by the higher 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 purchases and generation online exceeding its own system demand. The excess electricity is then sold to others in the market. For the three months ended September 30, 2015, market volumes increased compared to the same period in the prior year, reflecting increased opportunities for sales; however, those sales were made at lower market prices.

35

Electric fuel and purchased power

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

Fuel for electric generation

The expense for fuel for internal electric generation increased $7.2 million during the three months ended September 30, 2015, compared to the same period in the prior year, due to the following:

(In millions)
Increase in volume	$	4.8
Increase in per-unit cost		2.4
Total	$	7.2

This increase in expense reflects a 48.8% increase in internal generated volume delivered to the system primarily as a result of increased generation at Columbia based on market prices. Also contributing to the increase was a 16.5% increase in per-unit cost of internal electric generation.

Purchased power

Purchased power expense decreased $2.8 million during the three months ended September 30, 2015, compared to the same period in the prior year, due to the following:

(In millions)
Decrease in volume	$	(7.1)
Increase in per-unit cost		1.5
Fuel Rules Adjustments
Increase in recorded fuel rule credit in 2015		1.9
Return of 2015 fuel credit		(0.7)
Amortization of 2012 fuel rule credits in 2014		1.6
Total	$	(2.8)

The decrease in expense reflects a 30.9% decrease in the volume of power purchased from third parties primarily as a result of the increased internal generation at Columbia offset by a 9.3% increase in the per-unit cost of purchased power.

Under fuel rules, MGE is required to defer electric fuel-related costs that fall outside a 2% cost tolerance band around the amount used in the most recent rate proceeding. Any fuel rules adjustments are reflected in purchased power expense. Cost savings that may be returned to customers are recorded as an increase to purchased power expense, and higher costs that MGE is entitled to recover, after adjustment for excess revenues, are recorded as a reduction to purchased power expense. Any over/under recovery of the deferred costs is determined on an annual basis and adjusted in future billings to customers. During the three months ended September 30, 2015, MGE deferred $1.9 million in fuel related cost savings to be returned to customers. In addition, MGE returned $0.7 million of total electric fuel-related savings on customer bills during the three months ended September 30, 2015. During the three months ended September 30, 2014, MGE amortized $1.6 million of the 2012 fuel rule credits, which reduced purchased power expense for that period.

Electric operating and maintenance expenses

Electric operating and maintenance expenses increased $1.7 million during the three months ended September 30, 2015, compared to the same period in 2014. The following changes contributed to the net change:

(In millions)
Increased transmission costs	$	1.2
Increased production expenses		0.5
Increased administrative and general costs		0.1
Increased customer services		0.1
Decreased customer accounts costs		(0.2)
Total	$	1.7

36

For the three months ended September 30, 2015, increased transmission costs are primarily due to an increase in transmission reliability enhancements.

Electric depreciation expense

Electric depreciation expense increased $0.7 million for the three months ended September 30, 2015, compared to the same period in the prior year. This increase is related to the completion of the Columbia environmental project. The systems and equipment for Unit 2 and Unit 1 were placed into service in April 2014 and July 2014, respectively.

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,
		2015		2014	% Change	2015	2014	% Change
Residential	$	11,306	$	9,507	18.9 %	5,651	6,105	(7.4)%
Commercial/Industrial		5,039		11,188	(55.0)%	8,553	18,714	(54.3)%
Total retail		16,345		20,695	(21.0)%	14,204	24,819	(42.8)%
Gas transportation		990		608	62.8 %	15,939	7,127	123.6 %
Other revenues		96		101	(5.0)%	-	-	-  %
Total	$	17,431	$	21,404	(18.6)%	30,143	31,946	(5.6)%
Heating degree days (normal 173)						98	165	(40.6)%
Average rate per therm of
retail customer	$	1.151	$	0.834	38.0 %

Gas revenues decreased $4.0 million or 18.6% for the three months ended September 30, 2015, compared to the same period in 2014. These changes are related to the following factors:

(In millions)
Volume	$	(8.9)
Rate/PGA changes		4.5
Transportation and other effects		0.4
Total	$	(4.0)

·

Volume. For the three months ended September 30, 2015, retail gas deliveries decreased 42.8% compared to the same period in the prior year due, at least in part, to warmer weather in the current period compared to the prior period and a large commercial customer's decision to purchase gas from a third party supplier and to use MGE's facilities for the transport of that gas. The impact to gas income of this shift is not material.

·

Rate/PGA changes. In December 2014, the PSCW approved changes to customer rates and rate design for gas service. Rates were reduced by 2.0%, effective January 1, 2015. Gas rate design consists of a fixed monthly customer charge and a variable charge tied to actual usage, in addition to the separate charge for natural gas commodity costs that is recovered through the PGA. The change shifted more of the rate recovery to the monthly charge, reflecting the related fixed costs of providing gas services, and reduced the variable usage-based charge. Thus, gas net income is expected to be more evenly distributed during the year and less sensitive to weather.

MGE recovers the cost of natural gas in its gas segment through the purchased gas adjustment clause (PGA). Under the PGA, MGE is able to pass through to its gas customers the cost of gas. Changes in PGA recoveries affect revenues, but do not impact net income.

The average retail rate per therm for the three months ended September 30, 2015, increased 38.0% compared to the same period in 2014, reflecting a $6.5 million increase (comprised of a decrease in variable rate costs offset by an increase in fixed rate charges) related to rate design changes offset by a $2.0 million decrease in natural gas commodity costs (PGA). As noted previously, as a result of the rate design changes, revenues in the first and fourth quarters, when usage is higher, are expected to be lower than in past years; and revenues in the second and third quarters, when usage is lower, are expected to be higher than in past years.

37

·

Transportation and other effects. During the three months ended September 30, 2015, transportation and other effects increased $0.4 million primarily attributable to a large commercial customer's decision to purchase gas from a third party supplier and to use MGE's facilities for the transport of that gas. The impact to gas income of this shift is not material.

Cost of gas sold

For the three months ended September 30, 2015, cost of gas sold decreased by $6.7 million, compared to the same period in the prior year. The volume of gas purchased decreased 42.9%, which resulted in $4.7 million of decreased expense. The cost per therm of natural gas decreased 31.9%, which resulted in $2.0 million of decreased expense.

Gas operating and maintenance expenses

Gas operating and maintenance expenses decreased by $0.5 million for the three months ended September 30, 2015, compared to the same period in 2014. The following changes contributed to the net change:

(In millions)
Decreased customer service costs	$	(0.3)
Decreased administrative and general costs		(0.1)
Decreased customer accounts costs		(0.1)
Total	$	(0.5)

Nonregulated Energy Operations - MGE Energy and MGE

For the three months ended September 30, 2015 and 2014, net income at the nonregulated energy operations segment was $5.0 million and $4.8 million, respectively. 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.

Transmission Investment Operations - MGE Energy and MGE

Transmission investment other income

For the three months ended September 30, 2015 and 2014, other income at the transmission investment segment was $2.4 million. The transmission investment segment holds our interest in ATC, and its income reflects our equity in the earnings of ATC. See Footnote 3 of the Notes to Consolidated Financial Statements and "Other Matters" below for additional information concerning ATC and summarized financial information regarding ATC.

Consolidated Income Taxes - MGE Energy and MGE

MGE Energy's effective income tax rate for the three months ended September 30, 2015 and 2014, was 35.1% and 38.0%, respectively. MGE's effective income tax rate for the three months ended September 30, 2015 and 2014, was 35.1% and 37.9%, respectively. The decrease in the effective tax rate is due in part to a higher estimated domestic manufacturing deduction, offset by lower AFUDC equity earnings in 2015.

Noncontrolling Interest, Net of Tax - MGE

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

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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)		2015		2014
MGE Power Elm Road	$	4.1	$	4.1
MGE Power West Campus		1.8		1.9
MGE Transco		0.7		0.7

Nine Months Ended September 30, 2015 and 2014

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,
		2015		2014	% Change	2015	2014	% Change
Residential	$	104,733	$	102,698	2.0 %	608,204	616,775	(1.4)%
Commercial		170,670		163,992	4.1 %	1,400,358	1,394,272	0.4 %
Industrial		15,666		15,141	3.5 %	187,493	186,085	0.8 %
Other-retail/municipal		30,016		28,543	5.2 %	322,881	314,338	2.7 %
Total retail		321,085		310,374	3.5 %	2,518,936	2,511,470	0.3 %
Sales to the market		1,637		2,239	(26.9)%	44,260	62,538	(29.2)%
Adjustments to revenues		(3,548)		(4,195)	15.4 %	-	-	-  %
Total	$	319,174	$	308,418	3.5 %	2,563,196	2,574,008	(0.4)%
Cooling degree days (normal 659)						665	620	7.3 %

Electric operating revenues increased $10.8 million or 3.5% for the nine months ended September 30, 2015, compared to the same period in 2014, due to the following:

(In millions)
Rate changes	$	10.5
Volume		0.9
Other		0.7
Fuel credit		(0.7)
Sales to the market		(0.6)
Total	$	10.8

·

Rate changes. Rates charged to retail customers for the nine months ended September 30, 2015, were 3.4% or $10.5 million higher than those charged during the same period in the prior year.

In December 2014, the PSCW authorized MGE to increase 2015 rates for retail electric customers by 3.8% or $15.4 million. See "2015 Rate Filing" under "Executive Overview" for more information.

·

Volume. During the nine months ended September 30, 2015, there was a 0.3% increase in total retail sales volumes compared to the same period in the prior year driven by increased customer demand due, at least in part, to more favorable weather conditions, as evidenced by the higher 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 purchases and generation online exceeding its own system demand. The excess electricity is then sold to others in the market. For the nine months ended September 30, 2015, market volumes decreased compared to the

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same period in the prior year, reflecting decreased opportunities for sales. In addition, market settlement resulted in lower revenue per kWh for the nine months ended September 30, 2015, reflecting lower market prices in the early portion of that period.

Electric fuel and purchased power

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

Fuel for electric generation

The expense for fuel for internal electric generation increased $5.8 million during the nine months ended September 30, 2015, compared to the same period in the prior year, due to the following:

(In millions)
Increase in per-unit cost	$	4.1
Increase in volume		1.7
Total	$	5.8

This increase in expense reflects an 11.3% increase in per-unit cost of internal electric generation and a 4.4% increase in internal generated volume delivered to the system primarily as a result of increased generation at Columbia based on market prices.

Purchased power

Purchased power expense increased $3.8 million during the nine months ended September 30, 2015, compared to the same period in the prior year, due to the following:

(In millions)
Decrease in per-unit cost	$	(3.8)
Decrease in volume		(4.0)
Fuel Rules Adjustments
Increase in recorded fuel rule credit in 2015		7.6
Return of 2015 fuel credit		(0.7)
Amortization of 2012 fuel rule credits in 2014		4.7
Total	$	3.8

The decrease in expense (before fuel rules adjustments) reflects a 6.3% decrease in the per-unit cost of purchased power and a 6.4% decrease in the volume of power purchased from third parties primarily as a result of the increased internal generation at Columbia.

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. Cost savings that may be returned to customers are recorded as an increase to purchased power expense, and higher costs that MGE is entitled to recover, after adjustment for excess revenues, are recorded as a reduction to purchased power expense. Any over/under recovery of the deferred costs is determined on an annual basis and adjusted in future billings to customers. During the nine months ended September 30, 2015, MGE deferred $7.6 million in fuel related cost savings to be returned to customers. In addition, MGE returned $0.7 million of total electric fuel-related savings on customer bills during the nine months ended September 30, 2015. During the nine months ended September 30, 2014, MGE amortized $4.7 million of the 2012 fuel rule credits, which reduced purchased power expense for that period.

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Electric operating and maintenance expenses

Electric operating and maintenance expenses increased $2.9 million during the nine months ended September 30, 2015, compared to the same period in 2014. The following changes contributed to the net change:

(In millions)
Increased transmission costs	$	2.1
Increased administrative and general costs		1.7
Increased customer service costs		0.6
Decreased customer accounts costs		(0.8)
Decreased production expenses		(0.7)
Total	$	2.9

For the nine months ended September 30, 2015, increased transmission costs are primarily related to an increase in transmission reliability enhancements. In addition, increased administrative and general costs are primarily due to increased pension and other postretirement benefit costs predominantly driven by a reduction in the discount rate.

Electric depreciation expense

Electric depreciation expense increased $2.5 million for the nine months ended September 30, 2015, compared to the same period in the prior year. This increase is related to the completion of the Columbia environmental project. The systems and equipment for Unit 2 and Unit 1 were placed into service in April 2014 and July 2014, respectively.

Other Electric Income

Other electric income decreased $2.8 million, primarily due to AFUDC equity related to the completion of the Columbia environmental project. Unit 2 and Unit 1 were placed into service in April and July 2014, respectively.

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,
		2015		2014	% Change	2015	2014	% Change
Residential	$	64,208	$	84,275	(23.8)%	67,690	76,626	(11.7)%
Commercial/Industrial		39,973		76,460	(47.7)%	64,389	103,313	(37.7)%
Total retail		104,181		160,735	(35.2)%	132,079	179,939	(26.6)%
Gas transportation		3,462		2,223	55.7 %	56,946	27,651	105.9 %
Other revenues		385		377	2.1 %	-	-	-  %
Total	$	108,028	$	163,335	(33.9)%	189,025	207,590	(8.9)%
Heating degree days (normal 4,523)						4,653	5,240	(11.2)%
Average Rate Per Therm of
Retail Customer	$	0.789	$	0.893	(11.6)%

Gas revenues decreased $55.3 million or 33.9% for the nine months ended September 30, 2015, compared to the same period in 2014. These changes are related to the following factors:

(In millions)
Volume	$	(42.2)
Rate/PGA changes		(14.3)
Transportation and other effects		1.2
Total	$	(55.3)

·

Volume. For the nine months ended September 30, 2015, retail gas deliveries decreased 26.6% compared to the same period in the prior year, as a result of extremely cold weather experienced in the first quarter of 2014 and a large commercial customer's decision to purchase gas from a third party supplier and to use MGE's facilities for the transport of that gas. The impact to gas income of this shift is not material.

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·

Rate/PGA changes. In December 2014, the PSCW approved changes to customer rates and rate design for gas service. Rates were reduced by 2.0%, effective January 1, 2015. Gas rate design consists of a fixed monthly customer charge and a variable charge tied to actual usage, in addition to the separate charge for natural gas commodity costs that is recovered through the PGA. The change shifted more of the rate recovery to the monthly charge, reflecting the related fixed costs of providing gas services, and reduced the variable usage-based charge. Thus, gas net income is expected to be more evenly distributed during the year and less sensitive to weather.

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, 2015, decreased 11.6% compared to the same period in 2014, reflecting a $22.4 million decrease in natural gas commodity costs (PGA) offset by an $8.1 million increase (comprised of a decrease in variable rate costs offset by an increase in fixed rate charges) related to rate design changes. As noted previously, as a result of the rate design changes, revenues in the first and fourth quarters, when usage is higher, are expected to be lower than in past years; and revenues in the second and third quarters, when usage is lower, are expected to be higher than in past years.

·

Transportation and other effects. During the nine months ended September 30, 2015, transportation and other effects increased $1.2 million primarily attributable to a large commercial customer's decision to purchase gas from a third party supplier and to use MGE's facilities for the transport of that gas. The impact to gas income of this shift is not material.

Cost of gas sold

For the nine months ended September 30, 2015, cost of gas sold decreased by $49.8 million, compared to the same period in the prior year. The cost per therm of natural gas decreased 27.1%, which resulted in $21.5 million of decreased expense. In addition, the volume of purchased gas decreased 26.3%, which resulted in $28.3 million of decreased expense.

Gas operating and maintenance expenses

Gas operating and maintenance expenses decreased by $0.3 million for the nine months ended September 30, 2015, compared to the same period in 2014. The following changes contributed to the net change:

(In millions)
Decreased customer service costs	$	(0.7)
Decreased customer account costs		(0.5)
Increased administrative and general costs		0.9
Total	$	(0.3)

For the nine months ended September 30, 2015, increased administrative and general costs are primarily due to increased pension and other postretirement benefit costs predominantly driven by a reduction in the discount rate.

Nonregulated Energy Operations - MGE Energy and MGE

For the nine months ended September 30, 2015 and 2014, net income at the nonregulated energy operations segment was $15.1 million and $14.4 million, respectively. 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 construct, own and lease electric generating capacity to assist MGE.

Transmission Investment Operations - MGE Energy and MGE

Transmission investment other income

For the nine months ended September 30, 2015 and 2014, other income at the transmission investment segment was $6.6 million and $7.3 million, respectively. The transmission investment segment holds our interest in ATC, and its income reflects our equity in the earnings of ATC. See Footnote 3 of Notes to Consolidated Financial Statements 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

Both MGE Energy's and MGE's effective income tax rate for the nine months ended September 30, 2015 and 2014, was 36.1% and 37.8%, respectively. The decrease in the effective tax rate is due in part to a higher estimated domestic manufacturing deduction, offset by lower AFUDC equity earnings in 2015.

Noncontrolling Interest, Net of Tax - MGE

The noncontrolling interest, net of tax, reflects the accounting required for MGE Energy's interest in MGE Power Elm Road (the Elm Road Units) and MGE Power West Campus (WCCF). MGE Energy owns 100% of MGE Power Elm Road and MGE Power West Campus; however, due to the contractual agreements for these projects with MGE, the entities are considered VIEs with respect to MGE and their results are consolidated with those of MGE, the primary beneficiary of the VIEs. Also included in noncontrolling interest, net of tax, is MGE Energy's interest in MGE Transco, which holds our investment in ATC. The following table shows MGE Energy's noncontrolling interest, net of tax, reflected on MGE's consolidated statement of income:

		Nine Months Ended September 30,
(In millions)		2015		2014
MGE Power Elm Road	$	12.4	$	12.1
MGE Power West Campus		5.5		5.7
MGE Transco		1.9		2.0

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, 2015, except as noted below. Further discussion of the contractual obligations and commercial commitments is included in Footnote 18 of Notes to Consolidated Financial Statements, and "Contractual Obligations and Commercial Commitments for MGE Energy and MGE" under "Management's Discussion and Analysis of Financial Condition and Results of Operations" in MGE Energy's and MGE's 2014 Annual Report on Form 10-K.

Purchase Contracts - MGE Energy and MGE

See Footnote 8.c. of Notes to Consolidated Financial Statements for a description of commitments at September 30, 2015, that MGE Energy and MGE have entered with respect to various commodity supply contracts to meet their obligations to deliver natural gas to customers as well as the purchase and transport of coal.

Credit Facilities - MGE Energy and MGE

See Footnote 2.c. of Notes to Consolidated Financial Statements for a description of MGE Energy's and MGE's credit facilities at September 30, 2015.

Liquidity and Capital Resources

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

Cash Flows

The following summarizes cash flows for MGE Energy and MGE during the nine months ended September 30, 2015 and 2014:

		MGE Energy				MGE
(In thousands)		2015		2014		2015		2014
Cash provided by/(used for):
Operating activities	$	122,655	$	120,972	$	130,107	$	122,747
Investing activities		(53,181)		(69,233)		(52,934)		(68,645)
Financing activities		(40,962)		(31,833)		(39,764)		(45,927)

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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, 2015, was $122.7 million, an increase of $1.7 million when compared to the same period in the prior year.

MGE Energy's net income decreased $5.0 million for the nine months ended September 30, 2015, when compared to the same period in the prior year.

In 2015, MGE received a $10.0 million refund from the IRS for the 2014 tax year. Excluding the 2015 refund, MGE Energy's federal and state taxes paid decreased $1.0 million during the nine months ended September 30, 2015, when compared to the same period in the prior year.

Working capital accounts (excluding prepaid and accrued taxes) resulted in $2.5 million in cash used for operating activities for the nine months ended September 30, 2015, primarily due to increased inventories, decreased accounts payable, and decreased other current liabilities, partially offset by decreased receivables and decreased unbilled revenues. Working capital accounts (excluding prepaid and accrued taxes) resulted in $2.3 million in cash provided by operating activities for the nine months ended September 30, 2014, primarily due to decreased unbilled revenues and decreased accounts receivable, partially offset by increased inventories and decreased other current liabilities.

An increase in pension contribution resulted in an additional $10.0 million in cash used for operating activities for the nine months ended September 30, 2015, when compared to the same period in the prior year. Pension contributions reflect amounts required by law and discretionary amounts. There were no required contributions and no discretionary contributions for 2014.

For the nine months ended September 30, 2015, MGE deferred $7.6 million in fuel related cost savings to be returned to customers and returned $0.7 million of total electric fuel-related savings on customer bills. There were no deferred fuel related cost savings in 2014.

MGE

Cash provided by operating activities for the nine months ended September 30, 2015, was $130.1 million, an increase of $7.4 million when compared to the same period in the prior year.

Net income decreased $5.0 million for the nine months ended September 30, 2015, when compared to the same period in the prior year.

In 2015, MGE received a $10.0 million refund from the IRS for the 2014 tax year. Excluding the 2015 refund, MGE's federal and state taxes paid to MGE Energy decreased $7.1 million during the nine months ended September 30, 2015, when compared to the same period in the prior year.

Working capital accounts (excluding prepaid and accrued taxes) resulted in $6.3 million in cash provided by operating activities for the nine months ended September 30, 2015, primarily due to decreased receivables and decreased unbilled revenues, partially offset by increased inventories and decreased accounts payable. Working capital accounts (excluding prepaid taxes and accrued taxes) resulted in $4.9 million in cash provided by operating activities for the nine months ended September 30, 2014, primarily due to decreased unbilled revenues and decreased accounts receivable, partially offset by increased inventories and decreased accounts payable.

An increase in pension contribution resulted in an additional $10.0 million in cash used by operating activities for the nine months ended September 30, 2015, when compared to the same period in the prior year. Pension contributions reflect amounts required by law and discretionary amounts. There were no required contributions and no discretionary contributions for 2014.

For the nine months ended September 30, 2015, MGE deferred $7.6 million in fuel related cost savings to be returned to customers and returned $0.7 million of total electric fuel-related savings on customer bills. There were no deferred fuel related cost savings in 2014.

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Cash Used for Investing Activities

MGE Energy

MGE Energy's cash used for investing activities decreased $16.0 million for the nine months ended September 30, 2015, when compared to the same period in the prior year.

Capital expenditures for the nine months ended September 30, 2015, were $52.3 million. This amount represents a decrease of $13.8 million from the expenditures made in the same period in the prior year. This decrease primarily reflects $11.1 million of lower expenditures on the Columbia environmental project in 2015 versus 2014 and decreased expenditures on electric distribution assets.

MGE

MGE's cash used for investing activities decreased $15.7 million for the nine months ended September 30, 2015, when compared to the same period in the prior year.

Capital expenditures for the nine months ended September 30, 2015, were $52.3 million. This amount represents a decrease of $13.8 million from the expenditures made in the same period in the prior year. This decrease primarily reflects $11.1 million of lower expenditures on the Columbia environmental project in 2015 versus 2014 and decreased expenditures on electric distribution assets.

Cash Used for Financing Activities

MGE Energy

Cash used for MGE Energy's financing activities was $41.0 million for the nine months ended September 30, 2015, compared to $31.8 million of cash used for MGE Energy's financing activities in the nine months ended September 30, 2014.

For the nine months ended September 30, 2015, dividends paid were $29.8 million compared to $28.6 million in the prior year. This increase was a result of a higher dividend per share ($0.860 vs. $0.826).

For the nine months ended September 30, 2015, net short term debt repayments were $7.0 million. There were no short term debt repayments for the same period in the prior year.

MGE

During the nine months ended September 30, 2015, cash used for MGE's financing activities was $39.8 million compared to $45.9 million of cash used for MGE's financing activities in the prior year.

Dividends paid from MGE to MGE Energy were $20.0 million for the nine months ended September 30, 2015. For the nine months ended September 30, 2014, cash dividends paid from MGE to MGE Energy were $26.5 million.

Distributions to parent from noncontrolling interest, which represent distributions from MGE Power Elm Road and MGE Power West Campus, were $12.0 million for the nine months ended September 30, 2015, compared to $17.8 million in the prior year.

For the nine months ended September 30, 2015, equity contributions received from MGE Power West Campus and MGE Transco were $3.1 million compared to $1.4 million in the prior year.

For the nine months ended September 30, 2015, net short term debt repayments were $7.0 million. There were no short term debt repayments for the same period in the prior year.

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Capitalization Ratios

MGE Energy's capitalization ratios were as follows:

	MGE Energy
	September 30, 2015	December 31, 2014
Common shareholders' equity	63.5 %	61.9 %
Long-term debt*	36.5 %	37.5 %
Short-term debt	-%	0.6 %
*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, 2015, capital expenditures for MGE Energy and MGE totaled $52.3 million, which included $49.0 million of capital expenditures for utility operations.

Credit Ratings

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

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

Environmental Matters

The following discussion is limited to updates or developments in environmental matters that occurred during the nine months ended September 30, 2015. Further discussion of environmental matters is included in MGE Energy's and MGE's 2014 Annual Report on Form 10-K and Footnote 8.a. of Notes to Consolidated Financial Statements in this Report.

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

On August 3, 2015, the EPA finalized its Clean Power Plan rule setting guidelines for states to use in developing plans to control GHG emissions from existing fossil fuel-fired electric generating units (EGUs) and systems. When fully implemented in 2030, the Clean Power Plan is projected to reduce GHG emissions from this sector by 32 percent below 2005 levels. States are given up to three years to submit a plan to meet the reduction goals and are expected to meet interim goals starting in 2022 and the final goal in 2030. Implementation of the rule is expected to have a direct impact on coal and natural gas fired generating units, including possible changes in dispatch and additional operating costs.

On October 23, 2015, several states, including Wisconsin, and several state regulatory bodies filed a joint petition seeking to have the U.S. Court of Appeals for the District of Columbia Circuit stay the effectiveness of the Clean Power Plant rule, which would otherwise become effective on December 22, 2015, and seeking expedited review of the petitioners' challenges to the legality of the adoption of the rule.

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

Sulfur Dioxide (SO₂) NAAQS

In March 2015, pursuant to the court-approved consent decree with environmental groups, the EPA identified and published in the Federal Register a list of SO₂ NAAQS sources that meet an annual mass emissions and/or emissions rate threshold criteria (based on 2012 data) and thus will be included in the next round of attainment/nonattainment designations. MGE's Columbia plant was included in this list.

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In August 2015, the EPA published its data requirements rule that lays out expectations, designation process options, and timeframes for states and tribes to meet. The EPA must make final designation determinations for these areas between 2017 and 2020 depending on the area. Under this rule, the State of Wisconsin is required to submit its attainment delegation proposal for Columbia by July 2016. Since the 2012 data was collected, Columbia has installed pollution control equipment that has lowered its total SO₂ emissions and its SO₂ emissions rate. However, we will not know with any certainty if Columbia County will be determined to be in attainment until the State of Wisconsin completes its attainment/nonattainment demonstration and the EPA approves it. MGE will monitor and participate in developments with the Columbia County designation process. Management believes compliance costs will be recovered in future rates based on previous treatment of environmental compliance projects.

Supreme Court Remand of the EPA's Mercury and Air Toxic Standards (MATS) Rule

In June 2015, the U.S. Supreme Court remanded EPA's MATS rule to the D.C. Circuit Court. The Supreme Court's decision held the EPA was required to consider the cost of compliance when deciding that it was appropriate and necessary to regulate mercury under Section 112 of the Clean Air Act. The rule must go back to the D.C. Circuit Court but remains in effect pending action by that Court. If the D.C. Circuit Court rules to vacate MATS, the State of Wisconsin's mercury rule would remain in effect for utilities in Wisconsin. The Wisconsin rule has very similar requirements to MATS and thus the effects on MGE would not change in any significant manner. Further, MGE has previously determined that current pollution controls at its Columbia and Elm Road units would meet both MATS and the Wisconsin mercury rule. We do not expect any operational changes as a result of this rule remand.

EPA's Finalization of its Effluent Limitations Guidelines Rule for Steam Electric Power Plants

In September 2015, the EPA released its final rule for Effluent Limitations Guidelines (ELG) for the Steam Electric Power Generating industry. The ELG rule lowers the existing permissible water discharge of metals and other pollutants in wastewater from new and existing steam electric generation plants. The rule mostly covers certain wastewater pollutants attributed to air pollution control and ash handling systems at coal-burning power plants with units greater than 50 megawatt (MW) generation capacity. We are currently evaluating the rule for its effects on our operation and expect that equipment upgrades may be necessary at our Elm Road Units and Columbia plants. The rule will go into effect in 2018 and will apply to Wisconsin-based power plants as they renew their WPDES permits.

MGE cannot estimate costs associated with this rule with any certainty until we complete our evaluation. Management believes compliance costs will be recovered in future rates based on previous treatment of environmental compliance projects.

Ozone NAAQS

In October 2015, the EPA revised the primary and secondary ozone NAAQS, lowering it to 70 ppb. The final standard may cause Milwaukee County, where our Elm Road Units are located, to be designated as nonattainment for ozone. A nonattainment designation may have an effect on operations at our Elm Road Units, however, the NAAQS process involves many steps and any effect on our Elm Road Units will not be fully understood until the State of Wisconsin develops, receives approval for, and finalizes an implementation plan for Milwaukee County. MGE will continue to monitor developments, attainment designations, and state actions and implementation plans.

Other Matters

ATC

Several parties have filed a complaint with FERC seeking to reduce the base return on equity (ROE) of MISO and numerous other MISO transmission owners, including ATC, "due to changes in the capital markets." The complaint alleges that the MISO ROE should not exceed 9.15%, the equity components of hypothetical capital structures should be restricted to 50%, and the relevant incentive ROE adders should be discontinued. FERC denied the portion of the complaint seeking to restrict the use of capital structures that include more than 50% common equity and also denied the portion of the complaint requesting the termination of the incentive ROE adders used by certain transmission owners. MISO's base ROE is 12.38% and ATC's base ROE is 12.2%. FERC ordered formal hearing proceedings to begin, and an initial decision in the complaint is expected by November 30, 2015. ATC provided MGE its 2015 earnings reflecting an adjustment for this matter representing ATC's estimate of its potential refund liability. We derived approximately 6.4% of our net income for the nine months ended September 30, 2015, from our investment in ATC.

47

Rate Matters

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

Annual Fuel Proceeding

In August 2015, the PSCW approved on an interim basis MGE's application to implement a fuel credit associated with its fuel savings for 2015. The fuel credit established a mechanism to return the fuel savings to electric customers via a bill credit during the period from September 1, 2015, to December 31, 2015. The fuel credit was based on $5.9 million of actual fuel savings deferred through June 30, 2015. Approximately $2.7 million is expected to be returned to customers through December 31, 2015. The application further proposes a fuel credit to cover expected fuel savings for 2016 in the amount of approximately $5.0 million based on anticipated fuel costs. The actual fuel savings will depend upon the completion of the annual PSCW fuel cost audits for 2015 and 2016.

New Accounting Principles

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

48

Item 3. Quantitative and Qualitative Disclosures About Market Risk.

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

Commodity Price Risk

MGE has commodity price risk exposure with respect to the price of natural gas, electricity, coal, emission credits, and oil. MGE's electric operations burn natural gas in several of its peaking power plants and, in many cases, the cost of purchased power is tied to the cost of natural gas. MGE employs established policies and procedures to reduce the market risks associated with changing commodity prices. MGE's commodity risks are somewhat mitigated by the current ratemaking process in place for recovering electric fuel cost, purchased energy costs, and the cost of natural gas.

MGE's electric fuel costs are subject to fuel rules established by the PSCW. The fuel rules require the PSCW and Wisconsin utilities to defer electric fuel-related costs that fall outside a symmetrical cost tolerance band. Any over/under recovery of the actual costs is determined on an annual basis and is adjusted in future billings to electric retail customers. Under the electric fuel rules, MGE is required to defer the benefit of lower costs if the actual electric fuel costs fall outside the lower end of the range and is required to defer costs, less any excess revenues, if the actual electric fuel costs exceed the upper end of the range. Excess revenues are defined as revenues in the year in question that provide MGE with a greater return on common equity than authorized by the PSCW in MGE's latest rate order. The range is defined by the PSCW and has been modified throughout the years based on market conditions and other relevant factors. Currently, MGE is subject to a plus or minus 2% range. MGE assumes the risks and benefits of variances that are within the cost tolerance band. For 2015, fuel and purchased power costs included in MGE's base fuel rates are $123.0 million. See Footnote 10.b. of the Notes to Consolidated Financial Statements for additional information.

MGE recovers the cost of natural gas in its gas segment through the purchased gas adjustment clause (PGA). Under the PGA, MGE is able to pass through to its gas customers the cost of gas.

MGE also reduces price risk caused by market fluctuations via physical contracts and financial derivative contracts, including futures, swaps, options, forwards, and other contractual commitments. The maximum length of time over which cash flows related to energy commodities can be hedged under applicable PSCW approvals is four years.

MGE has financial gas and electric commodity contracts to hedge commodity price risk in the gas and electric segments. These contracts are primarily comprised of exchange-traded option and future contracts. MGE also holds FTRs, which are used to hedge the risk of increased transmission congestion charges. At September 30, 2015, the cost basis of these instruments exceeded their fair value by $0.4 million. Under the PGA clause and electric fuel rules, MGE may include in the costs of fuel (natural gas or power) the costs and benefits of the aforementioned fuel price risk management tools. Because these costs/benefits are recoverable, the related unrealized loss/gain has been deferred on the consolidated balance sheet as a regulatory asset/liability.

MGE has also entered into a purchased power agreement that provides MGE with firm capacity and energy that began on June 1, 2012, and ends on May 31, 2022 (the "base term"). The agreement also allows MGE an option to extend the contract after the base term. The agreement is considered a derivative contract and is recognized at its fair value on the consolidated balance sheet. However, the derivative qualifies for regulatory deferral and is recognized with a corresponding regulatory asset or liability depending on whether the fair value is in a loss or gain position. The fair value of the contract at September 30, 2015, reflects a loss position of $57.0 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.

49

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, 2015, no counterparties have defaulted.

MGE is obligated to provide service to all electric and gas customers within its respective franchised territories. MGE's franchised electric territory includes a 316 square-mile area in Dane County, Wisconsin, and MGE's franchised gas territory includes a service area covering 1,649 square miles in Wisconsin. Based on results for the year ended December 31, 2014, 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.

50

Item 4. Controls and Procedures.

During the third quarter of 2015, each registrant's management, including the principal executive officer and principal financial officer, evaluated its disclosure controls and procedures related to the recording, processing, summarization, and reporting of information in its periodic reports that it files with the SEC. These disclosure controls and procedures have been designed to ensure that material information relating to that registrant, including its subsidiaries, is accumulated and made known to that registrant's management, including these officers, by other employees of that registrant and its subsidiaries as appropriate to allow timely decisions regarding required disclosure, and that this information is recorded, processed, summarized, evaluated, and reported, as applicable, within the time periods specified in the SEC's rules and forms. Due to the inherent limitations of control systems, not all misstatements may be detected. These inherent limitations include the realities that judgments in decision making can be faulty and breakdowns can occur because of simple error or mistake. Additionally, controls can be circumvented by the individual acts of some persons, by collusion of two or more people, or by management override of the control. Also, the registrants do not control or manage certain of their unconsolidated entities and thus, their access and ability to apply their procedures to those entities is more limited than is the case for their consolidated subsidiaries.

As of September 30, 2015, 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, 2015, 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.

51

PART II. OTHER INFORMATION.

Item 1. Legal Proceedings.

MGE Energy and MGE

MGE Energy and its subsidiaries, including MGE, from time to time are involved in various legal proceedings that are handled and defended in the ordinary course of business.

See Footnote 8.a. and 8.b. of Notes to Consolidated Financial Statements for more information.

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

Issuer Purchases of Equity Securities

Period	Total Number of Shares Purchased		Average Price Paid per Share	Total Number of Shares Purchased as Part of Publicly Announced Plans or Programs*	Maximum number (or Approximate Dollar Value) of Shares That May Yet Be Purchased Under the Plans or Programs*
July 1-31, 2015	34,725	$	39.86	-	-
August 1-31, 2015	27,575		39.40	-	-
September 1-30, 2015	83,217		39.30	-	-
Total	145,517	$	39.45	-	-

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

Item 4. Mine Safety Disclosures.

Not applicable to MGE Energy and MGE.

Item 6. Exhibits.

12

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

Certifications Pursuant to Rule 13a-14(a) and 15d-14(a) of the Securities and Exchange Act of 1934 as to the Quarterly Report on Form 10-Q for the quarter ended September 30, 2015, filed by the following officers for the following companies:

31.1

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

31.2

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

31.3

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

31.4

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

52

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, 2015, filed by the following officers for the following companies:

32.1

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

32.2

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

32.3

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

32.4

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

101

Interactive Data Files:

101.INS

XBRL Instance

101.SCH

XBRL Taxonomy Extension Schema

101.CAL

XBRL Taxonomy Extension Calculation

101.DEF

XBRL Taxonomy Extension Definition

101.LAB

XBRL Taxonomy Extension Labels

101.PRE

XBRL Taxonomy Extension Presentation

53

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 5, 2015	/s/ Gary J. Wolter
	Gary J. Wolter Chairman, President and Chief Executive Officer (Duly Authorized Officer)
Date: November 5, 2015	/s/ Jeffrey C. Newman
	Jeffrey C. Newman Senior Vice President, Chief Financial Officer, Secretary and Treasurer (Chief Financial and Accounting Officer)

54

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 5, 2015	/s/ Gary J. Wolter
	Gary J. Wolter Chairman, President and Chief Executive Officer (Duly Authorized Officer)
Date: November 5, 2015	/s/ Jeffrey C. Newman
	Jeffrey C. Newman Senior Vice President, Chief Financial Officer, Secretary and Treasurer (Chief Financial and Accounting Officer)

55

EX-12

EXHIBIT 12

Madison Gas and Electric Company

Ratio of Earnings to Fixed Charges

Nine Months Ended September 30, 2015

(In thousands)

Earnings
Net income before minority interest	$60,240
Equity earnings	(6,568)
Income distribution from equity investees	4,732
Minority interest in pretax income	(3,086)
Amortization of capitalized interest	396
Federal and state income taxes	33,981
Fixed charges	16,079
Total Earnings as Defined	$105,774
Fixed Charges
Interest expense on long-term debt and other	$14,617
Interest on rentals*	617
Amortization of debt issuance costs	682
AFUDC - borrowed funds	163
Total Fixed Charges	$16,079
Ratio of Earnings to Fixed Charges	6.58X

*Management believes that using one-third of the total rental expense

gives a reasonable approximation for actual interest on rentals.

EX-31

EXHIBIT 31.1

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

I, Gary J. Wolter, certify that:

1.

I have reviewed this quarterly report on Form 10-Q of MGE Energy, Inc.;

2.

Based on my knowledge, this report does not contain any untrue statement of a material fact or omit to state a material fact necessary to make the statements made, in light of the circumstances under which such statements were made, not misleading with respect to the period covered by this report;

3.

Based on my knowledge, the financial statements, and other financial information included in this report, fairly present in all material respects the financial condition, results of operations and cash flows of the registrant as of, and for, the periods presented in this report;

4.

The registrant's other certifying officer and I are responsible for establishing and maintaining disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) and internal control over financial reporting (as defined in Exchange Act Rules 13a-15(f) and 15d-15(f)) for the registrant and have:

(a)

Designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be designed under our supervision, to ensure that material information relating to the registrant, including its consolidated subsidiaries, is made known to us by others within those entities, particularly during the period in which this report is being prepared;

(b)

Designed such internal control over financial reporting, or caused such internal control over financial reporting to be designed under our supervision, to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles;

(c)

Evaluated the effectiveness of the registrant's disclosure controls and procedures and presented in this report our conclusions about the effectiveness of the disclosure controls and procedures, as of the end of the period covered by this report based on such evaluation; and

(d)

Disclosed in this report any change in the registrant's internal control over financial reporting that occurred during the registrant's most recent fiscal quarter (the registrant's fourth fiscal quarter in the case of an annual report) that has materially affected, or is reasonably likely to materially affect, the registrant's internal control over financial reporting; and

5.

The registrant's other certifying officer and I have disclosed, based on our most recent evaluation of internal control over financial reporting, to the registrant's auditors and the audit committee of the registrant's board of directors (or persons performing the equivalent functions):

(a)

All significant deficiencies and material weaknesses in the design or operation of internal control over financial reporting which are reasonably likely to adversely affect the registrant's ability to record, process, summarize and report financial information; and

(b)

Any fraud, whether or not material, that involves management or other employees who have a significant role in the registrant's internal control over financial reporting.

/s/ Gary J. Wolter

Gary J. Wolter

Chairman, President and Chief Executive Officer

Date: November 5, 2015

EX-31

EXHIBIT 31.2

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

I, Jeffrey C. Newman, certify that:

1.

I have reviewed this quarterly report on Form 10-Q of MGE Energy, Inc.;

2.

Based on my knowledge, this report does not contain any untrue statement of a material fact or omit to state a material fact necessary to make the statements made, in light of the circumstances under which such statements were made, not misleading with respect to the period covered by this report;

3.

Based on my knowledge, the financial statements, and other financial information included in this report, fairly present in all material respects the financial condition, results of operations and cash flows of the registrant as of, and for, the periods presented in this report;

4.

The registrant's other certifying officer and I are responsible for establishing and maintaining disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) and internal control over financial reporting (as defined in Exchange Act Rules 13a-15(f) and 15d-15(f)) for the registrant and have:

(a)

Designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be designed under our supervision, to ensure that material information relating to the registrant, including its consolidated subsidiaries, is made known to us by others within those entities, particularly during the period in which this report is being prepared;

(b)

Designed such internal control over financial reporting, or caused such internal control over financial reporting to be designed under our supervision, to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles;

(c)

Evaluated the effectiveness of the registrant's disclosure controls and procedures and presented in this report our conclusions about the effectiveness of the disclosure controls and procedures, as of the end of the period covered by this report based on such evaluation; and

(d)

Disclosed in this report any change in the registrant's internal control over financial reporting that occurred during the registrant's most recent fiscal quarter (the registrant's fourth fiscal quarter in the case of an annual report) that has materially affected, or is reasonably likely to materially affect, the registrant's internal control over financial reporting; and

5.

The registrant's other certifying officer and I have disclosed, based on our most recent evaluation of internal control over financial reporting, to the registrant's auditors and the audit committee of the registrant's board of directors (or persons performing the equivalent functions):

(a)

All significant deficiencies and material weaknesses in the design or operation of internal control over financial reporting which are reasonably likely to adversely affect the registrant's ability to record, process, summarize and report financial information; and

(b)

Any fraud, whether or not material, that involves management or other employees who have a significant role in the registrant's internal control over financial reporting.

/s/ Jeffrey C. Newman

Jeffrey C. Newman

Senior Vice President, Chief Financial Officer,

Secretary and Treasurer

Date: November 5, 2015

EX-31

EXHIBIT 31.3

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

I, Gary J. Wolter, certify that:

1.

I have reviewed this quarterly report on Form 10-Q of Madison Gas and Electric Company;

2.

Based on my knowledge, this report does not contain any untrue statement of a material fact or omit to state a material fact necessary to make the statements made, in light of the circumstances under which such statements were made, not misleading with respect to the period covered by this report;

3.

Based on my knowledge, the financial statements, and other financial information included in this report, fairly present in all material respects the financial condition, results of operations and cash flows of the registrant as of, and for, the periods presented in this report;

4.

The registrant's other certifying officer and I are responsible for establishing and maintaining disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) and internal control over financial reporting (as defined in Exchange Act Rules 13a-15(f) and 15d-15(f)) for the registrant and have:

(a)

Designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be designed under our supervision, to ensure that material information relating to the registrant, including its consolidated subsidiaries, is made known to us by others within those entities, particularly during the period in which this report is being prepared;

(b)

Designed such internal control over financial reporting, or caused such internal control over financial reporting to be designed under our supervision, to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles;

(c)

Evaluated the effectiveness of the registrant's disclosure controls and procedures and presented in this report our conclusions about the effectiveness of the disclosure controls and procedures, as of the end of the period covered by this report based on such evaluation; and

(d)

Disclosed in this report any change in the registrant's internal control over financial reporting that occurred during the registrant's most recent fiscal quarter (the registrant's fourth fiscal quarter in the case of an annual report) that has materially affected, or is reasonably likely to materially affect, the registrant's internal control over financial reporting; and

5.

The registrant's other certifying officer and I have disclosed, based on our most recent evaluation of internal control over financial reporting, to the registrant's auditors and the audit committee of the registrant's board of directors (or persons performing the equivalent functions):

(a)

All significant deficiencies and material weaknesses in the design or operation of internal control over financial reporting which are reasonably likely to adversely affect the registrant's ability to record, process, summarize and report financial information; and

(b)

Any fraud, whether or not material, that involves management or other employees who have a significant role in the registrant's internal control over financial reporting.

/s/ Gary J. Wolter

Gary J. Wolter

Chairman, President and Chief Executive Officer

Date: November 5, 2015

EX-31

EXHIBIT 31.4

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

I, Jeffrey C. Newman, certify that:

1.

I have reviewed this quarterly report on Form 10-Q of Madison Gas and Electric Company;

2.

Based on my knowledge, this report does not contain any untrue statement of a material fact or omit to state a material fact necessary to make the statements made, in light of the circumstances under which such statements were made, not misleading with respect to the period covered by this report;

3.

Based on my knowledge, the financial statements, and other financial information included in this report, fairly present in all material respects the financial condition, results of operations and cash flows of the registrant as of, and for, the periods presented in this report;

4.

The registrant's other certifying officer and I are responsible for establishing and maintaining disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) and internal control over financial reporting (as defined in Exchange Act Rules 13a-15(f) and 15d-15(f)) for the registrant and have:

(a)

Designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be designed under our supervision, to ensure that material information relating to the registrant, including its consolidated subsidiaries, is made known to us by others within those entities, particularly during the period in which this report is being prepared;

(b)

Designed such internal control over financial reporting, or caused such internal control over financial reporting to be designed under our supervision, to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles;

(c)

Evaluated the effectiveness of the registrant's disclosure controls and procedures and presented in this report our conclusions about the effectiveness of the disclosure controls and procedures, as of the end of the period covered by this report based on such evaluation; and

(d)

Disclosed in this report any change in the registrant's internal control over financial reporting that occurred during the registrant's most recent fiscal quarter (the registrant's fourth fiscal quarter in the case of an annual report) that has materially affected, or is reasonably likely to materially affect, the registrant's internal control over financial reporting; and

5.

The registrant's other certifying officer and I have disclosed, based on our most recent evaluation of internal control over financial reporting, to the registrant's auditors and the audit committee of the registrant's board of directors (or persons performing the equivalent functions):

(a)

All significant deficiencies and material weaknesses in the design or operation of internal control over financial reporting which are reasonably likely to adversely affect the registrant's ability to record, process, summarize and report financial information; and

(b)

Any fraud, whether or not material, that involves management or other employees who have a significant role in the registrant's internal control over financial reporting.

/s/ Jeffrey C. Newman

Jeffrey C. Newman

Senior Vice President, Chief Financial Officer,

Secretary and Treasurer

Date: November 5, 2015

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, 2015, as filed with the Securities and Exchange Commission on the date hereof ("the Report"), I, Gary J. Wolter, Chief Executive Officer of the Company, certify, pursuant to 18 U.S.C. Section 1350, as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002, that:

1.

The Report fully complies with the requirements of Section 13(a) or 15(d) of the Securities Exchange Act of 1934, and

2.

The information contained in the Report fairly presents, in all material respects, the financial condition and results of operations of the Company.

/s/ Gary J. Wolter

Gary J. Wolter

Chairman, President and Chief Executive Officer

Date: November 5, 2015

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, 2015, as filed with the Securities and Exchange Commission on the date hereof ("the Report"), I, Jeffrey C. Newman, Chief Financial Officer of the Company, certify, pursuant to 18 U.S.C. Section 1350, as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002, that:

1.

The Report fully complies with the requirements of Section 13(a) or 15(d) of the Securities Exchange Act of 1934, and

2.

The information contained in the Report fairly presents, in all material respects, the financial condition and results of operations of the Company.

/s/ Jeffrey C. Newman

Jeffrey C. Newman

Senior Vice President, Chief Financial Officer,

Secretary and Treasurer

Date: November 5, 2015

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, 2015, as filed with the Securities and Exchange Commission on the date hereof ("the Report"), I, Gary J. Wolter, Chief Executive Officer of the Company, certify, pursuant to 18 U.S.C. Section 1350, as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002, that:

1.

The Report fully complies with the requirements of Section 13(a) or 15(d) of the Securities Exchange Act of 1934, and

2.

The information contained in the Report fairly presents, in all material respects, the financial condition and results of operations of the Company.

/s/ Gary J. Wolter

Gary J. Wolter

Chairman, President and Chief Executive Officer

Date: November 5, 2015

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, 2015, as filed with the Securities and Exchange Commission on the date hereof ("the Report"), I, Jeffrey C. Newman, Chief Financial Officer of the Company, certify, pursuant to 18 U.S.C. Section 1350, as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002, that:

1.

The Report fully complies with the requirements of Section 13(a) or 15(d) of the Securities Exchange Act of 1934, and

2.

The information contained in the Report fairly presents, in all material respects, the financial condition and results of operations of the Company.

/s/ Jeffrey C. Newman

Jeffrey C. Newman

Senior Vice President, Chief Financial Officer,

Secretary and Treasurer

Date: November 5, 2015

XML

Taxes (Details)	3 Months Ended		9 Months Ended
	Sep. 30, 2015	Sep. 30, 2014	Sep. 30, 2015	Sep. 30, 2014
Income Tax Disclosure [Line Items]
Effective income tax rate	35.10%	38.00%	36.10%	37.80%
MGE [Member]
Income Tax Disclosure [Line Items]
Effective income tax rate	35.10%	37.90%	36.10%	37.80%

XML

Segment Information (Details) - USD ($) $ in Thousands		3 Months Ended		9 Months Ended
		Sep. 30, 2015	Sep. 30, 2014	Sep. 30, 2015	Sep. 30, 2014
Segment Reporting Information [Line Items]
Operating revenues		$ 140,795	$ 135,135	$ 433,055	$ 474,145
Depreciation and amortization		(11,182)	(10,376)	(33,026)	(30,191)
Other operating expenses		(83,436)	(84,639)	(297,952)	(335,422)
Operating Income		46,177	40,120	102,077	108,532
Other income (deductions), net		2,564	2,636	7,115	10,736
Interest (expense) income, net		(5,036)	(5,141)	(15,135)	(14,550)
Income before income taxes		43,705	37,615	94,057	104,718
Income tax (provision) benefit		(15,351)	(14,286)	(33,946)	(39,585)
Net Income (Loss)		28,354	23,329	60,111	65,133
Electric [Member]
Segment Reporting Information [Line Items]
Operating revenues		121,453	112,869	319,174	308,418
Gas [Member]
Segment Reporting Information [Line Items]
Operating revenues		17,431	21,404	108,028	163,335
Non Regulated Energy [Member]
Segment Reporting Information [Line Items]
Operating revenues		1,911	862	5,853	2,392
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		140,795	135,135	433,055	474,145
Operating Segments [Member] | Electric [Member]
Segment Reporting Information [Line Items]
Operating revenues		121,616	113,025	319,574	308,819
Depreciation and amortization		(7,584)	(6,931)	(22,372)	(19,909)
Other operating expenses		(80,202)	(74,573)	(239,963)	(229,286)
Operating Income		33,830	31,521	57,239	59,624
Other income (deductions), net		141	136	247	2,999
Interest (expense) income, net		(2,798)	(2,832)	(8,385)	(7,571)
Income before income taxes		31,173	28,825	49,101	55,052
Income tax (provision) benefit		(10,321)	(10,758)	(15,868)	(19,602)
Net Income (Loss)		20,852	18,067	33,233	35,450
Operating Segments [Member] | Gas [Member]
Segment Reporting Information [Line Items]
Operating revenues		21,286	23,018	116,899	170,465
Depreciation and amortization		(1,714)	(1,575)	(5,018)	(4,700)
Other operating expenses		(16,906)	(22,199)	(96,063)	(144,907)
Operating Income		2,666	(756)	15,818	20,858
Other income (deductions), net		(7)	8	(33)	(44)
Interest (expense) income, net		(804)	(808)	(2,398)	(2,429)
Income before income taxes		1,855	(1,556)	13,387	18,385
Income tax (provision) benefit		(732)	651	(5,370)	(7,378)
Net Income (Loss)		1,123	(905)	8,017	11,007
Operating Segments [Member] | Non Regulated Energy [Member]
Segment Reporting Information [Line Items]
Operating revenues		11,777	11,536	35,419	34,409
Depreciation and amortization		(1,872)	(1,858)	(5,601)	(5,547)
Other operating expenses		(36)	(35)	(122)	(105)
Operating Income		9,869	9,643	29,696	28,757
Other income (deductions), net		0	0	0	0
Interest (expense) income, net		(1,491)	(1,545)	(4,516)	(4,676)
Income before income taxes		8,378	8,098	25,180	24,081
Income tax (provision) benefit		(3,362)	(3,251)	(10,106)	(9,665)
Net Income (Loss)		5,016	4,847	15,074	14,416
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		(15)	0	(15)	0
Operating Income		(15)	0	(15)	0
Other income (deductions), net		2,397	2,423	6,568	7,306
Interest (expense) income, net		0	0	0	0
Income before income taxes		2,382	2,423	6,553	7,306
Income tax (provision) benefit		(962)	(963)	(2,637)	(2,924)
Net Income (Loss)		1,420	1,460	3,916	4,382
Operating Segments [Member] | All Others [Member]
Segment Reporting Information [Line Items]
Operating revenues		0	0	0	0
Depreciation and amortization		(12)	(12)	(35)	(35)
Other operating expenses		(161)	(276)	(626)	(672)
Operating Income		(173)	(288)	(661)	(707)
Other income (deductions), net		33	69	333	475
Interest (expense) income, net		57	44	164	126
Income before income taxes		(83)	(175)	(164)	(106)
Income tax (provision) benefit		26	35	35	(16)
Net Income (Loss)		(57)	(140)	(129)	(122)
Consolidation Elimination Entries [Member]
Segment Reporting Information [Line Items]
Operating revenues		(13,884)	(12,444)	(38,837)	(39,548)
Depreciation and amortization		0	0	0	0
Other operating expenses		13,884	12,444	38,837	39,548
Operating Income		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		163	156	400	401
Consolidation Elimination Entries [Member] | Gas [Member]
Segment Reporting Information [Line Items]
Operating revenues		3,855	1,614	8,871	7,130
Consolidation Elimination Entries [Member] | Non Regulated Energy [Member]
Segment Reporting Information [Line Items]
Operating revenues		9,866	10,674	29,566	32,017
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		140,806	135,147	433,083	474,178
Depreciation and amortization		(11,170)	(10,364)	(32,991)	(30,156)
Other operating expenses	[1]	(97,686)	(97,712)	(328,571)	(370,962)
Operating Income	[1]	31,950	27,071	71,521	73,060
Other income (deductions), net	[1]	1,554	1,583	4,018	6,871
Interest (expense) income, net		(5,093)	(5,185)	(15,299)	(14,676)
Income tax (provision) benefit		(14,401)	(13,338)	(31,218)	(36,180)
Net Income Including Noncontrolling Interest		28,411	23,469	60,240	65,255
Less Net Income Attributable to Noncontrolling Interest, net of tax		(6,633)	(6,653)	(19,812)	(19,784)
Net Income (Loss)		21,778	16,816	40,428	45,471
MGE [Member] | Electric [Member]
Segment Reporting Information [Line Items]
Operating revenues		121,460	112,875	319,191	308,435
MGE [Member] | Gas [Member]
Segment Reporting Information [Line Items]
Operating revenues		17,435	21,410	108,039	163,351
MGE [Member] | Non Regulated Energy [Member]
Segment Reporting Information [Line Items]
Operating revenues		1,911	862	5,853	2,392
MGE [Member] | Transmission Investment [Member]
Segment Reporting Information [Line Items]
Operating revenues		0	0	0	0
MGE [Member] | Operating Segments [Member]
Segment Reporting Information [Line Items]
Operating revenues		140,806	135,147	433,083	474,178
MGE [Member] | Operating Segments [Member] | Electric [Member]
Segment Reporting Information [Line Items]
Operating revenues		121,616	113,025	319,574	308,819
Depreciation and amortization		(7,584)	(6,931)	(22,372)	(19,909)
Other operating expenses	[1]	(90,511)	(85,314)	(255,732)	(248,525)
Operating Income	[1]	23,521	20,780	41,470	40,385
Other income (deductions), net	[1]	129	119	148	2,636
Interest (expense) income, net		(2,798)	(2,832)	(8,385)	(7,571)
Net Income Including Noncontrolling Interest		20,852	18,067	33,233	35,450
Less Net Income Attributable to Noncontrolling Interest, net of tax		0	0	0	0
Net Income (Loss)		20,852	18,067	33,233	35,450
MGE [Member] | Operating Segments [Member] | Gas [Member]
Segment Reporting Information [Line Items]
Operating revenues		21,286	23,018	116,899	170,465
Depreciation and amortization		(1,714)	(1,575)	(5,018)	(4,700)
Other operating expenses	[1]	(17,635)	(21,544)	(101,405)	(152,182)
Operating Income	[1]	1,937	(101)	10,476	13,583
Other income (deductions), net	[1]	(10)	4	(61)	(147)
Interest (expense) income, net		(804)	(808)	(2,398)	(2,429)
Net Income Including Noncontrolling Interest		1,123	(905)	8,017	11,007
Less Net Income Attributable to Noncontrolling Interest, net of tax		0	0	0	0
Net Income (Loss)		1,123	(905)	8,017	11,007
MGE [Member] | Operating Segments [Member] | Non Regulated Energy [Member]
Segment Reporting Information [Line Items]
Operating revenues		11,777	11,536	35,419	34,409
Depreciation and amortization		(1,872)	(1,858)	(5,601)	(5,547)
Other operating expenses	[1]	(3,398)	(3,286)	(10,228)	(9,770)
Operating Income	[1]	6,507	6,392	19,590	19,092
Other income (deductions), net	[1]	0	0	0	0
Interest (expense) income, net		(1,491)	(1,545)	(4,516)	(4,676)
Net Income Including Noncontrolling Interest		5,016	4,847	15,074	14,416
Less Net Income Attributable to Noncontrolling Interest, net of tax		0	0	0	0
Net Income (Loss)		5,016	4,847	15,074	14,416
MGE [Member] | 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	[1]	(15)	0	(15)	0
Operating Income	[1]	(15)	0	(15)	0
Other income (deductions), net	[1]	1,435	1,460	3,931	4,382
Interest (expense) income, net		0	0	0	0
Net Income Including Noncontrolling Interest		1,420	1,460	3,916	4,382
Less Net Income Attributable to Noncontrolling Interest, net of tax		0	0	0	0
Net Income (Loss)		1,420	1,460	3,916	4,382
MGE [Member] | Consolidation Elimination Entries [Member]
Segment Reporting Information [Line Items]
Operating revenues		(13,873)	(12,432)	(38,809)	(39,515)
Depreciation and amortization		0	0	0	0
Other operating expenses	[1]	13,873	12,432	38,809	39,515
Operating Income	[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		(6,633)	(6,653)	(19,812)	(19,784)
Net Income (Loss)		(6,633)	(6,653)	(19,812)	(19,784)
MGE [Member] | Consolidation Elimination Entries [Member] | Electric [Member]
Segment Reporting Information [Line Items]
Operating revenues		156	150	383	384
MGE [Member] | Consolidation Elimination Entries [Member] | Gas [Member]
Segment Reporting Information [Line Items]
Operating revenues		3,851	1,608	8,860	7,114
MGE [Member] | Consolidation Elimination Entries [Member] | Non Regulated Energy [Member]
Segment Reporting Information [Line Items]
Operating revenues		9,866	10,674	29,566	32,017
MGE [Member] | Consolidation Elimination Entries [Member] | Transmission Investment [Member]
Segment Reporting Information [Line Items]
Operating revenues		$ 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.

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Derivative and Hedging Instruments (Details-5) $ in Thousands	3 Months Ended		9 Months Ended
	Sep. 30, 2015 USD ($) counterparty	Sep. 30, 2014 USD ($)	Sep. 30, 2015 USD ($) counterparty	Sep. 30, 2014 USD ($)	Dec. 31, 2014 USD ($)
Counterparties in net liability position or default [Abstract]
Derivative, net liability position of counterparties (less than $0.1 million)	$ 100		$ 100		$ 100
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	$ 862	$ 480	$ 1,860	$ (5,376)
Commodity Derivative Contracts [Member] | Cost Of Gas Sold Expense [Member]
Realized losses (gains) on income statement [Line Items]
Realized losses (gains) on income statement	(17)	(18)	1,742	(1,367)
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	(233)	(97)	(607)	(929)
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	1,757	1,068	3,348	461
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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Derivative and Hedging Instruments (Details-3) - USD ($) $ in Thousands	Sep. 30, 2015	Dec. 31, 2014
Offsetting Liabilities [Line Items]
Collateral posted against derivative positions	$ (800)	$ (2,200)
Commodity Derivative Contracts [Member]
Offsetting Liabilities [Line Items]
Gross amounts	1,258	2,433
Gross amounts offset in balance sheet	(431)	(223)
Collateral posted against derivative positions	(827)	(2,179)
Net amount presented in balance sheet	0	31
Purchased Power Agreement [Member]
Offsetting Liabilities [Line Items]
Gross amounts	56,950	53,430
Gross amounts offset in balance sheet	0	0
Collateral posted against derivative positions	0	0
Net amount presented in balance sheet	$ 56,950	$ 53,430

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Fair Value of Financial Instruments (Tables)

9 Months Ended

Sep. 30, 2015

Fair Value Disclosures [Abstract]

Estimated Fair Market Value of Financial Instruments

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

		September 30, 2015				December 31, 2014
(In thousands)		Carrying Amount		Fair Value		Carrying Amount		Fair Value
MGE Energy
Assets:
Cash and cash equivalents	$	94,267	$	94,267	$	65,755	$	65,755
Liabilities:
Short-term debt - commercial paper		-		-		7,000		7,000
Long-term debt*		396,562		446,176		399,690		457,420
MGE
Assets:
Cash and cash equivalents	$	41,971	$	41,971	$	4,562	$	4,562
Liabilities:
Short-term debt - commercial paper		-		-		7,000		7,000
Long-term debt*		396,562		446,176		399,690		457,420
*Includes long-term debt due within one year.

Assets and Liabilities Measured at Fair Value on a Recurring Basis

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

		Fair Value as of September 30, 2015
(In thousands)		Total		Level 1		Level 2		Level 3
MGE Energy
Assets:
Derivatives, net	$	379	$	-	$	-	$	379
Exchange-traded investments		627		627		-		-
Total Assets	$	1,006	$	627	$	-	$	379
Liabilities:
Derivatives, net(a)	$	57,777	$	316	$	-	$	57,461
Deferred compensation		3,160		-		3,160		-
Total Liabilities	$	60,937	$	316	$	3,160	$	57,461
MGE
Assets:
Derivatives, net	$	379	$	-	$	-	$	379
Exchange-traded investments		122		122		-		-
Total Assets	$	501	$	122	$	-	$	379
Liabilities:
Derivatives, net(a)	$	57,777	$	316	$	-	$	57,461
Deferred compensation		3,160		-		3,160		-
Total Liabilities	$	60,937	$	316	$	3,160	$	57,461

		Fair Value as of December 31, 2014
(In thousands)		Total		Level 1		Level 2		Level 3
MGE Energy
Assets:
Derivatives, net	$	642	$	-	$	-	$	642
Exchange-traded investments		927		927		-		-
Total Assets	$	1,569	$	927	$	-	$	642
Liabilities:
Derivatives, net(a)	$	55,640	$	1,012	$	-	$	54,628
Deferred compensation		2,832		-		2,832		-
Total Liabilities	$	58,472	$	1,012	$	2,832	$	54,628
MGE
Assets:
Derivatives, net	$	642	$	-	$	-	$	642
Exchange-traded investments		350		350		-		-
Total Assets	$	992	$	350	$	-	$	642
Liabilities:
Derivatives, net(a)	$	55,640	$	1,012	$	-	$	54,628
Deferred compensation		2,832		-		2,832		-
Total Liabilities	$	58,472	$	1,012	$	2,832	$	54,628
(a) These amounts are shown gross and exclude $0.8 million and $2.2 million of collateral that was
posted against derivative positions with counterparties as of September 30, 2015, and
December 31, 2014, respectively.

Significant Unobservable Inputs

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

	Model Input
Significant Unobservable Inputs	September 30, 2015	December 31, 2014
Basis adjustment:
On peak	97.4%	98.1%
Off peak	95.4%	95.0%
Counterparty fuel mix:
Internal generation	60% - 75%	50% - 70%
Purchased power	40% - 25%	50% - 30%

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

The following table summarizes the changes in Level 3 assets and liabilities measured at fair value on a recurring basis for both MGE Energy and MGE.

		Three Months Ended				Nine Months Ended
		September 30,				September 30,
(In thousands)		2015		2014		2015		2014
Beginning balance	$	(56,194)	$	(49,349)	$	(53,986)	$	(64,628)
Realized and unrealized gains (losses):
Included in regulatory liabilities (assets)		(888)		(3,752)		(3,096)		11,528
Included in other comprehensive income		-		-		-		-
Included in earnings		(2,285)		(1,419)		(4,497)		5,837
Included in current assets		-		-		-		(89)
Purchases		6,364		6,371		17,497		19,900
Sales		-		-		34		(60)
Issuances		-		-		-		-
Settlements		(4,079)		(4,952)		(13,034)		(25,589)
Transfers in and/or out of Level 3		-		-		-		-
Balance as of September 30,	$	(57,082)	$	(53,101)	$	(57,082)	$	(53,101)
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 gains (losses) included in income for Level 3 assets and liabilities measured at fair value on a recurring basis for both MGE Energy and MGE(b).

		Three Months Ended				Nine Months Ended
		September 30,				September 30,
(In thousands)		2015		2014		2015		2014
Purchased Power Expense	$	(2,302)	$	(1,411)	$	(4,515)	$	5,845
Cost of Gas Sold Expense		17		(8)		18		(8)
Total	$	(2,285)	$	(1,419)	$	(4,497)	$	5,837

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

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New Accounting Pronouncements

9 Months Ended

Sep. 30, 2015

New Accounting Pronouncements and Changes in Accounting Principles [Abstract]

New Accounting Pronouncements

New Accounting Pronouncements - MGE Energy and MGE.

a.Transfers and Servicing Assets.

In June 2014, the FASB issued authoritative guidance within the Codification's Transfers and Servicing topic that provides guidance on the accounting and disclosures for repurchase-to-maturity transactions, securities lending transactions, and repurchase financings. This authoritative guidance became effective January 1, 2015. The authoritative guidance changed the accounting for the Chattel Paper program and required additional disclosures. Prior to adoption of the standard, Chattel Paper was treated as an off-balance sheet arrangement. See Footnote 4 for additional information.

b.Revenue from Contracts with Customers.

In May 2014, the FASB issued authoritative guidance within the Codification's Revenue Recognition topic that provides guidance on the recognition, measurement, and disclosure of revenue from contracts with customers. This authoritative guidance was scheduled to become effective January 1, 2017. In July 2015, the FASB deferred the effective date to January 1, 2018. MGE Energy and MGE are currently assessing the impact this pronouncement will have on their financial statements.

c.Consolidations.

In February 2015, the FASB issued authoritative guidance within the Codification's Consolidation topic that provides guidance on the evaluation of certain legal entities for consolidation purposes. This authoritative guidance will become effective January 1, 2016. The impact of this guidance on our financial statements is not expected to be material.

d.Debt Issuance Costs.

In April 2015, the FASB issued authoritative guidance within the Codification's Interest topic that provides guidance on the presentation of debt issuance costs in financial statements. This authoritative guidance will become effective January 1, 2016. The authoritative guidance changes the presentation of debt issuance costs on the balance sheet from an asset to a direct deduction from the related debt liability. The impact of this guidance on our financial statements is not expected to be material.

e.Cloud Computing Arrangements.

In April 2015, the FASB issued authoritative guidance within the Codification's Software topic that provides guidance on the accounting treatment of cloud computer arrangements. This authoritative guidance will become effective January 1, 2016. The authoritative guidance provides criteria for determining whether a cloud computing arrangement contains a software license that should be accounted for as internal-use software. The impact of this guidance on our financial statements is not expected to be material.

f. Inventory Measurement.

In July 2015, the FASB issued authoritative guidance within the Codification's Inventory topic that provides guidance on the subsequent measurement of inventory. This authoritative guidance will become effective January 1, 2017. The authoritative guidance changes the subsequent measurement of inventory from the lower of cost or market to the lower of cost or net realizable value. MGE Energy and MGE are currently assessing the impact this pronouncement will have on their financial statements.

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Fair Value of Financial Instruments (Details-1) - USD ($) $ in Thousands		Sep. 30, 2015	Dec. 31, 2014
Carrying Amount [Member]
Assets:
Cash and cash equivalents		$ 94,267	$ 65,755
Liabilities:
Short-term debt - commercial paper		0	7,000
Long-term debt	[1]	396,562	399,690
Fair Value [Member]
Assets:
Cash and cash equivalents		94,267	65,755
Liabilities:
Short-term debt - commercial paper		0	7,000
Long-term debt	[1]	446,176	457,420
MGE [Member] | Carrying Amount [Member]
Assets:
Cash and cash equivalents		41,971	4,562
Liabilities:
Short-term debt - commercial paper		0	7,000
Long-term debt	[1]	396,562	399,690
MGE [Member] | Fair Value [Member]
Assets:
Cash and cash equivalents		41,971	4,562
Liabilities:
Short-term debt - commercial paper		0	7,000
Long-term debt	[1]	$ 446,176	$ 457,420

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

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Commitments and Contingencies (Details-1) $ in Millions	9 Months Ended
	Sep. 30, 2015 USD ($) Tons ppb MW
Columbia Environmental Project, SCR [Member] | MGE [Member]
Columbia Commitments
Share of projected project cost, minimum | $	$ 19
Share of projected project cost, maximum | $	$ 29
EPA [Member] | Legal Entity Type of Counterparty [Domain]
Effluent Limitations Guidelines and Standards for Steam Electric Power Generating Source Category [Abstract]
Air pollution control and ash handling systems capacity at coal burning power plants, minimum (in MW) | MW	50
EPA's Greenhouse Gas Reduction Guidelines
National average reduction of greenhouse gas emissions by the year 2030, percentage	32.00%
Compliance plan preparation term related to the greenhouse gas emissions reduction guidelines	3 years
Sulfur Dioxide NAAQS
Annual maximum level of sulfur dioxide for large stationary sources | Tons	2,000
Ozone NAAQS
Current primary regulated level of Ozone NAAQS (in parts per billion)	70
Current secondary regulated level of Ozone NAAQS (in parts per billion)	70

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Investment in ATC (Details-2) - ATC [Member] - USD ($) $ in Thousands	3 Months Ended		9 Months Ended
	Sep. 30, 2015	Sep. 30, 2014	Sep. 30, 2015	Sep. 30, 2014
Schedule Of Equity Method Investments [Line Items]
Operating revenues	$ 164,515	$ 163,643	$ 482,043	$ 486,970
Operating expenses	(78,059)	(76,561)	(238,336)	(229,589)
Other income (expense), net	585	693	566	1,403
Interest expense, net	(23,655)	(22,204)	(72,310)	(66,442)
Earnings before members' income taxes	$ 63,386	$ 65,571	$ 171,963	$ 192,342

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Fair Value of Financial Instruments (Details-3)	9 Months Ended	12 Months Ended
	Sep. 30, 2015	Dec. 31, 2014
Fair Value Inputs Assets Quantitative Information [Line Items]
Basis adjustment - on peak	97.40%	98.10%
Basis adjustment - off peak	95.40%	95.00%
US Treasury Bill Securities [Member]
Deferred compensation plan [Abstract]
Investment interest calculation, investment maturity period (26 weeks)	182 days
Investment interest calculation, monthly compounding rate	1.00%
Investment interest calculation, minimum annual rate compounded monthly	7.00%
Minimum [Member]
Counterparty fuel mix [Abstract]
Internal generation	60.00%	50.00%
Purchased power	40.00%	50.00%
Maximum [Member]
Counterparty fuel mix [Abstract]
Internal generation	75.00%	70.00%
Purchased power	25.00%	30.00%

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Derivative and Hedging Instruments (Details-4) - USD ($) $ in Thousands	3 Months Ended		9 Months Ended
	Sep. 30, 2015	Sep. 30, 2014	Sep. 30, 2015	Sep. 30, 2014
Regulatory Asset [Member]
Change In Derivative Fair Value [Roll Forward]
Beginning balance,	$ 56,048	$ 48,853	$ 54,998	$ 63,893
Unrealized loss (gain)	4,036	5,329	8,514	(18,090)
Realized gain (loss) reclassified to a deferred account	(408)	(314)	(1,700)	1,120
Realized gain (loss) reclassified to income statement	(2,278)	(1,184)	(4,414)	5,761
Ending balance,	57,398	52,684	57,398	52,684
Other Current Assets [Member]
Change In Derivative Fair Value [Roll Forward]
Beginning balance,	455	676	1,001	411
Unrealized loss (gain)	0	0	0	0
Realized gain (loss) reclassified to a deferred account	408	314	1,700	(1,120)
Realized gain (loss) reclassified to income statement	(91)	(249)	(1,929)	1,450
Ending balance,	$ 772	$ 741	$ 772	$ 741

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Consolidated Balance Sheets (Unaudited) - USD ($) $ in Thousands	Sep. 30, 2015	Dec. 31, 2014
Current Assets:
Cash and cash equivalents	$ 94,267	$ 65,755
Accounts receivable, less reserves	35,507	41,614
Other accounts receivables, less reserves	6,549	7,610
Unbilled revenues	21,252	31,262
Materials and supplies, at average cost	19,258	17,121
Fossil fuel	14,195	8,098
Stored natural gas, at average cost	16,998	21,036
Prepaid taxes	14,507	38,910
Regulatory assets - current	9,331	8,360
Deferred income taxes - current	0	3,482
Other current assets	9,916	10,711
Total Current Assets	241,780	253,959
Regulatory assets	155,469	156,823
Other deferred assets and other	10,028	7,018
Property, Plant, and Equipment:
Property, plant, and equipment, net	1,207,520	1,189,077
Construction work in progress	25,015	19,029
Total Property, Plant, and Equipment	1,232,535	1,208,106
Investments	74,016	71,760
Total Assets	1,713,828	1,697,666
Current Liabilities:
Long-term debt due within one year	4,245	4,182
Short-term debt	0	7,000
Accounts payable	35,854	41,655
Accrued interest and taxes	3,996	5,086
Accrued payroll related items	10,141	11,241
Deferred income taxes	945	0
Regulatory liabilities - current	4,376	0
Derivative liabilities	8,880	6,901
Other current liabilities	5,821	13,931
Total Current Liabilities	74,258	89,996
Other Credits:
Deferred income taxes	345,127	342,045
Investment tax credit - deferred	1,094	1,223
Regulatory liabilities	24,467	22,715
Accrued pension and other postretirement benefits	78,879	90,201
Derivative liabilities	48,070	46,560
Other deferred liabilities and other	60,476	50,269
Total Other Credits	558,113	553,013
Capitalization:
Common shareholders equity	689,374	659,401
Long-term debt	392,083	395,256
Total Capitalization	$ 1,081,457	$ 1,054,657
Commitments and contingencies (see Footnote 8)
Total Liabilities and Capitalization	$ 1,713,828	$ 1,697,666
MGE [Member]
Current Assets:
Cash and cash equivalents	41,971	4,562
Accounts receivable, less reserves	35,507	41,614
Affiliate receivables	602	7,112
Other accounts receivables, less reserves	6,490	7,524
Unbilled revenues	21,252	31,262
Materials and supplies, at average cost	19,258	17,121
Fossil fuel	14,195	8,098
Stored natural gas, at average cost	16,997	21,035
Prepaid taxes	13,418	39,103
Regulatory assets - current	9,331	8,360
Deferred income taxes - current	0	1,271
Other current assets	9,881	10,683
Total Current Assets	188,902	197,745
Affiliate receivable long-term	4,898	5,295
Regulatory assets	155,469	156,823
Other deferred assets and other	7,908	4,977
Property, Plant, and Equipment:
Property, plant, and equipment, net	1,206,828	1,188,351
Construction work in progress	25,015	19,029
Total Property, Plant, and Equipment	1,231,843	1,207,380
Investments	70,533	68,402
Total Assets	1,659,553	1,640,622
Current Liabilities:
Long-term debt due within one year	4,245	4,182
Short-term debt	0	7,000
Accounts payable	35,847	41,654
Accrued interest and taxes	3,950	5,039
Accrued payroll related items	10,141	11,241
Deferred income taxes	946	0
Regulatory liabilities - current	4,376	0
Derivative liabilities	8,880	6,901
Other current liabilities	5,600	11,350
Total Current Liabilities	73,985	87,367
Other Credits:
Deferred income taxes	337,233	334,773
Investment tax credit - deferred	1,094	1,223
Regulatory liabilities	24,467	22,715
Accrued pension and other postretirement benefits	78,879	90,201
Derivative liabilities	48,070	46,560
Other deferred liabilities and other	60,475	50,267
Total Other Credits	550,218	545,739
Capitalization:
Common shareholders equity	506,720	486,571
Noncontrolling interest	136,547	125,689
Total Equity	643,267	612,260
Long-term debt	392,083	395,256
Total Capitalization	$ 1,035,350	$ 1,007,516
Commitments and contingencies (see Footnote 8)
Total Liabilities and Capitalization	$ 1,659,553	$ 1,640,622

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Commitments and Contingencies (Details-2) $ in Thousands	9 Months Ended
	Sep. 30, 2015 USD ($)
Operating expense purchase contracts [Abstract]
Purchase obligation, 2015	$ 22,144
Purchase obligation, 2016	50,883
Purchase obligation, 2017	28,647
Purchase obligation, 2018	24,461
Purchase obligation, 2019	20,821
Coal [Member]
Operating expense purchase contracts [Abstract]
Purchase obligation, 2015	6,211	[1]
Purchase obligation, 2016	21,639	[1]
Purchase obligation, 2017	10,664	[1]
Purchase obligation, 2018	6,560	[1]
Purchase obligation, 2019	3,850	[1]
Natural Gas, Transportation and Storage [Member]
Operating expense purchase contracts [Abstract]
Purchase obligation, 2015	5,229	[2]
Purchase obligation, 2016	18,117	[2]
Purchase obligation, 2017	17,983	[2]
Purchase obligation, 2018	17,901	[2]
Purchase obligation, 2019	16,971	[2]
Natual Gas, Supply [Member]
Operating expense purchase contracts [Abstract]
Purchase obligation, 2015	10,704	[3]
Purchase obligation, 2016	11,127	[3]
Purchase obligation, 2017	0	[3]
Purchase obligation, 2018	0	[3]
Purchase obligation, 2019	0	[3]
Columbia Asset Retirement Obligation - Coal Combustion Residual Rule [Member]
Asset Retirement Obligation [Line Items]
Liabilities incurred	$ 2,300

[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. If any minimum purchase obligations must be paid under these contracts, management believes these obligations would be considered costs of service and recoverable in rates.

[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 established by FERC but may be subject to change.

[3] These commitments include market-bas ed pricing. Management expects to recover these costs in future customer rates.

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Chattel Paper Agreements (Tables)

9 Months Ended

Sep. 30, 2015

Transfers and Servicing [Abstract]

Schedule of Remaining Contractual Maturities for Chattel Paper Agreements

As of September 30,2015, the remaining contractual maturities of the chattel paper agreements were as follows:

(In thousands)		2015		2016		2017		2018		Thereafter		Total
Repurchase-to-Maturity Transactions:
Loans	$	132	$	735	$	472	$	504	$	1,963	$	3,806

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Investment in ATC (Tables)

9 Months Ended

Sep. 30, 2015

Equity Method Investments and Joint Ventures [Abstract]

ATC's Summarized Financial Data

For the nine months endedSeptember 30,2015 and 2014, MGE Transco recorded the following:

		Nine Months Ended
		September 30,
(In thousands)		2015		2014
Equity in earnings from investment in ATC	$	6,568	$	7,306
Dividends received from ATC		4,732		5,762
Capital contributions to ATC		533		1,420

ATC's summarized financial data for the three and nine months endedSeptember 30,2015 and 2014, is as follows:

		Three Months Ended				Nine Months Ended
		September 30,				September 30,
(In thousands)		2015		2014		2015		2014
Operating revenues	$	164,515	$	163,643	$	482,043	$	486,970
Operating expenses		(78,059)		(76,561)		(238,336)		(229,589)
Other income, net		585		693		566		1,403
Interest expense, net		(23,655)		(22,204)		(72,310)		(66,442)
Earnings before members' income taxes	$	63,386	$	65,571	$	171,963	$	192,342

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Derivative and Hedging Instruments (Details-1) $ in Thousands	9 Months Ended	12 Months Ended
	Sep. 30, 2015 USD ($) Dth MWh MW	Dec. 31, 2014 USD ($) Dth MWh MW	Jun. 30, 2015 USD ($)	Sep. 30, 2014 USD ($)	Jun. 30, 2014 USD ($)	Dec. 31, 2013 USD ($)
Gross Notional Volume of Open Derivatives
Derivative, right to reclaim collateral (receivable)	$ 800
Other Current Assets [Member]
Derivative fair values [Abstract]
Derivative fair value, net	772	$ 1,001	$ 455	$ 741	$ 676	$ 411
Commodity Contracts And Financial Transimission Rights [Member]
Derivative fair values [Abstract]
Derivative fair value, net	$ (400)	$ (1,600)
Commodity Derivative Contracts [Member]
Gross Notional Volume of Open Derivatives
Notional amount, energy measure (in MWh) | MWh	343,560	448,000
Notional amount, decatherm measure (in Dth) | Dth	6,547,500	4,405,000
Derivative fair values [Abstract]
Asset Derivatives, fair value, gross basis	$ 440	$ 223
Liability Derivatives, fair value, gross basis	1,258	2,433
Commodity Derivative Contracts [Member] | Other Current Assets [Member]
Derivative fair values [Abstract]
Asset Derivatives, fair value, gross basis	375	130
Commodity Derivative Contracts [Member] | Other Deferred Charges [Member]
Derivative fair values [Abstract]
Asset Derivatives, fair value, gross basis	65	93
Commodity Derivative Contracts [Member] | Derivative Liability (Current) [Member]
Derivative fair values [Abstract]
Liability Derivatives, fair value, gross basis	1,196	2,262
Commodity Derivative Contracts [Member] | Derivative Liability (Long-term) [Member]
Derivative fair values [Abstract]
Liability Derivatives, fair value, gross basis	$ 62	$ 171
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	3,286	1,854
Derivative fair values [Abstract]
Asset Derivatives, fair value, gross basis	$ 370	$ 642
Financial Transmission Rights [Member] | Other Current Assets [Member]
Derivative fair values [Abstract]
Asset Derivatives, fair value, gross basis	370	642
Financial Transmission Rights [Member] | Derivative Liability (Current) [Member]
Derivative fair values [Abstract]
Liability Derivatives, fair value, gross basis	0	0
PPA [Member]
Derivative fair values [Abstract]
Derivative fair value, net	(57,000)	(53,400)
Liability Derivatives, fair value, gross basis	56,950	53,430
PPA [Member] | Derivative Liability (Current) [Member]
Derivative fair values [Abstract]
Liability Derivatives, fair value, gross basis	8,880	6,870
PPA [Member] | Derivative Liability (Long-term) [Member]
Derivative fair values [Abstract]
Liability Derivatives, fair value, gross basis	$ 48,070	$ 46,560

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Pension and Other Postretirement Plans (Tables)

9 Months Ended

Sep. 30, 2015

Compensation and Retirement Disclosure [Abstract]

Schedule of Net Periodic Benefit Costs

The following table presents the components of MGE Energy's and MGE's net periodic benefit costs recognized for the three and nine months endedSeptember 30,2015 and 2014. 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)		2015		2014		2015		2014
Pension Benefits
Components of net periodic (benefit) cost:
Service cost	$	1,878	$	1,536	$	5,715	$	4,609
Interest cost		3,594		3,367		10,936		10,102
Expected return on assets		(5,930)		(5,467)		(18,045)		(16,402)
Amortization of:
Prior service cost		6		51		18		152
Actuarial loss		1,393		180		4,240		539
Net periodic (benefit) cost	$	941	$	(333)	$	2,864	$	(1,000)
Postretirement Benefits
Components of net periodic (benefit) cost:
Service cost	$	194	$	241	$	580	$	722
Interest cost		392		564		1,176		1,691
Expected return on assets		(355)		(478)		(1,063)		(1,432)
Amortization of:
Transition obligation		-		1		1		2
Prior service benefit		(337)		(487)		(1,009)		(1,462)
Actuarial loss		133		28		397		86
Net periodic (benefit) cost	$	27	$	(131)	$	82	$	(393)

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Commitments and Contingencies (Tables)

9 Months Ended

Sep. 30, 2015

Commitments and Contingencies Disclosure [Abstract]

Purchase Contracts, Fiscal Year Maturity Schedule

As of September 30,2015, the future commitments related to these purchase contracts were as follows:

(In thousands)		2015		2016		2017		2018		2019
Coal(a)	$	6,211	$	21,639	$	10,664	$	6,560	$	3,850
Natural gas
Transportation & storage(b)		5,229		18,117		17,983		17,901		16,971
Supply(c)		10,704		11,127		-		-		-
	$	22,144	$	50,883	$	28,647	$	24,461	$	20,821

(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. If any minimum purchase obligations must be paid under these contracts, management believes these obligations would be considered costs of service and recoverable in rates.

(b)MGE'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. Management expects to recover these costs in future customer rates.

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Madison Gas and Electric Company Consolidated Statements of Cash Flows (Unaudited) - USD ($) $ in Thousands	9 Months Ended
	Sep. 30, 2015	Sep. 30, 2014
Items not affecting cash:
Depreciation and amortization	$ 33,026	$ 30,191
Deferred income taxes	7,370	24,376
Provision for doubtful receivables	(78)	1,001
Employee benefit plan expenses	2,500	(814)
Equity earnings in ATC	(6,568)	(7,306)
Other items	(154)	(843)
Changes in working capital items:
Decrease in current assets	39,034	13,318
Decrease in current liabilities	(18,231)	(7,515)
Dividend income from ATC	4,732	5,762
Cash contributions to pension and other postretirement plans	(12,460)	(2,449)
Other noncurrent items, net	13,373	118
Cash Provided by Operating Activities	122,655	120,972
Investing Activities:
Capital expenditures	(52,311)	(66,138)
Capital contributions to investments	(785)	(1,830)
Other	(85)	(1,265)
Cash Used for Investing Activities	(53,181)	(69,233)
Financing Activities:
Repayment of long-term debt	(3,128)	(3,069)
Repayment of short-term debt	(7,000)	0
Other	(1,018)	(130)
Cash Used for Financing Activities	(40,962)	(31,833)
Change in cash and cash equivalents	28,512	19,906
Cash and cash equivalents at beginning of period	65,755	68,813
Cash and Cash Equivalents at End of Period	94,267	88,719
MGE [Member]
Operating Activities:
Net Income	60,240	65,255
Items not affecting cash:
Depreciation and amortization	32,991	30,156
Deferred income taxes	4,510	23,811
Provision for doubtful receivables	(78)	1,001
Employee benefit plan expenses	2,500	(814)
Equity earnings in ATC	(6,568)	(7,306)
Other items	234	(446)
Changes in working capital items:
Decrease in current assets	46,806	13,258
Decrease in current liabilities	(15,876)	(5,457)
Dividend income from ATC	4,732	5,762
Cash contributions to pension and other postretirement plans	(12,460)	(2,449)
Other noncurrent items, net	13,076	(24)
Cash Provided by Operating Activities	130,107	122,747
Investing Activities:
Capital expenditures	(52,311)	(66,138)
Capital contributions to investments	(533)	(1,420)
Other	(90)	(1,087)
Cash Used for Investing Activities	(52,934)	(68,645)
Financing Activities:
Cash dividends paid to parent by MGE	(20,000)	(26,500)
Distributions to parent from noncontrolling interest	(12,007)	(17,778)
Equity contribution received by noncontrolling interest	3,053	1,420
Repayment of long-term debt	(3,128)	(3,069)
Repayment of short-term debt	(7,000)	0
Other	(682)	0
Cash Used for Financing Activities	(39,764)	(45,927)
Change in cash and cash equivalents	37,409	8,175
Cash and cash equivalents at beginning of period	4,562	14,808
Cash and Cash Equivalents at End of Period	$ 41,971	$ 22,983

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Derivative and Hedging Instruments (Tables)

9 Months Ended

Sep. 30, 2015

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, 2015	December 31, 2014
Commodity derivative contracts	343,560 MWh	448,000 MWh
Commodity derivative contracts	6,547,500 Dth	4,405,000 Dth
FTRs	3,286 MW	1,854 MW

Fair Value of Derivative Instruments on the Balance Sheet

The following table summarizes the fair value of the derivative instruments on the consolidated balance sheets. All derivative instruments in this table are presented on a gross basis and are calculated prior to the netting of instruments with the same counterparty under a master netting agreement as well as the netting of collateral. For financial statement purposes, MGE Energy and MGE have netted instruments with the same counterparty under a master netting agreement as well as the netting of collateral. At September 30,2015, MGE Energy and MGE had the right to reclaim collateral (a receivable) of $0.8 million.

	Asset Derivatives			Liability Derivatives
(In thousands)	Balance Sheet Location		Fair Value	Balance Sheet Location		Fair Value
September 30, 2015
Commodity derivative contracts	Other current assets	$	375	Derivative liability (current)	$	1,196
Commodity derivative contracts	Other deferred charges		65	Derivative liability (long-term)		62
FTRs	Other current assets		370	Derivative liability (current)		-
PPA	N/A		N/A	Derivative liability (current)		8,880
PPA	N/A		N/A	Derivative liability (long-term)		48,070
December 31, 2014
Commodity derivative contracts	Other current assets	$	130	Derivative liability (current)	$	2,262
Commodity derivative contracts	Other deferred charges		93	Derivative liability (long-term)		171
FTRs	Other current assets		642	Derivative liability (current)		-
PPA	N/A		N/A	Derivative liability (current)		6,870
PPA	N/A		N/A	Derivative liability (long-term)		46,560

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 sheet		Collateral posted against derivative positions		Net amount presented in balance sheet
September 30, 2015
Commodity derivative contracts	$	440	$	(431)	$	-	$	9
FTRs		370		-		-		370
December 31, 2014
Commodity derivative contracts	$	223	$	(223)	$	-	$	-
FTRs		642		-		-		642

Offsetting Liabilities

Offsetting of Derivative Liabilities
(In thousands)		Gross amounts		Gross amounts offset in balance sheet		Collateral posted against derivative positions		Net amount presented in balance sheet
September 30, 2015
Commodity derivative contracts	$	1,258	$	(431)	$	(827)	$	-
PPA		56,950		-		-		56,950
December 31, 2014
Commodity derivative contracts	$	2,433	$	(223)	$	(2,179)	$	31
PPA		53,430		-		-		53,430

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 30,2015 and 2014, and the consolidated income statements for the three and nine months endedSeptember 30,2015 and 2014.

		2015				2014
(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,	$	56,048	$	455	$	48,853	$	676
Unrealized loss (gain)		4,036		-		5,329		-
Realized (loss) gain reclassified to a deferred
account		(408)		408		(314)		314
Realized (loss) gain reclassified to income
statement		(2,278)		(91)		(1,184)		(249)
Balance at September 30,	$	57,398	$	772	$	52,684	$	741
Nine Months Ended September 30:
Balance at January 1,	$	54,998	$	1,001	$	63,893	$	411
Unrealized loss (gain)		8,514		-		(18,090)		-
Realized (loss) gain reclassified to a deferred
account		(1,700)		1,700		1,120		(1,120)
Realized (loss) gain reclassified to income
statement		(4,414)		(1,929)		5,761		1,450
Balance at September 30,	$	57,398	$	772	$	52,684	$	741

Derivative Gains and Losses in Income Statement

		Realized losses (gains)
		2015				2014
(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	$	862	$	(17)	$	480	$	(18)
FTRs		(233)		-		(97)		-
PPA		1,757		-		1,068		-
Nine Months Ended September 30:
Commodity derivative contracts	$	1,860	$	1,742	$	(5,376)	$	(1,367)
FTRs		(607)		-		(929)		-
PPA		3,348		-		461		-

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Pension and Other Postretirement Plans (Details) - USD ($) $ in Thousands	3 Months Ended		9 Months Ended
	Sep. 30, 2015	Sep. 30, 2014	Sep. 30, 2015	Sep. 30, 2014
Pension Benefits [Member]
Components of net periodic cost (benefit):
Service cost	$ 1,878	$ 1,536	$ 5,715	$ 4,609
Interest cost	3,594	3,367	10,936	10,102
Expected return on assets	(5,930)	(5,467)	(18,045)	(16,402)
Amortization of:
Prior service (benefit) cost	6	51	18	152
Actuarial loss	1,393	180	4,240	539
Net periodic cost (benefit)	941	(333)	2,864	(1,000)
Postretirement Benefits [Member]
Components of net periodic cost (benefit):
Service cost	194	241	580	722
Interest cost	392	564	1,176	1,691
Expected return on assets	(355)	(478)	(1,063)	(1,432)
Amortization of:
Transition obligation	0	1	1	2
Prior service (benefit) cost	(337)	(487)	(1,009)	(1,462)
Actuarial loss	133	28	397	86
Net periodic cost (benefit)	$ 27	$ (131)	$ 82	$ (393)

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Fair Value of Financial Instruments (Details-4) - USD ($) $ in Thousands		3 Months Ended		9 Months Ended
		Sep. 30, 2015	Sep. 30, 2014	Sep. 30, 2015	Sep. 30, 2014
Fair Value, Liabilities Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Beginning balance,		$ (56,194)	$ (49,349)	$ (53,986)	$ (64,628)
Realized and unrealized gains (losses):
Included in regulatory liabilities (assets)		(888)	(3,752)	(3,096)	11,528
Included in other comprehensive income		0	0	0	0
Included in earnings	[1]	(2,285)	(1,419)	(4,497)	5,837
Included in current assets		0	0	0	(89)
Purchases		6,364	6,371	17,497	19,900
Sales		0	0	34	(60)
Issuances		0	0	0	0
Settlements		(4,079)	(4,952)	(13,034)	(25,589)
Transfers in and/or out of level 3		0	0	0	0
Ending balance,		(57,082)	(53,101)	(57,082)	(53,101)
Total gains (losses) included in earnings attributed to the change in unrealized gains (losses) related to assets and liabilities	[1]	0	0	0	0
Purchased Power Expense [Member]
Realized and unrealized gains (losses):
Included in earnings	[1]	(2,302)	(1,411)	(4,515)	5,845
Cost Of Gas Sold Expense [Member]
Realized and unrealized gains (losses):
Included in earnings	[1]	$ 17	$ (8)	$ 18	$ (8)

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

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MGE Energy Inc Consolidated Statements of Income (Unaudited) - USD ($) shares in Thousands, $ in Thousands	3 Months Ended		9 Months Ended
	Sep. 30, 2015	Sep. 30, 2014	Sep. 30, 2015	Sep. 30, 2014
Operating Revenues:
Regulated electric revenues	$ 121,453	$ 112,869	$ 319,174	$ 308,418
Regulated gas revenues	17,431	21,404	108,028	163,335
Nonregulated revenues	1,911	862	5,853	2,392
Total Operating Revenues	140,795	135,135	433,055	474,145
Operating Expenses:
Fuel for electric generation	17,055	9,838	41,624	35,836
Purchased power	18,484	21,303	62,614	58,779
Cost of gas sold	4,299	11,039	57,868	107,679
Other operations and maintenance	38,721	37,587	120,895	118,267
Depreciation and amortization	11,182	10,376	33,026	30,191
Other general taxes	4,877	4,872	14,951	14,861
Total Operating Expenses	94,618	95,015	330,978	365,613
Operating Income	46,177	40,120	102,077	108,532
Other income, net	2,564	2,636	7,115	10,736
Interest expense, net	(5,036)	(5,141)	(15,135)	(14,550)
Income before income taxes	43,705	37,615	94,057	104,718
Income tax provision	(15,351)	(14,286)	(33,946)	(39,585)
Net Income (Loss)	$ 28,354	$ 23,329	$ 60,111	$ 65,133
Earnings Per Share of Common Stock (basic and diluted)	$ 0.82	$ 0.67	$ 1.73	$ 1.88
Dividends per share of common stock	$ 0.295	$ 0.283	$ 0.860	$ 0.826
Weighted Average Shares Outstanding (basic and diluted)	34,668	34,668	34,668	34,668

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Derivative and Hedging Instruments (Details-2) - USD ($) $ in Thousands	Sep. 30, 2015	Dec. 31, 2014
Commodity Derivative Contracts [Member]
Offsetting Assets [Line Items]
Gross amounts	$ 440	$ 223
Gross amounts offset in balance sheet	(431)	(223)
Collateral posted against derivative positions	0	0
Net amount presented in balance sheet	9	0
Financial Transmission Rights [Member]
Offsetting Assets [Line Items]
Gross amounts	370	642
Gross amounts offset in balance sheet	0	0
Collateral posted against derivative positions	0	0
Net amount presented in balance sheet	$ 370	$ 642

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Consolidated Statements of Comprehensive Income (Unaudited) (Parantheticals) - USD ($) $ in Thousands	3 Months Ended		9 Months Ended
	Sep. 30, 2015	Sep. 30, 2014	Sep. 30, 2015	Sep. 30, 2014
Unrealized gain (loss) on available-for-sale securities, tax (benefit) expense	$ (56)	$ 63	$ (120)	$ 38
MGE [Member]
Unrealized gain (loss) on available-for-sale securities, tax (benefit) expense	$ (19)	$ 29	$ (92)	$ (36)

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Equity and Financing Arrangements (Details) - USD ($)	9 Months Ended
	Sep. 30, 2015	Sep. 30, 2014
Common Stock [Abstract]
Common stock issued during period	0	0
Dilutive Shares Calculation [Abstract]
Dilutive securities	$ 0
MGE [Member]
Credit Facilities [Line Items]
Commercial paper outstanding	0
MGE [Member] | MGE $60 million unsecured committed revolving line of credit
Credit Facilities [Line Items]
Available lines of credit	60,000,000
Line of credit, borrowings outstanding	$ 0
Line Of Credit Facility Fixed Base Rate For Federal Funds	0.50%
Line Of Credit Facility Fixed Base Rate For Eurodollar Rate	1.00%
MGE [Member] | MGE $60 million unsecured committed revolving line of credit | Minimum [Member]
Credit Facilities [Line Items]
Line Of Credit Facility Floating Rate Based Adder	0.00%
Line Of Credit Facility Eurodollar Based Adder	0.625%
MGE [Member] | MGE $60 million unsecured committed revolving line of credit | Maximum [Member]
Credit Facilities [Line Items]
Line Of Credit Facility Floating Rate Based Adder	0.125%
Line Of Credit Facility Eurodollar Based Adder	1.125%
MGE [Member] | MGE $40 million unsecured committed revolving line of credit
Credit Facilities [Line Items]
Available lines of credit	$ 40,000,000
Line of credit, borrowings outstanding	$ 0
Line Of Credit Facility Fixed Base Rate For Federal Funds	0.50%
Line Of Credit Facility Fixed Base Rate For Eurodollar Rate	1.00%
MGE [Member] | MGE $40 million unsecured committed revolving line of credit | Minimum [Member]
Credit Facilities [Line Items]
Line Of Credit Facility Floating Rate Based Adder	0.00%
Line Of Credit Facility Eurodollar Based Adder	0.625%
MGE [Member] | MGE $40 million unsecured committed revolving line of credit | Maximum [Member]
Credit Facilities [Line Items]
Line Of Credit Facility Floating Rate Based Adder	0.125%
Line Of Credit Facility Eurodollar Based Adder	1.125%
MGE Energy [Member] | MGE Energy $50 million unsecured commiteed revolving line of credit
Credit Facilities [Line Items]
Available lines of credit	$ 50,000,000
Line of credit, borrowings outstanding	$ 0
Line Of Credit Facility Fixed Base Rate For Federal Funds	0.50%
Line Of Credit Facility Fixed Base Rate For Eurodollar Rate	1.00%
MGE Energy [Member] | MGE Energy $50 million unsecured commiteed revolving line of credit | Minimum [Member]
Credit Facilities [Line Items]
Line Of Credit Facility Floating Rate Based Adder	0.00%
Line Of Credit Facility Eurodollar Based Adder	0.625%
MGE Energy [Member] | MGE Energy $50 million unsecured commiteed revolving line of credit | Maximum [Member]
Credit Facilities [Line Items]
Line Of Credit Facility Floating Rate Based Adder	0.125%
Line Of Credit Facility Eurodollar Based Adder	1.125%

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Derivative and Hedging Instruments

9 Months Ended

Sep. 30, 2015

Derivative Instruments and Hedging Activities Disclosure [Abstract]

Derivative and Hedging Instruments

Derivative and Hedging Instruments - MGE Energy and MGE.

a. Purpose.

As part of its regular operations, MGE enters into contracts, including options, swaps, futures, forwards, and other contractual commitments, to manage its exposure to commodity prices. To the extent that these contracts are derivatives, MGE assesses whether or not the normal purchases or normal sales exclusion applies. For contracts to which this exclusion cannot be applied, MGE Energy and MGE recognize such derivatives in the consolidated balance sheets at fair value. MGE's commodity derivative activities are conducted in accordance with its electric and gas risk management program, which is approved by the PSCW and limits the volume MGE can hedge with specific risk management strategies. The maximum length of time over which cash flows related to energy commodities can be hedged is four years. If the derivative qualifies for regulatory deferral, the derivatives are marked to fair value and are offset with a corresponding regulatory asset or liability. The deferred gain or loss is recognized in earnings in the delivery month applicable to the instrument. Gains and losses related to hedges qualifying for regulatory treatment are recoverable in gas rates through the PGA or in electric rates as a component of the fuel rules mechanism.

b. Notional Amounts.

The gross notional volume of open derivatives is as follows:

	September 30, 2015	December 31, 2014
Commodity derivative contracts	343,560 MWh	448,000 MWh
Commodity derivative contracts	6,547,500 Dth	4,405,000 Dth
FTRs	3,286 MW	1,854 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 30,2015, and December 31,2014, the cost basis of exchange traded derivatives and FTRs exceeded their fair value by $0.4 million and $1.6 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 30,2015, and December 31, 2014, reflects a loss position of $57.0 million and $53.4 million, respectively. The actual cost will be recognized in purchased power expense in the month of purchase.

The following table summarizes the fair value of the derivative instruments on the consolidated balance sheets. All derivative instruments in this table are presented on a gross basis and are calculated prior to the netting of instruments with the same counterparty under a master netting agreement as well as the netting of collateral. For financial statement purposes, MGE Energy and MGE have netted instruments with the same counterparty under a master netting agreement as well as the netting of collateral. At September 30,2015, MGE Energy and MGE had the right to reclaim collateral (a receivable) of $0.8 million.

	Asset Derivatives			Liability Derivatives
(In thousands)	Balance Sheet Location		Fair Value	Balance Sheet Location		Fair Value
September 30, 2015
Commodity derivative contracts	Other current assets	$	375	Derivative liability (current)	$	1,196
Commodity derivative contracts	Other deferred charges		65	Derivative liability (long-term)		62
FTRs	Other current assets		370	Derivative liability (current)		-
PPA	N/A		N/A	Derivative liability (current)		8,880
PPA	N/A		N/A	Derivative liability (long-term)		48,070
December 31, 2014
Commodity derivative contracts	Other current assets	$	130	Derivative liability (current)	$	2,262
Commodity derivative contracts	Other deferred charges		93	Derivative liability (long-term)		171
FTRs	Other current assets		642	Derivative liability (current)		-
PPA	N/A		N/A	Derivative liability (current)		6,870
PPA	N/A		N/A	Derivative liability (long-term)		46,560

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 sheet		Collateral posted against derivative positions		Net amount presented in balance sheet
September 30, 2015
Commodity derivative contracts	$	440	$	(431)	$	-	$	9
FTRs		370		-		-		370
December 31, 2014
Commodity derivative contracts	$	223	$	(223)	$	-	$	-
FTRs		642		-		-		642

Offsetting of Derivative Liabilities
(In thousands)		Gross amounts		Gross amounts offset in balance sheet		Collateral posted against derivative positions		Net amount presented in balance sheet
September 30, 2015
Commodity derivative contracts	$	1,258	$	(431)	$	(827)	$	-
PPA		56,950		-		-		56,950
December 31, 2014
Commodity derivative contracts	$	2,433	$	(223)	$	(2,179)	$	31
PPA		53,430		-		-		53,430

The following tables summarize the unrealized and realized gains (losses) related to the derivative instruments on the consolidated balance sheets at September 30,2015 and 2014, and the consolidated income statements for the three and nine months endedSeptember 30,2015 and 2014.

		2015				2014
(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,	$	56,048	$	455	$	48,853	$	676
Unrealized loss (gain)		4,036		-		5,329		-
Realized (loss) gain reclassified to a deferred
account		(408)		408		(314)		314
Realized (loss) gain reclassified to income
statement		(2,278)		(91)		(1,184)		(249)
Balance at September 30,	$	57,398	$	772	$	52,684	$	741
Nine Months Ended September 30:
Balance at January 1,	$	54,998	$	1,001	$	63,893	$	411
Unrealized loss (gain)		8,514		-		(18,090)		-
Realized (loss) gain reclassified to a deferred
account		(1,700)		1,700		1,120		(1,120)
Realized (loss) gain reclassified to income
statement		(4,414)		(1,929)		5,761		1,450
Balance at September 30,	$	57,398	$	772	$	52,684	$	741

		Realized losses (gains)
		2015				2014
(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	$	862	$	(17)	$	480	$	(18)
FTRs		(233)		-		(97)		-
PPA		1,757		-		1,068		-
Nine Months Ended September 30:
Commodity derivative contracts	$	1,860	$	1,742	$	(5,376)	$	(1,367)
FTRs		(607)		-		(929)		-
PPA		3,348		-		461		-

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 30,2015, 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 30,2015 and December 31, 2014, certain counterparties were in a net liability of less than $0.1 million.

Nonperformance of counterparties to the non-exchange traded derivatives could expose MGE to credit loss. However, MGE enters into transactions only with companies that meet or exceed strict credit guidelines, and it monitors these counterparties on an ongoing basis to mitigate nonperformance risk in its portfolio. As of September 30,2015,no counterparties have defaulted.

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Investment in ATC (Details-1) - USD ($) $ in Thousands		9 Months Ended
	Oct. 30, 2015	Sep. 30, 2015	Sep. 30, 2014	Dec. 31, 2014
Schedule Of Equity Method Investments [Line Items]
Equity earnings from investment		$ 6,568	$ 7,306
Dividend income from investment		4,732	5,762
Capital contributions to investment		785	1,830
MGE Transco [Member] | ATC [Member]
Schedule Of Equity Method Investments [Line Items]
Equity earnings from investment		6,568	7,306
Dividend income from investment		4,732	5,762
Capital contributions to investment		533	$ 1,420
Equity method investment		$ 70,000		$ 67,700
MGE Transco [Member] | ATC [Member] | Subsequent Event [Member]
Schedule Of Equity Method Investments [Line Items]
Capital contributions to investment	$ 200

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Fair Value of Financial Instruments

9 Months Ended

Sep. 30, 2015

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 30,2015, and December 31, 2014, the carrying amount of cash, cash equivalents, and outstanding commercial paper approximates fair market value due to the short maturity of those investments and obligations. The estimated fair market value of MGE Energy's and MGE's long-term debt is based on quoted market prices for similar financial instruments at September 30,2015, and December 31, 2014. Since long-term debt is not traded in an active market, it is classified as Level 2.The estimated fair market value of MGE Energy's and MGE's financial instruments are as follows:

		September 30, 2015				December 31, 2014
(In thousands)		Carrying Amount		Fair Value		Carrying Amount		Fair Value
MGE Energy
Assets:
Cash and cash equivalents	$	94,267	$	94,267	$	65,755	$	65,755
Liabilities:
Short-term debt - commercial paper		-		-		7,000		7,000
Long-term debt*		396,562		446,176		399,690		457,420
MGE
Assets:
Cash and cash equivalents	$	41,971	$	41,971	$	4,562	$	4,562
Liabilities:
Short-term debt - commercial paper		-		-		7,000		7,000
Long-term debt*		396,562		446,176		399,690		457,420
*Includes long-term debt due within one year.

b. Recurring Fair Value Measurements.

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

		Fair Value as of September 30, 2015
(In thousands)		Total		Level 1		Level 2		Level 3
MGE Energy
Assets:
Derivatives, net	$	379	$	-	$	-	$	379
Exchange-traded investments		627		627		-		-
Total Assets	$	1,006	$	627	$	-	$	379
Liabilities:
Derivatives, net(a)	$	57,777	$	316	$	-	$	57,461
Deferred compensation		3,160		-		3,160		-
Total Liabilities	$	60,937	$	316	$	3,160	$	57,461
MGE
Assets:
Derivatives, net	$	379	$	-	$	-	$	379
Exchange-traded investments		122		122		-		-
Total Assets	$	501	$	122	$	-	$	379
Liabilities:
Derivatives, net(a)	$	57,777	$	316	$	-	$	57,461
Deferred compensation		3,160		-		3,160		-
Total Liabilities	$	60,937	$	316	$	3,160	$	57,461

		Fair Value as of December 31, 2014
(In thousands)		Total		Level 1		Level 2		Level 3
MGE Energy
Assets:
Derivatives, net	$	642	$	-	$	-	$	642
Exchange-traded investments		927		927		-		-
Total Assets	$	1,569	$	927	$	-	$	642
Liabilities:
Derivatives, net(a)	$	55,640	$	1,012	$	-	$	54,628
Deferred compensation		2,832		-		2,832		-
Total Liabilities	$	58,472	$	1,012	$	2,832	$	54,628
MGE
Assets:
Derivatives, net	$	642	$	-	$	-	$	642
Exchange-traded investments		350		350		-		-
Total Assets	$	992	$	350	$	-	$	642
Liabilities:
Derivatives, net(a)	$	55,640	$	1,012	$	-	$	54,628
Deferred compensation		2,832		-		2,832		-
Total Liabilities	$	58,472	$	1,012	$	2,832	$	54,628
(a) These amounts are shown gross and exclude $0.8 million and $2.2 million of collateral that was
posted against derivative positions with counterparties as of September 30, 2015, and
December 31, 2014, respectively.

No transfers were made in or out of Level 1 or Level 2 for the nine months endedSeptember 30,2015.

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

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

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

This model is prepared by members of MGE's Energy Accounting department. On a quarterly basis, management in the Energy Supply and Finance departments review the assumptions, inputs, and fair value measurements.

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

	Model Input
Significant Unobservable Inputs	September 30, 2015	December 31, 2014
Basis adjustment:
On peak	97.4%	98.1%
Off peak	95.4%	95.0%
Counterparty fuel mix:
Internal generation	60% - 75%	50% - 70%
Purchased power	40% - 25%	50% - 30%

The deferred compensation plan allows participants to defer certain cash compensation into a notional investment account. These amounts are included within other deferred liabilities in the consolidated balance sheets of MGE Energy and MGE. The notional investments earn interest based upon the semiannual rate of U.S. Treasury Bills having a 26 week maturity increased by 1% compounded monthly with a minimum annual rate of 7%, compounded monthly. The notional investments are based upon observable market data, however, since the deferred compensation obligations themselves are not exchanged in an active market, they are classified as Level 2.

The following table summarizes the changes in Level 3 assets and liabilities measured at fair value on a recurring basis for both MGE Energy and MGE.

		Three Months Ended				Nine Months Ended
		September 30,				September 30,
(In thousands)		2015		2014		2015		2014
Beginning balance	$	(56,194)	$	(49,349)	$	(53,986)	$	(64,628)
Realized and unrealized gains (losses):
Included in regulatory liabilities (assets)		(888)		(3,752)		(3,096)		11,528
Included in other comprehensive income		-		-		-		-
Included in earnings		(2,285)		(1,419)		(4,497)		5,837
Included in current assets		-		-		-		(89)
Purchases		6,364		6,371		17,497		19,900
Sales		-		-		34		(60)
Issuances		-		-		-		-
Settlements		(4,079)		(4,952)		(13,034)		(25,589)
Transfers in and/or out of Level 3		-		-		-		-
Balance as of September 30,	$	(57,082)	$	(53,101)	$	(57,082)	$	(53,101)
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 gains (losses) included in income for Level 3 assets and liabilities measured at fair value on a recurring basis for both MGE Energy and MGE(b).

		Three Months Ended				Nine Months Ended
		September 30,				September 30,
(In thousands)		2015		2014		2015		2014
Purchased Power Expense	$	(2,302)	$	(1,411)	$	(4,515)	$	5,845
Cost of Gas Sold Expense		17		(8)		18		(8)
Total	$	(2,285)	$	(1,419)	$	(4,497)	$	5,837

(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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MGE Energy Inc Consolidated Statements of Cash Flows (Unaudited) - USD ($) $ in Thousands	9 Months Ended
	Sep. 30, 2015	Sep. 30, 2014
Operating Activities:
Net Income	$ 60,111	$ 65,133
Items not affecting cash:
Depreciation and amortization	33,026	30,191
Deferred income taxes	7,370	24,376
Provision for doubtful receivables	(78)	1,001
Employee benefit plan expenses	2,500	(814)
Equity earnings in ATC	(6,568)	(7,306)
Other items	(154)	(843)
Changes in working capital items:
Decrease in current assets	39,034	13,318
Decrease in current liabilities	(18,231)	(7,515)
Dividend income from ATC	4,732	5,762
Cash contributions to pension and other postretirement plans	(12,460)	(2,449)
Other noncurrent items, net	13,373	118
Cash Provided by Operating Activities	122,655	120,972
Investing Activities:
Capital expenditures	(52,311)	(66,138)
Capital contributions to investments	(785)	(1,830)
Other	(85)	(1,265)
Cash Used for Investing Activities	(53,181)	(69,233)
Financing Activities:
Cash dividends paid on common stock	(29,816)	(28,634)
Repayment of long-term debt	(3,128)	(3,069)
Repayment of short-term debt	(7,000)	0
Other	(1,018)	(130)
Cash Used for Financing Activities	(40,962)	(31,833)
Change in cash and cash equivalents	28,512	19,906
Cash and cash equivalents at beginning of period	65,755	68,813
Cash and Cash Equivalents at End of Period	$ 94,267	$ 88,719

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Madison Gas and Electric Company Consolidated Statements of Income (Unaudited) - USD ($) $ in Thousands		3 Months Ended		9 Months Ended
		Sep. 30, 2015	Sep. 30, 2014	Sep. 30, 2015	Sep. 30, 2014
Operating Revenues:
Regulated electric revenues		$ 121,453	$ 112,869	$ 319,174	$ 308,418
Regulated gas revenues		17,431	21,404	108,028	163,335
Nonregulated revenues		1,911	862	5,853	2,392
Total Operating Revenues		140,795	135,135	433,055	474,145
Operating Expenses:
Fuel for electric generation		17,055	9,838	41,624	35,836
Purchased power		18,484	21,303	62,614	58,779
Cost of gas sold		4,299	11,039	57,868	107,679
Other operations and maintenance		38,721	37,587	120,895	118,267
Depreciation and amortization		11,182	10,376	33,026	30,191
Other general taxes		4,877	4,872	14,951	14,861
Income tax provision		15,351	14,286	33,946	39,585
Total Operating Expenses		94,618	95,015	330,978	365,613
Operating Income		46,177	40,120	102,077	108,532
Other Income and Deductions:
Equity in earnings in ATC				6,568	7,306
Total Other Income and Deductions		2,564	2,636	7,115	10,736
Interest Expense:
Net Interest Expense		5,036	5,141	15,135	14,550
Net Income (Loss)		28,354	23,329	60,111	65,133
MGE [Member]
Operating Revenues:
Regulated electric revenues		121,460	112,875	319,191	308,435
Regulated gas revenues		17,435	21,410	108,039	163,351
Nonregulated revenues		1,911	862	5,853	2,392
Total Operating Revenues		140,806	135,147	433,083	474,178
Operating Expenses:
Fuel for electric generation		17,057	9,841	41,630	35,843
Purchased power		18,488	21,307	62,624	58,790
Cost of gas sold		4,302	11,045	57,879	107,695
Other operations and maintenance		38,561	37,309	120,269	117,593
Depreciation and amortization		11,170	10,364	32,991	30,156
Other general taxes		4,877	4,872	14,951	14,861
Income tax provision		14,401	13,338	31,218	36,180
Total Operating Expenses		108,856	108,076	361,562	401,118
Operating Income	[1]	31,950	27,071	71,521	73,060
Other Income and Deductions:
AFUDC - equity funds		206	255	501	3,306
Equity in earnings in ATC		2,398	2,423	6,568	7,306
Income tax provision		(977)	(984)	(2,763)	(3,390)
Other expense, net		(73)	(111)	(288)	(351)
Total Other Income and Deductions	[1]	1,554	1,583	4,018	6,871
Income before interest expense		33,504	28,654	75,539	79,931
Interest Expense:
Interest on long-term debt		5,123	5,225	15,410	15,714
Other interest, net		37	44	52	52
AFUDC - borrowed funds		(67)	(84)	(163)	(1,090)
Net Interest Expense		5,093	5,185	15,299	14,676
Net Income Including Noncontrolling Interest		28,411	23,469	60,240	65,255
Less Net Income Attributable to Noncontrolling Interest, net of tax		(6,633)	(6,653)	(19,812)	(19,784)
Net Income (Loss)		$ 21,778	$ 16,816	$ 40,428	$ 45,471

[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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Chattel Paper Agreements

9 Months Ended

Sep. 30, 2015

Transfers and Servicing [Abstract]

Chattel Paper Agreements

Chattel Paper Agreements - MGE Energy and MGE.

MGE makes available to qualifying customers a financing program for the purchase and installation of energy-related equipment that will provide more efficient use of utility service at the customer's property. The energy-related equipment installed at the customer sites is used to secure the customer loans. MGE is a party to a chattel paper purchase agreement with a financial institution under which it can sell or finance an undivided interest with recourse, in up to $10.0 million of the financing program receivables, until July 31, 2016.The length of the MGE guarantee to the financial institution varies from one to ten years depending on the term of the underlying customer loan. The loan balances outstanding at September 30,2015, approximate the fair value of the energy-related equipment acting as collateral. MGE accounts for these agreements as secured borrowings.

Prior to the Transfers and Servicing Asset authoritative accounting guidance that became effective in 2015, these agreements were treated as off-balance sheet arrangements. Beginning January 1, 2015, these agreements are included as assets and liabilities in the consolidated balance sheet. As of September 30,2015, assets (other accounts receivable and other deferred assets) and liabilities (accounts payable and other deferred liabilities) increased approximately $3.8 million as a cumulative result of the guidance. In addition, the cumulative effect of this guidance resulted in a $0.1 million reduction in retained earnings.

As of September 30,2015, the remaining contractual maturities of the chattel paper agreements were as follows:

(In thousands)		2015		2016		2017		2018		Thereafter		Total
Repurchase-to-Maturity Transactions:
Loans	$	132	$	735	$	472	$	504	$	1,963	$	3,806

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Document and Entity Information - shares	9 Months Ended
	Sep. 30, 2015	Oct. 31, 2015
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, 2015
Amendment Flag	false
Trading Symbol	MGEE
Document Fiscal Year Focus	2015
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

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Taxes

9 Months Ended

Sep. 30, 2015

Income Tax Disclosure [Abstract]

Taxes

Taxes - MGE Energy and MGE.

MGE Energy's effective income tax rates for the three and nine months endedSeptember 30,2015, were 35.1% and 36.1%, respectively, compared to 38.0% and 37.8% for the same periods in 2014. MGE's effective income tax rates for the three and nine months endedSeptember 30,2015, were 35.1% and 36.1%, respectively, compared to 37.9% and 37.8% for the same periods in 2014. The decrease in the effective tax rates is due in part to a higher domestic manufacturing deduction, offset by lower AFUDC equity earnings in 2015.

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MGE Energy Inc Consolidated Statements of Comprehensive Income (Unaudited) - USD ($) $ in Thousands	3 Months Ended		9 Months Ended
	Sep. 30, 2015	Sep. 30, 2014	Sep. 30, 2015	Sep. 30, 2014
Comprehensive Income [Abstract]
Net Income	$ 28,354	$ 23,329	$ 60,111	$ 65,133
Other comprehensive income (loss), net of tax:
Unrealized (loss) gain on available-for-sale securities, net of tax	(85)	95	(180)	56
Comprehensive Income	$ 28,269	$ 23,424	$ 59,931	$ 65,189

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Madison Gas and Electric Company Consolidated Statements of Common Equity (Unaudited) - USD ($) shares in Thousands, $ in Thousands	Total	MGE [Member]	Common Stock [Member]	Common Stock [Member] MGE [Member]	Additional Paid-In Capital [Member] MGE [Member]	Retained Earnings [Member]	Retained Earnings [Member] MGE [Member]	Accumulated Other Comprehensive (Loss)/Income [Member]	Accumulated Other Comprehensive (Loss)/Income [Member] MGE [Member]	Noncontrolling Interest [Member] MGE [Member]
Beginning balance, shares at Dec. 31, 2013			34,668	17,348
Beginning balance, value at Dec. 31, 2013		$ 576,454		$ 17,348	$ 192,417		$ 247,534		$ 192	$ 118,963
Increase (Decrease) In Stockholders' Equity [Roll Forward]
Net Income		65,255					45,471			19,784
Other comprehensive income (loss)	$ 56	(54)						$ 56	(54)
Cash dividends paid to parent by MGE		(26,500)					(26,500)
Equity contribution received by noncontrolling interest		1,420								1,420
Distributions to parent from noncontrolling interest		(17,778)								(17,778)
Ending balance, shares at Sep. 30, 2014			34,668	17,348
Ending balance, value at Sep. 30, 2014		598,797		$ 17,348	192,417		266,505		138	122,389
Beginning balance, shares at Dec. 31, 2014			34,668	17,348
Beginning balance, value at Dec. 31, 2014		612,260		$ 17,348	192,417		276,662		144	125,689
Cumulative effect of new accounting principle (See Footnote 4) at Dec. 31, 2014	(142)	(142)				$ (142)	(142)
Beginning balance, value - Adjusted at Dec. 31, 2014		612,118					276,520
Increase (Decrease) In Stockholders' Equity [Roll Forward]
Net Income		60,240					40,428			19,812
Other comprehensive income (loss)	$ (180)	(137)						$ (180)	(137)
Cash dividends paid to parent by MGE		(20,000)					(20,000)
Equity contribution received by noncontrolling interest		3,053								3,053
Distributions to parent from noncontrolling interest		(12,007)								(12,007)
Ending balance, shares at Sep. 30, 2015			34,668	17,348
Ending balance, value at Sep. 30, 2015		$ 643,267		$ 17,348	$ 192,417		$ 296,948		$ 7	$ 136,547

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MGE Energy Inc Consolidated Statements of Common Equity (Unaudited) - USD ($) shares in Thousands, $ in Thousands	Total	Common Stock [Member]	Additional Paid-In Capital [Member]	Retained Earnings [Member]	Accumulated Other Comprehensive Income [Member]
Beginning balance, shares at Dec. 31, 2013		34,668
Beginning balance, value at Dec. 31, 2013	$ 617,510	$ 34,668	$ 316,268	$ 266,197	$ 377
Increase (Decrease) In Stockholders' Equity [Roll Forward]
Net Income	65,133			65,133
Other comprehensive income (loss)	56				56
Common stock dividends declared	(28,634)			(28,634)
Cash in lieu of fractional shares related to stock split	(80)			(80)
Ending balance, shares at Sep. 30, 2014		34,668
Ending balance, value at Sep. 30, 2014	653,985	$ 34,668	316,268	302,616	433
Beginning balance, shares at Dec. 31, 2014		34,668
Beginning balance, value at Dec. 31, 2014	659,401	$ 34,668	316,268	308,007	458
Cumulative effect of new accounting principle (See Footnote 4) at Dec. 31, 2014	(142)			(142)
Beginning balance, value - Adjusted at Dec. 31, 2014	659,259			307,865
Increase (Decrease) In Stockholders' Equity [Roll Forward]
Net Income	60,111			60,111
Other comprehensive income (loss)	(180)				(180)
Common stock dividends declared	(29,816)			(29,816)
Ending balance, shares at Sep. 30, 2015		34,668
Ending balance, value at Sep. 30, 2015	$ 689,374	$ 34,668	$ 316,268	$ 338,160	$ 278

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Rate Matters

9 Months Ended

Sep. 30, 2015

Regulated Operations [Abstract]

Rate Matters

Rate Matters - MGE Energy and MGE.

a. Rate Proceedings.

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

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

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

On July 26, 2013, the PSCW authorized MGE to freeze electric and natural gas rates at 2013 levels for 2014. The order authorized 100% AFUDC on the Columbia scrubber construction project and deferral of increased costs related to ATC and MISO network upgrade fees. As part of the rate freeze plan authorized by the PSCW, effective January 1, 2014, approximately $6.3 million associated with a 2012 fuel rule surplus credit was required to be refunded to customers and was amortized in 2014. The fuel credit accrued interest at MGE's weighted cost of capital. The authorized return on common stock equity was unchanged at 10.3%.

b. Fuel Rules.

Fuel rules require the PSCW and Wisconsin utilities to defer electric fuel-related costs that fall outside a symmetrical cost tolerance band around the amount approved for a utility in its annual fuel proceedings. Any over/under recovery of the actual costs is determined on an annual basis and is adjusted in future billings to electric retail customers. The fuel rules bandwidth is currently set at plus or minus 2%. Under fuel rules, MGE would defer costs, less any excess revenues, if its actual electric fuel costs exceeded 102% of the electric fuel costs allowed in its latest rate order. Excess revenues are defined as revenues in the year in question that provide MGE with a greater return on common equity than authorized by the PSCW in MGE's latest rate order. Conversely, MGE is required to defer the benefit of lower costs if actual electric fuel costs were less than 98% of the electric fuel costs allowed in that order.

In August 2015, the PSCW approved on an interim basis MGE's application to implement a fuel credit associated with its fuel savings for 2015. The fuel credit established a mechanism to returnthe fuel savings to electric customers via a bill credit during the period from September 2015 to December 31, 2015. The fuel credit was based on $5.9 million of actual fuel savings deferred through June 30, 2015. Approximately $2.7 million is expected to be returned to customers through December 31, 2015. The application further proposes a fuel credit to cover expected fuel savings for 2016 in the amount of approximately $5.0 million based on anticipated fuel costs. The actual fuel savings will depend upon the completion of the annual PSCW fuel cost audits for 2015 and 2016.

As of September 30,2015, MGE has deferred $7.6million of 2015 electric fuel-related savings that are outside the range authorized by the PSCW. In September 2015, MGE returned $0.7million of total electric fuel-related savings on customer bills. As part of the rate freeze plan authorized by the PSCW for 2014, $4.7 million of the approximately $6.3 million associated with the 2012 fuel rule credit was amortized against purchased power expense during the nine months endedSeptember 30,2014.

c.Purchased Gas Adjustment Clause.

MGE's natural gas rates are subject to a fuel adjustment clause designed to recover or refund the difference between the actual cost of purchased gas and the amount included in rates. Differences between the amounts billed to customers and the actual costs recoverable are deferred and recovered or refunded in future periods by means of prospective monthly adjustments to rates. At September 30,2015, and December 31,2014, MGE had over collected $1.1 million and $1.2 million, respectively, which was recorded in other current liabilities on the consolidated balance sheets.

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Pension and Other Postretirement Plans

9 Months Ended

Sep. 30, 2015

Compensation and Retirement Disclosure [Abstract]

Pension and Other Postretirement Plans

Pension and Other Postretirement Plans - MGE Energy and MGE.

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

The following table presents the components of MGE Energy's and MGE's net periodic benefit costs recognized for the three and nine months endedSeptember 30,2015 and 2014. 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)		2015		2014		2015		2014
Pension Benefits
Components of net periodic (benefit) cost:
Service cost	$	1,878	$	1,536	$	5,715	$	4,609
Interest cost		3,594		3,367		10,936		10,102
Expected return on assets		(5,930)		(5,467)		(18,045)		(16,402)
Amortization of:
Prior service cost		6		51		18		152
Actuarial loss		1,393		180		4,240		539
Net periodic (benefit) cost	$	941	$	(333)	$	2,864	$	(1,000)
Postretirement Benefits
Components of net periodic (benefit) cost:
Service cost	$	194	$	241	$	580	$	722
Interest cost		392		564		1,176		1,691
Expected return on assets		(355)		(478)		(1,063)		(1,432)
Amortization of:
Transition obligation		-		1		1		2
Prior service benefit		(337)		(487)		(1,009)		(1,462)
Actuarial loss		133		28		397		86
Net periodic (benefit) cost	$	27	$	(131)	$	82	$	(393)

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Equity and Financing Arrangements

9 Months Ended

Sep. 30, 2015

Equity and Financing Arrangements Disclosure [Abstract]

Equity and Financing Arrangements

Equity and Financing Arrangements.

a. Common Stock - MGE Energy.

MGE Energy sells shares of its common stock through its Stock Plan. Those shares may be newly issued shares or shares that MGE Energy has purchased in the open market for resale to participants in the Stock Plan. All sales under the Stock Plan are covered by a shelf registration statement that MGE Energy filed with the SEC. For both the nine months endedSeptember 30,2015 and 2014, MGE Energy did not issue any new shares of common stock under the Stock Plan.

b. Dilutive Shares Calculation - MGE Energy.

MGE Energy does not hold any dilutive securities.

c. Credit Facilities- MGE Energy and MGE.

On June 1, 2015, MGE Energy and MGE entered into new revolving credit agreements, and terminated their existing revolving credit agreements.

MGE Energy entered into a Credit Agreement with an aggregate commitment of $50 million (MGE Energy Credit Agreement) with various financial institutions, as lenders, and JPMorgan Chase Bank, N.A., as administrative agent. Also, MGE entered into two revolving credit agreements: a Credit Agreement with an aggregate commitment of $60 million (MGE JPM Credit Agreement) with various financial institutions, as lenders, and JPMorgan Chase Bank, N.A., as administrative agent, and a Credit Agreement with an aggregate commitment of $40 million (MGE USB Credit Agreement) with various financial institutions, as lenders, and U.S. Bank National Association, as administrative agent. The MGE Energy Credit Agreement, the MGE JPM Credit Agreement, and the MGE USB Credit Agreement are collectively referred to as the Credit Agreements. As of September 30,2015, neither MGE Energy nor MGE had any borrowings outstanding under the Credit Agreements, and MGE had no commercial paper outstanding.

The Credit Agreements have a term expiring on June 1, 2020. Borrowings under the Credit Agreements may bear interest at a rate based upon either a "floating rate" or a "Eurodollar Rate" adjusted for statutory reserve requirements, plus an adder based upon the credit ratings assigned to MGE's senior unsecured long-term debt securities.The "floating rate" is calculated on a daily basis as the highest of a prime rate, a Federal Funds effective rate plus 0.5% per annum, or a Eurodollar Rate for a one-month interest period plus 1%. The "floating rate"adder ranges from zero to 0.125%.The "Eurodollar Rate" is calculated as provided in the Credit Agreements. The "Eurodollar Rate"adder ranges from 0.625% to 1.125%.

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Consolidated Statements of Common Equity (Unaudited) (Parentheticals) - $ / shares	3 Months Ended		9 Months Ended
	Sep. 30, 2015	Sep. 30, 2014	Sep. 30, 2015	Sep. 30, 2014
Consolidated Statements of Common Equity
Dividends per share of common stock	$ 0.295	$ 0.283	$ 0.860	$ 0.826

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Basis of Presentation

9 Months Ended

Sep. 30, 2015

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 2014 Annual Report on Form 10-K.

The accompanying consolidated financial statements as of September 30,2015, 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 MGE Energy's and MGE's 2014 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 52 through 101 of the 2014 Annual Report on Form 10-K.

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Investment in ATC

9 Months Ended

Sep. 30, 2015

Equity Method Investments and Joint Ventures [Abstract]

Investment in ATC

Investment in ATC - MGE Energy and MGE.

ATC owns and operates electric transmission facilities primarily in Wisconsin. MGE received an interest in ATC when it, like other Wisconsin electric utilities, contributed its electric transmission facilities to ATC as required by Wisconsin law. That interest is presently held by MGE Transco, which is jointly owned by MGE Energy and MGE.

MGE Transco has accounted for its investment in ATC under the equity method of accounting.For the nine months endedSeptember 30,2015 and 2014, MGE Transco recorded the following:

		Nine Months Ended
		September 30,
(In thousands)		2015		2014
Equity in earnings from investment in ATC	$	6,568	$	7,306
Dividends received from ATC		4,732		5,762
Capital contributions to ATC		533		1,420

MGE Transco's investment in ATC as of September 30,2015, and December 31, 2014, was $70.0 million and $67.7 million, respectively. On October 30, 2015, MGE Transco made a $0.2million capital contribution to ATC.

At September 30,2015, MGE is the majority owner, and MGE Energy, the holding company, is the minority owner of MGE Transco. MGE Energy's proportionate share of the equity and net income of MGE Transco is classified within the MGE financial statements as noncontrolling interest.

ATC's summarized financial data for the three and nine months endedSeptember 30,2015 and 2014, is as follows:

		Three Months Ended				Nine Months Ended
		September 30,				September 30,
(In thousands)		2015		2014		2015		2014
Operating revenues	$	164,515	$	163,643	$	482,043	$	486,970
Operating expenses		(78,059)		(76,561)		(238,336)		(229,589)
Other income, net		585		693		566		1,403
Interest expense, net		(23,655)		(22,204)		(72,310)		(66,442)
Earnings before members' income taxes	$	63,386	$	65,571	$	171,963	$	192,342

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Segment Information (Tables)

9 Months Ended

Sep. 30, 2015

Segment Reporting [Abstract]

Segment Information

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

(In thousands)MGE Energy		Electric		Gas		Non- Regulated Energy		Transmission Investment		All Others		Consolidation/ Elimination Entries		Consolidated Total
Three Months Ended September 30, 2015
Operating revenues	$	121,453	$	17,431	$	1,911	$	-	$	-	$	-	$	140,795
Interdepartmental revenues		163		3,855		9,866		-		-		(13,884)		-
Total operating revenues		121,616		21,286		11,777		-		-		(13,884)		140,795
Depreciation and amortization		(7,584)		(1,714)		(1,872)		-		(12)		-		(11,182)
Other operating expenses		(80,202)		(16,906)		(36)		(15)		(161)		13,884		(83,436)
Operating income (loss)		33,830		2,666		9,869		(15)		(173)		-		46,177
Other (deductions) income, net		141		(7)		-		2,397		33		-		2,564
Interest (expense) income, net		(2,798)		(804)		(1,491)		-		57		-		(5,036)
Income (loss) before taxes		31,173		1,855		8,378		2,382		(83)		-		43,705
Income tax (provision) benefit		(10,321)		(732)		(3,362)		(962)		26		-		(15,351)
Net income (loss)	$	20,852	$	1,123	$	5,016	$	1,420	$	(57)	$	-	$	28,354
Three Months Ended September 30, 2014
Operating revenues	$	112,869	$	21,404	$	862	$	-	$	-	$	-	$	135,135
Interdepartmental revenues		156		1,614		10,674		-		-		(12,444)		-
Total operating revenues		113,025		23,018		11,536		-		-		(12,444)		135,135
Depreciation and amortization		(6,931)		(1,575)		(1,858)		-		(12)		-		(10,376)
Other operating expenses		(74,573)		(22,199)		(35)		-		(276)		12,444		(84,639)
Operating income (loss)		31,521		(756)		9,643		-		(288)		-		40,120
Other income, net		136		8		-		2,423		69		-		2,636
Interest (expense) income, net		(2,832)		(808)		(1,545)		-		44		-		(5,141)
Income (loss) before taxes		28,825		(1,556)		8,098		2,423		(175)		-		37,615
Income tax (provision) benefit		(10,758)		651		(3,251)		(963)		35		-		(14,286)
Net income (loss)	$	18,067	$	(905)	$	4,847	$	1,460	$	(140)	$	-	$	23,329
Nine Months Ended September 30, 2015
Operating revenues	$	319,174	$	108,028	$	5,853	$	-	$	-	$	-	$	433,055
Interdepartmental revenues		400		8,871		29,566		-		-		(38,837)		-
Total operating revenues		319,574		116,899		35,419		-		-		(38,837)		433,055
Depreciation and amortization		(22,372)		(5,018)		(5,601)		-		(35)		-		(33,026)
Other operating expenses		(239,963)		(96,063)		(122)		(15)		(626)		38,837		(297,952)
Operating income (loss)		57,239		15,818		29,696		(15)		(661)		-		102,077
Other (deductions) income, net		247		(33)		-		6,568		333		-		7,115
Interest (expense) income, net		(8,385)		(2,398)		(4,516)		-		164		-		(15,135)
Income (loss) before taxes		49,101		13,387		25,180		6,553		(164)		-		94,057
Income tax (provision) benefit		(15,868)		(5,370)		(10,106)		(2,637)		35		-		(33,946)
Net income (loss)	$	33,233	$	8,017	$	15,074	$	3,916	$	(129)	$	-	$	60,111
Nine Months Ended September 30, 2014
Operating revenues	$	308,418	$	163,335	$	2,392	$	-	$	-	$	-	$	474,145
Interdepartmental revenues		401		7,130		32,017		-		-		(39,548)		-
Total operating revenues		308,819		170,465		34,409		-		-		(39,548)		474,145
Depreciation and amortization		(19,909)		(4,700)		(5,547)		-		(35)		-		(30,191)
Other operating expenses		(229,286)		(144,907)		(105)		-		(672)		39,548		(335,422)
Operating income (loss)		59,624		20,858		28,757		-		(707)		-		108,532
Other (deductions) income, net		2,999		(44)		-		7,306		475		-		10,736
Interest (expense) income, net		(7,571)		(2,429)		(4,676)		-		126		-		(14,550)
Income (loss) before taxes		55,052		18,385		24,081		7,306		(106)		-		104,718
Income tax provision		(19,602)		(7,378)		(9,665)		(2,924)		(16)		-		(39,585)
Net income (loss)	$	35,450	$	11,007	$	14,416	$	4,382	$	(122)	$	-	$	65,133

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

(In thousands)MGE		Electric		Gas		Non- Regulated Energy		Transmission Investment		Consolidation/ Elimination Entries		Consolidated Total
Three Months Ended September 30, 2015
Operating revenues	$	121,460	$	17,435	$	1,911	$	-	$	-	$	140,806
Interdepartmental revenues		156		3,851		9,866		-		(13,873)		-
Total operating revenues		121,616		21,286		11,777		-		(13,873)		140,806
Depreciation and amortization		(7,584)		(1,714)		(1,872)		-		-		(11,170)
Other operating expenses*		(90,511)		(17,635)		(3,398)		(15)		13,873		(97,686)
Operating income (loss)*		23,521		1,937		6,507		(15)		-		31,950
Other (deductions) income, net*		129		(10)		-		1,435		-		1,554
Interest expense, net		(2,798)		(804)		(1,491)		-		-		(5,093)
Net income		20,852		1,123		5,016		1,420		-		28,411
Less: Net income attributable to
noncontrolling interest, net of tax		-		-		-		-		(6,633)		(6,633)
Net income attributable to MGE	$	20,852	$	1,123	$	5,016	$	1,420	$	(6,633)	$	21,778
Three Months Ended September 30, 2014
Operating revenues	$	112,875	$	21,410	$	862	$	-	$	-	$	135,147
Interdepartmental revenues		150		1,608		10,674		-		(12,432)		-
Total operating revenues		113,025		23,018		11,536		-		(12,432)		135,147
Depreciation and amortization		(6,931)		(1,575)		(1,858)		-		-		(10,364)
Other operating expenses*		(85,314)		(21,544)		(3,286)		-		12,432		(97,712)
Operating income (loss)*		20,780		(101)		6,392		-		-		27,071
Other income, net*		119		4		-		1,460		-		1,583
Interest expense, net		(2,832)		(808)		(1,545)		-		-		(5,185)
Net income (loss)		18,067		(905)		4,847		1,460		-		23,469
Less: Net income attributable to
noncontrolling interest, net of tax		-		-		-		-		(6,653)		(6,653)
Net income (loss) attributable to MGE	$	18,067	$	(905)	$	4,847	$	1,460	$	(6,653)	$	16,816
Nine Months Ended September 30, 2015
Operating revenues	$	319,191	$	108,039	$	5,853	$	-	$	-	$	433,083
Interdepartmental revenues		383		8,860		29,566		-		(38,809)		-
Total operating revenues		319,574		116,899		35,419		-		(38,809)		433,083
Depreciation and amortization		(22,372)		(5,018)		(5,601)		-		-		(32,991)
Other operating expenses*		(255,732)		(101,405)		(10,228)		(15)		38,809		(328,571)
Operating income (loss)*		41,470		10,476		19,590		(15)		-		71,521
Other (deductions) income, net*		148		(61)		-		3,931		-		4,018
Interest expense, net		(8,385)		(2,398)		(4,516)		-		-		(15,299)
Net income		33,233		8,017		15,074		3,916		-		60,240
Less: Net income attributable to
noncontrolling interest, net of tax		-		-		-		-		(19,812)		(19,812)
Net income attributable to MGE	$	33,233	$	8,017	$	15,074	$	3,916	$	(19,812)	$	40,428
Nine Months Ended September 30, 2014
Operating revenues	$	308,435	$	163,351	$	2,392	$	-	$	-	$	474,178
Interdepartmental revenues		384		7,114		32,017		-		(39,515)		-
Total operating revenues		308,819		170,465		34,409		-		(39,515)		474,178
Depreciation and amortization		(19,909)		(4,700)		(5,547)		-		-		(30,156)
Other operating expenses*		(248,525)		(152,182)		(9,770)		-		39,515		(370,962)
Operating income (loss)*		40,385		13,583		19,092		-		-		73,060
Other (deductions) income, net*		2,636		(147)		-		4,382		-		6,871
Interest expense, net		(7,571)		(2,429)		(4,676)		-		-		(14,676)
Net income		35,450		11,007		14,416		4,382		-		65,255
Less: Net income attributable to
noncontrolling interest, net of tax		-		-		-		-		(19,784)		(19,784)
Net income attributable to MGE	$	35,450	$	11,007	$	14,416	$	4,382	$	(19,784)	$	45,471
*Amounts are shown net of the related tax expense, consistent with the presentation on the MGE Consolidated Statement of Income.

XML

Fair Value of Financial Instruments (Details-2) - USD ($) $ in Thousands		Sep. 30, 2015	Dec. 31, 2014
Liabilities:
Derivative liability, collateral offset		$ 800	$ 2,200
Recurring [Member]
Assets:
Derivative assets, net		379	642
Total Assets		1,006	1,569
Liabilities:
Derivative liabilities, net	[1]	57,777	55,640
Deferred compensation		3,160	2,832
Total liabilities		60,937	58,472
Recurring [Member] | Exchange Traded [Member]
Assets:
Available-for-sale securities		627	927
Recurring [Member] | Level 1 [Member]
Assets:
Derivative assets, net		0	0
Total Assets		627	927
Liabilities:
Derivative liabilities, net	[1]	316	1,012
Deferred compensation		0	0
Total liabilities		316	1,012
Recurring [Member] | Level 1 [Member] | Exchange Traded [Member]
Assets:
Available-for-sale securities		627	927
Recurring [Member] | Level 2 [Member]
Assets:
Derivative assets, net		0	0
Total Assets		0	0
Liabilities:
Derivative liabilities, net	[1]	0	0
Deferred compensation		3,160	2,832
Total liabilities		3,160	2,832
Recurring [Member] | Level 2 [Member] | Exchange Traded [Member]
Assets:
Available-for-sale securities		0	0
Recurring [Member] | Level 3 [Member]
Assets:
Derivative assets, net		379	642
Total Assets		379	642
Liabilities:
Derivative liabilities, net	[1]	57,461	54,628
Deferred compensation		0	0
Total liabilities		57,461	54,628
Recurring [Member] | Level 3 [Member] | Exchange Traded [Member]
Assets:
Available-for-sale securities		0	0
MGE [Member]
Liabilities:
Derivative liability, collateral offset		800	2,200
MGE [Member] | Recurring [Member]
Assets:
Derivative assets, net		379	642
Total Assets		501	992
Liabilities:
Derivative liabilities, net	[1]	57,777	55,640
Deferred compensation		3,160	2,832
Total liabilities		60,937	58,472
MGE [Member] | Recurring [Member] | Exchange Traded [Member]
Assets:
Available-for-sale securities		122	350
MGE [Member] | Recurring [Member] | Level 1 [Member]
Assets:
Derivative assets, net		0	0
Total Assets		122	350
Liabilities:
Derivative liabilities, net	[1]	316	1,012
Deferred compensation		0	0
Total liabilities		316	1,012
MGE [Member] | Recurring [Member] | Level 1 [Member] | Exchange Traded [Member]
Assets:
Available-for-sale securities		122	350
MGE [Member] | Recurring [Member] | Level 2 [Member]
Assets:
Derivative assets, net		0	0
Total Assets		0	0
Liabilities:
Derivative liabilities, net	[1]	0	0
Deferred compensation		3,160	2,832
Total liabilities		3,160	2,832
MGE [Member] | Recurring [Member] | Level 2 [Member] | Exchange Traded [Member]
Assets:
Available-for-sale securities		0	0
MGE [Member] | Recurring [Member] | Level 3 [Member]
Assets:
Derivative assets, net		379	642
Total Assets		379	642
Liabilities:
Derivative liabilities, net	[1]	57,461	54,628
Deferred compensation		0	0
Total liabilities		57,461	54,628
MGE [Member] | Recurring [Member] | Level 3 [Member] | Exchange Traded [Member]
Assets:
Available-for-sale securities		$ 0	$ 0

[1] These amounts are shown gross and exclude $0.8 million and $2.2 million of collateral that was posted against derivative positions with counterparties as of September 30, 2015 and December 31, 2014, respectively.

XML

Commitments and Contingencies

9 Months Ended

Sep. 30, 2015

Commitments and Contingencies Disclosure [Abstract]

Commitments and Contingencies

Commitments and Contingencies - MGE Energy and MGE.

a. Environmental.

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

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

In September 2015, the EPA released its final rule setting Effluent Limitations Guidelines (ELG) for the steam electric power generating industry. The ELG rule establishes federal limits on the amount of metals and other pollutants that can be discharged in wastewater from new and existing steam electric generation plants. The ELG rule mostly covers pollutants that are captured by certain air pollution control and via wet ash handling systems at coal-burning power plants with units greater than 50 megawatt (MW) generation capacity. Although we are still reviewing the ELG rule, we anticipate that some equipment upgrades may be necessary at the Columbia and Elm Road plants to comply with the new discharge standards. The rule will go into effect in 2018 and will be applied to Wisconsin-based power plants as they renew their WPDES permits.

MGE cannot accurately estimate the costs associated with the ELG rule without a more thorough evaluation. However, management believes that any compliance costs will be recovered in future rates based on previous treatment of environmental compliance projects.

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

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

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

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

On August 3, 2015, the EPA finalized its Clean Power Plan rule setting guidelines for states to use in developing plans to control GHG emissions from existing fossil fuel-fired electric generating units (EGUs) and systems. When fully implemented in 2030, the Clean Power Plan is projected to reduce GHG emissions from this sector by 32 percent below 2005 levels. States are given up to three years to submit a plan to meet the reduction goals and are expected to meet interim goals starting in 2022 and the final goal in 2030.Implementation of the rule is expected to have a direct impact on coal and natural gas fired generating units, including possible changes in dispatch and additional operating costs.

On October 23, 2015, several states, including Wisconsin, and several state regulatory bodies filed a joint petition seeking to have the U.S. Court of Appeals for the District of Columbia Circuit stay the effectiveness of the Clean Power Plant rule, which would otherwise become effective on December 22, 2015, and seeking expedited review of the petitioners' challenges to the legality of the adoption of the rule.

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

National Ambient Air Quality Standards (NAAQS)

The EPA's NAAQS regulations have been developed to set ambient levels of six pollutants to protect sensitive populations (primary NAAQS) and the environment (secondary NAAQS) from the negative effects of exposure to these pollutants at higher levels. MGE is following developments for several NAAQS, including for particulate matter, nitrogen dioxide, sulfur dioxide, and ozone. Further discussion on sulfur dioxide and ozone NAAQS follows. For additional information on the NAAQS process, see Footnote 18.d. of Notes to Consolidated Financial Statements under Item 8, Financial Statements and Supplementary Data, of MGE Energy's and MGE's 2014 Annual Report on Form 10-K.

Sulfur Dioxide (SO₂) NAAQS

The EPA's new 1-hour SO₂ NAAQS has been in place since 2010 and initial attainment/nonattainment designations by states were due in 2013. However, the EPA was sued by environmental groups for not making these designations in a timely and proper manner. In March 2015, the EPA entered into a court-approved consent decree requiring 1-hour SO₂ attainment/nonattainment area designations to be completed in three phases extending out until 2020. In August 2015, the EPA published its data requirements rule that lays out expectations, designation process options, and timeframes for states and tribes to meet. Under this new rule, states must submit their first designation proposals in July 2016 for those areas that contain large stationary sources of SO₂ (sources that emit over a threshold mass of SO₂, and/or over a threshold emissions rate). These proposals must identify one of the following options for demonstrating attainment with the 1-hour SO₂ NAAQS: modeling of SO₂emissions; monitoring of SO₂ emissions; or limiting large stationary sources to 2,000 ton per year of SO₂ emissions by January 13, 2017. The EPA must make final designation determinations for these areas between 2017 and 2020 depending on the area.

In March 2015, MGE's Columbia plant was identified in the Federal Register as meeting the criteria of a large stationary source of SO₂ (based on 2012 data). As such, the State of Wisconsin must submit an attainment/nonattainment area designation plan for Columbia County (the county in which the Columbia plant is located). Since the 2012 data was collected, Columbia has installed pollution control equipment that has lowered its total SO₂ emissions and its SO₂ emissions rate. However, we will not know with any certainty if Columbia County will be determined to be in attainment until the State of Wisconsin completes its attainment/nonattainment demonstration and the EPA approves it. The outcome of this designation may have an adverse effect on the operation of the Columbia plant. MGE will monitor and participate in developments with the Columbia County designation process. Management believes compliance costs will be recovered in future rates based on previous treatment of environmental compliance projects.

Ozone NAAQS

In October 2015, the EPA revised the primary and secondary ozone NAAQS, lowering each to 70 ppb. Based on current ozone monitoring data, it appears that Milwaukee County (where our Elm Road Units are located) may not attain the lowered standards. Current ozone monitoring data suggests that Dane and Columbia Counties (where our WCCF/Blount and Columbia Units are located, respectively) will meet the new ozone NAAQS. Nonetheless, final attainment designations for these three counties will be based upon air monitoring data for years 2014-2016 and must be approved by EPA. Once these designations are complete, the State of Wisconsin will develop implementation plans for each county designated as nonattainment, which could affect plant operations within the nonattainment counties. These implementation plans are not expected to be finalized until 2017 at the earliest. MGE will continue to monitor developments, attainment designations, and state actions and implementation plans.

EPA's Cross-State Air Pollution Rule

In July 2011, the EPA finalized its Cross-State Air Pollution Rule (CSAPR) as a court-ordered replacement for its Clean Air Interstate Rule (CAIR) that had been remanded in 2008. CSAPR is an interstate air pollution transport rule designed to reduce ozone and fine particulate matter (PM2.5) air levels in areas that the EPA has determined are being affected by pollution from neighboring and upwind states.

CSAPR has been the subject of extensive litigation. That litigation had delayed implementation and created uncertainty, however, the most recent D.C. Circuit ruling clears the way for CSAPR to be fully implemented in Wisconsin. Some uncertainty remains as to the ozone season NO_x budget for Wisconsin. In late 2014, the EPA tolled CSAPR's original compliance deadlines by three years and MGE's affected facilities must now meet their Phase I reduction obligations in 2015 and Phase II in 2017. MGE anticipates meeting its CSAPR requirements at all of our affected facilities by applying reductions achieved from recent pollution control installations and early reduction efforts. We do not anticipate this rule to have a significant impact on MGE.

Clean Air Visibility Rule (CAVR)

Columbia may be subject to the best available retrofit technology (BART) regulations, a subsection of the EPA's Clean Air Visibility Rule (CAVR), which may require pollution control retrofits. Columbia's pollution control upgrades and the EPA's stance that compliance with the CSAPR equals compliance with BART should mean that Columbia will not need to do additional work to meet BART requirements. At this time, however, the BART regulatory obligations, compliance strategies, and costs remain uncertain due to the legal uncertainty surrounding CSAPR.

EPA's Coal Combustion Residuals Rule

In December 2014, the EPA finalized its Disposal of Coal Combustion Residuals from Electric Utilities (CCR) rule. The rule became effective on October 19, 2015. It provides that coal ash will be regulated as a solid waste, and defines what ash use activities would be considered generally exempt beneficial reuse of coal ash. The rule also regulates landfills, ash ponds, and other surface impoundments for coal combustion residuals by regulating their design, location, monitoring, and operation. Landfills and impoundments that cannot meet design criteria will need to formally close within defined timeframes.

The Columbia and Elm Road Units co-owners and plant operators are evaluating the final rule to determine what changes may be necessary at those facilities and the associated timeframes. We anticipate that some design and operational changes may need to be made at these facilities. Review of our Elm Road facility has indicated that the costs to comply with this rule are not expected to be significant. We are still evaluating the rule's full effects at Columbia, however, Columbia's operator has developed a preliminary implementation schedule for meeting the various deadlines spelled out in the rule. Management believes compliance costs will be recovered in future rates based on previous treatment of environmental compliance projects.

Columbia

Based upon current available information, compliance with various environmental requirements and initiatives is expected to result in significant additional operating and capital expenditures at Columbia as noted below.

Columbia Clean Air Act Litigation

Columbia is a coal-fired generating station operated by WPL in which WPL, WPSC, and MGE have ownership interests. In December 2009, the EPA sent a Notice of Violation (NOV) to MGE as one of the co-owners of Columbia. The NOV alleged that WPL and the Columbia co-owners failed to comply with appropriate pre-construction review and permitting requirements and, as a result, violated the Prevention of Significant Deterioration program requirements, Title V Operating Permit requirements of the CAA, and the Wisconsin SIP. In April 2013, the EPA filed a lawsuit against the co-owners of Columbia asserting similar allegations. In September 2010 and April 2013, the Sierra Club filed civil lawsuits against WPL alleging violations of the CAA at Columbia and other Wisconsin facilities operated by WPL. In June 2013, the court approved and entered a consent decree entered by the EPA, Sierra Club, and the co-owners of Columbia to resolve these claims, while admitting no liability. One of the requirements of the consent decree requires installation of a SCR system at Columbia Unit 2 by December 31, 2018. Installation of the SCR has been approved by the PSCW. MGE's share of the projected cost for the SCR system is approximately $19-$29 million. In addition, the consent decree establishes emission rate limits for SO₂, NO_x, and particulate matter and annual plant-wide emission caps for SO₂ and NO_x. MGE intends to seek recovery in future rates of the costs associated with its compliance with the terms of the final consent decree and currently expects to recover any material compliance costs.

b. Legal Matters.

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

c. Purchase Contracts.

MGE Energy and MGE have entered into various commodity supply, transportation, and storage contracts to meet their obligations to deliver electricity and natural gas to customers. As of September 30,2015, the future commitments related to these purchase contracts were as follows:

(In thousands)		2015		2016		2017		2018		2019
Coal(a)	$	6,211	$	21,639	$	10,664	$	6,560	$	3,850
Natural gas
Transportation & storage(b)		5,229		18,117		17,983		17,901		16,971
Supply(c)		10,704		11,127		-		-		-
	$	22,144	$	50,883	$	28,647	$	24,461	$	20,821

(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. If any minimum purchase obligations must be paid under these contracts, management believes these obligations would be considered costs of service and recoverable in rates.

(b)MGE'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. Management expects to recover these costs in future customer rates.

d.Asset Retirement Obligation.

MGE Energy and MGE are required to record a liability for the fair value of an ARO to be recognized in the period in which it is incurred if it can be reasonably estimated. The offsetting associated asset retirement costs are capitalized as a long-lived asset and depreciated over the asset's useful life. As of September 30,2015, MGE recorded an obligation of $2.3 million for the fair value of its legal liability for asset retirement obligations (AROs) associated with the effect of the final Coal Combustion Residual Rule at Columbia.MGE has regulatory treatment and recognizes regulatory assets or liabilities for the timing differences between when we recover legal AROs in rates and when those costs would actually be recognized.

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Segment Information

9 Months Ended

Sep. 30, 2015

Segment Reporting [Abstract]

Segment Information

Segment Information - MGE Energy and MGE.

MGE Energy operates in the following business segments: electric utility, gas utility, nonregulated energy, transmission investment, and all other. See MGE Energy's and MGE's 2014 Annual Report on Form 10-K for additional discussion of each of these segments.

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

(In thousands)MGE Energy		Electric		Gas		Non- Regulated Energy		Transmission Investment		All Others		Consolidation/ Elimination Entries		Consolidated Total
Three Months Ended September 30, 2015
Operating revenues	$	121,453	$	17,431	$	1,911	$	-	$	-	$	-	$	140,795
Interdepartmental revenues		163		3,855		9,866		-		-		(13,884)		-
Total operating revenues		121,616		21,286		11,777		-		-		(13,884)		140,795
Depreciation and amortization		(7,584)		(1,714)		(1,872)		-		(12)		-		(11,182)
Other operating expenses		(80,202)		(16,906)		(36)		(15)		(161)		13,884		(83,436)
Operating income (loss)		33,830		2,666		9,869		(15)		(173)		-		46,177
Other (deductions) income, net		141		(7)		-		2,397		33		-		2,564
Interest (expense) income, net		(2,798)		(804)		(1,491)		-		57		-		(5,036)
Income (loss) before taxes		31,173		1,855		8,378		2,382		(83)		-		43,705
Income tax (provision) benefit		(10,321)		(732)		(3,362)		(962)		26		-		(15,351)
Net income (loss)	$	20,852	$	1,123	$	5,016	$	1,420	$	(57)	$	-	$	28,354
Three Months Ended September 30, 2014
Operating revenues	$	112,869	$	21,404	$	862	$	-	$	-	$	-	$	135,135
Interdepartmental revenues		156		1,614		10,674		-		-		(12,444)		-
Total operating revenues		113,025		23,018		11,536		-		-		(12,444)		135,135
Depreciation and amortization		(6,931)		(1,575)		(1,858)		-		(12)		-		(10,376)
Other operating expenses		(74,573)		(22,199)		(35)		-		(276)		12,444		(84,639)
Operating income (loss)		31,521		(756)		9,643		-		(288)		-		40,120
Other income, net		136		8		-		2,423		69		-		2,636
Interest (expense) income, net		(2,832)		(808)		(1,545)		-		44		-		(5,141)
Income (loss) before taxes		28,825		(1,556)		8,098		2,423		(175)		-		37,615
Income tax (provision) benefit		(10,758)		651		(3,251)		(963)		35		-		(14,286)
Net income (loss)	$	18,067	$	(905)	$	4,847	$	1,460	$	(140)	$	-	$	23,329
Nine Months Ended September 30, 2015
Operating revenues	$	319,174	$	108,028	$	5,853	$	-	$	-	$	-	$	433,055
Interdepartmental revenues		400		8,871		29,566		-		-		(38,837)		-
Total operating revenues		319,574		116,899		35,419		-		-		(38,837)		433,055
Depreciation and amortization		(22,372)		(5,018)		(5,601)		-		(35)		-		(33,026)
Other operating expenses		(239,963)		(96,063)		(122)		(15)		(626)		38,837		(297,952)
Operating income (loss)		57,239		15,818		29,696		(15)		(661)		-		102,077
Other (deductions) income, net		247		(33)		-		6,568		333		-		7,115
Interest (expense) income, net		(8,385)		(2,398)		(4,516)		-		164		-		(15,135)
Income (loss) before taxes		49,101		13,387		25,180		6,553		(164)		-		94,057
Income tax (provision) benefit		(15,868)		(5,370)		(10,106)		(2,637)		35		-		(33,946)
Net income (loss)	$	33,233	$	8,017	$	15,074	$	3,916	$	(129)	$	-	$	60,111
Nine Months Ended September 30, 2014
Operating revenues	$	308,418	$	163,335	$	2,392	$	-	$	-	$	-	$	474,145
Interdepartmental revenues		401		7,130		32,017		-		-		(39,548)		-
Total operating revenues		308,819		170,465		34,409		-		-		(39,548)		474,145
Depreciation and amortization		(19,909)		(4,700)		(5,547)		-		(35)		-		(30,191)
Other operating expenses		(229,286)		(144,907)		(105)		-		(672)		39,548		(335,422)
Operating income (loss)		59,624		20,858		28,757		-		(707)		-		108,532
Other (deductions) income, net		2,999		(44)		-		7,306		475		-		10,736
Interest (expense) income, net		(7,571)		(2,429)		(4,676)		-		126		-		(14,550)
Income (loss) before taxes		55,052		18,385		24,081		7,306		(106)		-		104,718
Income tax provision		(19,602)		(7,378)		(9,665)		(2,924)		(16)		-		(39,585)
Net income (loss)	$	35,450	$	11,007	$	14,416	$	4,382	$	(122)	$	-	$	65,133

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

(In thousands)MGE		Electric		Gas		Non- Regulated Energy		Transmission Investment		Consolidation/ Elimination Entries		Consolidated Total
Three Months Ended September 30, 2015
Operating revenues	$	121,460	$	17,435	$	1,911	$	-	$	-	$	140,806
Interdepartmental revenues		156		3,851		9,866		-		(13,873)		-
Total operating revenues		121,616		21,286		11,777		-		(13,873)		140,806
Depreciation and amortization		(7,584)		(1,714)		(1,872)		-		-		(11,170)
Other operating expenses*		(90,511)		(17,635)		(3,398)		(15)		13,873		(97,686)
Operating income (loss)*		23,521		1,937		6,507		(15)		-		31,950
Other (deductions) income, net*		129		(10)		-		1,435		-		1,554
Interest expense, net		(2,798)		(804)		(1,491)		-		-		(5,093)
Net income		20,852		1,123		5,016		1,420		-		28,411
Less: Net income attributable to
noncontrolling interest, net of tax		-		-		-		-		(6,633)		(6,633)
Net income attributable to MGE	$	20,852	$	1,123	$	5,016	$	1,420	$	(6,633)	$	21,778
Three Months Ended September 30, 2014
Operating revenues	$	112,875	$	21,410	$	862	$	-	$	-	$	135,147
Interdepartmental revenues		150		1,608		10,674		-		(12,432)		-
Total operating revenues		113,025		23,018		11,536		-		(12,432)		135,147
Depreciation and amortization		(6,931)		(1,575)		(1,858)		-		-		(10,364)
Other operating expenses*		(85,314)		(21,544)		(3,286)		-		12,432		(97,712)
Operating income (loss)*		20,780		(101)		6,392		-		-		27,071
Other income, net*		119		4		-		1,460		-		1,583
Interest expense, net		(2,832)		(808)		(1,545)		-		-		(5,185)
Net income (loss)		18,067		(905)		4,847		1,460		-		23,469
Less: Net income attributable to
noncontrolling interest, net of tax		-		-		-		-		(6,653)		(6,653)
Net income (loss) attributable to MGE	$	18,067	$	(905)	$	4,847	$	1,460	$	(6,653)	$	16,816
Nine Months Ended September 30, 2015
Operating revenues	$	319,191	$	108,039	$	5,853	$	-	$	-	$	433,083
Interdepartmental revenues		383		8,860		29,566		-		(38,809)		-
Total operating revenues		319,574		116,899		35,419		-		(38,809)		433,083
Depreciation and amortization		(22,372)		(5,018)		(5,601)		-		-		(32,991)
Other operating expenses*		(255,732)		(101,405)		(10,228)		(15)		38,809		(328,571)
Operating income (loss)*		41,470		10,476		19,590		(15)		-		71,521
Other (deductions) income, net*		148		(61)		-		3,931		-		4,018
Interest expense, net		(8,385)		(2,398)		(4,516)		-		-		(15,299)
Net income		33,233		8,017		15,074		3,916		-		60,240
Less: Net income attributable to
noncontrolling interest, net of tax		-		-		-		-		(19,812)		(19,812)
Net income attributable to MGE	$	33,233	$	8,017	$	15,074	$	3,916	$	(19,812)	$	40,428
Nine Months Ended September 30, 2014
Operating revenues	$	308,435	$	163,351	$	2,392	$	-	$	-	$	474,178
Interdepartmental revenues		384		7,114		32,017		-		(39,515)		-
Total operating revenues		308,819		170,465		34,409		-		(39,515)		474,178
Depreciation and amortization		(19,909)		(4,700)		(5,547)		-		-		(30,156)
Other operating expenses*		(248,525)		(152,182)		(9,770)		-		39,515		(370,962)
Operating income (loss)*		40,385		13,583		19,092		-		-		73,060
Other (deductions) income, net*		2,636		(147)		-		4,382		-		6,871
Interest expense, net		(7,571)		(2,429)		(4,676)		-		-		(14,676)
Net income		35,450		11,007		14,416		4,382		-		65,255
Less: Net income attributable to
noncontrolling interest, net of tax		-		-		-		-		(19,784)		(19,784)
Net income attributable to MGE	$	35,450	$	11,007	$	14,416	$	4,382	$	(19,784)	$	45,471
*Amounts are shown net of the related tax expense, consistent with the presentation on the MGE Consolidated Statement of Income.

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Rate Matters (Details) - USD ($) $ in Millions	9 Months Ended		12 Months Ended
	Sep. 30, 2015	Sep. 30, 2014	Dec. 31, 2014	Aug. 31, 2015
MGE [Member]
Purchased Gas Adjustment [Abstract]
Purchased gas adjustment, overcollection	$ 1.1		$ 1.2
PSCW [Member] | Legal Entity Type of Counterparty [Domain]
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%
PSCW [Member] | MGE [Member]
Rate Proceedings [Abstract]
Authorized return on equity, percentage	10.20%		10.30%
PSCW [Member] | MGE [Member] | Fuel Rules Surplus Credit, 2012 [Member]
Rate Proceedings [Abstract]
Return of electric fuel credit, total			$ 6.3
Fuel Rules [Abstract]
Return of electric fuel credit, current period		$ 4.7
PSCW [Member] | MGE [Member] | Fuel Rules Surplus Credit, 2015 [Member]
Fuel Rules [Abstract]
Fuel rules, deferred electric cost	$ 7.6
Return of electric fuel credit, current period	$ 0.7
PSCW [Member] | Total Estimated 2015 Fuel Rules Credit, 2015 [Member] | MGE [Member] | Subsequent Event [Member]
Rate Proceedings [Abstract]
Public Utilities Return Of Fuel Rules Surplus Credit Future Period				$ 5.9
PSCW [Member] | Estimated Return of 2015 Fuel Rules Credit During 2015 [Member] | MGE [Member] | Subsequent Event [Member]
Rate Proceedings [Abstract]
Public Utilities Return Of Fuel Rules Surplus Credit Future Period				2.7
PSCW [Member] | Estimated 2016 Fuel Rules Credit, 2016 [Member] | MGE [Member] | Subsequent Event [Member]
Rate Proceedings [Abstract]
Public Utilities Return Of Fuel Rules Surplus Credit Future Period				$ 5.0
PSCW [Member] | Columbia Environmental Project [Member] | MGE [Member]
Rate Proceedings [Abstract]
Authorized AFUDC Rate			100.00%
Electric [Member] | PSCW [Member] | MGE [Member]
Rate Proceedings [Abstract]
Authorized rate increase (decrease), percentage	3.80%		0.00%
Authorized rate increase (decrease), amount	$ 15.4		$ 0.0
Gas [Member] | PSCW [Member] | MGE [Member]
Rate Proceedings [Abstract]
Authorized rate increase (decrease), percentage	(2.00%)		0.00%
Authorized rate increase (decrease), amount	$ (3.8)		$ 0.0

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Share Based Compensation (Details) - Performance Units [Member] - USD ($) $ in Millions		1 Months Ended	9 Months Ended
	Feb. 20, 2015	Jan. 31, 2015	Sep. 30, 2015	Sep. 30, 2014
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Compensation expense			$ 0.4	$ 0.9
Cash payments distributed related to awards previously granted and now payable		$ 1.3
Awards forfeited during period, value			$ 0.2	$ 0.0
Awards forfeited during period, units			4,676	0
Outstanding awards vested during period			$ 4.2
Performance Unit Plan [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Awards granted during period (in units)	18,948
Award vesting period			5 years
Director Incentive Agreement [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Awards granted during period (in units)		3,794
Award vesting period			3 years

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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, 2015	Sep. 30, 2014	Sep. 30, 2015	Sep. 30, 2014
Other comprehensive income/(loss), net of tax:
Unrealized (loss) gain on available-for-sale securities, net of tax	$ (85)	$ 95	$ (180)	$ 56
Comprehensive Income	28,269	23,424	59,931	65,189
MGE [Member]
Net Income	28,411	23,469	60,240	65,255
Other comprehensive income/(loss), net of tax:
Unrealized (loss) gain on available-for-sale securities, net of tax	(28)	43	(137)	(54)
Total comprehensive income including noncontrolling interest	28,383	23,512	60,103	65,201
Less: Comprehensive income attributable to Noncontrolling Interest, net of tax	(6,633)	(6,653)	(19,812)	(19,784)
Comprehensive Income	$ 21,750	$ 16,859	$ 40,291	$ 45,417

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Consolidated Balance Sheets (Unaudited) (Parentheticals) - USD ($) $ in Thousands	Sep. 30, 2015	Dec. 31, 2014
Receivables, Net
Reserve for uncollectible accounts receivable	$ 3,418	$ 4,329
Reserve for uncollectible other accounts receivable	702	420
MGE [Member]
Receivables, Net
Reserve for uncollectible accounts receivable	3,418	4,329
Reserve for uncollectible other accounts receivable	$ 702	$ 420

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Significant Accounting Policies (Policies)

9 Months Ended

Sep. 30, 2015

Accounting Policies [Abstract]

Variable Interest Entities

MGE Power Elm Road and MGE Power West Campus own electric generating assets and lease those assets to MGE. Both entities are variable interest entities under applicable authoritative accounting guidance. MGE is considered the primary beneficiary of these entities as a result of contractual agreements. As a result, MGE has consolidated MGE Power Elm Road and MGE Power West Campus.

Common Stock

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

Investments - ATC

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

Chattel Paper Agreement

MGE makes available to qualifying customers a financing program for the purchase and installation of energy-related equipment that will provide more efficient use of utility service at the customer's property. The energy-related equipment installed at the customer sites is used to secure the customer loans. MGE is a party to a chattel paper purchase agreement with a financial institution under which it can sell or finance an undivided interest with recourse, in up to $10.0 million of the financing program receivables, until July 31, 2016.The length of the MGE guarantee to the financial institution varies from one to ten years depending on the term of the underlying customer loan. The loan balances outstanding at September 30,2015, approximate the fair value of the energy-related equipment acting as collateral. MGE accounts for these agreements as secured borrowings.

Prior to the Transfers and Servicing Asset authoritative accounting guidance that became effective in 2015, these agreements were treated as off-balance sheet arrangements. Beginning January 1, 2015, these agreements are included as assets and liabilities in the consolidated balance sheet. As of September 30,2015, assets (other accounts receivable and other deferred assets) and liabilities (accounts payable and other deferred liabilities) increased approximately $3.8 million as a cumulative result of the guidance. In addition, the cumulative effect of this guidance resulted in a $0.1 million reduction in retained earnings.

Share-based Compensation

Under MGE Energy'sPerformance Unit Plan, eligible employees may receive performance units that entitle the holder to receive a cash payment equal to the value of a designated number of shares of MGE Energy's common stock, plus dividend equivalent payments thereon, at the end of the set performance period.

On February 20, 2015, 18,948 units were granted based on the MGE Energy closing stock price as of that date. Units are subject to a five-year graded vesting schedule. On the grant date, MGE Energy and MGE measure the cost of the employee services received in exchange for a performance unit award based on the current market value of MGE Energy common stock. The fair value of the awards has been subsequently re-measured at September 30,2015, as required by applicable accounting standards. Changes in fair value have been recognized as compensation cost. Since this amount is re-measured quarterly throughout the vesting period, the compensation cost is subject to variability.

For nonretirement eligible employees, stock based compensation costs are accrued and recognized using the graded vesting method. Compensation cost for retirement eligible employees or employees that will become retirement eligible during the vesting schedule are recognized on an abridged horizon.

In December 2013, a Director Incentive Plan was approved for the non-employee members of the Board of Directors. This plan is similar to MGE Energy's Performance Unit Plan for eligible employees described above. Under the plan, a non-employee director can receive performance units that entitle the holder to receive a cash payment equal to the value of a designated number of shares of MGE Energy's common stock, plus dividend payments, at the end of the set performance period. The units are subject to a three-year graded vesting schedule. In January 2015, 3,794 units were granted. For accounting purposes, the awards will be measured similarly to the employee unit awards.

Derivative Hedging

As part of its regular operations, MGE enters into contracts, including options, swaps, futures, forwards, and other contractual commitments, to manage its exposure to commodity prices. To the extent that these contracts are derivatives, MGE assesses whether or not the normal purchases or normal sales exclusion applies. For contracts to which this exclusion cannot be applied, MGE Energy and MGE recognize such derivatives in the consolidated balance sheets at fair value. MGE's commodity derivative activities are conducted in accordance with its electric and gas risk management program, which is approved by the PSCW and limits the volume MGE can hedge with specific risk management strategies. The maximum length of time over which cash flows related to energy commodities can be hedged is four years. If the derivative qualifies for regulatory deferral, the derivatives are marked to fair value and are offset with a corresponding regulatory asset or liability. The deferred gain or loss is recognized in earnings in the delivery month applicable to the instrument. Gains and losses related to hedges qualifying for regulatory treatment are recoverable in gas rates through the PGA or in electric rates as a component of the fuel rules mechanism.

Derivative Netting

All derivative instruments in this table are presented on a gross basis and are calculated prior to the netting of instruments with the same counterparty under a master netting agreement as well as the netting of collateral. For financial statement purposes, MGE Energy and MGE have netted instruments with the same counterparty under a master netting agreement as well as the netting of collateral.

Wisconsin Fuel Rules

Fuel rules require the PSCW and Wisconsin utilities to defer electric fuel-related costs that fall outside a symmetrical cost tolerance band around the amount approved for a utility in its annual fuel proceedings. Any over/under recovery of the actual costs is determined on an annual basis and is adjusted in future billings to electric retail customers. The fuel rules bandwidth is currently set at plus or minus 2%. Under fuel rules, MGE would defer costs, less any excess revenues, if its actual electric fuel costs exceeded 102% of the electric fuel costs allowed in its latest rate order. Excess revenues are defined as revenues in the year in question that provide MGE with a greater return on common equity than authorized by the PSCW in MGE's latest rate order. Conversely, MGE is required to defer the benefit of lower costs if actual electric fuel costs were less than 98% of the electric fuel costs allowed in that order.

Purchased Gas Adjustment Clause

MGE's natural gas rates are subject to a fuel adjustment clause designed to recover or refund the difference between the actual cost of purchased gas and the amount included in rates. Differences between the amounts billed to customers and the actual costs recoverable are deferred and recovered or refunded in future periods by means of prospective monthly adjustments to rates. At September 30,2015, and December 31,2014, MGE had over collected $1.1 million and $1.2 million, respectively, which was recorded in other current liabilities on the consolidated balance sheets.

New Accounting Pronouncements Disclosure

New Accounting Pronouncements - MGE Energy and MGE.

a.Transfers and Servicing Assets.

In June 2014, the FASB issued authoritative guidance within the Codification's Transfers and Servicing topic that provides guidance on the accounting and disclosures for repurchase-to-maturity transactions, securities lending transactions, and repurchase financings. This authoritative guidance became effective January 1, 2015. The authoritative guidance changed the accounting for the Chattel Paper program and required additional disclosures. Prior to adoption of the standard, Chattel Paper was treated as an off-balance sheet arrangement. See Footnote 4 for additional information.

b.Revenue from Contracts with Customers.

In May 2014, the FASB issued authoritative guidance within the Codification's Revenue Recognition topic that provides guidance on the recognition, measurement, and disclosure of revenue from contracts with customers. This authoritative guidance was scheduled to become effective January 1, 2017. In July 2015, the FASB deferred the effective date to January 1, 2018. MGE Energy and MGE are currently assessing the impact this pronouncement will have on their financial statements.

c.Consolidations.

In February 2015, the FASB issued authoritative guidance within the Codification's Consolidation topic that provides guidance on the evaluation of certain legal entities for consolidation purposes. This authoritative guidance will become effective January 1, 2016. The impact of this guidance on our financial statements is not expected to be material.

d.Debt Issuance Costs.

In April 2015, the FASB issued authoritative guidance within the Codification's Interest topic that provides guidance on the presentation of debt issuance costs in financial statements. This authoritative guidance will become effective January 1, 2016. The authoritative guidance changes the presentation of debt issuance costs on the balance sheet from an asset to a direct deduction from the related debt liability. The impact of this guidance on our financial statements is not expected to be material.

e.Cloud Computing Arrangements.

In April 2015, the FASB issued authoritative guidance within the Codification's Software topic that provides guidance on the accounting treatment of cloud computer arrangements. This authoritative guidance will become effective January 1, 2016. The authoritative guidance provides criteria for determining whether a cloud computing arrangement contains a software license that should be accounted for as internal-use software. The impact of this guidance on our financial statements is not expected to be material.

f. Inventory Measurement.

In July 2015, the FASB issued authoritative guidance within the Codification's Inventory topic that provides guidance on the subsequent measurement of inventory. This authoritative guidance will become effective January 1, 2017. The authoritative guidance changes the subsequent measurement of inventory from the lower of cost or market to the lower of cost or net realizable value. MGE Energy and MGE are currently assessing the impact this pronouncement will have on their financial statements.

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 30,2015, and December 31, 2014, the carrying amount of cash, cash equivalents, and outstanding commercial paper approximates fair market value due to the short maturity of those investments and obligations. The estimated fair market value of MGE Energy's and MGE's long-term debt is based on quoted market prices for similar financial instruments at September 30,2015, and December 31, 2014. 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 classified as Level 3. Transactions done with an over-the-counter party are on inactive markets and are therefore considered unobservable and classified as Level 3. These transactions are valued based on quoted prices from markets with similar exchange traded transactions. FTRs are priced based upon monthly auction results for identical or similar instruments in a closed market with limited data available and are therefore classified as Level 3.

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

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

This model is prepared by members of MGE's Energy Accounting department. On a quarterly basis, management in the Energy Supply and Finance departments review the assumptions, inputs, and fair value measurements.

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

	Model Input
Significant Unobservable Inputs	September 30, 2015	December 31, 2014
Basis adjustment:
On peak	97.4%	98.1%
Off peak	95.4%	95.0%
Counterparty fuel mix:
Internal generation	60% - 75%	50% - 70%
Purchased power	40% - 25%	50% - 30%

The deferred compensation plan allows participants to defer certain cash compensation into a notional investment account. These amounts are included within other deferred liabilities in the consolidated balance sheets of MGE Energy and MGE. The notional investments earn interest based upon the semiannual rate of U.S. Treasury Bills having a 26 week maturity increased by 1% compounded monthly with a minimum annual rate of 7%, compounded monthly. The notional investments are based upon observable market data, however, since the deferred compensation obligations themselves are not exchanged in an active market, they are classified as Level 2.

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Chattel Paper Agreements (Details-1) - USD ($) $ in Thousands	9 Months Ended
	Sep. 30, 2015	Dec. 31, 2014
Transfer of Certain Financial Assets Accounted for as Secured Borrowings [Line Items]
Cumulative effect of new accounting guidance, retained earnings		$ (142)
Chattel Paper Agreements [Member]
Transfer of Certain Financial Assets Accounted for as Secured Borrowings [Line Items]
Repurchase agreement, maximum exposure	$ 10,000
Repurchase-to-Maturity Transactions, loans due	3,806
Cumulative effect of new accounting guidance, retained earnings		$ (100)
2015 [Member] | Chattel Paper Agreements [Member]
Transfer of Certain Financial Assets Accounted for as Secured Borrowings [Line Items]
Repurchase-to-Maturity Transactions, loans due	132
2016 [Member] | Chattel Paper Agreements [Member]
Transfer of Certain Financial Assets Accounted for as Secured Borrowings [Line Items]
Repurchase-to-Maturity Transactions, loans due	735
2017 [Member] | Chattel Paper Agreements [Member]
Transfer of Certain Financial Assets Accounted for as Secured Borrowings [Line Items]
Repurchase-to-Maturity Transactions, loans due	472
2018 [Member] | Chattel Paper Agreements [Member]
Transfer of Certain Financial Assets Accounted for as Secured Borrowings [Line Items]
Repurchase-to-Maturity Transactions, loans due	504
Thereafter [Member] | Chattel Paper Agreements [Member]
Transfer of Certain Financial Assets Accounted for as Secured Borrowings [Line Items]
Repurchase-to-Maturity Transactions, loans due	$ 1,963
Minimum [Member] | Chattel Paper Agreements [Member]
Transfer of Certain Financial Assets Accounted for as Secured Borrowings [Line Items]
MGE guarantee to the financial institution, term	1 year
Maximum [Member] | Chattel Paper Agreements [Member]
Transfer of Certain Financial Assets Accounted for as Secured Borrowings [Line Items]
MGE guarantee to the financial institution, term	10 years

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Share-Based Compensation

9 Months Ended

Sep. 30, 2015

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

Share-Based Compensation

Share-Based Compensation - MGE Energy and MGE.

Under MGE Energy'sPerformance Unit Plan, eligible employees may receive performance units that entitle the holder to receive a cash payment equal to the value of a designated number of shares of MGE Energy's common stock, plus dividend equivalent payments thereon, at the end of the set performance period.

On February 20, 2015, 18,948 units were granted based on the MGE Energy closing stock price as of that date. Units are subject to a five-year graded vesting schedule. On the grant date, MGE Energy and MGE measure the cost of the employee services received in exchange for a performance unit award based on the current market value of MGE Energy common stock. The fair value of the awards has been subsequently re-measured at September 30,2015, as required by applicable accounting standards. Changes in fair value have been recognized as compensation cost. Since this amount is re-measured quarterly throughout the vesting period, the compensation cost is subject to variability.

For nonretirement eligible employees, stock based compensation costs are accrued and recognized using the graded vesting method. Compensation cost for retirement eligible employees or employees that will become retirement eligible during the vesting schedule are recognized on an abridged horizon.

In December 2013, a Director Incentive Plan was approved for the non-employee members of the Board of Directors. This plan is similar to MGE Energy's Performance Unit Plan for eligible employees described above. Under the plan, a non-employee director can receive performance units that entitle the holder to receive a cash payment equal to the value of a designated number of shares of MGE Energy's common stock, plus dividend payments, at the end of the set performance period. The units are subject to a three-year graded vesting schedule. In January 2015, 3,794 units were granted. For accounting purposes, the awards will be measured similarly to the employee unit awards.

During the nine months endedSeptember 30,2015 and 2014, MGE recorded$0.4 million and $0.9 million, respectively, in compensation expense as a result of awards under the plans. In January 2015, cash payments of $1.3 million were distributed relating to awards that were granted in 2010. During the nine months endedSeptember 30,2015, MGE recorded a $0.2 million gain on 4,676 units forfeited. No forfeitures occurred during the nine months endedSeptember 30,2014. At September 30,2015, $4.2 million of outstanding awards are vested, and of this amount no cash settlements have occurred.