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, 2013

[ ] 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, 2013
MGE Energy, Inc.	Common stock, $1.00 par value, 23,113,638 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 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' 2012 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.

Where to Find More Information

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

3

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

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

MGE Energy and Subsidiaries:
CWDC	Central Wisconsin Development Corporation
MAGAEL	MAGAEL, LLC
MGE	Madison Gas and Electric Company
MGE Construct	MGE Construct, LLC
MGE Energy	MGE Energy, Inc.
MGE Power	MGE Power, LLC
MGE Power Elm Road	MGE Power Elm Road, LLC
MGE Power West Campus	MGE Power West Campus, LLC
MGE Transco	MGE Transco Investment, LLC
North Mendota	North Mendota Energy & Technology Park, LLC
Other Defined Terms:
AFUDC	Allowance for Funds Used During Construction
ATC	American Transmission Company LLC
Blount	Blount Station
CAA	Clean Air Act
CAIR	Clean Air Interstate Rule
CAVR	Clean Air Visibility Rule
Codification	Financial Accounting Standards Board Accounting Standards Codification
Columbia	Columbia Energy Center
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
DOE	United States Department of Energy
Dth	Dekatherms, a quantity measure used in respect of natural gas
EGUs	Electric Generating Units
Elm Road Units	Elm Road Generating Station
EPA	United States Environmental Protection Agency
FASB	Financial Accounting Standards Board
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
NGCC	Natural Gas Combined Cycle
NOV	Notice of Violation
NOx	Nitrogen Oxides
NSPS	New Source Performance Standards
OPRB	Other Postretirement Benefits
PGA	Purchased Gas Adjustment clause, a regulatory mechanism used to reconcile natural gas costs recovered in rates to actual costs
PJM	PJM Interconnection, LLC (a regional transmission organization)
PPA	Purchased power agreement
PSCW	Public Service Commission of Wisconsin
PSD	Prevention of Significant Deterioration

4

SCR	Selective Catalytic Reduction
SEC	Securities and Exchange Commission
SIP	State Implementation Plan
SO2	Sulfur Dioxide
Stock Plan	Direct Stock Purchase and Dividend Reinvestment Plan of MGE Energy
UW	University of Wisconsin at Madison
VIE	Variable Interest Entity
WCCF	West Campus Cogeneration Facility
WDNR	Wisconsin Department of Natural Resources
WEPCO	Wisconsin Electric Power Company
Working capital	Current assets less current liabilities
WPL	Wisconsin Power and Light Company
WPSC	Wisconsin Public Service Corporation

5

Item 1. Financial Statements.

MGE Energy, Inc.

Consolidated Statements of Income (unaudited)

(In thousands, except per-share amounts)

		Three Months Ended September 30,				Nine Months Ended September 30,
		2013		2012		2013		2012
Operating Revenues:
Regulated electric revenues	$	119,836	$	118,914	$	310,176	$	305,189
Regulated gas revenues		18,864		16,587		121,373		92,235
Nonregulated revenues		1,399		2,337		4,075		6,894
Total Operating Revenues		140,099		137,838		435,624		404,318
Operating Expenses:
Fuel for electric generation		13,950		16,395		34,520		36,727
Purchased power		21,981		18,102		61,237		54,962
Cost of gas sold		8,819		7,389		70,259		50,035
Other operations and maintenance		41,134		41,975		124,670		126,202
Depreciation and amortization		9,710		9,706		28,864		29,042
Other general taxes		4,605		4,383		14,049		13,937
Total Operating Expenses		100,199		97,950		333,599		310,905
Operating Income		39,900		39,888		102,025		93,413
Other income, net		3,750		2,856		9,770		7,975
Interest expense, net		(4,605)		(4,849)		(13,937)		(14,717)
Income before income taxes		39,045		37,895		97,858		86,671
Income tax provision		(14,692)		(14,253)		(37,030)		(32,711)
Net Income	$	24,353	$	23,642	$	60,828	$	53,960
Earnings Per Share of Common Stock
(basic and diluted)	$	1.05	$	1.02	$	2.63	$	2.33
Dividends per share of common stock	$	0.408	$	0.395	$	1.198	$	1.161
Weighted Average Shares Outstanding
(basic and diluted)		23,114		23,114		23,114		23,114

MGE Energy, Inc.

Consolidated Statements of Comprehensive Income (unaudited)

(In thousands)

		Three Months Ended September 30,				Nine Months Ended September 30,
		2013		2012		2013		2012
Net Income	$	24,353	$	23,642	$	60,828	$	53,960
Other comprehensive income (loss), net of tax:
Unrealized gain (loss) on available-for-sale
securities, net of tax ($24 and $5, and $117 and
$24, respectively)		36		(8)		176		35
Comprehensive Income	$	24,389	$	23,634	$	61,004	$	53,995

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,
		2013		2012
Operating Activities:
Net income	$	60,828	$	53,960
Items not affecting cash:
Depreciation and amortization		28,864		29,042
Deferred income taxes		32,706		54,602
Provision for doubtful receivables		1,551		1,537
Employee benefit plan expenses		9,908		13,815
Equity earnings in ATC		(7,045)		(6,764)
Other items		250		1,632
Changes in working capital items:
Decrease (increase) in current assets		15,053		(9,002)
Decrease in current liabilities		(5,496)		(13,418)
Dividend income from ATC		5,498		5,300
Cash contributions to pension and other postretirement plans		(33,919)		(24,336)
Debt make-whole premium		(6,757)		-
Other noncurrent items, net		7,159		9,518
Cash Provided by Operating Activities		108,600		115,886
Investing Activities:
Capital expenditures		(92,092)		(65,909)
Capital contributions to investments		(1,305)		(1,988)
Other		(780)		(291)
Cash Used for Investing Activities		(94,177)		(68,188)
Financing Activities:
Cash dividends paid on common stock		(27,685)		(26,820)
Repayment of long-term debt		(42,000)		(30,000)
Issuance of long-term debt		85,000		28,000
Other		(765)		(844)
Cash Provided by (Used for) Financing Activities		14,550		(29,664)
Change in cash and cash equivalents		28,973		18,034
Cash and cash equivalents at beginning of period		46,357		41,169
Cash and Cash Equivalents at End of Period	$	75,330	$	59,203
Supplemental disclosures of cash flow information:
Significant noncash investing activities:
Accrued capital expenditures	$	10,473	$	7,649

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		2013		2012
Current Assets:
Cash and cash equivalents	$	75,330	$	46,357
Receivable - margin account		1,357		1,818
Accounts receivable, less reserves of $3,959 and $3,885, respectively		37,442		41,386
Other accounts receivable, less reserves of $822 and $931, respectively		8,271		6,746
Unbilled revenues		20,290		28,262
Materials and supplies, at average cost		17,023		16,997
Fossil fuel		6,388		6,367
Stored natural gas, at average cost		18,004		14,980
Prepaid taxes		12,722		19,520
Regulatory assets - current		8,689		10,327
Deferred income taxes - current		-		23,483
Other current assets		8,349		6,694
Total Current Assets		213,865		222,937
Regulatory assets		213,068		218,853
Other deferred assets and other		6,436		7,075
Property, Plant, and Equipment:
Property, plant, and equipment, net		1,012,281		975,053
Construction work in progress		131,096		98,411
Total Property, Plant, and Equipment		1,143,377		1,073,464
Investments		66,965		64,595
Total Assets	$	1,643,711	$	1,586,924
LIABILITIES AND CAPITALIZATION
Current Liabilities:
Long-term debt due within one year	$	4,082	$	3,013
Accounts payable		39,532		43,518
Accrued interest and taxes		4,041		4,296
Accrued payroll related items		9,819		10,063
Deferred income taxes		969		-
Regulatory liabilities - current		4,622		-
Derivative liabilities		9,310		9,270
Other current liabilities		6,337		5,637
Total Current Liabilities		78,712		75,797
Other Credits:
Deferred income taxes		278,899		270,410
Investment tax credit - deferred		1,466		1,520
Regulatory liabilities		25,757		24,538
Accrued pension and other postretirement benefits		133,730		162,835
Derivative liabilities		59,710		63,320
Other deferred liabilities and other		52,249		50,584
Total Other Credits		551,811		573,207
Capitalization:
Common shareholders' equity		612,748		579,429
Long-term debt		400,440		358,491
Total Capitalization		1,013,188		937,920
Commitments and contingencies (see Footnote 8)		-		-
Total Liabilities and Capitalization	$	1,643,711	$	1,586,924

The accompanying notes are an integral part of the above unaudited consolidated financial statements.

8

MGE Energy, Inc.

Consolidated Statements of Common Equity (unaudited)

(In thousands, except per-share amounts)

	Common Stock				Additional Paid-in Capital		Retained Earnings		Accumulated Other Comprehensive Income		Total
	Shares		Value
2012
Beginning balance - December 31, 2011	23,114	$	23,114	$	316,268	$	211,458	$	112	$	550,952
Net income							53,960				53,960
Other comprehensive income									35		35
Common stock dividends declared
($1.161 per share)							(26,820)				(26,820)
Ending balance - September 30, 2012	23,114	$	23,114	$	316,268	$	238,598	$	147	$	578,127
2013
Beginning balance - December 31, 2012	23,114	$	23,114	$	316,268	$	239,953	$	94	$	579,429
Net income							60,828				60,828
Other comprehensive income									176		176
Common stock dividends declared
($1.198 per share)							(27,685)				(27,685)
Ending balance - September 30, 2013	23,114	$	23,114	$	316,268	$	273,096	$	270	$	612,748

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,
		2013		2012		2013		2012
Operating Revenues:
Regulated electric revenues	$	119,836	$	118,914	$	310,176	$	305,189
Regulated gas revenues		18,864		16,587		121,373		92,235
Nonregulated revenues		1,399		2,337		4,075		6,894
Total Operating Revenues		140,099		137,838		435,624		404,318
Operating Expenses:
Fuel for electric generation		13,950		16,395		34,520		36,727
Purchased power		21,981		18,102		61,237		54,962
Cost of gas sold		8,819		7,389		70,259		50,035
Other operations and maintenance		40,990		41,766		124,133		125,320
Depreciation and amortization		9,710		9,706		28,864		29,042
Other general taxes		4,605		4,384		14,049		13,938
Income tax provision		13,798		13,669		34,237		30,273
Total Operating Expenses		113,853		111,411		367,299		340,297
Operating Income		26,246		26,427		68,325		64,021
Other Income and Deductions:
AFUDC - equity funds		852		514		2,178		978
Equity in earnings in ATC		2,340		2,280		7,045		6,764
Income tax provision		(880)		(587)		(2,802)		(2,555)
Other income, net		407		(77)		118		(207)
Total Other Income and Deductions		2,719		2,130		6,539		4,980
Income before interest expense		28,965		28,557		74,864		69,001
Interest Expense:
Interest on long-term debt		4,910		5,065		14,757		15,335
Other interest, net		5		25		(31)		(116)
AFUDC - borrowed funds		(281)		(209)		(718)		(398)
Net Interest Expense		4,634		4,881		14,008		14,821
Net Income	$	24,331	$	23,676	$	60,856	$	54,180
Less Net Income Attributable to Noncontrolling Interest, net of tax		(6,861)		(6,153)		(20,547)		(18,305)
Net Income Attributable to MGE	$	17,470	$	17,523	$	40,309	$	35,875

Madison Gas and Electric Company

Consolidated Statements of Comprehensive Income (unaudited)

(In thousands)

		Three Months Ended September 30,				Nine Months Ended September 30,
		2013		2012		2013		2012
Net Income	$	24,331	$	23,676	$	60,856	$	54,180
Other comprehensive income (loss), net of tax:
Unrealized gain (loss) on available-for-sale
securities, net of tax ($33 and $5, and $52 and
$20, respectively)		49		(7)		77		(30)
Comprehensive Income	$	24,380	$	23,669	$	60,933	$	54,150
Less: Comprehensive Income Attributable to
Noncontrolling Interest, net of tax		(6,861)		(6,153)		(20,547)		(18,305)
Comprehensive Income Attributable to MGE	$	17,519	$	17,516	$	40,386	$	35,845

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,
		2013		2012
Operating Activities:
Net income	$	60,856	$	54,180
Items not affecting cash:
Depreciation and amortization		28,864		29,042
Deferred income taxes		31,467		53,984
Provision for doubtful receivables		1,551		1,537
Employee benefit plan expenses		9,908		13,815
Equity earnings in ATC		(7,045)		(6,764)
Other items		652		2,028
Changes in working capital items:
Decrease (increase) in current assets		14,599		(10,446)
Decrease in current liabilities		(4,911)		(14,052)
Dividend income from ATC		5,498		5,300
Cash contributions to pension and other postretirement plans		(33,919)		(24,336)
Debt make-whole premium		(6,757)		-
Other noncurrent items, net		7,063		9,281
Cash Provided by Operating Activities		107,826		113,569
Investing Activities:
Capital expenditures		(92,092)		(65,909)
Capital contributions to investments		(1,065)		(1,775)
Other		(678)		(271)
Cash Used for Investing Activities		(93,835)		(67,955)
Financing Activities:
Cash dividends paid to parent by MGE		-		(13,456)
Distributions to parent from noncontrolling interest		(21,148)		(15,500)
Equity contribution received by noncontrolling interest		1,065		1,775
Repayment of long-term debt		(42,000)		(30,000)
Issuance of long-term debt		85,000		28,000
Other		(668)		(795)
Cash Provided by (Used for) Financing Activities		22,249		(29,976)
Change in cash and cash equivalents		36,240		15,638
Cash and cash equivalents at beginning of period		6,350		13,898
Cash and Cash Equivalents at End of Period	$	42,590	$	29,536
Supplemental disclosures of cash flow information:
Significant noncash investing activities:
Accrued capital expenditures	$	10,473	$	7,649

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		2013		2012
Current Assets:
Cash and cash equivalents	$	42,590	$	6,350
Receivable - margin account		1,357		1,818
Accounts receivable, less reserves of $3,959 and $3,885, respectively		37,442		41,386
Affiliate receivables		532		634
Other accounts receivable, less reserves of $822 and $931, respectively		8,220		6,732
Unbilled revenues		20,290		28,262
Materials and supplies, at average cost		17,023		16,997
Fossil fuel		6,388		6,367
Stored natural gas, at average cost		18,004		14,980
Prepaid taxes		17,334		23,561
Regulatory assets - current		8,689		10,327
Deferred income taxes - current		-		23,305
Other current assets		8,310		6,670
Total Current Assets		186,179		187,389
Affiliate receivable long-term		5,957		6,354
Regulatory assets		213,068		218,853
Other deferred assets and other		4,695		6,540
Property, Plant, and Equipment:
Property, plant, and equipment, net		1,012,150		974,549
Construction work in progress		131,096		98,411
Total Property, Plant, and Equipment		1,143,246		1,072,960
Investments		64,287		61,555
Total Assets	$	1,617,432	$	1,553,651
LIABILITIES AND CAPITALIZATION
Current Liabilities:
Long-term debt due within one year	$	4,082	$	3,013
Accounts payable		39,532		43,517
Affiliate payables		40		767
Accrued interest and taxes		4,056		4,248
Accrued payroll related items		9,819		10,063
Deferred income taxes		1,379		-
Regulatory liabilities - current		4,622		-
Derivative liabilities		9,310		9,270
Other current liabilities		6,166		4,491
Total Current Liabilities		79,006		75,369
Other Credits:
Deferred income taxes		273,456		266,231
Investment tax credit - deferred		1,466		1,520
Regulatory liabilities		25,757		24,538
Accrued pension and other postretirement benefits		133,730		162,835
Derivative liabilities		59,710		63,320
Other deferred liabilities and other		52,251		50,581
Total Other Credits		546,370		569,025
Capitalization:
Common shareholder's equity		473,682		433,296
Noncontrolling interest		117,934		117,470
Total Equity		591,616		550,766
Long-term debt		400,440		358,491
Total Capitalization		992,056		909,257
Commitments and contingencies (see Footnote 8)		-		-
Total Liabilities and Capitalization	$	1,617,432	$	1,553,651

The accompanying notes are an integral part of the above unaudited consolidated financial statements.

12

Madison Gas and Electric Company

Consolidated Statements of Common Equity (unaudited)

(In thousands)

	Common Stock				Additional Paid-in Capital		Retained Earnings	Accumulated Other Comprehensive (Loss)/Income			Non- Controlling Interest		Total
	Shares		Value
2012
Beginning balance - Dec. 31, 2011	17,348	$	17,348	$	192,417	$	203,114	$	47	$	114,351	$	527,277
Net income							35,875				18,305		54,180
Other comprehensive loss									(30)				(30)
Cash dividends paid to parent
by MGE							(13,456)						(13,456)
Equity contribution received by
noncontrolling interest											1,775		1,775
Distributions to parent from
noncontrolling interest											(15,500)		(15,500)
Ending balance - September 30, 2012	17,348	$	17,348	$	192,417	$	225,533	$	17	$	118,931	$	554,246
2013
Beginning balance - Dec. 31, 2012	17,348	$	17,348	$	192,417	$	223,527	$	4	$	117,470	$	550,766
Net income							40,309				20,547		60,856
Other comprehensive income									77				77
Equity contribution received by
noncontrolling interest											1,065		1,065
Distributions to parent from
noncontrolling interest											(21,148)		(21,148)
Ending balance - September 30, 2013	17,348	$	17,348	$	192,417	$	263,836	$	81	$	117,934	$	591,616

The accompanying notes are an integral part of the above unaudited consolidated financial statements.

13

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

Notes to Consolidated Financial Statements (unaudited)

September 30, 2013

1.

Basis of Presentation - MGE Energy and MGE.

This report is a combined report of MGE Energy and MGE. References in this report to "MGE Energy" are to MGE Energy, Inc. and its subsidiaries. References in this report to "MGE" are to Madison Gas and Electric Company.

MGE Power Elm Road and MGE Power West Campus own electric generating assets and lease those assets to MGE. Both entities are variable interest entities under applicable authoritative guidance. MGE is considered the primary beneficiary of these entities as a result of contractual agreements. As a result, MGE has consolidated MGE Power Elm Road and MGE Power West Campus. See Footnote 2 of Notes to Consolidated Financial Statements under Item 8, Financial Statements and Supplementary Data, of MGE Energy's and MGE's 2012 Annual Report on Form 10-K.

The accompanying consolidated financial statements as of September 30, 2013, 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 2012 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 51 through 104 of the 2012 Annual Report on Form 10-K.

2.

Equity and Financing Arrangements.

a.

Common Stock - MGE Energy.

MGE Energy purchases stock in the open market for issuance pursuant to its Stock Plan. All MGE Energy common stock issued under the Stock Plan is sold pursuant to a registration statement that has been filed with the SEC and is currently effective.

MGE Energy can issue new shares of its common stock through the Stock Plan. For both the nine months ended September 30, 2013 and 2012, 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 19, 2013, each of MGE Energy and MGE entered into an amendment to its existing credit agreement dated as of July 30, 2010, with various financial institutions, as lenders, and JPMorgan Chase Bank, N.A., as administrative agent. In the case of MGE Energy, the principal purposes of the amendment are to increase the revolving credit facility to $50 million from $40 million and to extend the expiration date of the credit agreement to July 31, 2017 from July 31, 2015. In the case of MGE, the principal purposes of the amendment are to increase the revolving credit facility to $100 million from $75 million and to extend the expiration date of the credit agreement to July 31, 2017 from July 31, 2015. In addition, both amendments lowered the adders used in the determination of the interest rates under the existing credit agreements. As a result of the amendments, the existing credit agreements for both of MGE Energy and MGE carry interest at either (i) a "floating rate," plus an adder ranging from zero to 0.125%, depending upon the credit ratings assigned to MGE's senior unsecured long-term debt securities; or (ii) a "Eurodollar Rate," plus an adder ranging from 0.675% to 1.125%, depending 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

14

period plus 1%. The "Eurodollar Rate" is calculated as provided in the credit agreements for the selected interest period. As of September 30, 2013, neither MGE Energy nor MGE had any borrowings outstanding under their respective credit agreements and MGE had no commercial paper outstanding.

d.

Long-term Debt - MGE Energy and MGE.

On July 18, 2013, MGE issued $20 million in principal amount of 4.42% senior notes, Series A, due July 15, 2043 and $20 million in principal amount of 4.47%, senior notes, Series B, due July 15, 2048. The Notes were issued pursuant to a Note Purchase Agreement with several note purchasers. The Notes are unsecured and are not issued under, or governed by, MGE's Indenture dated as of September 1, 1998, which governs MGE's Medium-Term Notes. MGE used the net proceeds from the sale of the Notes to redeem on July 18, 2013, $20 million of its 5.26% Medium-Term Notes due September 29, 2017, and to make a $20 million partial redemption of its 5.59% Senior Notes due September 11, 2018. MGE paid a redemption price equal to the principal amount of the notes that were redeemed, plus accrued interest to the redemption date, plus a make-whole premium equal to $3.2 million and $3.6 million, for the 5.26% Medium-Term Notes due September 29, 2017 and 5.59% Senior Notes due September 11, 2018, respectively. The make-whole premiums are treated as a regulatory asset and will be amortized over the life of the Series A and Series B Notes. Any interest savings in 2013 will be deferred. There is $20 million principal amount of the 5.59% Senior Notes remaining outstanding after the redemption.

The Note Purchase Agreement under which the Series A and Series B Notes were issued also includes the issuance on September 16, 2013, of $30 million in principal amount of 3.09% Senior Notes, Series C, due September 15, 2023 and $15 million of 3.29% Senior Notes, Series D, due September 15, 2026. The Series C Notes and the Series D Notes carry interest rates of 3.09% per annum and 3.29% per annum, respectively. The proceeds of the Notes are expected to be used to help finance the Columbia environmental project.

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. 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, 2013 and 2012, MGE Transco recorded equity earnings from the investment in ATC of $7.0 million and $6.8 million, respectively. Dividends received from ATC were $5.5 million and $5.3 million for the nine months ended September 30, 2013 and 2012, respectively. In addition, during the nine months ended September 30, 2013 and 2012, MGE Transco made $1.1 million and $1.8 million in capital contributions to ATC, respectively. On October 31, 2013, MGE Transco made a $0.4 million capital contribution to ATC.

MGE Transco's investment in ATC as of September 30, 2013, and December 31, 2012, was $63.6 million and $61.0 million, respectively.

At September 30, 2013, 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, 2013 and 2012, is as follows:

		Three Months Ended September 30,				Nine Months Ended September 30,
(In thousands)		2013		2012		2013		2012
Operating revenues	$	160,480	$	150,303	$	464,345	$	450,136
Operating expenses		(77,595)		(68,813)		(217,240)		(210,139)
Other income (expense), net		917		(5)		585		(832)
Interest expense, net		(21,136)		(20,983)		(63,232)		(61,260)
Earnings before members' income taxes	$	62,666	$	60,502	$	184,458	$	177,905

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4.

Columbia Environmental Project Construction - MGE Energy and MGE.

MGE and two other utilities jointly own Columbia, a coal-fired generating facility. WPL is the plant operator and permit holder, and owns 46.2% of Columbia. WPSC owns a 31.8% interest, and MGE owns a 22% interest, in Columbia. In early 2011, the PSCW issued a Certificate and Order authorizing the construction of scrubbers and bag houses and associated equipment on Columbia Units 1 and 2 to reduce SO₂ and mercury emissions. The scrubbers and bag houses are expected to support compliance obligations for current and anticipated air quality regulations, including CAIR, CAIR's eventual replacement, the Mercury and Air Toxics Standards (MATS), and the Wisconsin Mercury Rule. The operator's current estimate shows that MGE's share of the capital expenditures required for this project is approximately $140 million. As of September 30, 2013, MGE had accumulated $113.6 million (excluding carrying costs) related to its share of the project, which is reflected in the Construction Work in Progress balance on MGE Energy's and MGE's consolidated balance sheets. MGE's share of the capital expenditures associated with the Columbia environmental project is expected to be approximately $12 million for the remainder of 2013 and $14 million in 2014. These amounts may change as a result of modifications to the project estimate or timing differences. MGE's share of various contractual commitments entered for the project as of September 30, 2013, is $24.4 million. For the three months ended September 30, 2013 and 2012, MGE has recognized after tax $0.8 million and $0.4 million, respectively, in AFUDC equity related to this project. For the nine months ended September 30, 2013 and 2012, MGE has recognized after tax $1.9 million and $0.7 million, respectively, in AFUDC equity related to this project.

MGE expects that the costs pertaining to this project will be fully recoverable through rates. For 2012, the PSCW authorized MGE 100% AFUDC on this project during construction. Beginning in 2013, similar to MGE's other utility construction projects, the PSCW authorized MGE a 50% current return (included in customer rates) and the remaining 50% as AFUDC.

5.

Taxes - MGE Energy and MGE.

a.

Accounting for Uncertainty in Income Taxes.

MGE Energy and MGE account for the difference between the tax benefit amount taken on prior year tax returns, or expected to be taken on a current year tax return, and the tax benefit amount recognized in the financial statements as an unrecognized tax benefit.

MGE Energy has adopted a tax method of accounting to accelerate tax deductions for repairs. MGE Energy and MGE have an unrecognized tax benefit at September 30, 2013, and December 31, 2012, in the amount of $2.3 million and $3.2 million, respectively, for the tax uncertainty related to the change in tax method of accounting for repairs. The reduction in unrecognized tax benefits is due to the Internal Revenue Service completing the examination of tax periods 2007-2009 with no adverse adjustments to these positions.

b.

Effective Tax Rate.

MGE Energy's and MGE's effective income tax rate for the three and nine months ended September 30, 2013, are 37.6% and 37.8%, respectively, compared to 37.6% and 37.7% for the same periods in 2012.

c.

Final Tangible Property Regulations.

In September 2013, the IRS and Treasury Department released final regulations under Sections 162(a) and 263(a) on the deduction and capitalization of expenditures related to tangible property, replacing the 2011 temporary regulations issued in December 2011. The final regulations did not have a material impact on MGE Energy's and MGE's consolidated financial statements.

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.

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The following table presents the components of MGE Energy's and MGE's net periodic benefit costs recognized for the three and nine months ended September 30, 2013 and 2012. A portion of the net periodic benefit cost is capitalized within the consolidated balance sheets.

		Three Months Ended September 30,				Nine Months Ended September 30,
(In thousands)		2013		2012		2013		2012
Pension Benefits
Components of net periodic benefit cost:
Service cost	$	1,924	$	1,871	$	5,764	$	5,613
Interest cost		3,178		3,236		9,521		9,711
Expected return on assets		(4,764)		(3,917)		(14,273)		(11,756)
Amortization of:
Prior service cost		79		111		237		333
Actuarial loss		2,011		2,058		6,023		6,177
Net periodic benefit cost	$	2,428	$	3,359	$	7,272	$	10,078
Postretirement Benefits
Components of net periodic benefit cost:
Service cost	$	594	$	626	$	1,781	$	1,879
Interest cost		966		1,089		2,898		3,267
Expected return on assets		(542)		(421)		(1,626)		(1,263)
Amortization of:
Transition obligation		-		103		2		309
Prior service cost		28		27		83		81
Actuarial loss		310		601		930		1,802
Net periodic benefit cost	$	1,356	$	2,025	$	4,068	$	6,075

The PSCW allowed MGE to defer the 2009 incremental pension and OPRB costs above the amounts recovered in rates. During both the three months ended September 30, 2013 and 2012, $0.3 million has been recovered in rates. During both the nine months ended September 30, 2013 and 2012, $0.9 million has been recovered in rates. These costs are not reflected in the table above.

7.

Share-Based Compensation - MGE Energy and MGE.

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

In addition to units granted in 2009 through 2012, on February 15, 2013, 15,256 units were granted based on the MGE Energy closing stock price as of that date. These units are subject to a five-year graded vesting schedule. 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, 2013, 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 the event of a bona fide retirement, not followed by work for a competitor, the executive will receive full vesting credit for each outstanding award.

During the nine months ended September 30, 2013 and 2012, MGE recorded $1.1 million and $1.4 million, respectively, in compensation expense as a result of the Performance Unit Plan. In January 2013, cash payments of $1.0 million were distributed relating to awards that were granted in 2008 and became payable under the Performance Unit Plan. No forfeitures occurred during the nine months ended September 30, 2013 or 2012. At September 30, 2013, $3.6 million of outstanding awards are vested.

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8.

Commitments and Contingencies.

a.

Environmental - MGE Energy and MGE.

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

·

The President's announced plan and directive to the EPA to regulate carbon pollution, or GHG emissions, from new and existing electric power generation, which is discussed below.

·

Rules to regulate NO_x and SO₂ emissions, including the EPA's Cross State Air Pollution Rule (CSAPR), which is currently vacated as a result of a federal appellate court ruling; and Wisconsin's plan for implementing the EPA's Clean Air Visibility Rule (CAVR). In June 2013, the U.S. Supreme Court indicated that it would review the CSAPR appellate court ruling. The Sierra Club has sought federal appellate court review of Wisconsin's implementation plan for CAVR. Both the vacation of CSAPR and the appellate court review of Wisconsin's implementation plan for CAVR make the nature of compliance requirements uncertain.

·

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

·

The EPA's proposed cooling water intake rules. The EPA issued a proposed Phase II rule and alternative compliance strategies for existing facilities in April 2011 and has announced that it intends to release the final rule in November 2013.

The matters in the second, third, and fourth bullet points are discussed further in Footnote 18.e. in MGE Energy's and MGE's 2012 Annual Report on Form 10-K. In addition to the developments noted above, the following discussion is an update to the current status of environmental matters set forth in that Footnote.

Water Quality

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

In June 2013, the EPA published a proposed rule focusing on the reduction of metals and other pollutants in wastewater from new and existing coal-burning electric generation plants. The proposed rule is technology-driven in that specific technologies may need to be installed and sites that already have these technologies will be deemed to meet the requirements of the rule. The proposed rule as written will likely affect Columbia and the Elm Road Units. The EPA has announced that it plans to finalize the rule by May 22, 2014 and that it expects the rule to affect power plants as they renew their water discharge permits beginning in July 2017. We are currently evaluating the rule's specific impacts at these sites and will not know the full extent of those impacts until the rule is finalized.

Air Quality

Greenhouse Gas Regulation

President Obama's Executive Order Regarding Climate Change and his Directive to the EPA Regarding Power Sector Pollution Standards

In June 2013, President Obama introduced his "National Climate Action Plan." The plan consists of planned federal actions and directives to several federal agencies, including the EPA, on a range of activities and policies designed to reduce greenhouse gas emissions in the United States. The directive to the EPA, which President Obama provided to the EPA in a memo, to develop carbon pollution standards for the electric power sector, has the greatest potential effect on MGE's operations. See the GHG New Performance Standards discussion below for additional details.

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GHG New Source Performance Standards (NSPS)

In a June 2013 directive, President Obama instructed the EPA to re-propose greenhouse gas standards for new power plants by September 20, 2013, based on comments received on their original rule proposal issued in March 2012, and to finalize those standards in a timely manner. The EPA met the President's directive and published revised proposed standards for new power plants in September 2013, that would require, if finalized, that new coal-fired units and small natural gas units meet carbon dioxide emission levels significantly below current levels.

The June 2013 directive also instructed the EPA to propose standards, regulations or guidelines for modified, reconstructed and existing power plants under Sections 111(b) and 111(d) of the Clean Air Act no later than June 2014 and to finalize those standards by June 2015. The directive further instructs the EPA to require states to submit implementation plans for this rule by June 30, 2016. The Directive asks the EPA to aim to develop a market-based approach towards carbon reduction, promote cleaner technologies while keeping energy options diverse, work with other government agencies to keep energy affordable and improve energy efficiencies, and engage States, the power industry, and the other key stakeholders in establishing and implementing strategies for greenhouse gas reductions.

While it is too early to predict with any certainty the specific costs that MGE will incur with implementation of a greenhouse gas reduction rule introduced under Section 111 of the Clean Air Act, it is reasonable to assume that costs of implementation of this rule could be significant depending on the approach taken.

Columbia

MGE and two other utilities jointly own Columbia, a coal-fired generating facility, which accounts for 225 MW (29%) of MGE's net summer generating capability. WPL is the plant operator and permit holder, and owns 46.2% of Columbia. Wisconsin Public Service Corporation (WPSC) owns a 31.8% interest, and MGE owns a 22% interest in Columbia. Based upon current available information, compliance with various environmental requirements and initiatives is expected to result in significant additional operating and capital expenditures at Columbia as noted below.

Columbia Environmental Project

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

Title V Operating Permit Petition

As discussed in Footnote 18.e. in MGE Energy's and MGE's 2012 Annual Report on Form 10-K, the WDNR's renewal of WPL's Title V operating permit for Columbia has been the subject of litigation initiated by a citizen group. On February 4, 2013, the parties involved dismissed the litigation without prejudice. The resolution of the Clean Air Act litigation, discussed below, included resolution of the citizen group's challenge to the renewal of the Columbia Title V operating permit. By letter dated July 30, 2013, the EPA withdrew its proposal that WPL apply to the EPA for the issuance of the renewed Columbia Title V permit. MGE believes the permits currently in effect for Columbia remain in effect at this time and will now be renewed by the WDNR. MGE continues to follow these developments and is unable to predict the outcome of this matter and its impact on its operations or financial condition.

Columbia Clean Air Act Litigation

In December 2009, the EPA sent a notice of violation (NOV) to MGE as one of the co-owners of Columbia. The NOV alleges that WPL, as owner-operator, and the other co-owners failed to comply with appropriate pre-construction review and permitting requirements and, as a result, violated the PSD program requirements, the Title V operating permit requirements of the CAA and the Wisconsin State Implementation Plan (SIP). In April 2013, the EPA filed a lawsuit against the co-owners of Columbia asserting similar allegations. In September 2010 and April 2013, Sierra Club filed lawsuits against WPL alleging violations of the CAA at Columbia and other WPL-operated Wisconsin facilities.

In April 2013, WPL, as owner-operator, along with the other owners of Columbia, entered into a consent decree with the EPA and the Sierra Club to resolve these claims, while admitting no liability. In June 2013, the consent decree was approved and entered by the Court. The consent decree requires installation of the following emission controls at Columbia: scrubbers and baghouses at Columbia Units 1 and 2 by December 31, 2014, and an SCR system at Columbia Unit 2 by December 31, 2018. In addition, the consent decree establishes emission rate limits for SO₂, nitrogen oxide (NO_x), and particulate matter for Columbia Units 1 and 2. The consent decree also includes annual plant-wide emission caps for SO₂ and NO_x for

19

Columbia. MGE also paid approximately $0.2 million as its share of a civil penalty and will complete approximately $0.6 million in environmental mitigation projects. MGE intends to seek recovery in rates of the costs associated with its compliance with the terms of the final consent decree and currently expects to recover any material compliance costs.

b.

Chattel Paper Agreement and Other Guarantees - MGE 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. MGE is party to a chattel paper purchase agreement with a financial institution under which it can sell or finance an undivided interest with recourse, in up to $10.0 million of the financing program receivables, until July 31, 2014. At September 30, 2013, MGE has outstanding a $5.0 million interest in these receivables. MGE retains the servicing responsibility for these receivables. As of September 30, 2013, the servicing asset recognized by MGE is $0.3 million.

MGE accounts for servicing rights under the amortization method. Initial determination of the servicing asset fair value is based on the present value of the estimated future cash flows. The discount rate is based on the PSCW authorized weighted cost of capital.

MGE would be required to perform under its guarantee if a customer defaulted on its loan. The energy-related equipment installed at the customer sites is used to secure the customer loans. The loan balances outstanding at September 30, 2013, approximate the fair value of the energy-related equipment acting as collateral. The length of the MGE guarantee to the financial institution varies from one to ten years depending on the term of the underlying customer loan. Principal payments for the remainder of 2013 and the next four years on the loans are:

(In thousands)		2013		2014		2015		2016		2017
Chattel Paper	$	213	$	621	$	937	$	862	$	455

c.

Legal Matters - MGE Energy and MGE.

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

d.

Purchase Contracts - MGE Energy and MGE.

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, 2013, the future commitments related to these purchase contracts were as follows:

(In thousands)		2013		2014		2015		2016		2017
Coal(a)	$	7,407	$	17,705	$	9,921	$	3,770	$	1,040
Natural gas supply(b)		14,549		13,601		-		-		-
Purchase power(c)		49,397		49,262		47,776		48,795		49,816
Other		1,691		-		-		-		-
	$	73,044	$	80,568	$	57,697	$	52,565	$	50,856

(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 are 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)

These commitments include market-based pricing. Management expects to recover these costs in future customer rates.

(c)

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

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9.

Derivative and Hedging Instruments - MGE Energy and MGE.

a.

Purpose.

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

b.

Notional Amounts.

The gross notional volume of open derivatives is as follows:

	September 30, 2013	December 31, 2012
Commodity derivative contracts	300,195 MWh	444,650 MWh
Commodity derivative contracts	5,970,000 Dth	1,980,000 Dth
FTRs	3,099 MW	2,670 MW

c.

Financial Statement Presentation.

MGE Energy and MGE offset fair value amounts recognized for the right to reclaim collateral (a receivable) or the obligation to return collateral (a payable) against fair value amounts recognized for derivative instruments executed with the same counterparty under a master netting agreement.

MGE purchases and sells exchange-traded and over-the-counter options, swaps, and future contracts. These arrangements are primarily entered into to help stabilize the price risk associated with gas or power purchases. These transactions are employed by both MGE's gas and electric segments. Additionally, as a result of the firm transmission agreements that MGE holds on transmission paths in the MISO market, MGE holds FTRs. An FTR is a financial instrument that entitles the holder to a stream of revenues or charges based on the differences in hourly day-ahead energy prices between two points on the transmission grid. The fair values of these instruments are reflected as a 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, 2013, and December 31, 2012, the fair value of exchange traded derivatives and FTRs exceeded their cost basis by $0.9 million and $0.3 million, respectively.

MGE is a party to a ten-year purchased power agreement that provides MGE with firm capacity and energy during a base term from June 1, 2012, through May 31, 2022. The agreement also allows MGE an option to extend the contract after the base term. The agreement is accounted for as a derivative contract and is recognized at its fair value on the consolidated balance sheet. However, the derivative qualifies for regulatory deferral and is recognized with a corresponding regulatory asset or liability depending on whether the fair value is in a loss or gain position. The fair value of the contract at September 30, 2013, and December 31, 2012, reflects a loss position of $69.0 million and $72.6 million, respectively. The actual fuel 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 sheet. All derivative instruments in this table are presented on a gross basis and are calculated prior to the netting of instruments with the same counterparty under a master netting agreement as well as the netting of collateral. For financial statement purposes, MGE Energy and MGE have netted instruments with the same counterparty under a master netting agreement as well as the netting of collateral.

	Asset Derivatives			Liability Derivatives
(In thousands)	Balance Sheet Location		Fair Value	Balance Sheet Location		Fair Value
September 30, 2013
Commodity derivative contracts	Other current assets	$	608	Derivative liability (current)	$	213
Commodity derivative contracts	Other deferred charges		32	Derivative liability (long-term)		18
FTRs	Other current assets		528	Derivative liability (current)		-
Ten-year PPA	N/A		N/A	Derivative liability (current)		9,310
Ten-year PPA	N/A		N/A	Derivative liability (long-term)		59,710
December 31, 2012
Commodity derivative contracts	Other current assets	$	365	Derivative liability (current)	$	394
Commodity derivative contracts	Other deferred charges		95	Derivative liability (long-term)		11
FTRs	Other current assets		206	Derivative liability (current)		-
Ten-year PPA	N/A		N/A	Derivative liability (current)		9,270
Ten-year PPA	N/A		N/A	Derivative liability (long-term)		63,320

The following tables show the effect of netting arrangements for recognized derivative assets and liabilities that are subject to a master netting arrangement or similar arrangement on the balance sheet.

Offsetting of Derivative Assets
		Gross amounts		Gross amounts offset in balance sheet		Collateral posted against derivative positions		Net amount presented in balance sheet
(In thousands)
September 30, 2013
Commodity derivative contracts	$	640	$	(231)	$	-	$	409
FTRs		528		-		-		528
December 31, 2012
Commodity derivative contracts	$	460	$	(405)	$	-	$	55
FTRs		206		-		-		206

Offsetting of Derivative Liabilities
		Gross amounts		Gross amounts offset in balance sheet		Collateral posted against derivative positions		Net amount presented in balance sheet
(In thousands)
September 30, 2013
Commodity derivative contracts	$	231	$	(231)	$	-	$	-
Ten-year PPA		69,020		-		-		69,020
December 31, 2012
Commodity derivative contracts	$	405	$	(405)	$	-	$	-
Ten-year PPA		72,590		-		-		72,590

22

The following tables summarize the unrealized and realized gains and losses related to the derivative instruments on the consolidated balance sheet at September 30, 2013 and 2012, and the consolidated income statement for the three and nine months ended September 30, 2013 and 2012.

		2013				2012
(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,	$	66,649	$	658	$	79,362	$	718
Change in unrealized loss (gain)		2,330		-		(468)		-
Realized loss reclassified to a deferred account		(275)		275		(223)		223
Realized loss reclassified to income
statement		(621)		(111)		(3,414)		(161)
Balance at September 30,	$	68,083	$	822	$	75,257	$	780
Nine Months Ended September 30:
Balance at January 1,	$	72,329	$	574	$	42,356	$	1,604
Change in unrealized loss (gain)		(1,330)		-		42,633		-
Realized loss reclassified to a deferred account		(953)		953		(3,103)		3,103
Realized loss reclassified to income
statement		(1,963)		(705)		(6,629)		(3,927)
Balance at September 30,	$	68,083	$	822	$	75,257	$	780

		Realized losses (gains)
		Regulated gas revenues		Fuel for electric generation/ purchased power		Cost of gas sold
(In thousands)
Three Months Ended September 30, 2013:
Commodity derivative contracts	$	-	$	(7)	$	-
FTRs		-		(387)		-
Ten-year PPA		-		1,126		-
Three Months Ended September 30, 2012:
Commodity derivative contracts	$	-	$	176	$	-
FTRs		-		(256)		-
Ten-year PPA		-		3,655		-
Nine Months Ended September 30, 2013:
Commodity derivative contracts	$	-	$	(523)	$	608
FTRs		-		(896)		-
Ten-year PPA		-		3,479		-
Nine Months Ended September 30, 2012:
Commodity derivative contracts	$	-	$	2,685	$	3,090
FTRs		-		(93)		-
Ten-year PPA		-		4,874		-

MGE's commodity derivative contracts, FTRs, and ten-year PPA are subject to regulatory deferral. These derivatives are marked to fair value and are offset with a corresponding regulatory asset or liability. Realized gains and losses are deferred on the consolidated balance sheet and are recognized in earnings in the delivery month applicable to the instrument. As a result of the above described treatment, there are no unrealized gains or losses that flow through earnings.

The ten-year PPA has a provision that may require MGE to post collateral if MGE's debt rating falls below investment grade (i.e., below BBB-). The amount of collateral that it may be required to post varies from $20.0 million to $40.0 million, depending on MGE's nominated capacity amount. As of September 30, 2013, no collateral has been posted. Certain counterparties extend MGE a credit limit. If MGE exceeds these limits, the counterparties may require collateral to be posted. As of September 30, 2013, and December 31, 2012, no counterparties were in a net liability position.

23

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, 2013, no counterparties have defaulted.

10.

Rate Matters - MGE Energy and MGE.

a.

Rate Proceedings.

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

On December 14, 2012, the PSCW authorized MGE to increase 2013 rates for retail electric customers by 3.8% or $14.9 million and to increase gas rates by 1.0% or $1.6 million. The change in retail electric rates was driven by costs for new environmental equipment at Columbia, final construction costs for the Elm Road Units, transmission reliability enhancements, and purchased power costs. The authorized return on common stock equity remains unchanged at 10.3%.

On December 15, 2011, under a limited reopener of MGE's last rate order, the PSCW authorized MGE to increase 2012 rates for retail electric customers by 4.3% or $15.7 million and to increase gas rates by 0.3% or $0.6 million. The change in retail electric rates was driven by MGE's electric fuel and purchased power costs, increased transmission costs, an update to the Elm Road Units' costs, and an increase for energy efficiency programs. The PSCW also approved deferral of CSAPR costs.

b.

Fuel Rules.

Fuel rules require the PSCW and Wisconsin utilities to defer electric fuel-related costs that fall outside a symmetrical cost tolerance band around the amount approved for a utility in its most recent base rate proceedings. Any over/under recovery of the actual costs is determined on an annual basis and will be adjusted in future billings to electric retail customers. The fuel rules bandwidth is currently set at plus or minus 2%. Under fuel rules, MGE would defer costs, less any excess revenues, if its actual electric fuel costs exceeded 102% of the electric fuel costs allowed in its latest rate order. Excess revenues are defined as revenues in the year in question that provide MGE with a greater return on common equity than authorized by the PSCW in MGE's latest rate order. Conversely, MGE is required to defer the benefit of lower costs if actual electric fuel costs were less than 98% of the electric fuel costs allowed in that order. As of September 30, 2013, MGE has deferred $4.4 million (to be returned to customers in a future period) of 2013 electric fuel-related savings that are outside the range authorized by the PSCW.

11.

Fair Value of Financial Instruments - MGE Energy and MGE.

Fair value is defined as the price that would be received to sell an asset or would be paid to transfer a liability (an exit price) in the principal or most advantageous market for the asset or liability in an orderly transaction between market participants at the measurement date. The standard clarifies that fair value should be based on the assumptions market participants would use when pricing the asset or liability including assumptions about risk. The standard also establishes a three level fair value hierarchy based upon the observability of the assumptions used and requires the use of observable market data when available. The levels are:

Level 1 - Pricing inputs are quoted prices within active markets for identical assets or liabilities.

Level 2 - Pricing inputs are quoted prices within active markets for similar assets or liabilities; quoted prices for identical or similar instruments in markets that are not active; and model-derived valuations that are correlated with or otherwise verifiable by observable market data.

Level 3 - Pricing inputs are unobservable and reflect management's best estimate of what market participants would use in pricing the asset or liability.

24

a.

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

At September 30, 2013, and December 31, 2012, the carrying amount of cash and cash equivalents approximates fair market value due to the short maturity of those investments and obligations. The estimated fair market value of MGE Energy's and MGE's long-term debt is based on quoted market prices for similar financial instruments at September 30, 2013, and December 31, 2012. Since the 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, 2013				December 31, 2012
		Carrying Amount		Fair Value		Carrying Amount		Fair Value
(In thousands)
MGE Energy
Assets:
Cash and cash equivalents	$	75,330	$	75,330	$	46,357	$	46,357
Liabilities:
Long-term debt*		404,805		445,247		361,805		427,456
MGE
Assets:
Cash and cash equivalents	$	42,590	$	42,590	$	6,350	$	6,350
Liabilities:
Long-term debt*		404,805		445,247		361,805		427,456
*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, 2013
(In thousands)		Total		Level 1		Level 2		Level 3
MGE Energy
Assets:
Exchange-traded investments	$	613	$	613	$	-	$	-
Total Assets	$	613	$	613	$	-	$	-
Liabilities:
Derivatives, net	$	68,083	$	(245)	$	-	$	68,328
Deferred compensation		2,253		-		2,253		-
Total Liabilities	$	70,336	$	(245)	$	2,253	$	68,328
MGE
Assets:
Exchange-traded investments	$	246	$	246	$	-	$	-
Total Assets	$	246	$	246	$	-	$	-
Liabilities:
Derivatives, net	$	68,083	$	(245)	$	-	$	68,328
Deferred compensation		2,253		-		2,253		-
Total Liabilities	$	70,336	$	(245)	$	2,253	$	68,328

25

		Fair Value as of December 31, 2012
(In thousands)		Total		Level 1		Level 2		Level 3
MGE Energy
Assets:
Exchange-traded investments	$	320	$	320	$	-	$	-
Total Assets	$	320	$	320	$	-	$	-
Liabilities:
Derivatives, net	$	72,329	$	(17)	$	-	$	72,346
Deferred compensation		2,010		-		2,010		-
Total Liabilities	$	74,339	$	(17)	$	2,010	$	72,346
MGE
Assets:
Exchange-traded investments	$	117	$	117	$	-	$	-
Total Assets	$	117	$	117	$	-	$	-
Liabilities:
Derivatives, net	$	72,329	$	(17)	$	-	$	72,346
Deferred compensation		2,010		-		2,010		-
Total Liabilities	$	74,339	$	(17)	$	2,010	$	72,346

No transfers were made in or out of Level 1 or Level 2 for the nine months ended September 30, 2013.

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

Derivatives include exchange-traded derivative contracts, over-the-counter transactions, a ten-year purchased power agreement, and FTRs. Most exchange-traded derivative contracts are valued based on unadjusted quoted prices in active markets and are therefore classified as Level 1. A small number of exchange-traded derivative contracts are valued using quoted market pricing in markets with insufficient volumes and are therefore classified as Level 3. Transactions done with an over-the-counter party are on inactive markets and are therefore classified as Level 3. These transactions are valued based on quoted prices from markets with similar exchange traded transactions. FTRs are priced based upon monthly auction results for identical or similar instruments in a closed market with limited data available and are therefore classified as Level 3.

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

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

26

This model is prepared by members of MGE's Energy Supply group. It is reviewed on a quarterly basis by management in Energy Supply and Finance to review the assumptions, inputs, and fair value measurements.

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

Significant Unobservable Inputs	Model Input
Basis adjustment:
On peak	99.7%
Off peak	97.9%
Counterparty fuel mix:
Internal generation	50 % - 70 %
Purchased power	50 % - 30 %

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

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

		Three Months Ended September 30,				Nine Months Ended September 30,
(In thousands)		2013		2012		2013		2012
Beginning balance,	$	(66,856)	$	(79,580)	$	(72,346)	$	(40,661)
Realized and unrealized gains (losses):
Included in regulatory liabilities (assets)		(1,472)		3,465		4,018		(35,455)
Included in other comprehensive income		-		-		-		-
Included in earnings		(174)		(3,422)		(2,034)		(6,659)
Included in current assets		(38)		-		(94)		(77)
Purchases		6,052		5,864		17,709		7,764
Sales		-		45		(2)		77
Issuances		-		-		-		-
Settlements		(5,840)		(2,487)		(15,579)		(1,104)
Transfers in and/or out of Level 3		-		-		-		-
Balance as of September 30,	$	(68,328)	$	(76,115)	$	(68,328)	$	(76,115)
Total gains (losses) included in earnings attributed to the change in unrealized gains (losses) related to assets and liabilities held at September 30,(a)		-		-		-		-
	$		$		$		$

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^(a).

		Three Months Ended September 30,				Nine Months Ended September 30,
(In thousands)		2013		2012		2013		2012
Purchased Power Expense	$	(174)	$	(3,422)	$	(2,034)	$	(6,659)
Cost of Gas Sold Expense		-		-		-		-
Regulated Gas Revenues		-		-		-		-
Total	$	(174)	$	(3,422)	$	(2,034)	$	(6,659)

(a)

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

27

12.

New Accounting Pronouncements - MGE Energy and MGE.

a.

Presentation of Comprehensive Income.

In February 2013, the FASB issued authoritative guidance within the Codification's Comprehensive Income topic that provides guidance on the reporting of amounts reclassified out of accumulated other comprehensive income. Reclassification adjustments will be presented either on the financial statement where income is presented or as a separate disclosure in the notes to the financial statements. This authoritative guidance became effective January 1, 2013. The authoritative guidance had no effect on our financial statement presentation or notes to the financial statements.

b.

Disclosures about Offsetting Assets and Liabilities.

In December 2011, the FASB issued authoritative guidance within the Codification's Balance Sheet topic that provides guidance on disclosures about offsetting assets and liabilities. The new disclosure requirements mandate that entities disclose both gross and net information for instruments and transactions eligible for offset in the balance sheet as well as instruments and transactions subject to a master netting arrangement. In addition, the standard requires disclosure of collateral received and posted in connections with a master netting arrangement. On January 31, 2013, the FASB issued additional authoritative guidance which clarified the scope of disclosures about offsetting assets and liabilities. The revised guidance limits the scope of the new balance sheet offsetting disclosures to derivatives, repurchase agreements, and securities lending transactions to the extent that they are (1) offset in the financial statements or (2) subject to an enforceable master netting arrangement or similar agreement. This authoritative guidance became effective January 1, 2013. The authoritative guidance did not have a financial impact, but required additional disclosures. See Footnote 9 for additional information.

c.

Obligations Resulting from Joint and Several Liability Arrangements for Which the Total Amount of the Obligation Is Fixed at the Reporting Date.

In February 2013, the FASB issued authoritative guidance within the Codification's Balance Sheet topic that provides guidance on the recognition, measurement, and disclosure of obligations resulting from joint and several liability arrangements for which the total amount of the obligation is fixed at the reporting date. This authoritative guidance will become effective January 1, 2014. The authoritative guidance will not have a financial or disclosure impact.

d.

Presentation of an Unrecognized Tax Benefit.

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

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 2012 Annual Report on Form 10-K for additional discussion of each of these segments.

28

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

(In thousands) MGE Energy		Electric		Gas		Non- Regulated Energy		Transmission Investment		All Others		Consolidation/ Elimination Entries		Consolidated Total
Three Months Ended September 30, 2013
Operating revenues	$	119,836	$	18,864	$	1,399	$	-	$	-	$	-	$	140,099
Interdepartmental revenues		172		2,757		10,660		-		-		(13,589)		-
Total operating revenues		120,008		21,621		12,059		-		-		(13,589)		140,099
Depreciation and amortization		(6,425)		(1,497)		(1,788)		-		-		-		(9,710)
Other operating expenses		(82,414)		(21,485)		(33)		(1)		(145)		13,589		(90,489)
Operating income (loss)		31,169		(1,361)		10,238		(1)		(145)		-		39,900
Other income, net		1,166		92		-		2,340		152		-		3,750
Interest (expense) income, net		(2,309)		(729)		(1,596)		-		29		-		(4,605)
Income (loss) before taxes		30,026		(1,998)		8,642		2,339		36		-		39,045
Income tax (provision) benefit		(11,021)		751		(3,469)		(939)		(14)		-		(14,692)
Net income (loss)	$	19,005	$	(1,247)	$	5,173	$	1,400	$	22	$	-	$	24,353
Three Months Ended September 30, 2012
Operating revenues	$	118,914	$	16,587	$	2,337	$	-	$	-	$	-	$	137,838
Interdepartmental revenues		159		4,658		8,679		-		-		(13,496)		-
Total operating revenues		119,073		21,245		11,016		-		-		(13,496)		137,838
Depreciation and amortization		(6,530)		(1,399)		(1,777)		-		-		-		(9,706)
Other operating expenses		(78,823)		(22,675)		(36)		-		(206)		13,496		(88,244)
Operating income (loss)		33,720		(2,829)		9,203		-		(206)		-		39,888
Other income, net		342		97		-		2,280		137		-		2,856
Interest (expense) income, net		(2,535)		(715)		(1,631)		-		32		-		(4,849)
Income (loss) before taxes		31,527		(3,447)		7,572		2,280		(37)		-		37,895
Income tax (provision) benefit		(11,873)		1,565		(3,039)		(909)		3		-		(14,253)
Net income (loss)	$	19,654	$	(1,882)	$	4,533	$	1,371	$	(34)	$	-	$	23,642
Nine Months Ended September 30, 2013
Operating revenues	$	310,176	$	121,373	$	4,075	$	-	$	-	$	-	$	435,624
Interdepartmental revenues		410		10,449		31,924		-		-		(42,783)		-
Total operating revenues		310,586		131,822		35,999		-		-		(42,783)		435,624
Depreciation and amortization		(19,139)		(4,357)		(5,368)		-		-		-		(28,864)
Other operating expenses		(235,390)		(111,494)		(96)		(1)		(537)		42,783		(304,735)
Operating income (loss)		56,057		15,971		30,535		(1)		(537)		-		102,025
Other income, net		2,226		69		-		7,045		430		-		9,770
Interest (expense) income, net		(7,028)		(2,166)		(4,814)		-		71		-		(13,937)
Income (loss) before taxes		51,255		13,874		25,721		7,044		(36)		-		97,858
Income tax (provision) benefit		(18,148)		(5,844)		(10,209)		(2,837)		8		-		(37,030)
Net income (loss)	$	33,107	$	8,030	$	15,512	$	4,207	$	(28)	$	-	$	60,828
Nine Months Ended September 30, 2012
Operating revenues	$	305,189	$	92,235	$	6,894	$	-	$	-	$	-	$	404,318
Interdepartmental revenues		387		10,721		26,032		-		-		(37,140)		-
Total operating revenues		305,576		102,956		32,926		-		-		(37,140)		404,318
Depreciation and amortization		(19,554)		(4,158)		(5,330)		-		-		-		(29,042)
Other operating expenses		(223,876)		(94,162)		(85)		-		(880)		37,140		(281,863)
Operating income (loss)		62,146		4,636		27,511		-		(880)		-		93,413
Other income, net		602		170		-		6,764		439		-		7,975
Interest (expense) income, net		(7,727)		(2,179)		(4,915)		-		104		-		(14,717)
Income (loss) before taxes		55,021		2,627		22,596		6,764		(337)		-		86,671
Income tax (provision) benefit		(20,300)		(740)		(9,069)		(2,719)		117		-		(32,711)
Net income (loss)	$	34,721	$	1,887	$	13,527	$	4,045	$	(220)	$	-	$	53,960

29

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, 2013
Operating revenues	$	119,836	$	18,864	$	1,399	$	-	$	-	$	140,099
Interdepartmental revenues		172		2,757		10,660		-		(13,589)		-
Total operating revenues		120,008		21,621		12,059		-		(13,589)		140,099
Depreciation and amortization		(6,425)		(1,497)		(1,788)		-		-		(9,710)
Other operating expenses*		(93,481)		(20,748)		(3,502)		(1)		13,589		(104,143)
Operating income (loss)*		20,102		(624)		6,769		(1)		-		26,246
Other income, net*		1,212		106		-		1,401		-		2,719
Interest expense, net		(2,309)		(729)		(1,596)		-		-		(4,634)
Net income (loss)		19,005		(1,247)		5,173		1,400		-		24,331
Less: Net income attributable to
noncontrolling interest, net of tax		-		-		-		-		(6,861)		(6,861)
Net income (loss) attributable to MGE	$	19,005	$	(1,247)	$	5,173	$	1,400	$	(6,861)	$	17,470
Three Months Ended September 30, 2012
Operating revenues	$	118,914	$	16,587	$	2,337	$	-	$	-	$	137,838
Interdepartmental revenues		159		4,658		8,679		-		(13,496)		-
Total operating revenues		119,073		21,245		11,016		-		(13,496)		137,838
Depreciation and amortization		(6,530)		(1,399)		(1,777)		-		-		(9,706)
Other operating expenses*		(90,946)		(21,180)		(3,075)		-		13,496		(101,705)
Operating income (loss)*		21,597		(1,334)		6,164		-		-		26,427
Other income, net*		592		167		-		1,371		-		2,130
Interest expense, net		(2,535)		(715)		(1,631)		-		-		(4,881)
Net income (loss)		19,654		(1,882)		4,533		1,371		-		23,676
Less: Net income attributable to
noncontrolling interest, net of tax		-		-		-		-		(6,153)		(6,153)
Net income (loss) attributable to MGE	$	19,654	$	(1,882)	$	4,533	$	1,371	$	(6,153)	$	17,523
Nine Months Ended September 30, 2013
Operating revenues	$	310,176	$	121,373	$	4,075	$	-	$	-	$	435,624
Interdepartmental revenues		410		10,449		31,924		-		(42,783)		-
Total operating revenues		310,586		131,822		35,999		-		(42,783)		435,624
Depreciation and amortization		(19,139)		(4,357)		(5,368)		-		-		(28,864)
Other operating expenses*		(253,566)		(117,346)		(10,305)		(1)		42,783		(338,435)
Operating income (loss)*		37,881		10,119		20,326		(1)		-		68,325
Other income, net*		2,254		77		-		4,208		-		6,539
Interest expense, net		(7,028)		(2,166)		(4,814)		-		-		(14,008)
Net income		33,107		8,030		15,512		4,207		-		60,856
Less: Net income attributable to
noncontrolling interest, net of tax		-		-		-		-		(20,547)		(20,547)
Net income attributable to MGE	$	33,107	$	8,030	$	15,512	$	4,207	$	(20,547)	$	40,309
Nine Months Ended September 30, 2012
Operating revenues	$	305,189	$	92,235	$	6,894	$	-	$	-	$	404,318
Interdepartmental revenues		387		10,721		26,032		-		(37,140)		-
Total operating revenues		305,576		102,956		32,926		-		(37,140)		404,318
Depreciation and amortization		(19,554)		(4,158)		(5,330)		-		-		(29,042)
Other operating expenses*		(244,303)		(94,938)		(9,154)		-		37,140		(311,255)
Operating income*		41,719		3,860		18,442		-		-		64,021
Other income, net*		729		206		-		4,045		-		4,980
Interest expense, net		(7,727)		(2,179)		(4,915)		-		-		(14,821)
Net income		34,721		1,887		13,527		4,045		-		54,180
Less: Net income attributable to
noncontrolling interest, net of tax		-		-		-		-		(18,305)		(18,305)
Net income attributable to MGE	$	34,721	$	1,887	$	13,527	$	4,045	$	(18,305)	$	35,875

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

30

The following table shows segment information for MGE Energy's and MGE's assets and capital expenditures:

(In thousands) MGE Energy		Utility							Consolidated
		Electric		Gas		Assets not Allocated		Nonregulated Energy			Transmission Investment		All Others		Consolidation/ Elimination Entries		Total
Assets:
September 30, 2013	$	948,030	$	274,896	$	50,963	$	289,808		$	63,666	$	408,340	$	(391,992)	$	1,643,711
December 31, 2012		888,444		285,468		18,559		323,216			61,064		413,291		(403,118)		1,586,924
Capital Expenditures:
Nine Months Ended September 30, 2013	$	79,637	$	9,423	$	-	$	3,032		$	-	$	-	$	-	$	92,092
Year ended Dec. 31, 2012		81,965		13,812		-		2,658			-		-		-		98,435

(In thousands) MGE		Utility						Consolidated
		Electric		Gas		Assets not Allocated		Nonregulated Energy		Transmission Investment		Elimination Entries		Total
Assets:
September 30, 2013	$	948,030	$	274,896	$	50,963	$	289,758	$	63,666	$	(9,881)	$	1,617,432
December 31, 2012		888,444		285,468		18,559		323,166		61,064		(23,050)		1,553,651
Capital Expenditures:
Nine Months Ended September 30, 2013	$	79,637	$	9,423	$	-	$	3,032	$	-	$	-	$	92,092
Year ended Dec. 31, 2012		81,965		13,812		-		2,658		-		-		98,435

31

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 140,000 customers in Dane County, Wisconsin, including the city of Madison, and purchases and distributes natural gas to approximately 145,000 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.

Overview

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

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

·

Weather, and its impact on customer sales of electricity and gas,

·

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

·

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

·

Energy commodity prices,

·

Equity price risk pertaining to pension related assets,

·

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

·

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

·

Construction risk in connection with the Columbia environmental project,

and other factors listed in "Item 1A. Risk Factors" in our 2012 Annual Report on Form 10-K.

For the three months ended September 30, 2013, MGE Energy's earnings were $24.4 million or $1.05 per share compared to $23.6 million or $1.02 per share for the same period in the prior year. MGE's earnings for both the three months ended September 30, 2013 and 2012, were $17.5 million.

For the nine months ended September 30, 2013, MGE Energy's earnings were $60.8 million or $2.63 per share compared to $54.0 million or $2.33 per share for the same period in the prior year. MGE's earnings for the nine months ended September 30, 2013, were $40.3 million compared to $35.9 million for the same period in the prior year.

32

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

(In thousands)		Three Months Ended September 30,				Nine Months Ended September 30,
Business Segment:		2013		2012		2013		2012
Electric Utility	$	19,005	$	19,654	$	33,107	$	34,721
Gas Utility		(1,247)		(1,882)		8,030		1,887
Nonregulated Energy		5,173		4,533		15,512		13,527
Transmission Investment		1,400		1,371		4,207		4,045
All Other		22		(34)		(28)		(220)
Net Income	$	24,353	$	23,642	$	60,828	$	53,960

Our net income during the three months ended September 30, 2013, primarily reflects the effects of the following factors:

·

Electric net income decreased due to a 2.7% decrease in electric retail sales reflecting lower customer demand. The decline in customer demand was driven by a return to more normal weather in 2013 compared to unusually warm weather in 2012. The average temperature in July 2013 was 71.9 degrees compared to 79.7 degrees in July 2012.

·

Gas net loss decreased due to a 4.3% increase in gas sales reflecting higher customer demand and lower operating and maintenance expenditures over the prior year.

·

Higher nonregulated revenues primarily attributable to approved recovery in December 2012 of force majeure costs associated with the construction of the Elm Road Units. The recovery of the force majeure costs began in 2013. A portion of the recovery pertaining to periods prior to the PSCW order will only affect 2013.

Our net income during the nine months ended September 30, 2013, primarily reflects the effects of the following factors:

·

Electric net income decreased due to a 1.9% decrease in electric retail sales reflecting lower customer demand. The decline in customer demand was driven by a return to more normal weather in 2013 compared to unusually warm weather in 2012. The average temperature in July 2013 was 71.9 degrees compared to 79.7 degrees in July 2012. In addition, operating and maintenance expenditures increased over the prior year driven by increased costs at Columbia.

·

Gas net income increased due to a 25.5% increase in gas sales reflecting higher customer demand due to a colder winter. Heating degree days (a measure for determining the impact of weather during the heating season) increased by 34% compared to the prior year. In addition, operating and maintenance expenditures decreased over the prior year.

·

Higher nonregulated revenues primarily attributable to approved recovery in December 2012 of force majeure costs associated with the construction of the Elm Road Units. The recovery of the force majeure costs began in 2013. A portion of the recovery pertaining to periods prior to the PSCW order will only affect 2013.

During the first nine months of 2013, the following events occurred:

Columbia Environmental Project: In early 2011, the PSCW authorized the construction of air emission reduction systems and associated equipment on Columbia Units 1 and 2. MGE's estimated share of the capital expenditures required to complete this project will be approximately $140 million. As of September 30, 2013, MGE has accumulated $113.6 million (excluding carrying costs) related to its share of the project, which is reflected in the Construction Work in Progress balance on MGE Energy's and MGE's consolidated balance sheets. Of this amount, MGE has accumulated $53.7 million in 2013. MGE has recognized $1.9 million (after tax) in AFUDC equity related to this project for the nine months ended September 30, 2013.

Credit Facilities: In late June 2013, we amended the existing credit facilities at MGE Energy and MGE to increase the aggregate commitments available thereunder to $50 million and $100 million, respectively, to extend the maturity date of each facility to July 31, 2017, and to lower the adders used in the determination of the interest rates applicable to credit extensions under those facilities. See "Credit Facilities" under "Contractual Obligations and Commercial Commitments" below.

33

Long-term Debt: In September 2013, MGE issued $30 million of its 3.09% senior notes and $15 million of its 3.29% senior notes. The notes will mature on September 15, 2023 and September 15, 2026, respectively. The proceeds of the notes are expected to be used to help finance the Columbia environmental project. See "Long-term Debt" under "Contractual Obligations and Commercial Commitments" below for more information.

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

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

Environmental Initiatives: There are proposed legislation, rules, and initiatives involving matters related to air emissions, water effluent, hazardous materials, and greenhouse gases, all of which affect generation plant capital expenditures and operating costs as well as future operational planning. Such legislation and rulemaking could significantly affect the costs of owning and operating fossil-fueled generating plants, such as Columbia and Elm Road, from which we derive approximately 45% of our electric generating capacity. We would expect to seek and receive recovery of any such costs in rates; however, it is difficult to estimate the amount of such costs due to the uncertainty as to the timing and form of the legislation and rules, and the scope and time of the recovery of costs in rates. In addition, the Columbia owners, including MGE, resolved claims surrounding the alleged failure, among other things, to obtain necessary air permits and implement necessary emission controls associated with past activities at Columbia. See Columbia discussion in Footnote 8.a. in Notes to Consolidated Financial Statements.

Columbia Environmental Project: MGE's share of the capital expenditures associated with the Columbia environmental project will be approximately $12 million for the remainder of 2013 million and $14 million in 2014. We intend to fund any remaining capital commitments with funds generated from normal operations and the issuance of long-term and short-term debt. See "Long-Term Debt" under "Contractual Obligations and Commercial Commitments" below for more information.

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, 2013, there were no borrowings outstanding under our lines of credit.

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

Three Months Ended September 30, 2013 and 2012

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:

(In thousands, except cooling degree days)		Revenues				Sales (kWh)
		Three Months Ended September 30,				Three Months Ended September 30,
		2013		2012	% Change	2013	2012	% Change
Residential	$	40,578	$	42,652	(4.9)%	238,046	264,217	(9.9)%
Commercial		62,582		60,317	3.8 %	502,924	507,696	(0.9)%
Industrial		5,612		5,468	2.6 %	66,366	65,994	0.6 %
Other-retail/municipal		11,952		11,356	5.2 %	123,221	118,548	3.9 %
Total retail		120,724		119,793	0.8 %	930,557	956,455	(2.7)%
Sales to the market		465		390	19.2 %	8,038	2,802	186.9 %
Adjustments to revenues		(1,353)		(1,269)	(6.6)%	-	-	- %
Total	$	119,836	$	118,914	0.8 %	938,595	959,257	(2.2)%
Cooling degree days (normal 474)						517	729	(29.1)%

34

Electric operating revenues increased $0.9 million or 0.8% for the three months ended September 30, 2013, due to the following:

(In millions)
Rate changes	$	4.1
Volume		(3.2)
Sales to the market		0.1
Adjustments to revenues		(0.1)
Total	$	0.9

·

Rate changes. Rates charged to retail customers for the three months ended September 30, 2013, were 3.6% or $4.1 million higher than those charged during the same period in the prior year.

In December 2012, the PSCW authorized MGE to increase 2013 rates for retail electric customers by 3.8% or $14.9 million. The increase in retail electric rates was driven by costs for new environmental equipment at Columbia, final construction costs for the Elm Road Units, transmission reliability enhancements, and purchased power costs.

·

Volume. During the three months ended September 30, 2013, there was a 2.7% decrease in total retail sales volumes compared to the same period in the prior year driven by a return to more normal weather in 2013 compared to unusually warm weather in 2012.

·

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.

·

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

Electric fuel and purchased power

The expense for fuel for electric generation decreased $2.4 million or 14.9% during the three months ended September 30, 2013, compared to the same period in the prior year. Internal electric generated volume delivered to the system decreased 6.1%, which resulted in $1.0 million of decreased expense. Internal electric generation costs decreased $1.4 million as a result of a 9.4% decrease in the per-unit cost (largely due to lower Elm Road and Columbia coal costs).

Excluding the fuel rules adjustments discussed below, purchased power expense increased $3.1 million, compared to the same period in the prior year. This increase in expense reflects a $1.2 million or 7.6% increase in the volume of power purchased from third parties and an increase of $1.9 million or 11.7% increase in the per-unit cost of purchased power.

Based on PSCW 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. During the three months ended September 30, 2013 and 2012, MGE's actual fuel costs fell below the lower end of this tolerance band, which resulted in MGE deferring $4.0 million and $3.2 million, respectively, in fuel-related cost savings to be returned to customers and MGE recording a corresponding increase in purchased power costs. Any over/under recovery of the deferred costs is determined on an annual basis and adjusted in future billings to customers. After combining the fuel rules adjustments with the actual savings discussed above, purchased power expense increased $3.9 million ($3.1 million increase discussed above plus $0.8 million fuel rules difference) during the three months ended September 30, 2013, compared to the prior year.

35

Electric operating and maintenance expenses

Electric operating and maintenance expenses increased $0.1 million during the three months ended September 30, 2013, compared to the same period in 2012. The following changes contributed to the net change:

(In millions)
Increased transmission costs	$	1.0
Increased production expenses		0.4
Increased distribution expenses		0.4
Increased other costs		0.2
Decreased customer service costs		(0.2)
Decreased administrative and general costs		(1.7)
Total	$	0.1

For the three months ended September 30, 2013, increased transmission costs are primarily due to an increase in transmission reliability enhancements. A decrease in administrative and general costs is primarily due to decreased pension costs.

Gas Utility Operations - MGE Energy and MGE

Gas deliveries and revenues

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

(In thousands, except HDD and average rate per therm of retail customer)		Revenues				Therms Delivered
		Three Months Ended September 30,				Three Months Ended September 30,
		2013		2012	% Change	2013	2012	% Change
Residential	$	8,794	$	8,004	9.9 %	5,676	5,658	0.3 %
Commercial/Industrial		9,343		7,960	17.4 %	17,789	17,175	3.6 %
Total retail		18,137		15,964	13.6 %	23,465	22,833	2.8 %
Gas transportation		593		515	15.1 %	6,937	6,310	9.9 %
Other revenues		134		108	24.1 %	-	-	- %
Total	$	18,864	$	16,587	13.7 %	30,402	29,143	4.3 %
Heating degree days (normal 177)						157	212	(25.9)%
Average rate per therm of
retail customer	$	0.773	$	0.699	10.6 %

Gas revenues increased $2.3 million or 13.7% for the three months ended September 30, 2013. These changes are related to the following factors:

(In millions)
Gas costs/rates	$	1.7
Gas deliveries		0.4
Transportation and other effects		0.2
Total	$	2.3

·

Gas costs/rates. The average retail rate per therm for the three months ended September 30, 2013, increased 10.6% compared to the same period in 2012, reflecting higher natural gas commodity costs.

·

Retail gas deliveries. For the three months ended September 30, 2013, retail gas deliveries increased 2.8% compared to the same period in 2012 as a result of increased demand in the commercial/industrial sector.

Cost of gas sold

For the three months ended September 30, 2013, cost of gas sold increased by $1.4 million, compared to the same period in the prior year. The cost per therm of natural gas increased 15.9%, which resulted in $1.2 million of increased expense. In addition, the volume of gas purchased increased 3.0%, which resulted in $0.2 million of increased expense.

36

Gas operating and maintenance expenses

Gas operating and maintenance expenses decreased by $0.9 million for the three months ended September 30, 2013, compared to the same period in 2012. The following changes contributed to the net change:

(In millions)
Decreased administrative and general costs	$	(0.8)
Decreased customer service costs		(0.3)
Increased customer accounts costs		0.2
Total	$	(0.9)

For the three months ended September 30, 2013, decreased administrative and general costs are primarily due to decreased pension costs.

Nonregulated Energy Operations - MGE Energy and MGE

For the three months ended September 30, 2013 and 2012, net income at the nonregulated energy operations segment was $5.2 million and $4.5 million, respectively. The nonregulated energy operations are conducted through MGE Energy's subsidiaries: MGE Power Elm Road and MGE Power West Campus. These subsidiaries have been formed to construct, own and lease electric generating capacity to assist MGE.

Results for the three months ended September 30, 2013, reflect the recovery of force majeure costs associated with the construction of the Elm Road Units. In December 2012, as part of WEPCO's (the operator and primary owner of the Elm Road Units) 2013 Wisconsin rate case, the PSCW determined that 100% of the construction costs for the Elm Road Units were prudently incurred, and approved the recovery in rates of more than 99.5% of these costs. The recovery of the force majeure costs began in 2013. A portion of the recovery pertaining to periods prior to the PSCW order will only affect 2013.

Transmission Investment Operations - MGE Energy and MGE

Transmission investment other income

For both the three months ended September 30, 2013 and 2012, other income at the transmission investment segment was $2.3 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 Notes to Consolidated Financial Statements for additional information concerning ATC and summarized financial information regarding ATC.

Consolidated Income Taxes - MGE Energy and MGE

MGE Energy's and MGE's effective income tax rate for both the three months ended September 30, 2013 and 2012, was 37.6%.

Noncontrolling Interest, Net of Tax - MGE

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

		Three Months Ended September 30,
(In millions)		2013		2012
MGE Power Elm Road	$	4.3	$	3.7
MGE Power West Campus		1.9		1.9
MGE Transco		0.6		0.6

37

Nine Months Ended September 30, 2013 and 2012

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:

(In thousands, except cooling degree days)		Revenues				Sales (kWh)
		Nine Months Ended September 30,				Nine Months Ended September 30,
		2013		2012	% Change	2013	2012	% Change
Residential	$	104,020	$	102,481	1.5 %	624,877	646,238	(3.3)%
Commercial		164,024		160,309	2.3 %	1,382,151	1,400,390	(1.3)%
Industrial		15,283		15,130	1.0 %	189,882	191,363	(0.8)%
Other-retail/municipal		30,322		29,886	1.5 %	326,717	334,097	(2.2)%
Total retail		313,649		307,806	1.9 %	2,523,627	2,572,088	(1.9)%
Sales to the market		682		1,144	(40.4)%	22,052	25,760	(14.4)%
Adjustments to revenues		(4,155)		(3,761)	(10.5)%	-	-	- %
Total	$	310,176	$	305,189	1.6 %	2,545,679	2,597,848	(2.0)%
Cooling degree days (normal 656)						707	1,065	(33.6)%

Electric operating revenues increased $5.0 million or 1.6% for the nine months ended September 30, 2013, due to the following:

(In millions)
Rate changes	$	11.6
Volume		(5.8)
Sales to the market		(0.5)
Adjustments to revenues		(0.3)
Total	$	5.0

·

Rate changes. Rates charged to retail customers for the nine months ended September 30, 2013, were 3.9% or $11.6 million higher than those charged during the same period in the prior year.

In December 2012, the PSCW authorized MGE to increase 2013 rates for retail electric customers by 3.8% or $14.9 million. The increase in retail electric rates was driven by costs for new environmental equipment at Columbia, final construction costs for the Elm Road Units, transmission reliability enhancements, and purchased power costs.

·

Volume. During the nine months ended September 30, 2013, there was a 1.9% decrease in total retail sales volumes compared to the same period in the prior year driven by a return to more normal weather in 2013 compared to unusually warm weather in 2012.

·

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.

·

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

Electric fuel and purchased power

The expense for fuel for electric generation decreased $2.2 million or 6.0% during the nine months ended September 30, 2013, compared to the same period in the prior year. Internal electric generated volume delivered to the system decreased 1.9%, which resulted in $0.7 million of decreased expense. Internal electric generation costs decreased $1.5 million as a result of a 4.2% decrease in the per-unit cost (largely due to lower Elm Road and Columbia coal costs).

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Excluding the fuel rules adjustments discussed below, purchased power expense increased $7.8 million during the nine months ended September 30, 2013, compared to the same period in the prior year. This increase in expense reflects an $8.8 million or 18.3% increase in the per-unit cost of purchased power, partially offset by a $1.0 million or 2.2% decrease in the volume of power purchased from third parties.

Based on PSCW 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. During the nine months ended September 30, 2013 and 2012, MGE's actual fuel costs fell below the lower end of this tolerance band, which resulted in MGE deferring $4.4 million and $5.9 million, respectively, in fuel-related cost savings to be returned to customers and MGE recording a corresponding increase in purchased power costs. Any over/under recovery of the deferred costs is determined on an annual basis and adjusted in future billings to customers. After combining the fuel rules adjustments with the actual savings discussed above, purchased power expense increased $6.3 million ($7.8 million increase discussed above less $1.5 million fuel rules difference) during the nine months ended September 30, 2013, compared to the prior year.  

Electric operating and maintenance expenses

Electric operating and maintenance expenses increased $1.3 million during the nine months ended September 30, 2013, compared to the same period in 2012. The following changes contributed to the net change:

(In millions)
Increased transmission costs	$	2.5
Increased production costs		2.2
Increased distribution costs		0.8
Increased customer accounts costs		0.2
Decreased customer services costs		(0.9)
Decreased administrative and general costs		(3.5)
Total	$	1.3

For the nine months ended September 30, 2013, increased transmission costs are due to an increase in transmission reliability enhancements and increased production costs are primarily due to increased costs at Columbia. Decreased administrative and general costs are primarily due to decreased pension costs and decreased customer service costs are due to lower energy conservation spending.

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:

(In thousands, except HDD and average rate per therm of retail customer)		Revenues				Therms Delivered
		Nine Months Ended September 30,				Nine Months Ended September 30,
		2013		2012	% Change	2013	2012	% Change
Residential	$	66,034	$	51,620	27.9 %	67,181	51,246	31.1 %
Commercial/Industrial		52,758		38,521	37.0 %	89,836	72,743	23.5 %
Total retail		118,792		90,141	31.8 %	157,017	123,989	26.6 %
Gas transportation		2,181		1,744	25.1 %	27,048	22,726	19.0 %
Other revenues		400		350	14.3 %	-	-	- %
Total	$	121,373	$	92,235	31.6 %	184,065	146,715	25.5 %
Heating degree days (normal 4,500)						4,799	3,581	34.0 %
Average Rate Per Therm of
Retail Customer	$	0.757	$	0.727	4.1 %

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Gas revenues increased $29.1 million or 31.6% for the nine months ended September 30, 2013. These changes are related to the following factors:

(In millions)
Gas deliveries	$	24.0
Gas costs/rates		4.6
Transportation and other effects		0.5
Total	$	29.1

·

Retail gas deliveries. For the nine months ended September 30, 2013, retail gas deliveries increased 26.6% compared to the same period in 2012, as a result of colder weather during the winter months compared to milder weather in the prior year.

·

Gas costs/rates. The average retail rate per therm for the nine months ended September 30, 2013, increased 4.1% compared to the same period in 2012, reflecting higher natural gas commodity costs.

Cost of gas sold

For the nine months ended September 30, 2013, cost of gas sold increased by $20.2 million, compared to the same period in the prior year. The volume of purchased gas increased 27.0%, which resulted in $13.5 million of increased expense. In addition, the cost per therm of natural gas increased 10.6%, which resulted in $6.7 million of increased expense.

Gas operating and maintenance expenses

Gas operating and maintenance expenses decreased by $2.5 million for the nine months ended September 30, 2013, compared to the same period in 2012. The following changes contributed to the net change:

(In millions)
Decreased administrative and general costs	$	(1.8)
Decreased customer service costs		(1.0)
Increased distribution costs		0.2
Increased customer accounts costs		0.1
Total	$	(2.5)

For the nine months ended September 30, 2013, decreased administrative and general costs are primarily due to decreased pension costs and decreased customer service costs are due to lower energy conservation spending.

Nonregulated Energy Operations - MGE Energy and MGE

For the nine months ended September 30, 2013 and 2012, net income at the nonregulated energy operations segment was $15.5 million and $13.5 million, respectively. The nonregulated energy operations are conducted through MGE Energy's subsidiaries: MGE Power, MGE Power Elm Road and MGE Power West Campus. These subsidiaries have been formed to construct, own and lease electric generating capacity to assist MGE.

Results for the nine months ended September 30, 2013, reflect the recovery of force majeure costs associated with the construction of the Elm Road Units. In December 2012, as part of WEPCO's (the operator and primary owner of the Elm Road Units) 2013 Wisconsin rate case, the PSCW determined that 100% of the construction costs for the Elm Road Units were prudently incurred, and approved the recovery in rates of more than 99.5% of these costs. The recovery of the force majeure costs began in 2013. A portion of the recovery pertaining to periods prior to the PSCW order will only affect 2013.

Transmission Investment Operations - MGE Energy and MGE

Transmission investment other income

For the nine months ended September 30, 2013 and 2012, other income at the transmission investment segment was $7.0 million and $6.8 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 for additional information concerning ATC and summarized financial information regarding ATC.

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Consolidated Income Taxes - MGE Energy and MGE

MGE Energy's and MGE's effective income tax rate for the nine months ended September 30, 2013, was 37.8% compared to 37.7% for the same period in 2012.

Noncontrolling Interest, Net of Tax - MGE

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

		Nine Months Ended September 30,
(In millions)		2013		2012
MGE Power Elm Road	$	13.0	$	11.1
MGE Power West Campus		5.7		5.6
MGE Transco		1.8		1.6

Contractual Obligations and Commercial Commitments - MGE Energy and MGE

There were no material changes, other than from the normal course of business, to MGE Energy's and MGE's contractual obligations (representing cash obligations that are considered to be firm commitments) and commercial commitments (representing commitments triggered by future events) during the nine months ended September 30, 2013, except as noted below. Further discussion of the contractual obligations and commercial commitments is included in Footnote 8 of Notes to Consolidated Financial Statements in this Report, and Footnote 18 of Notes to Consolidated Financial Statements, and "Contractual Obligations and Commercial Commitments for MGE Energy and MGE" under "Management's Discussion and Analysis of Financial Condition and Results of Operations" in MGE Energy's and MGE's 2012 Annual Report on Form 10-K.

Purchase Contracts - MGE Energy and MGE

See Footnote 8.d. of Notes to Consolidated Financial Statements for a description of commitments at September 30, 2013, that MGE Energy and MGE have entered with respect to various commodity supply, transportation, and storage contracts to meet their obligations to deliver electricity and natural gas to customers.

Credit Facilities - MGE Energy and MGE

As of September 30, 2013, MGE Energy and MGE had bank lines of credit under committed credit facilities as follows:

(In millions)		Aggregate Bank Commitments	Expiration Date
MGE Energy	$	50.0	July 31, 2017
MGE	$	100.0	July 31, 2017

The credit agreements for both of MGE Energy and MGE carry interest at either (i) a "floating rate," plus an adder ranging from zero to 0.125%, depending upon the credit ratings assigned to MGE's senior unsecured long-term debt securities; or (ii) a "Eurodollar Rate," plus an adder ranging from 0.675% to 1.125%, depending 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 "Eurodollar Rate" is calculated as provided in the credit agreements for the selected interest period. As of September 30, 2013, neither MGE Energy nor MGE had any borrowings outstanding under their respective credit agreements and MGE had no commercial paper outstanding.

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Long-term Debt - MGE Energy and MGE

MGE issued $85 million of senior unsecured notes during 2013 pursuant to a Note Purchase Agreement with several note purchasers, the proceeds of which were used to refinance $40 million of senior unsecured notes and to assist with the financing of the Columbia environmental project. See Footnote 2.d. of Notes to Consolidated Financial Statements for information regarding the notes that were issued and the notes that were redeemed.

Liquidity and Capital Resources

Cash Flows

The following summarizes cash flows for MGE Energy and MGE during the nine months ended September 30, 2013 and 2012:

		MGE Energy				MGE
(In thousands)		2013		2012		2013		2012
Cash provided by/(used for):
Operating activities	$	108,600	$	115,886	$	107,826	$	113,569
Investing activities		(94,177)		(68,188)		(93,835)		(67,955)
Financing activities		14,550		(29,664)		22,249		(29,976)

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, 2013, was $108.6 million, a decrease of $7.3 million when compared to the same period in the prior year primarily related to working capital changes.

MGE Energy's net income increased $6.9 million for the nine months ended September 30, 2013, when compared to the same period in the prior year.

Working capital accounts (excluding prepaid taxes) resulted in $2.8 million in cash provided by operating activities for the nine months ended September 30, 2013, primarily due to decreased accounts receivable and decreased unbilled revenues, partially offset by decreased accounts payable and increased gas inventories. Working capital accounts resulted in $1.1 million in cash used for operating activities for the nine months ended September 30, 2012, primarily due to decreased accounts payable, partially offset by decreased receivable - margin and decreased unbilled revenues.

An increase in pension contribution resulted in an additional $9.6 million in cash used for operating activities for the nine months ended September 30, 2013, when compared to the same period in the prior year. These contributions reflect amounts required by law and discretionary amounts.

During the nine months ended September 30, 2013, MGE paid a make-whole premium equal to $6.8 million related to the redemption of $40 million of long-term debt.

MGE

Cash provided by operating activities for the nine months ended September 30, 2013, was $107.8 million, a decrease of $5.7 million when compared to the same period in the prior year primarily related to working capital changes.

Net income increased $6.7 million for the nine months ended September 30, 2013, when compared to the same period in the prior year.

Working capital accounts (excluding prepaid taxes) resulted in $3.5 million in cash provided by operating activities for the nine months ended September 30, 2013, primarily due to decreased accounts receivable, decreased unbilled revenues, and increased current liabilities, partially offset by decreased accounts payable and increased gas inventories.

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Working capital accounts resulted in $1.9 million in cash used for operating activities for the nine months ended September 30, 2012, primarily due to decreased accounts payable, partially offset by decreased receivable - margin and decreased unbilled revenues.

An increase in pension contribution resulted in an additional $9.6 million in cash used for operating activities for the nine months ended September 30, 2013, when compared to the same period in the prior year. These contributions reflect amounts required by law and discretionary amounts.

During the nine months ended September 30, 2013, MGE paid a make-whole premium equal to $6.8 million related to the redemption of $40 million of long-term debt.

Cash Used for Investing Activities

MGE Energy

MGE Energy's cash used for investing activities increased $26.0 million for the nine months ended September 30, 2013, when compared to the same period in the prior year.

Capital expenditures for the nine months ended September 30, 2013, were $92.1 million. This amount represents an increase of $26.2 million from the expenditures made in the same period in the prior year. This increase is due primarily to $19.9 million of increased expenditures on the Columbia environmental project.

MGE

MGE's cash used for investing activities increased $25.9 million for the nine months ended September 30, 2013, when compared to the same period in the prior year.

Capital expenditures for the nine months ended September 30, 2013, were $92.1 million. This amount represents an increase of $26.2 million from the expenditures made in the same period in the prior year. This increase is due primarily to $19.9 million of increased expenditures on the Columbia environmental project.

Cash Provided by (Used for) Financing Activities

MGE Energy

Cash provided by MGE Energy's financing activities was $14.6 million for the nine months ended September 30, 2013, compared to $29.7 million of cash used for the nine months ended September 30, 2012.

For the nine months ended September 30, 2013, dividends paid were $27.7 million compared to $26.8 million in the prior year. This increase was a result of a higher dividend per share ($1.198 vs. $1.161).

During the nine months ended September 30, 2013, MGE issued $85 million of long-term debt, which was used to retire $40 million of long-term debt and to assist with the funding for the Columbia environmental project. During the nine months ended September 30, 2012, MGE issued and retired $28.0 million of long-term debt.

MGE

During the nine months ended September 30, 2013, cash provided by MGE's financing activities was $22.2 million compared to $30.0 million of cash used for MGE's financing activities in the prior year.

Dividends paid from MGE to MGE Energy were $13.5 million during the nine months ended September 30, 2012.

During the nine months ended September 30, 2013, MGE issued $85 million of long-term debt, which was used to retire $40 million of long-term debt and to assist with the funding for the Columbia environmental project. During the nine months ended September 30, 2012, MGE issued and retired $28.0 million of long-term debt.

Distributions to parent from noncontrolling interest, which represent distributions from MGE Power Elm Road and MGE Power West Campus, were $21.1 million for the nine months ended September 30, 2013, compared to $15.5 million in the prior year.

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Capitalization Ratios

MGE Energy's capitalization ratios were as follows:

	MGE Energy
	September 30, 2013	December 31, 2012
Common shareholders' equity	60.2 %	61.6 %
Long-term debt*	39.8 %	38.4 %
*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, 2013, capital expenditures for MGE Energy and MGE totaled $92.1 million, which included $89.1 million of capital expenditures for utility operations.

In early 2011, the PSCW authorized the construction of air emission reduction systems and associated equipment on Columbia Units 1 and 2. MGE's estimated share of the capital expenditures required to complete this project will be approximately $140 million. MGE's share of the capital expenditures associated with the Columbia environmental project will be approximately $12 million for the remainder of 2013 and $14 million in 2014. During the nine months ended September 30, 2013, MGE had incurred $53.7 million (excluding carrying costs) in construction expenditures at Columbia related to the project. MGE has recognized $1.9 million (after tax) in AFUDC equity related to this project for the nine months ended September 30, 2013.

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, 2013. Further discussion of environmental matters is included in MGE Energy's and MGE's 2012 Annual Report on Form 10-K and Footnote 8.a. of Notes to Consolidated Financial Statements in this Report.

Vacation of EPA's Cross State Air Pollution Rule (CSAPR) and Reinstatement of the Clean Air Interstate Rule (CAIR)

In 2005, EPA promulgated the Clean Air Interstate Rule (CAIR) to reduce ozone and fine particulate matter emissions by reducing nitrogen oxide (NO_x) and sulfur dioxide (SO₂) emissions. NO_x and SO₂ interact in the atmosphere to form ambient ozone from NO_x and fine particulate matter pollution from NO_x and SO₂. The CAIR generally requires NO_x and SO₂ emission reductions from fossil fuel-fired EGUs (25 MW or greater) in the eastern half of the United States in two phases and includes a regional cap-and-trade system. The first phase (currently in place) requires annual regional emission reductions from 2003 levels of 55% for NO_x and 40% for SO₂. The second phase (beginning in 2015) reduces regional NO_x and SO₂ emissions further from 2003 levels to 65% and 70%, respectively. MGE owns or has partial ownership in several generation units currently subject to the CAIR: Blount, Columbia, Elm Road Units, and its combustion turbines located in West Marinette and Fitchburg.

In December 2008, the U.S. Court of Appeals for the D.C. Circuit remanded the CAIR to the EPA with directions to revise or replace the rule. The Court's remand order directed that the CAIR remain in effect until the EPA promulgated a replacement rule. The Court's order did not include a deadline for the EPA to act.

In August 2011, the EPA responded to the remand of the CAIR by promulgating the Cross State Air Pollution Rule (CSAPR). In August 2012, a federal appellate court vacated CSAPR and instructed the EPA to continue administering the CAIR pending finalizing a valid alternative program to control interstate pollution. That appellate decision is scheduled to be reviewed by the U.S. Supreme Court. At this time, the CAIR remains effective.

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MGE is currently in compliance with the CAIR Phase I requirements. In addition MGE will be able to meet Phase II NO_x emissions reductions through using our NO_x allowances provided under the rule, and we will meet Phase II SO₂ emissions reductions through installation of pollution controls. New SO₂ controls at Columbia are already underway and are planned to be completed by mid-2014. MGE expects that any costs incurred to meet Phase II of the CAIR will be fully recoverable through rates. MGE will monitor the Supreme Court's response to the CSAPR appeals and any subsequent actions by the EPA to continue to evaluate potential impacts to our operations.

Greenhouse Gas Regulation

President Obama's Executive Order Regarding Climate Change and his Directive to the EPA Regarding Power Sector Pollution Standards

In June 2013, President Obama introduced his "National Climate Action Plan." The plan consists of planned federal actions and directives to several federal agencies, including the EPA, on a range of activities and policies designed to reduce greenhouse gas emissions in the United States. The directive to the EPA, which President Obama provided to the EPA in a memo, to develop carbon pollution standards for the electric power sector, has the greatest potential effect on MGE's operations. See the GHG New Performance Standards discussion below for additional details.

GHG New Source Performance Standards (NSPS)

In a June 2013 directive, President Obama instructed the EPA to re-propose greenhouse gas standards for new power plants by September 20, 2013, based on comments received on their original rule proposal issued in March 2012, and to finalize those standards in a timely manner. The EPA met the President's directive and published revised proposed standards for new power plants in September 2013, that would require, if finalized, that new coal-fired units and small natural gas units meet carbon dioxide emission levels significantly below current levels.

The June 2013 directive also instructed the EPA to propose standards, regulations or guidelines for modified, reconstructed and existing power plants under Sections 111(b) and 111(d) of the Clean Air Act no later than June 2014 and to finalize those standards by June 2015. The directive further instructs the EPA to require states to submit implementation plans for this rule by June 30, 2016. The Directive asks the EPA to aim to develop a market-based approach towards carbon reduction, promote cleaner technologies while keeping energy options diverse, work with other government agencies to keep energy affordable and improve energy efficiencies, and engage States, the power industry, and the other key stakeholders in establishing and implementing strategies for greenhouse gas reductions.

While it is too early to predict with any certainty the specific costs that MGE will incur with implementation of a greenhouse gas reduction rule introduced under Section 111 of the Clean Air Act, it is reasonable to assume that costs of implementation of this rule could be significant depending on the approach taken. We will continue to monitor developments.

Columbia

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 alleges 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. Based on a preliminary estimate received by WPL, MGE's share of the projected cost for construction of the SCR system at Columbia is approximately $50-$60 million. See Footnote 8.a. of Notes to Consolidated Financial Statements for additional information regarding these matters.

New Accounting Principles

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

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Item 3. Quantitative and Qualitative Disclosures About Market Risk.

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

Commodity Price Risk

MGE has commodity price risk exposure with respect to the price of natural gas, electricity, coal, emission credits, and oil. MGE employs established policies and procedures to reduce the market risks associated with changing commodity prices. MGE's commodity risks are somewhat mitigated by the current ratemaking process in place for recovering electric fuel cost, purchased energy costs, and the cost of natural gas. MGE's electric fuel costs are subject to fuel rules established by the PSCW.

MGE's electric operations burn natural gas in several of its peaking power plants and, in many cases, the cost of purchased power is tied to the cost of natural gas. MGE bears regulatory risk for the recovery of such fuel and purchased power costs when they are higher than the base rate established in its current rate structure.

The fuel rules require the PSCW and Wisconsin utilities to defer electric fuel-related costs that fall outside a symmetrical cost tolerance band. Any over/under recovery of the actual costs is determined on an annual basis and will be adjusted in future billings to electric retail customers. Under the electric fuel rules, MGE is required to defer the benefit of lower costs if the actual electric fuel rules costs fall outside the lower end of the range and would defer costs, less any excess revenues, if the actual electric fuel rules costs exceeded the upper end of the range. Excess revenues are defined as revenues in the year in question that provide MGE with a greater return on common equity than authorized by the PSCW in MGE's latest rate order. The range is defined by the PSCW and has been modified throughout the years based on market conditions and other relevant factors. Currently, MGE is subject to a plus or minus 2% range. MGE assumes the risks and benefits of variances that are within the cost tolerance band. For 2013 and 2014, fuel and purchased power costs included in MGE's base fuel rates are $106.1 million. See Footnote 10.b. of 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, 2013, the fair value of these instruments exceeded their cost basis by $0.9 million. Under the PGA clause and electric fuel rules, MGE may include in the costs of fuel (natural gas or power) the costs and benefits of the aforementioned fuel price risk management tools. Because these costs/benefits are recoverable, the related unrealized loss/gain has been deferred on the consolidated balance sheet as a regulatory asset/liability.

MGE has also entered into a ten-year purchased power agreement that provides MGE with firm capacity and energy that began on June 1, 2012, and ends on May 31, 2022 (the "base term"). The agreement also allows MGE the option to extend the contract after the base term. The agreement is 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, 2013, reflects a loss position of $69.0 million.

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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.

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, 2013, 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 1,631 square miles in Wisconsin. Based on results for the year ended December 31, 2012, 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.

47

Item 4. Controls and Procedures.

During the third quarter of 2013, 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, 2013, 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, 2013, 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. The registrants did implement a new income tax and asset accounting system to track plant, property, and equipment. The change is not expected to have any material effect on the registrants' internal control over financial reporting.

48

PART II. OTHER INFORMATION.

Item 1. Legal Proceedings.

MGE Energy and MGE

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

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

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

Issuer Purchases of Equity Securities

Period	Total Number of Shares Purchased		Average Price Paid per Share	Total Number of Shares Purchased as Part of Publicly Announced Plans or Programs*	Maximum number (or Approximate Dollar Value) of Shares That May Yet Be Purchased Under the Plans or Programs*
July 1-31, 2013	19,320	$	57.12	-	-
August 1-31, 2013	25,612		57.51	-	-
September 1-30, 2013	67,290		52.68	-	-
Total	112,222	$	54.55	-	-

* 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, 2013, 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

49

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, 2013, 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

50

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 7, 2013	/s/ Gary J. Wolter
	Gary J. Wolter Chairman, President and Chief Executive Officer (Duly Authorized Officer)
Date: November 7, 2013	/s/ Jeffrey C. Newman
	Jeffrey C. Newman Vice President, Chief Financial Officer, Secretary and Treasurer (Chief Financial and Accounting Officer)

51

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 7, 2013	/s/ Gary J. Wolter
	Gary J. Wolter Chairman, President and Chief Executive Officer (Duly Authorized Officer)
Date: November 7, 2013	/s/ Jeffrey C. Newman
	Jeffrey C. Newman Vice President, Chief Financial Officer, Secretary and Treasurer (Chief Financial and Accounting Officer)

52

EX-12

EXHIBIT 12

Madison Gas and Electric Company

Ratio of Earnings to Fixed Charges

Nine Months Ended September 30, 2013

(In thousands)

Earnings
Net income before minority interest	$60,856
Equity earnings	(7,045)
Income distribution from equity investees	5,498
Minority interest in pre-tax income	(2,981)
Amortization of capitalized interest	395
Federal and state income taxes	37,039
Fixed charges	15,373
Total Earnings as Defined	$109,135
Fixed Charges
Interest expense on long-term debt and other	$13,509
Interest on rentals*	647
Amortization of debt issuance costs	499
AFUDC - borrowed funds	718
Total Fixed Charges	$15,373
Ratio of Earnings to Fixed Charges	7.10X

*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 7, 2013

EX-31

EXHIBIT 31.2

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

I, Jeffrey C. Newman, certify that:

1.

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

2.

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

3.

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

4.

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

(a)

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

(b)

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

(c)

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

(d)

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

5.

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

(a)

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

(b)

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

/s/ Jeffrey C. Newman

Jeffrey C. Newman

Vice President, Chief Financial Officer,

Secretary and Treasurer

Date: November 7, 2013

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 7, 2013

EX-31

EXHIBIT 31.4

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

I, Jeffrey C. Newman, certify that:

1.

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

2.

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

3.

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

4.

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

(a)

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

(b)

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

(c)

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

(d)

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

5.

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

(a)

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

(b)

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

s/ Jeffrey C. Newman

Jeffrey C. Newman

Vice President, Chief Financial Officer,

Secretary and Treasurer

Date: November 7, 2013

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, 2013, 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 7, 2013

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, 2013, as filed with the Securities and Exchange Commission on the date hereof ("the Report"), I, Jeffrey C. Newman, Chief Financial Officer of the Company, certify, pursuant to 18 U.S.C. Section 1350, as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002, that:

1.

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

2.

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

/s/ Jeffrey C. Newman

Jeffrey C. Newman

Vice President, Chief Financial Officer,

Secretary and Treasurer

Date: November 7, 2013

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, 2013, 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 7, 2013

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, 2013, as filed with the Securities and Exchange Commission on the date hereof ("the Report"), I, Jeffrey C. Newman, Chief Financial Officer of the Company, certify, pursuant to 18 U.S.C. Section 1350, as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002, that:

1.

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

2.

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

/s/ Jeffrey C. Newman

Jeffrey C. Newman

Vice President, Chief Financial Officer,

Secretary and Treasurer

Date: November 7, 2013

XML

Columbia Environmental Project Construction

9 Months Ended

Sep. 30, 2013

Regulated Operations [Abstract]

Columbia Environmental Project Construction

4.       Columbia Environmental Project Construction - MGE Energy and MGE.

MGE and two other utilities jointly own Columbia, a coal-fired generating facility. WPL is the plant operator and permit holder, and owns 46.2% of Columbia. WPSC owns a 31.8% interest, and MGE owns a 22% interest, in Columbia. In early 2011, the PSCW issued a Certificate and Order authorizing the construction of scrubbers and bag houses and associated equipment on Columbia Units 1 and 2 to reduce SO2 and mercury emissions. The scrubbers and bag houses are expected to support compliance obligations for current and anticipated air quality regulations, including CAIR, CAIR's eventual replacement, the Mercury and Air Toxics Standards (MATS), and the Wisconsin Mercury Rule. The operator's current estimate shows that MGE's share of the capital expenditures required for this project is approximately $140 million. As of September 30, 2013, MGE had accumulated $113.6 million (excluding carrying costs) related to its share of the project, which is reflected in the Construction Work in Progress balance on MGE Energy's and MGE's consolidated balance sheets. MGE's share of the capital expenditures associated with the Columbia environmental project is expected to be approximately $12million for the remainder of 2013 and $14 million in 2014. These amounts may change as a result of modifications to the project estimate or timing differences. MGE's share of various contractual commitments entered for the project as of September 30, 2013 is $24.4 million. For the three months endedSeptember 30, 2013 and 2012,MGE has recognized after tax $0.8 millionand $0.4 million, respectively, in AFUDC equity related to this project. For the nine months endedSeptember 30, 2013 and 2012, MGE has recognized after tax $1.9 million and $0.7 million, respectively, in AFUDC equity related to this project.

MGE expects that the costs pertaining to this project will be fully recoverable through rates. For 2012, the PSCW authorized MGE 100% AFUDC on this project during construction. Beginning in 2013, similar to MGE's other utility construction projects, the PSCW authorized MGE a 50% current return (included in customer rates) and the remaining 50% as AFUDC.

XML

Consolidated Balance Sheets (Unaudited) (Parentheticals) (USD $) In Thousands, unless otherwise specified	Sep. 30, 2013	Dec. 31, 2012
Receivables, Net
Reserve for uncollectible accounts receivable	$ 3,959	$ 3,885
Reserve for uncollectible other accounts receivable	822	931
MGE [Member]
Receivables, Net
Reserve for uncollectible accounts receivable	3,959	3,885
Reserve for uncollectible other accounts receivable	$ 822	$ 931

XML

Fair Value of Financial Instruments

9 Months Ended

Sep. 30, 2013

Fair Value Disclosures [Abstract]

Fair Value of Financial Instruments

11.       Fair Value of Financial Instruments - MGE Energy and MGE.

Fair value is defined as the price that would be received to sell an asset or would be paid to transfer a liability (an exit price) in the principal or most advantageous market for the asset or liability in an orderly transaction between market participants at the measurement date. The standard clarifies that fair value should be based on the assumptions market participants would use when pricing the asset or liability including assumptions about risk. The standard also establishes a three level fair value hierarchy based upon the observability of the assumptions used and requires the use of observable market data when available. The levels are:

Level 1 - Pricing inputs are quoted prices within active markets for identical assets or liabilities.

Level 2 - Pricing inputs are quoted prices within active markets for similar assets or liabilities; quoted prices for identical or similar instruments in markets that are not active; and model-derived valuations that are correlated with or otherwise verifiable by observable market data.

Level 3 - Pricing inputs are unobservable and reflect management's best estimate of what market participants would use in pricing the asset or liability.

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

At September 30,2013 and December 31, 2012, the carrying amount of cash and cash equivalents approximates fair market value due to the short maturity of those investments and obligations. The estimated fair market value of MGE Energy's and MGE's long-term debt is based on quoted market prices for similar financial instruments at September 30,2013 and December 31, 2012. Since the 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, 2013				December 31, 2012
		Carrying		Fair		Carrying		Fair
(In thousands)		Amount		Value		Amount		Value
MGE Energy
Assets:
Cash and cash equivalents	$	75,330	$	75,330	$	46,357	$	46,357
Liabilities:
Long-term debt*		404,805		445,247		361,805		427,456
MGE
Assets:
Cash and cash equivalents		42,590		42,590		6,350		6,350
Liabilities:
Long-term debt*		404,805		445,247		361,805		427,456
*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, 2013
(In thousands)		Total		Level 1		Level 2		Level 3
MGE Energy
Assets:
Exchange-traded investments	$	613	$	613	$	0	$	0
Total Assets	$	613	$	613	$	0	$	0
Liabilities:
Derivatives, net	$	68,083	$	(245)	$	0	$	68,328
Deferred compensation		2,253		0		2,253		0
Total Liabilities	$	70,336	$	(245)	$	2,253	$	68,328
MGE
Assets:
Exchange-traded investments	$	246	$	246	$	0	$	0
Total Assets	$	246	$	246	$	0	$	0
Liabilities:
Derivatives, net	$	68,083	$	(245)	$	0	$	68,328
Deferred compensation		2,253		0		2,253		0
Total Liabilities	$	70,336	$	(245)	$	2,253	$	68,328
	Fair Value as of December 31, 2012
(In thousands)		Total		Level 1		Level 2		Level 3
MGE Energy
Assets:
Exchange-traded investments	$	320	$	320	$	0	$	0
Total Assets	$	320	$	320	$	0	$	0
Liabilities:
Derivatives, net	$	72,329	$	(17)	$	0	$	72,346
Deferred compensation		2,010		0		2,010		0
Total Liabilities	$	74,339	$	(17)	$	2,010	$	72,346
MGE
Assets:
Exchange-traded investments	$	117	$	117	$	0	$	0
Total Assets	$	117	$	117	$	0	$	0
Liabilities:
Derivatives, net	$	72,329	$	(17)	$	0	$	72,346
Deferred compensation		2,010		0		2,010		0
Total Liabilities	$	74,339	$	(17)	$	2,010	$	72,346

No transfers were made in or out of Level 1 or Level 2 for the nine months endedSeptember 30,2013.

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

Derivatives include exchange-traded derivative contracts, over-the-counter transactions, a ten-year purchased power agreement, and FTRs. Most exchange-traded derivative contracts are valued based on unadjusted quoted prices in active markets and are therefore classified as Level 1. A small number of exchange-traded derivative contracts are valued using quoted market pricing in markets with insufficient volumes and are therefore classified as Level 3. Transactions done with an over-the-counter party are on inactive markets and are therefore classified as Level 3. These transactions are valued based on quoted prices from markets with similar exchange traded transactions. FTRs are priced based upon monthly auction results for identical or similar instruments in a closed market with limited data available and are therefore classified as Level 3.

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

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

This model is prepared by members of MGE's Energy Supply group. It is reviewed on a quarterly basis by management in Energy Supply and Finance to review the assumptions, inputs, and fair value measurements.

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

Significant Unobservable Inputs	Model Input
Basis adjustment:
On peak	99.7%
Off peak	97.9%
Counterparty fuel mix:
Internal generation	50 % - 70 %
Purchased power	50 % - 30 %

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

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

		Three Months Ended				Nine Months Ended
		September 30,				September 30,
(In thousands)		2013		2012		2013		2012
Beginning balance,	$	(66,856)	$	(79,580)	$	(72,346)	$	(40,661)
Realized and unrealized gains (losses):
Included in regulatory liabilities (assets)		(1,472)		3,465		4,018		(35,455)
Included in other comprehensive income		0		0		0		0
Included in earnings		(174)		(3,422)		(2,034)		(6,659)
Included in current assets		(38)		0		(94)		(77)
Purchases		6,052		5,864		17,709		7,764
Sales		0		45		(2)		77
Issuances		0		0		0		0
Settlements		(5,840)		(2,487)		(15,579)		(1,104)
Transfers in and/or out of Level 3		0		0		0		0
Balance as of September 30,	$	(68,328)	$	(76,115)	$	(68,328)	$	(76,115)
Total gains (losses) included in earnings attributed to
the change in unrealized gains (losses) related to
assets and liabilities held at September 30,(a)	$	0	$	0	$	0	$	0

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(a).

		Three Months Ended				Nine Months Ended
		September 30,				September 30,
(In thousands)		2013		2012		2013		2012
Purchased Power Expense	$	(174)	$	(3,422)	$	(2,034)	$	(6,659)
Cost of Gas Sold Expense		0		0		0		0
Regulated Gas Revenues		0		0		0		0
Total	$	(174)	$	(3,422)	$	(2,034)	$	(6,659)

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

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Taxes

9 Months Ended

Sep. 30, 2013

Income Tax Disclosure [Abstract]

Taxes

5.Taxes - MGE Energy and MGE.

a.Accounting for Uncertainty in Income Taxes.

MGE Energy and MGE account for the difference between the tax benefit amount taken on prior year tax returns, or expected to be taken on a current year tax return, and the tax benefit amount recognized in the financial statements as an unrecognized tax benefit.

MGE Energy has adopted a tax method of accounting to accelerate tax deductions for repairs.MGE Energy and MGE have an unrecognized tax benefit at September 30, 2013 and December 31, 2012, in the amount of $2.3 million and $3.2million, respectively, for the tax uncertainty related to the change in tax method of accounting forrepairs. The reduction in unrecognized tax benefits is due to the Internal Revenue Service completing the examination of tax periods 2007-2009 with no adverse adjustments to these positions.

b.Effective Tax Rate.

MGE Energy's and MGE's effective income tax rate for the three and nine months endedSeptember 30, 2013, are37.6% and 37.8%, respectively, compared to 37.6% and 37.7% for the same periods in 2012.

c.Final Tangible Property Regulations.

In September 2013, the IRS and Treasury Department released final regulations under Sections 162(a) and 263(a) on the deduction and capitalization of expenditures related to tangible property, replacing the 2011 temporary regulations issued in December 2011. The final regulations did not have a material impact on MGE Energy's and MGE's consolidated financial statements.

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Fair Value of Financial Instruments (Details-1) (USD $) In Thousands, unless otherwise specified	9 Months Ended
	Sep. 30, 2013	Sep. 30, 2013 Maximum [Member]	Sep. 30, 2013 Minimum [Member]	Sep. 30, 2013 Carrying Amount [Member]		Dec. 31, 2012 Carrying Amount [Member]		Sep. 30, 2013 Fair Value [Member]		Dec. 31, 2012 Fair Value [Member]		Sep. 30, 2013 MGE [Member] Carrying Amount [Member]		Dec. 31, 2012 MGE [Member] Carrying Amount [Member]		Sep. 30, 2013 MGE [Member] Fair Value [Member]		Dec. 31, 2012 MGE [Member] Fair Value [Member]
Assets:
Cash and cash equivalents				$ 75,330		$ 46,357		$ 75,330		$ 46,357		$ 42,590		$ 6,350		$ 42,590		$ 6,350
Liabilities:
Long-term debt				$ 404,805	[1]	$ 361,805	[1]	$ 445,247	[1]	$ 427,456	[1]	$ 404,805	[1]	$ 361,805	[1]	$ 445,247	[1]	$ 427,456	[1]
Fair Value Inputs Assets Quantitative Information [Line Items]
Basis adjustment - on peak	99.70%
Basis adjustment - off peak	97.90%
Counterparty fuel mix [Abstract]
Internal generation		70.00%	50.00%
Purchased power		50.00%	30.00%

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

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Taxes (Details) (USD $) In Millions, unless otherwise specified	3 Months Ended		9 Months Ended
	Sep. 30, 2013	Sep. 30, 2012	Sep. 30, 2013	Sep. 30, 2012	Dec. 31, 2012
Income Tax Disclosure [Line Items]
Total unrecognized tax benefit	$ 2.3		$ 2.3		$ 3.2
Effective income tax rate	37.60%	37.60%	37.80%	37.70%
MGE [Member]
Income Tax Disclosure [Line Items]
Effective income tax rate	37.60%	37.60%	37.80%	37.70%

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Significant Accounting Policies (Policies)

9 Months Ended

Sep. 30, 2013

Accounting Policies [Abstract]

Variable Interest Entities

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

Share-based Compensation

In addition to units granted in 2009 through 2012, on February 15, 2013,15,256 units were granted based on the MGE Energy closing stock price as of that date. These units are subject to a five-year graded vesting schedule. 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, 2013, 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 the event of a bona fide retirement, not followed by work for a competitor, the executive will receive full vesting credit for each outstanding award.

Derivative Hedging

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

Derivative Netting

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

Wisconsin Fuel Rules

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

Recurring Fair Value Measurements

Fair value is defined as the price that would be received to sell an asset or would be paid to transfer a liability (an exit price) in the principal or most advantageous market for the asset or liability in an orderly transaction between market participants at the measurement date. The standard clarifies that fair value should be based on the assumptions market participants would use when pricing the asset or liability including assumptions about risk. The standard also establishes a three level fair value hierarchy based upon the observability of the assumptions used and requires the use of observable market data when available. The levels are:

Level 1 - Pricing inputs are quoted prices within active markets for identical assets or liabilities.

Level 2 - Pricing inputs are quoted prices within active markets for similar assets or liabilities; quoted prices for identical or similar instruments in markets that are not active; and model-derived valuations that are correlated with or otherwise verifiable by observable market data.

Level 3 - Pricing inputs are unobservable and reflect management's best estimate of what market participants would use in pricing the asset or liability.

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

Derivatives include exchange-traded derivative contracts, over-the-counter transactions, a ten-year purchased power agreement, and FTRs. Most exchange-traded derivative contracts are valued based on unadjusted quoted prices in active markets and are therefore classified as Level 1. A small number of exchange-traded derivative contracts are valued using quoted market pricing in markets with insufficient volumes and are therefore classified as Level 3. Transactions done with an over-the-counter party are on inactive markets and are therefore classified as Level 3. These transactions are valued based on quoted prices from markets with similar exchange traded transactions. FTRs are priced based upon monthly auction results for identical or similar instruments in a closed market with limited data available and are therefore classified as Level 3.

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

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

This model is prepared by members of MGE's Energy Supply group. It is reviewed on a quarterly basis by management in Energy Supply and Finance to review the assumptions, inputs, and fair value measurements.

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

Significant Unobservable Inputs	Model Input
Basis adjustment:
On peak	99.7%
Off peak	97.9%
Counterparty fuel mix:
Internal generation	50 % - 70 %
Purchased power	50 % - 30 %

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

New Accounting Pronouncements Disclosure

a.Presentation of Comprehensive Income.

In February 2013, the FASB issued authoritative guidance within the Codification's Comprehensive Income topic that provides guidance on the reporting of amounts reclassified out of accumulated other comprehensive income. Reclassification adjustments will be presented either on the financial statement where income is presented or as a separate disclosure in the notes to the financial statements. This authoritative guidance became effective January 1, 2013. The authoritative guidance had no effect on our financial statement presentation or notes to the financial statements.

b.Disclosures about Offsetting Assets and Liabilities.

In December 2011, the FASB issued authoritative guidance within the Codification's Balance Sheet topic that provides guidance on disclosures about offsetting assets and liabilities. The new disclosure requirements mandate that entities disclose both gross and net information for instruments and transactions eligible for offset in the balance sheet as well as instruments and transactions subject to a master netting arrangement. In addition, the standard requires disclosure of collateral received and posted in connections with a master netting arrangement. On January 31, 2013, the FASB issued additional authoritative guidance which clarified the scope of disclosures about offsetting assets and liabilities. The revised guidance limits the scope of the new balance sheet offsetting disclosures to derivatives, repurchase agreements, and securities lending transactions to the extent that they are (1) offset in the financial statements or (2) subject to an enforceable master netting arrangement or similar agreement. This authoritative guidance became effective January 1, 2013. The authoritative guidance did not have a financial impact, but required additional disclosures. See Footnote 9 for additional information.

c.Obligations Resulting from Joint and Several Liability Arrangements for Which the Total Amount of the Obligation Is Fixed at the Reporting Date.

In February 2013, the FASB issued authoritative guidance within the Codification's Balance Sheet topic that provides guidance on the recognition, measurement, and disclosure of obligations resulting from joint and several liability arrangements for which the total amount of the obligation is fixed at the reporting date. This authoritative guidance will become effective January 1, 2014. The authoritative guidance will not have a financial or disclosure impact.

d. Presentation of an Unrecognized Tax Benefit.

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

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Segment Information

9 Months Ended

Sep. 30, 2013

Segment Reporting [Abstract]

Segment Information

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 2012 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)						Non-						Consolidation/
MGE Energy						Regulated		Transmission		All		Elimination		Consolidated
		Electric		Gas		Energy		Investment		Others		Entries		Total
Three Months Ended September 30, 2013
Operating revenues	$	119,836	$	18,864	$	1,399	$	0	$	0	$	0	$	140,099
Interdepartmental revenues		172		2,757		10,660		0		0		(13,589)		0
Total operating revenues		120,008		21,621		12,059		0		0		(13,589)		140,099
Depreciation and amortization		(6,425)		(1,497)		(1,788)		0		0		0		(9,710)
Other operating expenses		(82,414)		(21,485)		(33)		(1)		(145)		13,589		(90,489)
Operating income (loss)		31,169		(1,361)		10,238		(1)		(145)		0		39,900
Other income, net		1,166		92		0		2,340		152		0		3,750
Interest (expense) income, net		(2,309)		(729)		(1,596)		0		29		0		(4,605)
Income (loss) before taxes		30,026		(1,998)		8,642		2,339		36		0		39,045
Income tax (provision) benefit		(11,021)		751		(3,469)		(939)		(14)		0		(14,692)
Net income (loss)	$	19,005	$	(1,247)	$	5,173	$	1,400	$	22	$	0	$	24,353
Three Months Ended September 30, 2012
Operating revenues	$	118,914	$	16,587	$	2,337	$	0	$	0	$	0	$	137,838
Interdepartmental revenues		159		4,658		8,679		0		0		(13,496)		0
Total operating revenues		119,073		21,245		11,016		0		0		(13,496)		137,838
Depreciation and amortization		(6,530)		(1,399)		(1,777)		0		0		0		(9,706)
Other operating expenses		(78,823)		(22,675)		(36)		0		(206)		13,496		(88,244)
Operating income (loss)		33,720		(2,829)		9,203		0		(206)		0		39,888
Other income, net		342		97		0		2,280		137		0		2,856
Interest (expense) income, net		(2,535)		(715)		(1,631)		0		32		0		(4,849)
Income (loss) before taxes		31,527		(3,447)		7,572		2,280		(37)		0		37,895
Income tax (provision) benefit		(11,873)		1,565		(3,039)		(909)		3		0		(14,253)
Net income (loss)	$	19,654	$	(1,882)	$	4,533	$	1,371	$	(34)	$	0	$	23,642
Nine Months Ended September 30, 2013
Operating revenues	$	310,176	$	121,373	$	4,075	$	0	$	0	$	0	$	435,624
Interdepartmental revenues		410		10,449		31,924		0		0		(42,783)		0
Total operating revenues		310,586		131,822		35,999		0		0		(42,783)		435,624
Depreciation and amortization		(19,139)		(4,357)		(5,368)		0		0		0		(28,864)
Other operating expenses		(235,390)		(111,494)		(96)		(1)		(537)		42,783		(304,735)
Operating income (loss)		56,057		15,971		30,535		(1)		(537)		0		102,025
Other income, net		2,226		69		0		7,045		430		0		9,770
Interest (expense) income, net		(7,028)		(2,166)		(4,814)		0		71		0		(13,937)
Income (loss) before taxes		51,255		13,874		25,721		7,044		(36)		0		97,858
Income tax (provision) benefit		(18,148)		(5,844)		(10,209)		(2,837)		8		0		(37,030)
Net income (loss)	$	33,107	$	8,030	$	15,512	$	4,207	$	(28)	$	0	$	60,828
Nine Months Ended September 30, 2012
Operating revenues	$	305,189	$	92,235	$	6,894	$	0	$	0	$	0	$	404,318
Interdepartmental revenues		387		10,721		26,032		0		0		(37,140)		0
Total operating revenues		305,576		102,956		32,926		0		0		(37,140)		404,318
Depreciation and amortization		(19,554)		(4,158)		(5,330)		0		0		0		(29,042)
Other operating expenses		(223,876)		(94,162)		(85)		0		(880)		37,140		(281,863)
Operating income (loss)		62,146		4,636		27,511		0		(880)		0		93,413
Other income, net		602		170		0		6,764		439		0		7,975
Interest (expense) income, net		(7,727)		(2,179)		(4,915)		0		104		0		(14,717)
Income (loss) before taxes		55,021		2,627		22,596		6,764		(337)		0		86,671
Income tax (provision) benefit		(20,300)		(740)		(9,069)		(2,719)		117		0		(32,711)
Net income (loss)	$	34,721	$	1,887	$	13,527	$	4,045	$	(220)	$	0	$	53,960

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

(In thousands)						Non-				Consolidation/
MGE						Regulated		Transmission		Elimination		Consolidated
		Electric		Gas		Energy		Investment		Entries		Total
Three Months Ended September 30, 2013
Operating revenues	$	119,836	$	18,864	$	1,399	$	0	$	0	$	140,099
Interdepartmental revenues		172		2,757		10,660		0		(13,589)		0
Total operating revenues		120,008		21,621		12,059		0		(13,589)		140,099
Depreciation and amortization		(6,425)		(1,497)		(1,788)		0		0		(9,710)
Other operating expenses*		(93,481)		(20,748)		(3,502)		(1)		13,589		(104,143)
Operating income (loss)*		20,102		(624)		6,769		(1)		0		26,246
Other income, net*		1,212		106		0		1,401		0		2,719
Interest expense, net		(2,309)		(729)		(1,596)		0		0		(4,634)
Net income (loss)		19,005		(1,247)		5,173		1,400		0		24,331
Less: Net income attributable to
noncontrolling interest, net of tax		0		0		0		0		(6,861)		(6,861)
Net income (loss) attributable to MGE	$	19,005	$	(1,247)	$	5,173	$	1,400	$	(6,861)	$	17,470
Three Months Ended September 30, 2012
Operating revenues	$	118,914	$	16,587	$	2,337	$	0	$	0	$	137,838
Interdepartmental revenues		159		4,658		8,679		0		(13,496)		0
Total operating revenues		119,073		21,245		11,016		0		(13,496)		137,838
Depreciation and amortization		(6,530)		(1,399)		(1,777)		0		0		(9,706)
Other operating expenses*		(90,946)		(21,180)		(3,075)		0		13,496		(101,705)
Operating income (loss)*		21,597		(1,334)		6,164		0		0		26,427
Other income, net*		592		167		0		1,371		0		2,130
Interest expense, net		(2,535)		(715)		(1,631)		0		0		(4,881)
Net income (loss)		19,654		(1,882)		4,533		1,371		0		23,676
Less: Net income attributable to
noncontrolling interest, net of tax		0		0		0		0		(6,153)		(6,153)
Net income (loss) attributable to MGE	$	19,654	$	(1,882)	$	4,533	$	1,371	$	(6,153)	$	17,523
Nine Months Ended September 30, 2013
Operating revenues	$	310,176	$	121,373	$	4,075	$	0	$	0	$	435,624
Interdepartmental revenues		410		10,449		31,924		0		(42,783)		0
Total operating revenues		310,586		131,822		35,999		0		(42,783)		435,624
Depreciation and amortization		(19,139)		(4,357)		(5,368)		0		0		(28,864)
Other operating expenses*		(253,566)		(117,346)		(10,305)		(1)		42,783		(338,435)
Operating income (loss)*		37,881		10,119		20,326		(1)		0		68,325
Other income, net*		2,254		77		0		4,208		0		6,539
Interest expense, net		(7,028)		(2,166)		(4,814)		0		0		(14,008)
Net income		33,107		8,030		15,512		4,207		0		60,856
Less: Net income attributable to
noncontrolling interest, net of tax		0		0		0		0		(20,547)		(20,547)
Net income attributable to MGE	$	33,107	$	8,030	$	15,512	$	4,207	$	(20,547)	$	40,309
Nine Months Ended September 30, 2012
Operating revenues	$	305,189	$	92,235	$	6,894	$	0	$	0	$	404,318
Interdepartmental revenues		387		10,721		26,032		0		(37,140)		0
Total operating revenues		305,576		102,956		32,926		0		(37,140)		404,318
Depreciation and amortization		(19,554)		(4,158)		(5,330)		0		0		(29,042)
Other operating expenses*		(244,303)		(94,938)		(9,154)		0		37,140		(311,255)
Operating income*		41,719		3,860		18,442		0		0		64,021
Other income, net*		729		206		0		4,045		0		4,980
Interest expense, net		(7,727)		(2,179)		(4,915)		0		0		(14,821)
Net income		34,721		1,887		13,527		4,045		0		54,180
Less: Net income attributable to
noncontrolling interest, net of tax		0		0		0		0		(18,305)		(18,305)
Net income attributable to MGE	$	34,721	$	1,887	$	13,527	$	4,045	$	(18,305)	$	35,875
*Amounts are shown net of the related tax expense, consistent with the presentation on the consolidated MGE Income Statement.

The following table shows segment information for MGE Energy's and MGE's assets and capital expenditures:
		Utility						Consolidated
(In thousands)						Assets							Consolidation/
MGE Energy						not	Nonregulated			Transmission		All		Elimination
		Electric		Gas		Allocated		Energy		Investment		Others		Entries		Total
Assets:
September 30, 2013	$	948,030	$	274,896	$	50,963	$	289,808	$	63,666	$	408,340	$	(391,992)	$	1,643,711
December 31, 2012		888,444		285,468		18,559		323,216		61,064		413,291		(403,118)		1,586,924
Capital Expenditures:
Nine Months Ended September 30, 2013	$	79,637	$	9,423	$	0	$	3,032	$	0	$	0	$	0	$	92,092
Year ended Dec. 31, 2012		81,965		13,812		0		2,658		0		0		0		98,435

		Utility						Consolidated
(In thousands)						Assets
MGE						not	Nonregulated			Transmission		Elimination
		Electric		Gas		Allocated		Energy		Investment		Entries		Total
Assets:
September 30, 2013	$	948,030	$	274,896	$	50,963	$	289,758	$	63,666	$	(9,881)	$	1,617,432
December 31, 2012		888,444		285,468		18,559		323,166		61,064		(23,050)		1,553,651
Capital Expenditures:
Nine Months Ended September 30, 2013	$	79,637	$	9,423	$	0	$	3,032	$	0	$	0	$	92,092
Year ended Dec. 31, 2012		81,965		13,812		0		2,658		0		0		98,435

XML

Derivative and Hedging Instruments (Details-4) (USD $)			3 Months Ended		9 Months Ended		3 Months Ended		9 Months Ended		3 Months Ended		9 Months Ended		3 Months Ended		9 Months Ended		3 Months Ended		9 Months Ended		3 Months Ended		9 Months Ended		3 Months Ended		9 Months Ended		3 Months Ended		9 Months Ended		3 Months Ended		9 Months Ended
	Sep. 30, 2013	Dec. 31, 2012	Sep. 30, 2013 Commodity Derivative Contracts [Member] Regulated Gas Revenues [Member]	Sep. 30, 2012 Commodity Derivative Contracts [Member] Regulated Gas Revenues [Member]	Sep. 30, 2013 Commodity Derivative Contracts [Member] Regulated Gas Revenues [Member]	Sep. 30, 2012 Commodity Derivative Contracts [Member] Regulated Gas Revenues [Member]	Sep. 30, 2013 Commodity Derivative Contracts [Member] Fuel For Electric Generation Purchased Power [Member]	Sep. 30, 2012 Commodity Derivative Contracts [Member] Fuel For Electric Generation Purchased Power [Member]	Sep. 30, 2013 Commodity Derivative Contracts [Member] Fuel For Electric Generation Purchased Power [Member]	Sep. 30, 2012 Commodity Derivative Contracts [Member] Fuel For Electric Generation Purchased Power [Member]	Sep. 30, 2013 Commodity Derivative Contracts [Member] Cost Of Gas Sold Expense [Member]	Sep. 30, 2012 Commodity Derivative Contracts [Member] Cost Of Gas Sold Expense [Member]	Sep. 30, 2013 Commodity Derivative Contracts [Member] Cost Of Gas Sold Expense [Member]	Sep. 30, 2012 Commodity Derivative Contracts [Member] Cost Of Gas Sold Expense [Member]	Sep. 30, 2013 Financial Transmission Rights [Member] Regulated Gas Revenues [Member]	Sep. 30, 2012 Financial Transmission Rights [Member] Regulated Gas Revenues [Member]	Sep. 30, 2013 Financial Transmission Rights [Member] Regulated Gas Revenues [Member]	Sep. 30, 2012 Financial Transmission Rights [Member] Regulated Gas Revenues [Member]	Sep. 30, 2013 Financial Transmission Rights [Member] Fuel For Electric Generation Purchased Power [Member]	Sep. 30, 2012 Financial Transmission Rights [Member] Fuel For Electric Generation Purchased Power [Member]	Sep. 30, 2013 Financial Transmission Rights [Member] Fuel For Electric Generation Purchased Power [Member]	Sep. 30, 2012 Financial Transmission Rights [Member] Fuel For Electric Generation Purchased Power [Member]	Sep. 30, 2013 Financial Transmission Rights [Member] Cost Of Gas Sold Expense [Member]	Sep. 30, 2012 Financial Transmission Rights [Member] Cost Of Gas Sold Expense [Member]	Sep. 30, 2013 Financial Transmission Rights [Member] Cost Of Gas Sold Expense [Member]	Sep. 30, 2012 Financial Transmission Rights [Member] Cost Of Gas Sold Expense [Member]	Sep. 30, 2013 Purchased Power Agreement [Member] Regulated Gas Revenues [Member]	Sep. 30, 2012 Purchased Power Agreement [Member] Regulated Gas Revenues [Member]	Sep. 30, 2013 Purchased Power Agreement [Member] Regulated Gas Revenues [Member]	Sep. 30, 2012 Purchased Power Agreement [Member] Regulated Gas Revenues [Member]	Sep. 30, 2013 Purchased Power Agreement [Member] Fuel For Electric Generation Purchased Power [Member]	Sep. 30, 2012 Purchased Power Agreement [Member] Fuel For Electric Generation Purchased Power [Member]	Sep. 30, 2013 Purchased Power Agreement [Member] Fuel For Electric Generation Purchased Power [Member]	Sep. 30, 2012 Purchased Power Agreement [Member] Fuel For Electric Generation Purchased Power [Member]	Sep. 30, 2013 Purchased Power Agreement [Member] Cost Of Gas Sold Expense [Member]	Sep. 30, 2012 Purchased Power Agreement [Member] Cost Of Gas Sold Expense [Member]	Sep. 30, 2013 Purchased Power Agreement [Member] Cost Of Gas Sold Expense [Member]	Sep. 30, 2012 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	$ (7,000)	$ 176,000	$ (523,000)	$ 2,685,000	$ 0	$ 0	$ 608,000	$ 3,090,000	$ 0	$ 0	$ 0	$ 0	$ (387,000)	$ (256,000)	$ (896,000)	$ (93,000)	$ 0	$ 0	$ 0	$ 0	$ 0	$ 0	$ 0	$ 0	$ 1,126,000	$ 3,655,000	$ 3,479,000	$ 4,874,000	$ 0	$ 0	$ 0	$ 0
Derivative collateral required to be posted for ten-year PPA [Abstract]
Minimum collateral required	20,000,000
Maximum collateral required	40,000,000
Required collateral posted	0
Counterparties in net liability position [Abstract]
Counterparties in net liability position	$ 0	$ 0

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Equity and Financing Arrangements (Details) (USD $)	9 Months Ended				3 Months Ended							9 Months Ended
	Sep. 30, 2013	Sep. 30, 2012	Jul. 18, 2013 Issuance of debt - 4.42%, due 2043 [Member]	Jul. 18, 2013 Issuance of debt - 4.47%, due 2048 [Member]	Jul. 18, 2013 Repayment of debt - 5.26%, due 2017 [Member]	Jul. 18, 2013 Repayment of debt - 5.59%, due 2018 [Member]	Jul. 18, 2013 5.59%, due 2018 [Member]	Sep. 16, 2013 Issuance of debt - 3.09%, due 2023 [Member]	Sep. 16, 2013 Issuance of debt - 3.29%, due 2026 [Member]	Sep. 30, 2013 MGE Energy [Member]	Jun. 19, 2013 MGE Energy [Member]	Sep. 30, 2013 MGE [Member]	Sep. 30, 2012 MGE [Member]	Jun. 19, 2013 MGE [Member]
Common Stock [Abstract]
Common stock issued during period	0	0
Dilutive Shares Calculation [Abstract]
Dilutive securities	$ 0
Credit Facilities [Line Items]
Revolving credit facility										50,000,000	40,000,000	100,000,000		75,000,000
Floating rate-based borrowings adder minimum										0.00%		0.00%
Floating rate-based borrowings adder maximum										0.125%		0.125%
Eurodollar-based borrowings adder minimum										0.675%		0.675%
Eurodollar-based borrowings adder maximum										1.125%		1.125%
Federal funds fixed base rate										0.50%		0.50%
Eurodollar fixed base rate										1.00%		1.00%
Line of credit borrowings										0		0
Commercial paper outstanding												0
Debt Instruments [Line Items]
Unsecured debt			20,000,000	20,000,000				30,000,000	15,000,000
Interest rate			4.42%	4.47%	5.26%	5.59%	5.59%	3.09%	3.29%
Redeemed and retired debt					20,000,000	20,000,000
Debt make-whole premium	6,757,000	0			3,200,000	3,600,000						6,757,000	0
Secured debt							$ 20,000,000

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Share Based Compensation (Details) (USD $) In Millions, except Share data, unless otherwise specified	1 Months Ended	9 Months Ended
	Jan. 31, 2013	Sep. 30, 2013	Sep. 30, 2012
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Compensation expense		$ 1.1	$ 1.4
Performance Units [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Awards granted during period (in units)		15,256
Award vesting period		5 years
Cash payments distributed related to awards previously granted and now payable	1.0
Awards forfeited during period		0	0
Outstanding awards vested during period		$ 3.6

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Fair Value of Financial Instruments (Details-2) (USD $) In Thousands, unless otherwise specified	9 Months Ended
	Sep. 30, 2013	Dec. 31, 2012
Deferred compensation interest calculation [Abstract]
U.S Treasury Bills maturity	26
Increase compounded monthly	1.00%
Minimum annual rate	7.00%
Assets:
Exchange-traded investments	$ 613	$ 320
Total Assets	613	320
Liabilities:
Derivatives, net	68,083	72,329
Deferred compensation	2,253	2,010
Total liabilities	70,336	74,339
Level 1 [Member]
Assets:
Exchange-traded investments	613	320
Total Assets	613	320
Liabilities:
Derivatives, net	(245)	(17)
Deferred compensation	0	0
Total liabilities	(245)	(17)
Level 2 [Member]
Assets:
Exchange-traded investments	0	0
Total Assets	0	0
Liabilities:
Derivatives, net	0	0
Deferred compensation	2,253	2,010
Total liabilities	2,253	2,010
Level 3 [Member]
Assets:
Exchange-traded investments	0	0
Total Assets	0	0
Liabilities:
Derivatives, net	68,328	72,346
Deferred compensation	0	0
Total liabilities	68,328	72,346
MGE [Member]
Assets:
Exchange-traded investments	246	117
Total Assets	246	117
Liabilities:
Derivatives, net	68,083	72,329
Deferred compensation	2,253	2,010
Total liabilities	70,336	74,339
MGE [Member] | Level 1 [Member]
Assets:
Exchange-traded investments	246	117
Total Assets	246	117
Liabilities:
Derivatives, net	(245)	(17)
Deferred compensation	0	0
Total liabilities	(245)	(17)
MGE [Member] | Level 2 [Member]
Assets:
Exchange-traded investments	0	0
Total Assets	0	0
Liabilities:
Derivatives, net	0	0
Deferred compensation	2,253	2,010
Total liabilities	2,253	2,010
MGE [Member] | Level 3 [Member]
Assets:
Exchange-traded investments	0	0
Total Assets	0	0
Liabilities:
Derivatives, net	68,328	72,346
Deferred compensation	0	0
Total liabilities	$ 68,328	$ 72,346

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Derivative and Hedging Instruments (Tables)

9 Months Ended

Sep. 30, 2013

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, 2013	December 31, 2012
Commodity derivative contracts	300,195 MWh	444,650 MWh
Commodity derivative contracts	5,970,000 Dth	1,980,000 Dth
FTRs	3,099 MW	2,670 MW

Fair Value of Derivative Instruments on the Balance Sheet

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

	Asset Derivatives			Liability Derivatives
(In thousands)	Balance Sheet Location		Fair Value	Balance Sheet Location		Fair Value
September 30, 2013
Commodity derivative contracts	Other current assets	$	608	Derivative liability (current)	$	213
Commodity derivative contracts	Other deferred charges		32	Derivative liability (long-term)		18
FTRs	Other current assets		528	Derivative liability (current)		0
Ten-year PPA	N/A		N/A	Derivative liability (current)		9,310
Ten-year PPA	N/A		N/A	Derivative liability (long-term)		59,710
December 31, 2012
Commodity derivative contracts	Other current assets	$	365	Derivative liability (current)	$	394
Commodity derivative contracts	Other deferred charges		95	Derivative liability (long-term)		11
FTRs	Other current assets		206	Derivative liability (current)		0
Ten-year PPA	N/A		N/A	Derivative liability (current)		9,270
Ten-year PPA	N/A		N/A	Derivative liability (long-term)		63,320

Offsetting Assets

The following tables show the effect of netting arrangements for recognized derivative assets and liabilities that are subject to a master netting arrangement or similar arrangement on the balance sheet.

Offsetting of Derivative Assets
				Gross amounts		Collateral		Net amount
				offset in		posted against		presented in
(In thousands)		Gross amounts		balance sheet		derivative positions		balance sheet
September 30, 2013
Commodity derivative contracts	$	640	$	(231)	$	-	$	409
FTRs		528		-		-		528
December 31, 2012
Commodity derivative contracts	$	460	$	(405)	$	-	$	55
FTRs		206		-		-		206

Offsetting Liabilities

Offsetting of Derivative Liabilities
				Gross amounts		Collateral		Net amount
				offset in		posted against		presented in
(In thousands)		Gross amounts		balance sheet		derivative positions		balance sheet
September 30, 2013
Commodity derivative contracts	$	231	$	(231)	$	-	$	-
Ten-year PPA		69,020		-		-		69,020
December 31, 2012
Commodity derivative contracts	$	405	$	(405)	$	-	$	-
Ten-year PPA		72,590		-		-		72,590

Derivative Gains and Losses in Balance Sheet

The following tables summarize the unrealized and realized gains and losses related to the derivative instruments on the consolidated balance sheet at September 30, 2013 and 2012, and the consolidated income statement for the three and nine months endedSeptember 30, 2013 and 2012.

		2013				2012
(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,	$	66,649	$	658	$	79,362	$	718
Change in unrealized loss (gain)		2,330		0		(468)		0
Realized loss reclassified to a deferred account		(275)		275		(223)		223
Realized loss reclassified to income
statement		(621)		(111)		(3,414)		(161)
Balance at September 30,	$	68,083	$	822	$	75,257	$	780
Nine Months Ended September 30:
Balance at January 1,	$	72,329	$	574	$	42,356	$	1,604
Change in unrealized loss (gain)		(1,330)		0		42,633		0
Realized loss reclassified to a deferred account		(953)		953		(3,103)		3,103
Realized loss reclassified to income
statement		(1,963)		(705)		(6,629)		(3,927)
Balance at September 30,	$	68,083	$	822	$	75,257	$	780

Derivative Gains and Losses in Income Statement

		Realized losses (gains)
				Fuel for electric
		Regulated		generation/		Cost of
(In thousands)		gas revenues		purchased power		gas sold
Three Months Ended September 30, 2013:
Commodity derivative contracts	$	0	$	(7)	$	0
FTRs		0		(387)		0
Ten-year PPA		0		1,126		0
Three Months Ended September 30, 2012:
Commodity derivative contracts	$	0	$	176	$	0
FTRs		0		(256)		0
Ten-year PPA		0		3,655		0
Nine Months Ended September 30, 2013:
Commodity derivative contracts	$	0	$	(523)	$	608
FTRs		0		(896)		0
Ten-year PPA		0		3,479		0
Nine Months Ended September 30, 2012:
Commodity derivative contracts	$	0	$	2,685	$	3,090
FTRs		0		(93)		0
Ten-year PPA		0		4,874		0

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Derivative and Hedging Instruments (Details-1) (USD $)	Sep. 30, 2013 MW MWh Dth	Dec. 31, 2012 MWh Dth MW
Gross notional volume of open derivatives [Abstract]
Commodity derivative contracts - MWh	300,195	444,650
Commodity derivative contracts - Dth	5,970,000	1,980,000
Financial transmission rights - MW	3,099	2,670
Derivative fair values [Abstract]
Exchange traded and financial transmission rights	$ 900,000	$ 300,000
Purchased power agreement	(69,000,000)	(72,600,000)
Derivatives Fair Value [Line Items]
Derivative liability (current)	9,310,000	9,270,000
Derivative liability (long-term)	59,710,000	63,320,000
Commodity Derivative Contracts [Member]
Derivatives Fair Value [Line Items]
Other current assets	608,000	365,000
Other defered charges	32,000	95,000
Derivative liability (current)	213,000	394,000
Derivative liability (long-term)	18,000	11,000
Offsetting Assets [Line Items]
Gross amounts	640,000	460,000
Gross amounts offset in balance sheet	(231,000)	(405,000)
Collateral posted against derivative positions	0	0
Net amount presented in balance sheet	409,000	55,000
Financial Transmission Rights [Member]
Derivatives Fair Value [Line Items]
Other current assets	528,000	206,000
Derivative liability (current)	0	0
Offsetting Assets [Line Items]
Gross amounts	528,000	206,000
Gross amounts offset in balance sheet	0	0
Collateral posted against derivative positions	0	0
Net amount presented in balance sheet	528,000	206,000
Purchased Power Agreement [Member]
Derivatives Fair Value [Line Items]
Derivative liability (current)	9,310,000	9,270,000
Derivative liability (long-term)	$ 59,710,000	$ 63,320,000

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New Accounting Pronouncements

9 Months Ended

Sep. 30, 2013

New Accounting Pronouncements and Changes in Accounting Principles [Abstract]

New Accounting Pronouncements

12.New Accounting Pronouncements - MGE Energy and MGE.

a.Presentation of Comprehensive Income.

In February 2013, the FASB issued authoritative guidance within the Codification's Comprehensive Income topic that provides guidance on the reporting of amounts reclassified out of accumulated other comprehensive income. Reclassification adjustments will be presented either on the financial statement where income is presented or as a separate disclosure in the notes to the financial statements. This authoritative guidance became effective January 1, 2013. The authoritative guidance had no effect on our financial statement presentation or notes to the financial statements.

b.Disclosures about Offsetting Assets and Liabilities.

In December 2011, the FASB issued authoritative guidance within the Codification's Balance Sheet topic that provides guidance on disclosures about offsetting assets and liabilities. The new disclosure requirements mandate that entities disclose both gross and net information for instruments and transactions eligible for offset in the balance sheet as well as instruments and transactions subject to a master netting arrangement. In addition, the standard requires disclosure of collateral received and posted in connections with a master netting arrangement. On January 31, 2013, the FASB issued additional authoritative guidance which clarified the scope of disclosures about offsetting assets and liabilities. The revised guidance limits the scope of the new balance sheet offsetting disclosures to derivatives, repurchase agreements, and securities lending transactions to the extent that they are (1) offset in the financial statements or (2) subject to an enforceable master netting arrangement or similar agreement. This authoritative guidance became effective January 1, 2013. The authoritative guidance did not have a financial impact, but required additional disclosures. See Footnote 9 for additional information.

c.Obligations Resulting from Joint and Several Liability Arrangements for Which the Total Amount of the Obligation Is Fixed at the Reporting Date.

In February 2013, the FASB issued authoritative guidance within the Codification's Balance Sheet topic that provides guidance on the recognition, measurement, and disclosure of obligations resulting from joint and several liability arrangements for which the total amount of the obligation is fixed at the reporting date. This authoritative guidance will become effective January 1, 2014. The authoritative guidance will not have a financial or disclosure impact.

d. Presentation of an Unrecognized Tax Benefit.

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

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Consolidated Statements of Comprehensive Income (Unaudited) (Parantheticals) (USD $) In Thousands, unless otherwise specified	3 Months Ended		9 Months Ended
	Sep. 30, 2013	Sep. 30, 2012	Sep. 30, 2013	Sep. 30, 2012
Comprehensive Income [Abstract]
Unrealized gain (loss) on available-for-sale securities, taxes	$ 24	$ (5)	$ 117	$ 24
MGE [Member]
Comprehensive Income [Abstract]
Unrealized gain (loss) on available-for-sale securities, taxes	$ 33	$ (5)	$ 52	$ (20)

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Madison Gas and Electric Company Consolidated Statements of Cash Flows (Unaudited) (USD $) In Thousands, unless otherwise specified	9 Months Ended
	Sep. 30, 2013	Sep. 30, 2012
Items not affecting cash:
Depreciation and amortization	$ 28,864	$ 29,042
Deferred income taxes	32,706	54,602
Provision for doubtful receivables	1,551	1,537
Employee benefit plan expenses	9,908	13,815
Equity earnings in ATC	(7,045)	(6,764)
Other items	250	1,632
Changes in working capital items:
Decrease (increase) in current assets	15,053	(9,002)
Decrease in current liabilities	(5,496)	(13,418)
Dividend income from ATC	5,498	5,300
Cash contributions to pension and other postretirement plans	(33,919)	(24,336)
Debt make-whole premium	(6,757)	0
Other noncurrent items, net	7,159	9,518
Cash Provided by Operating Activities	108,600	115,886
Investing Activities:
Capital expenditures	(92,092)	(65,909)
Capital contributions to investments	(1,305)	(1,988)
Other	(780)	(291)
Cash Used for Investing Activities	(94,177)	(68,188)
Financing Activities:
Cash dividends paid on common stock	(27,685)	(26,820)
Repayment of long-term debt	(42,000)	(30,000)
Issuance of long-term debt	85,000	28,000
Other	(765)	(844)
Cash Provided by (Used for) Financing Activities	14,550	(29,664)
Change in cash and cash equivalents	28,973	18,034
Cash and cash equivalents at beginning of period	46,357	41,169
Cash and Cash Equivalents at End of Period	75,330	59,203
Significant noncash investing activities:
Accrued capital expenditures	10,473	7,649
MGE [Member]
Operating Activities:
Net Income	60,856	54,180
Items not affecting cash:
Depreciation and amortization	28,864	29,042
Deferred income taxes	31,467	53,984
Provision for doubtful receivables	1,551	1,537
Employee benefit plan expenses	9,908	13,815
Equity earnings in ATC	(7,045)	(6,764)
Other items	652	2,028
Changes in working capital items:
Decrease (increase) in current assets	14,599	(10,446)
Decrease in current liabilities	(4,911)	(14,052)
Dividend income from ATC	5,498	5,300
Cash contributions to pension and other postretirement plans	(33,919)	(24,336)
Debt make-whole premium	(6,757)	0
Other noncurrent items, net	7,063	9,281
Cash Provided by Operating Activities	107,826	113,569
Investing Activities:
Capital expenditures	(92,092)	(65,909)
Capital contributions to investments	(1,065)	(1,775)
Other	(678)	(271)
Cash Used for Investing Activities	(93,835)	(67,955)
Financing Activities:
Cash dividends paid to parent by MGE	0	(13,456)
Distributions to parent from noncontrolling interest	(21,148)	(15,500)
Equity contribution received by noncontrolling interest	1,065	1,775
Repayment of long-term debt	(42,000)	(30,000)
Issuance of long-term debt	85,000	28,000
Other	(668)	(795)
Cash Provided by (Used for) Financing Activities	22,249	(29,976)
Change in cash and cash equivalents	36,240	15,638
Cash and cash equivalents at beginning of period	6,350	13,898
Cash and Cash Equivalents at End of Period	42,590	29,536
Significant noncash investing activities:
Accrued capital expenditures	$ 10,473	$ 7,649

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MGE Energy Inc Consolidated Statements of Common Equity (Unaudited) (USD $) In Thousands		Total	Common Stock [Member]	Additional Paid-In Capital [Member]	Retained Earnings [Member]	Accumulated Other Comprehensive Income [Member]
Beginning balance, value at Dec. 31, 2011		$ 550,952	$ 23,114	$ 316,268	$ 211,458	$ 112
Beginning balance, shares at Dec. 31, 2011			23,114
Net Income		53,960			53,960
Other comprehensive income (loss)		35				35
Common stock dividends declared	[1]	(26,820)			(26,820)
Ending balance, value at Sep. 30, 2012		578,127	23,114	316,268	238,598	147
Ending balance, shares at Sep. 30, 2012			23,114
Beginning balance, value at Dec. 31, 2012		579,429	23,114	316,268	239,953	94
Beginning balance, shares at Dec. 31, 2012			23,114
Net Income		60,828			60,828
Other comprehensive income (loss)		176				176
Common stock dividends declared	[2]	(27,685)			(27,685)
Ending balance, value at Sep. 30, 2013		$ 612,748	$ 23,114	$ 316,268	$ 273,096	$ 270
Ending balance, shares at Sep. 30, 2013			23,114

[1] $1.161 per share

[2] $1.198 per share

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Consolidated Balance Sheets (Unaudited) (USD $) In Thousands, unless otherwise specified	Sep. 30, 2013		Dec. 31, 2012
Current Assets:
Cash and cash equivalents	$ 75,330		$ 46,357
Receivable - margin account	1,357		1,818
Accounts receivable, less reserves	37,442	[1]	41,386	[2]
Other accounts receivables, less reserves	8,271	[3]	6,746	[4]
Unbilled revenues	20,290		28,262
Materials and supplies, at average cost	17,023		16,997
Fossil fuel	6,388		6,367
Stored natural gas, at average cost	18,004		14,980
Prepaid taxes	12,722		19,520
Regulatory assets - current	8,689		10,327
Deferred income taxes - current	0		23,483
Other current assets	8,349		6,694
Total Current Assets	213,865		222,937
Regulatory assets	213,068		218,853
Other deferred assets and other	6,436		7,075
Property, Plant, and Equipment:
Property, plant, and equipment, net	1,012,281		975,053
Construction work in progress	131,096		98,411
Total Property, Plant, and Equipment	1,143,377		1,073,464
Investments	66,965		64,595
Total Assets	1,643,711		1,586,924
Current Liabilities:
Long-term debt due within one year	4,082		3,013
Accounts payable	39,532		43,518
Accrued interest and taxes	4,041		4,296
Accrued payroll related items	9,819		10,063
Deferred income taxes	969		0
Regulatory liabilities - current	4,622		0
Derivative liabilities	9,310		9,270
Other current liabilities	6,337		5,637
Total Current Liabilities	78,712		75,797
Other Credits:
Deferred income taxes	278,899		270,410
Investment tax credit - deferred	1,466		1,520
Regulatory liabilities	25,757		24,538
Accrued pension and other postretirement benefits	133,730		162,835
Derivative liabilities	59,710		63,320
Other deferred liabilities and other	52,249		50,584
Total Other Credits	551,811		573,207
Capitalization:
Common shareholders equity	612,748		579,429
Long-term debt	400,440		358,491
Total Capitalization	1,013,188		937,920
Commitments and contingencies (see Footnote 8)	0		0
Total Liabilities and Capitalization	1,643,711		1,586,924
MGE [Member]
Current Assets:
Cash and cash equivalents	42,590		6,350
Receivable - margin account	1,357		1,818
Accounts receivable, less reserves	37,442	[1]	41,386	[2]
Affiliate receivables	532		634
Other accounts receivables, less reserves	8,220	[3]	6,732	[4]
Unbilled revenues	20,290		28,262
Materials and supplies, at average cost	17,023		16,997
Fossil fuel	6,388		6,367
Stored natural gas, at average cost	18,004		14,980
Prepaid taxes	17,334		23,561
Regulatory assets - current	8,689		10,327
Deferred income taxes - current	0		23,305
Other current assets	8,310		6,670
Total Current Assets	186,179		187,389
Affiliate receivable long-term	5,957		6,354
Regulatory assets	213,068		218,853
Other deferred assets and other	4,695		6,540
Property, Plant, and Equipment:
Property, plant, and equipment, net	1,012,150		974,549
Construction work in progress	131,096		98,411
Total Property, Plant, and Equipment	1,143,246		1,072,960
Investments	64,287		61,555
Total Assets	1,617,432		1,553,651
Current Liabilities:
Long-term debt due within one year	4,082		3,013
Accounts payable	39,532		43,517
Affiliate payables	40		767
Accrued interest and taxes	4,056		4,248
Accrued payroll related items	9,819		10,063
Deferred income taxes	1,379		0
Regulatory liabilities - current	4,622		0
Derivative liabilities	9,310		9,270
Other current liabilities	6,166		4,491
Total Current Liabilities	79,006		75,369
Other Credits:
Deferred income taxes	273,456		266,231
Investment tax credit - deferred	1,466		1,520
Regulatory liabilities	25,757		24,538
Accrued pension and other postretirement benefits	133,730		162,835
Derivative liabilities	59,710		63,320
Other deferred liabilities and other	52,251		50,581
Total Other Credits	546,370		569,025
Capitalization:
Common shareholders equity	473,682		433,296
Noncontrolling interest	117,934		117,470
Total Equity	591,616		550,766
Long-term debt	400,440		358,491
Total Capitalization	992,056		909,257
Commitments and contingencies (see Footnote 8)	0		0
Total Liabilities and Capitalization	$ 1,617,432		$ 1,553,651

[1] less reserves of $3,959

[2] less reserves of $3,885

[3] less reserves of $822

[4] less reserves of $931

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Commitments and Contingencies (Details-1) (USD $) In Millions, unless otherwise specified	9 Months Ended
	Sep. 30, 2013
Columbia Clean Air Act Litigation [Abstract]
Columbia Clean Air Act litigation civil penalties	$ 0.2
Columbia Clean Air Act litigation environmental mitigation costs	$ 0.6
Columbia Units [Member]
Jointly Owned Utility Plant Interests [Line Items]
Generating capability - MW	225
Columbia's share of MGE's net generating capability	29.00%
WPL ownership interest of Columbia	46.20%
WPSC ownership interest of Columbia	31.80%
MGE ownership interest in jointly owned plant	22.00%

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Investment in ATC (Tables)

9 Months Ended

Sep. 30, 2013

Equity Method Investments and Joint Ventures [Abstract]

ATC's Summarized Financial Data

ATC's summarized financial data for the three and nine months endedSeptember 30, 2013 and 2012, is as follows:

		Three Months Ended				Nine Months Ended
		September 30,				September 30,
(In thousands)		2013		2012		2013		2012
Operating revenues	$	160,480	$	150,303	$	464,345	$	450,136
Operating expenses		(77,595)		(68,813)		(217,240)		(210,139)
Other income (expense), net		917		(5)		585		(832)
Interest expense, net		(21,136)		(20,983)		(63,232)		(61,260)
Earnings before members' income taxes	$	62,666	$	60,502	$	184,458	$	177,905

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Fair Value of Financial Instruments (Tables)

9 Months Ended

Sep. 30, 2013

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, 2013				December 31, 2012
		Carrying		Fair		Carrying		Fair
(In thousands)		Amount		Value		Amount		Value
MGE Energy
Assets:
Cash and cash equivalents	$	75,330	$	75,330	$	46,357	$	46,357
Liabilities:
Long-term debt*		404,805		445,247		361,805		427,456
MGE
Assets:
Cash and cash equivalents		42,590		42,590		6,350		6,350
Liabilities:
Long-term debt*		404,805		445,247		361,805		427,456
*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, 2013
(In thousands)		Total		Level 1		Level 2		Level 3
MGE Energy
Assets:
Exchange-traded investments	$	613	$	613	$	0	$	0
Total Assets	$	613	$	613	$	0	$	0
Liabilities:
Derivatives, net	$	68,083	$	(245)	$	0	$	68,328
Deferred compensation		2,253		0		2,253		0
Total Liabilities	$	70,336	$	(245)	$	2,253	$	68,328
MGE
Assets:
Exchange-traded investments	$	246	$	246	$	0	$	0
Total Assets	$	246	$	246	$	0	$	0
Liabilities:
Derivatives, net	$	68,083	$	(245)	$	0	$	68,328
Deferred compensation		2,253		0		2,253		0
Total Liabilities	$	70,336	$	(245)	$	2,253	$	68,328
	Fair Value as of December 31, 2012
(In thousands)		Total		Level 1		Level 2		Level 3
MGE Energy
Assets:
Exchange-traded investments	$	320	$	320	$	0	$	0
Total Assets	$	320	$	320	$	0	$	0
Liabilities:
Derivatives, net	$	72,329	$	(17)	$	0	$	72,346
Deferred compensation		2,010		0		2,010		0
Total Liabilities	$	74,339	$	(17)	$	2,010	$	72,346
MGE
Assets:
Exchange-traded investments	$	117	$	117	$	0	$	0
Total Assets	$	117	$	117	$	0	$	0
Liabilities:
Derivatives, net	$	72,329	$	(17)	$	0	$	72,346
Deferred compensation		2,010		0		2,010		0
Total Liabilities	$	74,339	$	(17)	$	2,010	$	72,346

Significant Unobservable Inputs

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

Significant Unobservable Inputs	Model Input
Basis adjustment:
On peak	99.7%
Off peak	97.9%
Counterparty fuel mix:
Internal generation	50 % - 70 %
Purchased power	50 % - 30 %

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

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

		Three Months Ended				Nine Months Ended
		September 30,				September 30,
(In thousands)		2013		2012		2013		2012
Beginning balance,	$	(66,856)	$	(79,580)	$	(72,346)	$	(40,661)
Realized and unrealized gains (losses):
Included in regulatory liabilities (assets)		(1,472)		3,465		4,018		(35,455)
Included in other comprehensive income		0		0		0		0
Included in earnings		(174)		(3,422)		(2,034)		(6,659)
Included in current assets		(38)		0		(94)		(77)
Purchases		6,052		5,864		17,709		7,764
Sales		0		45		(2)		77
Issuances		0		0		0		0
Settlements		(5,840)		(2,487)		(15,579)		(1,104)
Transfers in and/or out of Level 3		0		0		0		0
Balance as of September 30,	$	(68,328)	$	(76,115)	$	(68,328)	$	(76,115)
Total gains (losses) included in earnings attributed to
the change in unrealized gains (losses) related to
assets and liabilities held at September 30,(a)	$	0	$	0	$	0	$	0

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

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

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

		Three Months Ended				Nine Months Ended
		September 30,				September 30,
(In thousands)		2013		2012		2013		2012
Purchased Power Expense	$	(174)	$	(3,422)	$	(2,034)	$	(6,659)
Cost of Gas Sold Expense		0		0		0		0
Regulated Gas Revenues		0		0		0		0
Total	$	(174)	$	(3,422)	$	(2,034)	$	(6,659)

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

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Columbia Environmental Project Construction (Details) (USD $)	3 Months Ended		9 Months Ended		12 Months Ended
	Sep. 30, 2013	Sep. 30, 2012	Sep. 30, 2013	Sep. 30, 2012	Dec. 31, 2012
Expected Capital Expenditures [Line Items]
Total incurred costs to date	$ 131,096,000		$ 131,096,000		$ 98,411,000
Authorized MGE rate of return	50.00%		50.00%
Columbia Environmental Project [Member]
Expected Capital Expenditures [Line Items]
MGE's total share of expected capital expenditures			140,000,000
Total incurred costs to date	113,600,000		113,600,000
MGE's share of expected capital expenditures current year			12,000,000
MGE's share of expected capital expenditures next year			14,000,000
Columbia environmental project commitments	24,400,000		24,400,000
AFUDC - equity funds	$ 800,000	$ 400,000	$ 1,900,000	$ 700,000
Authorized AFUDC Rate			50.00%		100.00%
Columbia Units [Member]
Jointly Owned Utility Plant Interests [Line Items]
WPL ownership interest of Columbia	46.20%		46.20%
WPSC ownership interest of Columbia	31.80%		31.80%
MGE ownership interest in jointly owned plant	22.00%		22.00%

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Fair Value of Financial Instruments (Details-3) (USD $) In Thousands, unless otherwise specified	3 Months Ended				9 Months Ended
	Sep. 30, 2013		Sep. 30, 2012		Sep. 30, 2013		Sep. 30, 2012
Changes in level 3 assets and liabilities measured at fair value on a recurring basis [Abstract]
Beginning balance,	$ (66,856)		$ (79,580)		$ (72,346)		$ (40,661)
Realized and unrealized gains (losses):
Included in regulatory liabilities (assets)	(1,472)		3,465		4,018		(35,455)
Included in other comprehensive income	0		0		0		0
Included in earnings	(174)		(3,422)		(2,034)		(6,659)
Included in current assets	(38)		0		(94)		(77)
Purchases	6,052		5,864		17,709		7,764
Sales	0		45		(2)		77
Issuances	0		0		0		0
Settlements	(5,840)		(2,487)		(15,579)		(1,104)
Transfers in and/or out of level 3	0		0		0		0
Ending balance,	(68,328)		(76,115)		(68,328)		(76,115)
Total gains (losses) included in earnings attributed to the change in unrealized gains (losses) related to assets and liabilities	0	[1]	0	[1]	0	[1]	0	[1]
Fair Value Assets And Liabilities Measured On Recurring Basis Gain Loss Included In Earnings [Line Items]
Realized and unrealized gains (losses) included in income for level 3 instruments.	(174)	[1]	(3,422)	[1]	(2,034)	[1]	(6,659)	[1]
Purchased Power Expense [Member]
Fair Value Assets And Liabilities Measured On Recurring Basis Gain Loss Included In Earnings [Line Items]
Realized and unrealized gains (losses) included in income for level 3 instruments.	(174)	[1]	(3,422)	[1]	(2,034)	[1]	(6,659)	[1]
Cost Of Gas Sold Expense [Member]
Fair Value Assets And Liabilities Measured On Recurring Basis Gain Loss Included In Earnings [Line Items]
Realized and unrealized gains (losses) included in income for level 3 instruments.	0	[1]	0	[1]	0	[1]	0	[1]
Regulated Gas Revenues [Member]
Fair Value Assets And Liabilities Measured On Recurring Basis Gain Loss Included In Earnings [Line Items]
Realized and unrealized gains (losses) included in income for level 3 instruments.	$ 0	[1]	$ 0	[1]	$ 0	[1]	$ 0	[1]

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

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Derivative and Hedging Instruments (Details-3) (USD $) In Thousands, unless otherwise specified	3 Months Ended		9 Months Ended
	Sep. 30, 2013	Sep. 30, 2012	Sep. 30, 2013	Sep. 30, 2012
Regulatory Asset [Member]
Derivative Unrealized Realized Gains Losses On Balance Sheet [Line Items]
Beginning balance,	$ 66,649	$ 79,362	$ 72,329	$ 42,356
Change in unrealized loss (gain)	2,330	(468)	(1,330)	42,633
Realized loss reclassified to a deferred account	(275)	(223)	(953)	(3,103)
Realized gain (loss) reclassified to income statement	(621)	(3,414)	(1,963)	(6,629)
Ending balance,	68,083	75,257	68,083	75,257
Other Current Assets [Member]
Derivative Unrealized Realized Gains Losses On Balance Sheet [Line Items]
Beginning balance,	658	718	574	1,604
Change in unrealized loss (gain)	0	0	0	0
Realized loss reclassified to a deferred account	275	223	953	3,103
Realized gain (loss) reclassified to income statement	(111)	(161)	(705)	(3,927)
Ending balance,	$ 822	$ 780	$ 822	$ 780

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Madison Gas and Electric Company Consolidated Statements of Income (Unaudited) (USD $) In Thousands, unless otherwise specified	3 Months Ended		9 Months Ended
	Sep. 30, 2013	Sep. 30, 2012	Sep. 30, 2013	Sep. 30, 2012
Operating Revenues:
Regulated electric revenues	$ 119,836	$ 118,914	$ 310,176	$ 305,189
Regulated gas revenues	18,864	16,587	121,373	92,235
Nonregulated revenues	1,399	2,337	4,075	6,894
Total Operating Revenues	140,099	137,838	435,624	404,318
Operating Expenses:
Fuel for electric generation	13,950	16,395	34,520	36,727
Purchased power	21,981	18,102	61,237	54,962
Cost of gas sold	8,819	7,389	70,259	50,035
Other operations and maintenance	41,134	41,975	124,670	126,202
Depreciation and amortization	9,710	9,706	28,864	29,042
Other general taxes	4,605	4,383	14,049	13,937
Income tax provision	14,692	14,253	37,030	32,711
Total Operating Expenses	100,199	97,950	333,599	310,905
Operating Income	39,900	39,888	102,025	93,413
Other Income and Deductions:
Equity in earnings in ATC			7,045	6,764
Total Other Income and Deductions	3,750	2,856	9,770	7,975
Interest Expense:
Net Interest Expense	4,605	4,849	13,937	14,717
Net Income (Loss)	24,353	23,642	60,828	53,960
MGE [Member]
Operating Revenues:
Regulated electric revenues	119,836	118,914	310,176	305,189
Regulated gas revenues	18,864	16,587	121,373	92,235
Nonregulated revenues	1,399	2,337	4,075	6,894
Total Operating Revenues	140,099	137,838	435,624	404,318
Operating Expenses:
Fuel for electric generation	13,950	16,395	34,520	36,727
Purchased power	21,981	18,102	61,237	54,962
Cost of gas sold	8,819	7,389	70,259	50,035
Other operations and maintenance	40,990	41,766	124,133	125,320
Depreciation and amortization	9,710	9,706	28,864	29,042
Other general taxes	4,605	4,384	14,049	13,938
Income tax provision	13,798	13,669	34,237	30,273
Total Operating Expenses	113,853	111,411	367,299	340,297
Operating Income	26,246	26,427	68,325	64,021
Other Income and Deductions:
AFUDC - equity funds	852	514	2,178	978
Equity in earnings in ATC	2,340	2,280	7,045	6,764
Income tax provision	(880)	(587)	(2,802)	(2,555)
Other income, net	407	(77)	118	(207)
Total Other Income and Deductions	2,719	2,130	6,539	4,980
Income before interest expense	28,965	28,557	74,864	69,001
Interest Expense:
Interest on long-term debt	4,910	5,065	14,757	15,335
Other interest, net	5	25	(31)	(116)
AFUDC - borrowed funds	(281)	(209)	(718)	(398)
Net Interest Expense	4,634	4,881	14,008	14,821
Net Income Including Noncontrolling Interest	24,331	23,676	60,856	54,180
Less Net Income Attributable to Noncontrolling Interest, net of tax	(6,861)	(6,153)	(20,547)	(18,305)
Net Income (Loss)	$ 17,470	$ 17,523	$ 40,309	$ 35,875

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Basis of Presentation

9 Months Ended

Sep. 30, 2013

Organization, Consolidation and Presentation of Financial Statements [Abstract]

Basis of Presentation

1.       Basis of Presentation - MGE Energy and MGE.

       This report is a combined report of MGE Energy and MGE. References in this report to "MGE Energy" are to MGE Energy, Inc. and its subsidiaries. References in this report to "MGE" are to Madison Gas and Electric Company.

MGE Power Elm Road and MGE Power West Campus own electric generating assets and lease those assets to MGE. Both entities are variable interest entities under applicable authoritative guidance. MGE is considered the primary beneficiary of these entities as a result of contractual agreements. As a result, MGE has consolidated MGE Power Elm Road and MGE Power West Campus. See Footnote 2 of Notes to Consolidated Financial Statements under Item 8, Financial Statements and Supplementary Data, of MGE Energy's and MGE's 2012 Annual Report on Form 10-K.

       The accompanying consolidated financial statements as of September 30, 2013, 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 2012 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 51 through 104 of the 2012 Annual Report on Form 10-K.

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Madison Gas and Electric Company Consolidated Statements of Comprehensive Income (Unaudited) (USD $) In Thousands, unless otherwise specified	3 Months Ended				9 Months Ended
	Sep. 30, 2013		Sep. 30, 2012		Sep. 30, 2013		Sep. 30, 2012
Other comprehensive income (loss), net of tax:
Unrealized gain (loss) on available-for-sale securities, net of tax	$ 36	[1]	$ (8)	[2]	$ 176	[3]	$ 35	[1]
Comprehensive Income	24,389		23,634		61,004		53,995
MGE [Member]
Net Income	24,331		23,676		60,856		54,180
Other comprehensive income (loss), net of tax:
Unrealized gain (loss) on available-for-sale securities, net of tax	49	[4]	(7)	[2]	77	[5]	(30)	[6]
Total comprehensive income including noncontrolling interest	24,380		23,669		60,933		54,150
Less: Comprehensive income attributable to Noncontrolling Interest, net of tax	(6,861)		(6,153)		(20,547)		(18,305)
Comprehensive Income	$ 17,519		$ 17,516		$ 40,386		$ 35,845

[1] Net of $24 tax

[2] Net of $5 tax

[3] Net of $117 tax

[4] Net of $33 tax

[5] Net of $52 tax

[6] Net of $20 tax

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MGE Energy Inc Consolidated Statements of Income (Unaudited) (USD $) In Thousands, except Per Share data, unless otherwise specified	3 Months Ended		9 Months Ended
	Sep. 30, 2013	Sep. 30, 2012	Sep. 30, 2013	Sep. 30, 2012
Operating Revenues:
Regulated electric revenues	$ 119,836	$ 118,914	$ 310,176	$ 305,189
Regulated gas revenues	18,864	16,587	121,373	92,235
Nonregulated revenues	1,399	2,337	4,075	6,894
Total Operating Revenues	140,099	137,838	435,624	404,318
Operating Expenses:
Fuel for electric generation	13,950	16,395	34,520	36,727
Purchased power	21,981	18,102	61,237	54,962
Cost of gas sold	8,819	7,389	70,259	50,035
Other operations and maintenance	41,134	41,975	124,670	126,202
Depreciation and amortization	9,710	9,706	28,864	29,042
Other general taxes	4,605	4,383	14,049	13,937
Total Operating Expenses	100,199	97,950	333,599	310,905
Operating Income	39,900	39,888	102,025	93,413
Other income, net	3,750	2,856	9,770	7,975
Interest expense, net	(4,605)	(4,849)	(13,937)	(14,717)
Income before income taxes	39,045	37,895	97,858	86,671
Income tax provision	(14,692)	(14,253)	(37,030)	(32,711)
Net Income (Loss)	$ 24,353	$ 23,642	$ 60,828	$ 53,960
Earnings Per Share of Common Stock (basic and diluted)	$ 1.05	$ 1.02	$ 2.63	$ 2.33
Dividends per share of common stock	$ 0.408	$ 0.395	$ 1.198	$ 1.161
Weighted Average Shares Outstanding (basic and diluted)	23,114	23,114	23,114	23,114

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Segment Information (Details) (USD $) In Thousands, unless otherwise specified	3 Months Ended		9 Months Ended		12 Months Ended
	Sep. 30, 2013	Sep. 30, 2012	Sep. 30, 2013	Sep. 30, 2012	Dec. 31, 2012
Segment Reporting Information [Line Items]
Operating revenues	$ 140,099	$ 137,838	$ 435,624	$ 404,318
Interdepartmental revenues	0	0	0	0
Total operating revenues	140,099	137,838	435,624	404,318
Depreciation and amortization	(9,710)	(9,706)	(28,864)	(29,042)
Other operating expenses	(90,489)	(88,244)	(304,735)	(281,863)
Operating Income	39,900	39,888	102,025	93,413
Other income, net	3,750	2,856	9,770	7,975
Interest (expense) income, net	(4,605)	(4,849)	(13,937)	(14,717)
Income before income taxes	39,045	37,895	97,858	86,671
Income tax (provision) benefit	(14,692)	(14,253)	(37,030)	(32,711)
Net Income (Loss)	24,353	23,642	60,828	53,960
Segment Reporting Assets And Capital Expenditures [Abstract]
Assets	1,643,711		1,643,711		1,586,924
Capital Expenditures			92,092		98,435
Electric [Member]
Segment Reporting Information [Line Items]
Operating revenues	119,836	118,914	310,176	305,189
Interdepartmental revenues	172	159	410	387
Total operating revenues	120,008	119,073	310,586	305,576
Depreciation and amortization	(6,425)	(6,530)	(19,139)	(19,554)
Other operating expenses	(82,414)	(78,823)	(235,390)	(223,876)
Operating Income	31,169	33,720	56,057	62,146
Other income, net	1,166	342	2,226	602
Interest (expense) income, net	(2,309)	(2,535)	(7,028)	(7,727)
Income before income taxes	30,026	31,527	51,255	55,021
Income tax (provision) benefit	(11,021)	(11,873)	(18,148)	(20,300)
Net Income (Loss)	19,005	19,654	33,107	34,721
Segment Reporting Assets And Capital Expenditures [Abstract]
Assets	948,030		948,030		888,444
Capital Expenditures			79,637		81,965
Gas [Member]
Segment Reporting Information [Line Items]
Operating revenues	18,864	16,587	121,373	92,235
Interdepartmental revenues	2,757	4,658	10,449	10,721
Total operating revenues	21,621	21,245	131,822	102,956
Depreciation and amortization	(1,497)	(1,399)	(4,357)	(4,158)
Other operating expenses	(21,485)	(22,675)	(111,494)	(94,162)
Operating Income	(1,361)	(2,829)	15,971	4,636
Other income, net	92	97	69	170
Interest (expense) income, net	(729)	(715)	(2,166)	(2,179)
Income before income taxes	(1,998)	(3,447)	13,874	2,627
Income tax (provision) benefit	751	1,565	(5,844)	(740)
Net Income (Loss)	(1,247)	(1,882)	8,030	1,887
Segment Reporting Assets And Capital Expenditures [Abstract]
Assets	274,896		274,896		285,468
Capital Expenditures			9,423		13,812
Non Regulated Energy [Member]
Segment Reporting Information [Line Items]
Operating revenues	1,399	2,337	4,075	6,894
Interdepartmental revenues	10,660	8,679	31,924	26,032
Total operating revenues	12,059	11,016	35,999	32,926
Depreciation and amortization	(1,788)	(1,777)	(5,368)	(5,330)
Other operating expenses	(33)	(36)	(96)	(85)
Operating Income	10,238	9,203	30,535	27,511
Other income, net	0	0	0	0
Interest (expense) income, net	(1,596)	(1,631)	(4,814)	(4,915)
Income before income taxes	8,642	7,572	25,721	22,596
Income tax (provision) benefit	(3,469)	(3,039)	(10,209)	(9,069)
Net Income (Loss)	5,173	4,533	15,512	13,527
Segment Reporting Assets And Capital Expenditures [Abstract]
Assets	289,808		289,808		323,216
Capital Expenditures			3,032		2,658
Transmission Investment [Member]
Segment Reporting Information [Line Items]
Operating revenues	0	0	0	0
Interdepartmental revenues	0	0	0	0
Total operating revenues	0	0	0	0
Depreciation and amortization	0	0	0	0
Other operating expenses	(1)	0	(1)	0
Operating Income	(1)	0	(1)	0
Other income, net	2,340	2,280	7,045	6,764
Interest (expense) income, net	0	0	0	0
Income before income taxes	2,339	2,280	7,044	6,764
Income tax (provision) benefit	(939)	(909)	(2,837)	(2,719)
Net Income (Loss)	1,400	1,371	4,207	4,045
Segment Reporting Assets And Capital Expenditures [Abstract]
Assets	63,666		63,666		61,064
Capital Expenditures			0		0
All Others [Member]
Segment Reporting Information [Line Items]
Operating revenues	0	0	0	0
Interdepartmental revenues	0	0	0	0
Total operating revenues	0	0	0	0
Depreciation and amortization	0	0	0	0
Other operating expenses	(145)	(206)	(537)	(880)
Operating Income	(145)	(206)	(537)	(880)
Other income, net	152	137	430	439
Interest (expense) income, net	29	32	71	104
Income before income taxes	36	(37)	(36)	(337)
Income tax (provision) benefit	(14)	3	8	117
Net Income (Loss)	22	(34)	(28)	(220)
Segment Reporting Assets And Capital Expenditures [Abstract]
Assets	408,340		408,340		413,291
Capital Expenditures			0		0
Consolidation Elimination Entries [Member]
Segment Reporting Information [Line Items]
Operating revenues	0	0	0	0
Interdepartmental revenues	(13,589)	(13,496)	(42,783)	(37,140)
Total operating revenues	(13,589)	(13,496)	(42,783)	(37,140)
Depreciation and amortization	0	0	0	0
Other operating expenses	13,589	13,496	42,783	37,140
Operating Income	0	0	0	0
Other income, 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
Segment Reporting Assets And Capital Expenditures [Abstract]
Assets	(391,992)		(391,992)		(403,118)
Capital Expenditures			0		0
Assets Not Allocated [Member]
Segment Reporting Assets And Capital Expenditures [Abstract]
Assets	50,963		50,963		18,559
Capital Expenditures			0		0
MGE [Member]
Segment Reporting Information [Line Items]
Operating revenues	140,099	137,838	435,624	404,318
Interdepartmental revenues	0	0	0	0
Total operating revenues	140,099	137,838	435,624	404,318
Depreciation and amortization	(9,710)	(9,706)	(28,864)	(29,042)
Other operating expenses	(104,143)	(101,705)	(338,435)	(311,255)
Operating Income	26,246	26,427	68,325	64,021
Other income, net	2,719	2,130	6,539	4,980
Interest (expense) income, net	(4,634)	(4,881)	(14,008)	(14,821)
Income tax (provision) benefit	(13,798)	(13,669)	(34,237)	(30,273)
Net Income Including Noncontrolling Interest	24,331	23,676	60,856	54,180
Less Net Income Attributable to Noncontrolling Interest, net of tax	(6,861)	(6,153)	(20,547)	(18,305)
Net Income (Loss)	17,470	17,523	40,309	35,875
Segment Reporting Assets And Capital Expenditures [Abstract]
Assets	1,617,432		1,617,432		1,553,651
Capital Expenditures			92,092		98,435
MGE [Member] | Electric [Member]
Segment Reporting Information [Line Items]
Operating revenues	119,836	118,914	310,176	305,189
Interdepartmental revenues	172	159	410	387
Total operating revenues	120,008	119,073	310,586	305,576
Depreciation and amortization	(6,425)	(6,530)	(19,139)	(19,554)
Other operating expenses	(93,481)	(90,946)	(253,566)	(244,303)
Operating Income	20,102	21,597	37,881	41,719
Other income, net	1,212	592	2,254	729
Interest (expense) income, net	(2,309)	(2,535)	(7,028)	(7,727)
Net Income Including Noncontrolling Interest	19,005	19,654	33,107	34,721
Less Net Income Attributable to Noncontrolling Interest, net of tax	0	0	0	0
Net Income (Loss)	19,005	19,654	33,107	34,721
Segment Reporting Assets And Capital Expenditures [Abstract]
Assets	948,030		948,030		888,444
Capital Expenditures			79,637		81,965
MGE [Member] | Gas [Member]
Segment Reporting Information [Line Items]
Operating revenues	18,864	16,587	121,373	92,235
Interdepartmental revenues	2,757	4,658	10,449	10,721
Total operating revenues	21,621	21,245	131,822	102,956
Depreciation and amortization	(1,497)	(1,399)	(4,357)	(4,158)
Other operating expenses	(20,748)	(21,180)	(117,346)	(94,938)
Operating Income	(624)	(1,334)	10,119	3,860
Other income, net	106	167	77	206
Interest (expense) income, net	(729)	(715)	(2,166)	(2,179)
Net Income Including Noncontrolling Interest	(1,247)	(1,882)	8,030	1,887
Less Net Income Attributable to Noncontrolling Interest, net of tax	0	0	0	0
Net Income (Loss)	(1,247)	(1,882)	8,030	1,887
Segment Reporting Assets And Capital Expenditures [Abstract]
Assets	274,896		274,896		285,468
Capital Expenditures			9,423		13,812
MGE [Member] | Non Regulated Energy [Member]
Segment Reporting Information [Line Items]
Operating revenues	1,399	2,337	4,075	6,894
Interdepartmental revenues	10,660	8,679	31,924	26,032
Total operating revenues	12,059	11,016	35,999	32,926
Depreciation and amortization	(1,788)	(1,777)	(5,368)	(5,330)
Other operating expenses	(3,502)	(3,075)	(10,305)	(9,154)
Operating Income	6,769	6,164	20,326	18,442
Other income, net	0	0	0	0
Interest (expense) income, net	(1,596)	(1,631)	(4,814)	(4,915)
Net Income Including Noncontrolling Interest	5,173	4,533	15,512	13,527
Less Net Income Attributable to Noncontrolling Interest, net of tax	0	0	0	0
Net Income (Loss)	5,173	4,533	15,512	13,527
Segment Reporting Assets And Capital Expenditures [Abstract]
Assets	289,758		289,758		323,166
Capital Expenditures			3,032		2,658
MGE [Member] | Transmission Investment [Member]
Segment Reporting Information [Line Items]
Operating revenues	0	0	0	0
Interdepartmental revenues	0	0	0	0
Total operating revenues	0	0	0	0
Depreciation and amortization	0	0	0	0
Other operating expenses	(1)	0	(1)	0
Operating Income	(1)	0	(1)	0
Other income, net	1,401	1,371	4,208	4,045
Interest (expense) income, net	0	0	0	0
Net Income Including Noncontrolling Interest	1,400	1,371	4,207	4,045
Less Net Income Attributable to Noncontrolling Interest, net of tax	0	0	0	0
Net Income (Loss)	1,400	1,371	4,207	4,045
Segment Reporting Assets And Capital Expenditures [Abstract]
Assets	63,666		63,666		61,064
Capital Expenditures			0		0
MGE [Member] | Consolidation Elimination Entries [Member]
Segment Reporting Information [Line Items]
Operating revenues	0	0	0	0
Interdepartmental revenues	(13,589)	(13,496)	(42,783)	(37,140)
Total operating revenues	(13,589)	(13,496)	(42,783)	(37,140)
Depreciation and amortization	0	0	0	0
Other operating expenses	13,589	13,496	42,783	37,140
Operating Income	0	0	0	0
Other income, net	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	(6,861)	(6,153)	(20,547)	(18,305)
Net Income (Loss)	(6,861)	(6,153)	(20,547)	(18,305)
Segment Reporting Assets And Capital Expenditures [Abstract]
Assets	(9,881)		(9,881)		(23,050)
Capital Expenditures			0		0
MGE [Member] | Assets Not Allocated [Member]
Segment Reporting Assets And Capital Expenditures [Abstract]
Assets	50,963		50,963		18,559
Capital Expenditures			$ 0		$ 0

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Pension and Other Postretirement Plans (Tables)

9 Months Ended

Sep. 30, 2013

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 ended September 30, 2013 and 2012. 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)		2013		2012		2013		2012
Pension Benefits
Components of net periodic benefit cost:
Service cost	$	1,924	$	1,871	$	5,764	$	5,613
Interest cost		3,178		3,236		9,521		9,711
Expected return on assets		(4,764)		(3,917)		(14,273)		(11,756)
Amortization of:
Prior service cost		79		111		237		333
Actuarial loss		2,011		2,058		6,023		6,177
Net periodic benefit cost	$	2,428	$	3,359	$	7,272	$	10,078
Postretirement Benefits
Components of net periodic benefit cost:
Service cost	$	594	$	626	$	1,781	$	1,879
Interest cost		966		1,089		2,898		3,267
Expected return on assets		(542)		(421)		(1,626)		(1,263)
Amortization of:
Transition obligation		0		103		2		309
Prior service cost		28		27		83		81
Actuarial loss		310		601		930		1,802
Net periodic benefit cost	$	1,356	$	2,025	$	4,068	$	6,075

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Rate Matters

9 Months Ended

Sep. 30, 2013

Regulated Operations [Abstract]

Rate Matters

10.       Rate Matters - MGE Energy and MGE.

a.       Rate Proceedings.

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

On December 14, 2012, the PSCW authorized MGE to increase 2013 rates for retail electric customers by 3.8% or $14.9 million and to increase gas rates by 1.0% or $1.6 million. The change in retail electric rates was driven by costs for new environmental equipment at Columbia, final construction costs for the Elm Road Units, transmission reliability enhancements, and purchased power costs. The authorized return on common stock equity remains unchanged at 10.3%.

On December 15, 2011, under a limited reopener of MGE'slast rate order, the PSCW authorized MGE to increase 2012 rates for retail electric customers by 4.3% or $15.7 million and to increase gas rates by 0.3% or $0.6 million. The change in retail electric rates was driven by MGE's electric fuel and purchased power costs, increased transmission costs, an update to the Elm Road Units' costs, and an increase for energy efficiency programs. The PSCW also approved deferral of CSAPR costs.

b.       Fuel Rules.

Fuel rules require the PSCW and Wisconsin utilities to defer electric fuel-related costs that fall outside a symmetrical cost tolerance band around the amount approved for a utility in its most recent base rate proceedings. Any over/under recovery of the actual costs is determined on an annual basis and will be adjusted in future billings to electric retail customers. The fuel rules bandwidth is currently set at plus or minus 2%. Under fuel rules, MGE would defer costs, less any excess revenues, if its actual electric fuel costs exceeded 102% of the electric fuel costs allowed in its latest rate order. Excess revenues are defined as revenues in the year in question that provide MGE with a greater return on common equity than authorized by the PSCW in MGE's latest rate order. Conversely, MGE is required to defer the benefit of lower costs if actual electric fuel costs were less than 98% of the electric fuel costs allowed in that order.As of September 30, 2013, MGE has deferred $4.4 million (to be returned to customers in a future period) of 2013 electric fuel-related savings that are outside the range authorized by the PSCW.

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Derivative and Hedging Instruments (Details-2) (USD $) In Thousands, unless otherwise specified	Sep. 30, 2013	Dec. 31, 2012
Commodity Derivative Contracts [Member]
Offsetting Liabilities [Line Items]
Gross amounts	$ 231	$ 405
Gross amounts offset in balance sheet	(231)	(405)
Collateral posted against derivative positions	0	0
Net amount presented in balance sheet	0	0
Purchased Power Agreement [Member]
Offsetting Liabilities [Line Items]
Gross amounts	69,020	72,590
Gross amounts offset in balance sheet	0	0
Collateral posted against derivative positions	0	0
Net amount presented in balance sheet	$ 69,020	$ 72,590

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Pension and Other Postretirement Plans (Details) (USD $)	3 Months Ended		9 Months Ended
	Sep. 30, 2013	Sep. 30, 2012	Sep. 30, 2013	Sep. 30, 2012
Deferred pension and OPRB costs recovered [Abstract]
Deferred pension and OPRB costs recovered	$ 300,000	$ 300,000	$ 900,000	$ 900,000
Pension Benefits [Member]
Components of net periodic benefit cost:
Service cost	1,924,000	1,871,000	5,764,000	5,613,000
Interest cost	3,178,000	3,236,000	9,521,000	9,711,000
Expected return on assets	(4,764,000)	(3,917,000)	(14,273,000)	(11,756,000)
Amortization of:
Prior service cost	79,000	111,000	237,000	333,000
Actuarial loss	2,011,000	2,058,000	6,023,000	6,177,000
Net periodic benefit cost	2,428,000	3,359,000	7,272,000	10,078,000
Postretirement Benefits [Member]
Components of net periodic benefit cost:
Service cost	594,000	626,000	1,781,000	1,879,000
Interest cost	966,000	1,089,000	2,898,000	3,267,000
Expected return on assets	(542,000)	(421,000)	(1,626,000)	(1,263,000)
Amortization of:
Transition obligation	0	103,000	2,000	309,000
Prior service cost	28,000	27,000	83,000	81,000
Actuarial loss	310,000	601,000	930,000	1,802,000
Net periodic benefit cost	$ 1,356,000	$ 2,025,000	$ 4,068,000	$ 6,075,000

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Investment in ATC (Details-1) (USD $)	9 Months Ended					4 Months Ended
	Sep. 30, 2013	Sep. 30, 2012	Sep. 30, 2013 MGE Transco [Member] ATC [Member]	Sep. 30, 2012 MGE Transco [Member] ATC [Member]	Dec. 31, 2012 MGE Transco [Member] ATC [Member]	Oct. 31, 2013 MGE Transco [Member] ATC [Member] Subsequent Event [Member]
Schedule Of Equity Method Investments [Line Items]
Equity earnings from investment	$ 7,045,000	$ 6,764,000	$ 7,000,000	$ 6,800,000
Dividend income from investment	5,498,000	5,300,000	5,500,000	5,300,000
Capital contributions to investment	1,305,000	1,988,000	1,100,000	1,800,000		400,000
Equity method investment			$ 63,600,000		$ 61,000,000

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Investment in ATC (Details-2) (ATC [Member], USD $) In Thousands, unless otherwise specified	3 Months Ended		9 Months Ended
	Sep. 30, 2013	Sep. 30, 2012	Sep. 30, 2013	Sep. 30, 2012
ATC [Member]
Schedule Of Equity Method Investments [Line Items]
Operating revenues	$ 160,480	$ 150,303	$ 464,345	$ 450,136
Operating expenses	(77,595)	(68,813)	(217,240)	(210,139)
Other income (expense), net	917	(5)	585	(832)
Interest expense, net	(21,136)	(20,983)	(63,232)	(61,260)
Earnings before members' income taxes	$ 62,666	$ 60,502	$ 184,458	$ 177,905

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Consolidated Statements of Common Equity (Unaudited) (Parentheticals) (USD $)	3 Months Ended		9 Months Ended
	Sep. 30, 2013	Sep. 30, 2012	Sep. 30, 2013	Sep. 30, 2012
Consolidated Statements of Common Equity
Dividends per share of common stock	$ 0.408	$ 0.395	$ 1.198	$ 1.161

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Commitments and Contingencies (Tables)

9 Months Ended

Sep. 30, 2013

Commitments and Contingencies Disclosure [Abstract]

Chattel Paper Agreement, Fiscal Year Maturity Schedule

Principal payments for the remainder of 2013 and the next four years on the loans are:

(In thousands)		2013		2014		2015		2016		2017
Chattel Paper	$	213	$	621	$	937	$	862	$	455

Purchase Contracts, Fiscal Year Maturity Schedule

As of September 30, 2013, the future commitments related to these purchase contracts were as follows:

(In thousands)		2013		2014		2015		2016		2017
Coal(a)	$	7,407	$	17,705	$	9,921	$	3,770	$	1,040
Natural gas
Transportation & storage
Natural gas supply(b)		14,549		13,601		0		0		0
Purchase power(c)		49,397		49,262		47,776		48,795		49,816
Other		1,691		0		0		0		0
	$	73,044	$	80,568	$	57,697	$	52,565	$	50,856

(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 are 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)These commitments include market-based pricing. Management expects to recover these costs in future customer rates.

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

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Commitments and Contingencies (Details-2) (USD $)	9 Months Ended
	Sep. 30, 2013
Chattel Paper Purchase Agreement [Abstract]
Chattel paper purchase agreement maximum interest	$ 10,000,000
Outstanding interest in chattel paper receivables	5,000,000
Servicing asset recognized	300,000
Operating expense purchase contracts [Abstract]
Purchase obligation due in remainder of fiscal year	73,044,000
Purchase obligation due in second year	80,568,000
Purchase obligation due in third year	57,697,000
Purchase obligation due in fourth year	52,565,000
Purchase obligation due in fifth year	50,856,000
Chattel Paper [Member]
Contractual obligation [Abstract]
Contractual obligation due in remainder of fiscal year	213,000
Contractual obligation due in second year	621,000
Contractual obligation due in third year	937,000
Contractual obligation due in fourth year	862,000
Contractual obligation due in fifth year	455,000
Coal Commitment [Member]
Operating expense purchase contracts [Abstract]
Purchase obligation due in remainder of fiscal year	7,407,000	[1]
Purchase obligation due in second year	17,705,000	[1]
Purchase obligation due in third year	9,921,000	[1]
Purchase obligation due in fourth year	3,770,000	[1]
Purchase obligation due in fifth year	1,040,000	[1]
Natural Gas Supply Commitment [Member]
Operating expense purchase contracts [Abstract]
Purchase obligation due in remainder of fiscal year	14,549,000	[2]
Purchase obligation due in second year	13,601,000	[2]
Purchase obligation due in third year	0	[2]
Purchase obligation due in fourth year	0	[2]
Purchase obligation due in fifth year	0	[2]
Purchase Power Commitment [Member]
Operating expense purchase contracts [Abstract]
Purchase obligation due in remainder of fiscal year	49,397,000	[3]
Purchase obligation due in second year	49,262,000	[3]
Purchase obligation due in third year	47,776,000	[3]
Purchase obligation due in fourth year	48,795,000	[3]
Purchase obligation due in fifth year	49,816,000	[3]
Other Commitment [Member]
Operating expense purchase contracts [Abstract]
Purchase obligation due in remainder of fiscal year	1,691,000
Purchase obligation due in second year	0
Purchase obligation due in third year	0
Purchase obligation due in fourth year	0
Purchase obligation due in fifth year	$ 0
Chattel Paper [Member] | Minimum [Member]
Chattel Paper Purchase Agreement [Abstract]
Guarantee to financial institution, term	1 year
Chattel Paper [Member] | Maximum [Member]
Chattel Paper Purchase Agreement [Abstract]
Guarantee to financial institution, term	10 years

[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 are 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] These commitments include market-based pricing. Management expects to recover these costs in future customer rates.

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

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Investment in ATC

9 Months Ended

Sep. 30, 2013

Equity Method Investments and Joint Ventures [Abstract]

Investment in ATC

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. 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, 2013 and 2012, MGE Transco recorded equity earnings from the investment in ATC of $7.0million and $6.8million, respectively. Dividends received from ATC were $5.5 million and $5.3 million for the nine months endedSeptember 30, 2013 and 2012, respectively. In addition, during the nine months endedSeptember 30, 2013 and 2012, MGE Transco made $1.1 million and $1.8 million in capital contributions to ATC, respectively.On October 31, 2013, MGE Transco made a $0.4million capital contribution to ATC.

MGE Transco's investment in ATC as of September 30, 2013 and December 31, 2012 was $63.6 million and $61.0 million, respectively.

At September 30, 2013, 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, 2013 and 2012, is as follows:

		Three Months Ended				Nine Months Ended
		September 30,				September 30,
(In thousands)		2013		2012		2013		2012
Operating revenues	$	160,480	$	150,303	$	464,345	$	450,136
Operating expenses		(77,595)		(68,813)		(217,240)		(210,139)
Other income (expense), net		917		(5)		585		(832)
Interest expense, net		(21,136)		(20,983)		(63,232)		(61,260)
Earnings before members' income taxes	$	62,666	$	60,502	$	184,458	$	177,905

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Madison Gas and Electric Company Consolidated Statements of Common Equity (Unaudited) (USD $) In Thousands	Total USD ($)	MGE [Member] USD ($)	Common Stock [Member]	Common Stock [Member] MGE [Member] USD ($)	Additional Paid-In Capital [Member] MGE [Member] USD ($)	Retained Earnings [Member] MGE [Member] USD ($)	Accumulated Other Comprehensive (Loss)/Income [Member] USD ($)	Accumulated Other Comprehensive (Loss)/Income [Member] MGE [Member] USD ($)	Noncontrolling Interest [Member] MGE [Member] USD ($)
Beginning balance, value at Dec. 31, 2011		$ 527,277		$ 17,348	$ 192,417	$ 203,114		$ 47	$ 114,351
Beginning balance, shares at Dec. 31, 2011			23,114	17,348
Net Income		54,180				35,875			18,305
Other comprehensive income (loss)	35	(30)					35	(30)
Cash dividends paid to parent by MGE		(13,456)				(13,456)
Equity contribution received by noncontrolling interest		1,775							1,775
Distributions to parent from noncontrolling interest		(15,500)							(15,500)
Ending balance, value at Sep. 30, 2012		554,246		17,348	192,417	225,533		17	118,931
Ending balance, shares at Sep. 30, 2012			23,114	17,348
Beginning balance, value at Jun. 30, 2012
Net Income		23,676
Ending balance, value at Sep. 30, 2012		554,246		17,348	192,417
Ending balance, shares at Sep. 30, 2012			23,114	17,348
Beginning balance, value at Dec. 31, 2012		550,766		17,348	192,417	223,527		4	117,470
Beginning balance, shares at Dec. 31, 2012			23,114	17,348
Net Income		60,856				40,309			20,547
Other comprehensive income (loss)	176	77					176	77
Cash dividends paid to parent by MGE		0
Equity contribution received by noncontrolling interest		1,065							1,065
Distributions to parent from noncontrolling interest		(21,148)							(21,148)
Ending balance, value at Sep. 30, 2013		591,616		17,348	192,417	263,836		81	117,934
Ending balance, shares at Sep. 30, 2013			23,114	17,348
Beginning balance, value at Jun. 30, 2013
Net Income		24,331
Ending balance, value at Sep. 30, 2013		$ 591,616		$ 17,348	$ 192,417
Ending balance, shares at Sep. 30, 2013			23,114	17,348

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MGE Energy Inc Consolidated Statements of Cash Flows (Unaudited) (USD $) In Thousands, unless otherwise specified	9 Months Ended
	Sep. 30, 2013	Sep. 30, 2012
Operating Activities:
Net Income	$ 60,828	$ 53,960
Items not affecting cash:
Depreciation and amortization	28,864	29,042
Deferred income taxes	32,706	54,602
Provision for doubtful receivables	1,551	1,537
Employee benefit plan expenses	9,908	13,815
Equity earnings in ATC	(7,045)	(6,764)
Other items	250	1,632
Changes in working capital items:
Decrease (increase) in current assets	15,053	(9,002)
Decrease in current liabilities	(5,496)	(13,418)
Dividend income from ATC	5,498	5,300
Cash contributions to pension and other postretirement plans	(33,919)	(24,336)
Debt make-whole premium	(6,757)	0
Other noncurrent items, net	7,159	9,518
Cash Provided by Operating Activities	108,600	115,886
Investing Activities:
Capital expenditures	(92,092)	(65,909)
Capital contributions to investments	(1,305)	(1,988)
Other	(780)	(291)
Cash Used for Investing Activities	(94,177)	(68,188)
Financing Activities:
Cash dividends paid on common stock	(27,685)	(26,820)
Repayment of long-term debt	(42,000)	(30,000)
Issuance of long-term debt	85,000	28,000
Other	(765)	(844)
Cash Provided by (Used for) Financing Activities	14,550	(29,664)
Change in cash and cash equivalents	28,973	18,034
Cash and cash equivalents at beginning of period	46,357	41,169
Cash and Cash Equivalents at End of Period	75,330	59,203
Significant noncash investing activities:
Accrued capital expenditures	$ 10,473	$ 7,649

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Rate Matters (Details) (USD $) In Millions, unless otherwise specified	9 Months Ended		12 Months Ended
	Sep. 30, 2013	Sep. 30, 2013 Columbia Environmental Project [Member]	Dec. 31, 2012 Columbia Environmental Project [Member]	Dec. 31, 2013 PSCW [Member]	Dec. 31, 2014 PSCW [Member] Approved Future Rate Matters [Member]	Dec. 31, 2014 PSCW [Member] Columbia Environmental Project [Member] Approved Future Rate Matters [Member]	Dec. 31, 2013 Electric [Member] PSCW [Member]	Dec. 31, 2012 Electric [Member] PSCW [Member]	Dec. 31, 2014 Electric [Member] PSCW [Member] Approved Future Rate Matters [Member]	Dec. 31, 2013 Gas [Member] PSCW [Member]	Dec. 31, 2012 Gas [Member] PSCW [Member]	Dec. 31, 2014 Gas [Member] PSCW [Member] Approved Future Rate Matters [Member]
Rate Proceedings [Abstract]
Authorized AFUDC Rate		50.00%	100.00%			100.00%
Return of electric fuel credit					$ 6.2
Authorized return on equity, percentage				10.30%	10.30%
Authorized rate increase (decrease), percentage							3.80%	4.30%	0.00%	1.00%	0.30%	0.00%
Authorized rate increase (decrease), amount							14.9	15.7		1.6	0.6
Fuel Rules [Abstract]
Fuel rules bandwidth	2.00%
Electric fuel deferred costs upper threshold	102.00%
Electric fuel deferred costs lower threshold	98.00%
Electric fuel costs deferred	$ 4.4

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Segment Information (Tables)

9 Months Ended

Sep. 30, 2013

Segment Reporting [Abstract]

Segment Information

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

(In thousands)						Non-						Consolidation/
MGE Energy						Regulated		Transmission		All		Elimination		Consolidated
		Electric		Gas		Energy		Investment		Others		Entries		Total
Three Months Ended September 30, 2013
Operating revenues	$	119,836	$	18,864	$	1,399	$	0	$	0	$	0	$	140,099
Interdepartmental revenues		172		2,757		10,660		0		0		(13,589)		0
Total operating revenues		120,008		21,621		12,059		0		0		(13,589)		140,099
Depreciation and amortization		(6,425)		(1,497)		(1,788)		0		0		0		(9,710)
Other operating expenses		(82,414)		(21,485)		(33)		(1)		(145)		13,589		(90,489)
Operating income (loss)		31,169		(1,361)		10,238		(1)		(145)		0		39,900
Other income, net		1,166		92		0		2,340		152		0		3,750
Interest (expense) income, net		(2,309)		(729)		(1,596)		0		29		0		(4,605)
Income (loss) before taxes		30,026		(1,998)		8,642		2,339		36		0		39,045
Income tax (provision) benefit		(11,021)		751		(3,469)		(939)		(14)		0		(14,692)
Net income (loss)	$	19,005	$	(1,247)	$	5,173	$	1,400	$	22	$	0	$	24,353
Three Months Ended September 30, 2012
Operating revenues	$	118,914	$	16,587	$	2,337	$	0	$	0	$	0	$	137,838
Interdepartmental revenues		159		4,658		8,679		0		0		(13,496)		0
Total operating revenues		119,073		21,245		11,016		0		0		(13,496)		137,838
Depreciation and amortization		(6,530)		(1,399)		(1,777)		0		0		0		(9,706)
Other operating expenses		(78,823)		(22,675)		(36)		0		(206)		13,496		(88,244)
Operating income (loss)		33,720		(2,829)		9,203		0		(206)		0		39,888
Other income, net		342		97		0		2,280		137		0		2,856
Interest (expense) income, net		(2,535)		(715)		(1,631)		0		32		0		(4,849)
Income (loss) before taxes		31,527		(3,447)		7,572		2,280		(37)		0		37,895
Income tax (provision) benefit		(11,873)		1,565		(3,039)		(909)		3		0		(14,253)
Net income (loss)	$	19,654	$	(1,882)	$	4,533	$	1,371	$	(34)	$	0	$	23,642
Nine Months Ended September 30, 2013
Operating revenues	$	310,176	$	121,373	$	4,075	$	0	$	0	$	0	$	435,624
Interdepartmental revenues		410		10,449		31,924		0		0		(42,783)		0
Total operating revenues		310,586		131,822		35,999		0		0		(42,783)		435,624
Depreciation and amortization		(19,139)		(4,357)		(5,368)		0		0		0		(28,864)
Other operating expenses		(235,390)		(111,494)		(96)		(1)		(537)		42,783		(304,735)
Operating income (loss)		56,057		15,971		30,535		(1)		(537)		0		102,025
Other income, net		2,226		69		0		7,045		430		0		9,770
Interest (expense) income, net		(7,028)		(2,166)		(4,814)		0		71		0		(13,937)
Income (loss) before taxes		51,255		13,874		25,721		7,044		(36)		0		97,858
Income tax (provision) benefit		(18,148)		(5,844)		(10,209)		(2,837)		8		0		(37,030)
Net income (loss)	$	33,107	$	8,030	$	15,512	$	4,207	$	(28)	$	0	$	60,828
Nine Months Ended September 30, 2012
Operating revenues	$	305,189	$	92,235	$	6,894	$	0	$	0	$	0	$	404,318
Interdepartmental revenues		387		10,721		26,032		0		0		(37,140)		0
Total operating revenues		305,576		102,956		32,926		0		0		(37,140)		404,318
Depreciation and amortization		(19,554)		(4,158)		(5,330)		0		0		0		(29,042)
Other operating expenses		(223,876)		(94,162)		(85)		0		(880)		37,140		(281,863)
Operating income (loss)		62,146		4,636		27,511		0		(880)		0		93,413
Other income, net		602		170		0		6,764		439		0		7,975
Interest (expense) income, net		(7,727)		(2,179)		(4,915)		0		104		0		(14,717)
Income (loss) before taxes		55,021		2,627		22,596		6,764		(337)		0		86,671
Income tax (provision) benefit		(20,300)		(740)		(9,069)		(2,719)		117		0		(32,711)
Net income (loss)	$	34,721	$	1,887	$	13,527	$	4,045	$	(220)	$	0	$	53,960

(In thousands)						Non-				Consolidation/
MGE						Regulated		Transmission		Elimination		Consolidated
		Electric		Gas		Energy		Investment		Entries		Total
Three Months Ended September 30, 2013
Operating revenues	$	119,836	$	18,864	$	1,399	$	0	$	0	$	140,099
Interdepartmental revenues		172		2,757		10,660		0		(13,589)		0
Total operating revenues		120,008		21,621		12,059		0		(13,589)		140,099
Depreciation and amortization		(6,425)		(1,497)		(1,788)		0		0		(9,710)
Other operating expenses*		(93,481)		(20,748)		(3,502)		(1)		13,589		(104,143)
Operating income (loss)*		20,102		(624)		6,769		(1)		0		26,246
Other income, net*		1,212		106		0		1,401		0		2,719
Interest expense, net		(2,309)		(729)		(1,596)		0		0		(4,634)
Net income (loss)		19,005		(1,247)		5,173		1,400		0		24,331
Less: Net income attributable to
noncontrolling interest, net of tax		0		0		0		0		(6,861)		(6,861)
Net income (loss) attributable to MGE	$	19,005	$	(1,247)	$	5,173	$	1,400	$	(6,861)	$	17,470
Three Months Ended September 30, 2012
Operating revenues	$	118,914	$	16,587	$	2,337	$	0	$	0	$	137,838
Interdepartmental revenues		159		4,658		8,679		0		(13,496)		0
Total operating revenues		119,073		21,245		11,016		0		(13,496)		137,838
Depreciation and amortization		(6,530)		(1,399)		(1,777)		0		0		(9,706)
Other operating expenses*		(90,946)		(21,180)		(3,075)		0		13,496		(101,705)
Operating income (loss)*		21,597		(1,334)		6,164		0		0		26,427
Other income, net*		592		167		0		1,371		0		2,130
Interest expense, net		(2,535)		(715)		(1,631)		0		0		(4,881)
Net income (loss)		19,654		(1,882)		4,533		1,371		0		23,676
Less: Net income attributable to
noncontrolling interest, net of tax		0		0		0		0		(6,153)		(6,153)
Net income (loss) attributable to MGE	$	19,654	$	(1,882)	$	4,533	$	1,371	$	(6,153)	$	17,523
Nine Months Ended September 30, 2013
Operating revenues	$	310,176	$	121,373	$	4,075	$	0	$	0	$	435,624
Interdepartmental revenues		410		10,449		31,924		0		(42,783)		0
Total operating revenues		310,586		131,822		35,999		0		(42,783)		435,624
Depreciation and amortization		(19,139)		(4,357)		(5,368)		0		0		(28,864)
Other operating expenses*		(253,566)		(117,346)		(10,305)		(1)		42,783		(338,435)
Operating income (loss)*		37,881		10,119		20,326		(1)		0		68,325
Other income, net*		2,254		77		0		4,208		0		6,539
Interest expense, net		(7,028)		(2,166)		(4,814)		0		0		(14,008)
Net income		33,107		8,030		15,512		4,207		0		60,856
Less: Net income attributable to
noncontrolling interest, net of tax		0		0		0		0		(20,547)		(20,547)
Net income attributable to MGE	$	33,107	$	8,030	$	15,512	$	4,207	$	(20,547)	$	40,309
Nine Months Ended September 30, 2012
Operating revenues	$	305,189	$	92,235	$	6,894	$	0	$	0	$	404,318
Interdepartmental revenues		387		10,721		26,032		0		(37,140)		0
Total operating revenues		305,576		102,956		32,926		0		(37,140)		404,318
Depreciation and amortization		(19,554)		(4,158)		(5,330)		0		0		(29,042)
Other operating expenses*		(244,303)		(94,938)		(9,154)		0		37,140		(311,255)
Operating income*		41,719		3,860		18,442		0		0		64,021
Other income, net*		729		206		0		4,045		0		4,980
Interest expense, net		(7,727)		(2,179)		(4,915)		0		0		(14,821)
Net income		34,721		1,887		13,527		4,045		0		54,180
Less: Net income attributable to
noncontrolling interest, net of tax		0		0		0		0		(18,305)		(18,305)
Net income attributable to MGE	$	34,721	$	1,887	$	13,527	$	4,045	$	(18,305)	$	35,875
*Amounts are shown net of the related tax expense, consistent with the presentation on the consolidated MGE Income Statement.

The following table shows segment information for MGE Energy's and MGE's assets and capital expenditures:
		Utility						Consolidated
(In thousands)						Assets							Consolidation/
MGE Energy						not	Nonregulated			Transmission		All		Elimination
		Electric		Gas		Allocated		Energy		Investment		Others		Entries		Total
Assets:
September 30, 2013	$	948,030	$	274,896	$	50,963	$	289,808	$	63,666	$	408,340	$	(391,992)	$	1,643,711
December 31, 2012		888,444		285,468		18,559		323,216		61,064		413,291		(403,118)		1,586,924
Capital Expenditures:
Nine Months Ended September 30, 2013	$	79,637	$	9,423	$	0	$	3,032	$	0	$	0	$	0	$	92,092
Year ended Dec. 31, 2012		81,965		13,812		0		2,658		0		0		0		98,435

		Utility						Consolidated
(In thousands)						Assets
MGE						not	Nonregulated			Transmission		Elimination
		Electric		Gas		Allocated		Energy		Investment		Entries		Total
Assets:
September 30, 2013	$	948,030	$	274,896	$	50,963	$	289,758	$	63,666	$	(9,881)	$	1,617,432
December 31, 2012		888,444		285,468		18,559		323,166		61,064		(23,050)		1,553,651
Capital Expenditures:
Nine Months Ended September 30, 2013	$	79,637	$	9,423	$	0	$	3,032	$	0	$	0	$	92,092
Year ended Dec. 31, 2012		81,965		13,812		0		2,658		0		0		98,435

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Pension and Other Postretirement Plans

9 Months Ended

Sep. 30, 2013

Compensation and Retirement Disclosure [Abstract]

Pension and Other Postretirement Plans

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, 2013 and 2012. 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)		2013		2012		2013		2012
Pension Benefits
Components of net periodic benefit cost:
Service cost	$	1,924	$	1,871	$	5,764	$	5,613
Interest cost		3,178		3,236		9,521		9,711
Expected return on assets		(4,764)		(3,917)		(14,273)		(11,756)
Amortization of:
Prior service cost		79		111		237		333
Actuarial loss		2,011		2,058		6,023		6,177
Net periodic benefit cost	$	2,428	$	3,359	$	7,272	$	10,078
Postretirement Benefits
Components of net periodic benefit cost:
Service cost	$	594	$	626	$	1,781	$	1,879
Interest cost		966		1,089		2,898		3,267
Expected return on assets		(542)		(421)		(1,626)		(1,263)
Amortization of:
Transition obligation		0		103		2		309
Prior service cost		28		27		83		81
Actuarial loss		310		601		930		1,802
Net periodic benefit cost	$	1,356	$	2,025	$	4,068	$	6,075

The PSCW allowed MGE to defer the 2009 incremental pension and OPRB costs above the amounts recovered in rates. During both the three months endedSeptember 30,2013 and 2012, $0.3 millionhas been recovered in rates. During both the nine months ended September 30, 2013 and 2012, $0.9 million has been recovered in rates. These costs are not reflected in the table above.

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Equity and Financing Arrangements

9 Months Ended

Sep. 30, 2013

Equity and Financing Arrangements Disclosure [Abstract]

Equity and Financing Arrangements

2.       Equity and Financing Arrangements.

a.       Common Stock- MGE Energy.

MGE Energy purchases stock in the open market for issuance pursuant to its Stock Plan. All MGE Energy common stock issued under the Stock Plan is sold pursuant to a registration statement that has been filed with the SEC and is currently effective.

MGE Energy can issue new shares of its common stock through the Stock Plan. For both the nine months ended September 30, 2013 and 2012, 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 19, 2013, each of MGE Energy and MGE entered into an amendment to its existing credit agreement dated as of July 30, 2010, with various financial institutions, as lenders, and JPMorgan Chase Bank, N.A., as administrative agent. In the case of MGE Energy, the principal purposes of the amendment are to increase the revolving credit facility to $50 million from $40 million and to extend the expiration date of the credit agreement to July 31, 2017 from July 31, 2015. In the case of MGE, the principal purposes of the amendment are to increase the revolving credit facility to $100 million from $75 million and to extend the expiration date of the credit agreement to July 31, 2017 from July 31, 2015. In addition, both amendments lowered the adders used in the determination of the interest rates under the existing credit agreements. As a result of the amendments, the existing credit agreements for both of MGEEnergy and MGE carry interest at either (i) a "floating rate," plus an adder ranging from zero to 0.125%, depending upon the credit ratings assigned to MGE's senior unsecured long-term debt securities; or (ii) a "Eurodollar Rate," plus an adder ranging from 0.675% to 1.125%, depending 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 "Eurodollar Rate" is calculated as provided in the credit agreements for the selected interest period. As of September 30, 2013, neither MGE Energy nor MGE had any borrowings outstanding under their respective credit agreements and MGE had no commercial paper outstanding.

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

On July 18, 2013, MGE issued $20 million in principal amount of 4.42% senior notes, Series A, due July 15, 2043 and $20 million in principal amount of 4.47%, senior notes, Series B, due July 15, 2048. The Notes were issued pursuant to a Note Purchase Agreement with several note purchasers. The Notes are unsecured and are not issued under, or governed by, MGE's Indenture dated as of September 1, 1998, which governs MGE's Medium-Term Notes. MGE used the net proceeds from the sale of the Notes to redeem on July 18, 2013, $20 million of its 5.26% Medium-Term Notes due September 29, 2017, and to make a $20 million partial redemption of its 5.59% Senior Notes due September 11, 2018. MGE paid a redemption price equal to the principal amount of the notes that were redeemed, plus accrued interest to the redemption date, plus a make-whole premium equal to $3.2 million and $3.6 million, for the 5.26% Medium-Term Notes due September 29, 2017 and 5.59% Senior Notes due September 11, 2018, respectively. The make-whole premiums are treated as a regulatory asset and will be amortized over the life of the Series A and Series B Notes. Any interest savings in 2013 will be deferred.There is $20 million principal amount of the 5.59% Senior Notes remaining outstanding after the redemption.

The Note Purchase Agreement under which the Series A and Series B Notes were issued also includes the issuance on September 16, 2013 of $30 million in principal amount of 3.09% Senior Notes, Series C, due September 15, 2023 and $15 million of 3.29% Senior Notes, Series D, due September 15, 2026. The Series C Notes and the Series D Notes carry interest rates of 3.09% per annum and 3.29% per annum, respectively. The proceeds of the Notes are expected to be used to help finance the Columbia environmental project.

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Derivative and Hedging Instruments

9 Months Ended

Sep. 30, 2013

Derivative Instruments and Hedging Activities Disclosure [Abstract]

Derivative and Hedging Instruments

9.       Derivative and Hedging Instruments - MGE Energy and MGE.

a.       Purpose.

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

b.       Notional Amounts.

The gross notional volume of open derivatives is as follows:

	September 30, 2013	December 31, 2012
Commodity derivative contracts	300,195 MWh	444,650 MWh
Commodity derivative contracts	5,970,000 Dth	1,980,000 Dth
FTRs	3,099 MW	2,670 MW

c.Financial Statement Presentation.

MGE Energy and MGE offset fair value amounts recognized for the right to reclaim collateral (a receivable) or the obligation to return collateral (a payable) against fair value amounts recognized for derivative instruments executed with the same counterparty under a master netting agreement.

MGE purchases and sells exchange-traded and over-the-counter options, swaps, and future contracts. These arrangements are primarily entered into to help stabilize the price risk associated with gas or power purchases. These transactions are employed by both MGE's gas and electric segments. Additionally, as a result of the firm transmission agreements that MGE holds on transmission paths in the MISO market,MGE holdsFTRs. An FTR is a financial instrument that entitles the holder to a stream of revenues or charges based on the differences in hourly day-ahead energy prices between two points on the transmission grid. The fair values of these instruments are reflected as a 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, 2013 and December 31,2012, the fair value of exchange traded derivatives and FTRs exceeded their cost basis by $0.9 million and $0.3 million, respectively.

MGE is a party to a ten-year purchased power agreement that provides MGE with firm capacity and energy during a base term from June 1, 2012, through May 31, 2022. The agreement also allows MGE an option to extend the contract after the base term. The agreement is accounted for as a derivative contract and is recognized at its fair value on the consolidated balance sheet. However, the derivative qualifies for regulatory deferral and is recognized with a corresponding regulatory asset or liability depending on whether the fair value is in a loss or gain position. The fair value of the contract at September 30, 2013 and December 31, 2012, reflects a loss position of $69.0 million and $72.6 million, respectively. The actual fuel cost will be recognized in purchased power expense in the month of purchase.

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

	Asset Derivatives			Liability Derivatives
(In thousands)	Balance Sheet Location		Fair Value	Balance Sheet Location		Fair Value
September 30, 2013
Commodity derivative contracts	Other current assets	$	608	Derivative liability (current)	$	213
Commodity derivative contracts	Other deferred charges		32	Derivative liability (long-term)		18
FTRs	Other current assets		528	Derivative liability (current)		0
Ten-year PPA	N/A		N/A	Derivative liability (current)		9,310
Ten-year PPA	N/A		N/A	Derivative liability (long-term)		59,710
December 31, 2012
Commodity derivative contracts	Other current assets	$	365	Derivative liability (current)	$	394
Commodity derivative contracts	Other deferred charges		95	Derivative liability (long-term)		11
FTRs	Other current assets		206	Derivative liability (current)		0
Ten-year PPA	N/A		N/A	Derivative liability (current)		9,270
Ten-year PPA	N/A		N/A	Derivative liability (long-term)		63,320

The following tables show the effect of netting arrangements for recognized derivative assets and liabilities that are subject to a master netting arrangement or similar arrangement on the balance sheet.

Offsetting of Derivative Assets
				Gross amounts		Collateral		Net amount
				offset in		posted against		presented in
(In thousands)		Gross amounts		balance sheet		derivative positions		balance sheet
September 30, 2013
Commodity derivative contracts	$	640	$	(231)	$	-	$	409
FTRs		528		-		-		528
December 31, 2012
Commodity derivative contracts	$	460	$	(405)	$	-	$	55
FTRs		206		-		-		206

Offsetting of Derivative Liabilities
				Gross amounts		Collateral		Net amount
				offset in		posted against		presented in
(In thousands)		Gross amounts		balance sheet		derivative positions		balance sheet
September 30, 2013
Commodity derivative contracts	$	231	$	(231)	$	-	$	-
Ten-year PPA		69,020		-		-		69,020
December 31, 2012
Commodity derivative contracts	$	405	$	(405)	$	-	$	-
Ten-year PPA		72,590		-		-		72,590

The following tables summarize the unrealized and realized gains and losses related to the derivative instruments on the consolidated balance sheet at September 30, 2013 and 2012, and the consolidated income statement for the three and nine months endedSeptember 30, 2013 and 2012.

		2013				2012
(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,	$	66,649	$	658	$	79,362	$	718
Change in unrealized loss (gain)		2,330		0		(468)		0
Realized loss reclassified to a deferred account		(275)		275		(223)		223
Realized loss reclassified to income
statement		(621)		(111)		(3,414)		(161)
Balance at September 30,	$	68,083	$	822	$	75,257	$	780
Nine Months Ended September 30:
Balance at January 1,	$	72,329	$	574	$	42,356	$	1,604
Change in unrealized loss (gain)		(1,330)		0		42,633		0
Realized loss reclassified to a deferred account		(953)		953		(3,103)		3,103
Realized loss reclassified to income
statement		(1,963)		(705)		(6,629)		(3,927)
Balance at September 30,	$	68,083	$	822	$	75,257	$	780

		Realized losses (gains)
				Fuel for electric
		Regulated		generation/		Cost of
(In thousands)		gas revenues		purchased power		gas sold
Three Months Ended September 30, 2013:
Commodity derivative contracts	$	0	$	(7)	$	0
FTRs		0		(387)		0
Ten-year PPA		0		1,126		0
Three Months Ended September 30, 2012:
Commodity derivative contracts	$	0	$	176	$	0
FTRs		0		(256)		0
Ten-year PPA		0		3,655		0
Nine Months Ended September 30, 2013:
Commodity derivative contracts	$	0	$	(523)	$	608
FTRs		0		(896)		0
Ten-year PPA		0		3,479		0
Nine Months Ended September 30, 2012:
Commodity derivative contracts	$	0	$	2,685	$	3,090
FTRs		0		(93)		0
Ten-year PPA		0		4,874		0

MGE's commodity derivative contracts, FTRs, and ten-year PPA are subject to regulatory deferral. These derivatives are marked to fair value and are offset with a corresponding regulatory asset or liability. Realized gains and losses are deferred on the consolidated balance sheet and are recognized in earnings in the delivery month applicable to the instrument. As a result of the above described treatment, there are no unrealized gains or losses that flow through earnings.

The ten-year PPA has a provision that may require MGE to post collateral if MGE's debt rating falls below investment grade (i.e., below BBB-). The amount of collateral that it may be required to post varies from $20.0 million to $40.0 million, depending on MGE's nominated capacity amount. As of September 30, 2013, no collateral has been posted. Certain counterparties extend MGE a credit limit. If MGE exceeds these limits, the counterparties may require collateral to be posted.As ofSeptember 30, 2013 and December 31,2012,no counterparties were in a net liability position.

Nonperformance of counterparties to the non-exchange traded derivatives could expose MGE to credit loss. However, MGE enters into transactions only with companies that meet or exceed strict credit guidelines, and it monitors these counterparties on an ongoing basis to mitigate nonperformance risk in its portfolio. As of September 30, 2013,no counterparties have defaulted.

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Share-Based Compensation

9 Months Ended

Sep. 30, 2013

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

Share-Based Compensation

7.       Share-Based Compensation - MGE Energy and MGE.

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

In addition to units granted in 2009 through 2012, on February 15, 2013,15,256 units were granted based on the MGE Energy closing stock price as of that date. These units are subject to a five-year graded vesting schedule. 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, 2013, 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 the event of a bona fide retirement, not followed by work for a competitor, the executive will receive full vesting credit for each outstanding award.

During the nine months ended September 30, 2013 and 2012, MGE recorded $1.1 million and $1.4 million, respectively, in compensation expense as a result of the Performance Unit Plan. In January 2013, cash payments of $1.0 million were distributed relating to awards that were granted in 2008 and became payable under the Performance Unit Plan. No forfeitures occurred during the nine months ended September 30, 2013 or 2012. At September 30, 2013, $3.6 million of outstanding awards are vested.

XML

Document and Entity Information	9 Months Ended
	Sep. 30, 2013
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, 2013
Amendment Flag	false
Document Fiscal Year Focus	2013
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	23,113,638
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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Commitments and Contingencies

9 Months Ended

Sep. 30, 2013

Commitments and Contingencies Disclosure [Abstract]

Commitments and Contingencies

8.Commitments and Contingencies.

a.       Environmental - MGE Energy and MGE.

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

• The President's announced plan and directive to the EPA to regulate carbon pollution, or GHG emissions, from new and existing electric power generation, which is discussed below.
• Rules to regulate NOx and SO2 emissions, including the EPA's Cross State Air Pollution Rule (CSAPR), which is currently vacated as a result of a federal appellate court ruling; and Wisconsin's plan for implementing the EPA's Clean Air Visibility Rule (CAVR). In June 2013, the U.S. Supreme Court indicated that it would review the CSAPR appellate court ruling. The Sierra Club has sought federal appellate court review of Wisconsin's implementation plan for CAVR. Both the vacation of CSAPR and the appellate court review of Wisconsin's implementation plan for CAVR make the nature of compliance requirements uncertain.
• Rules to regulate mercury and similar emissions, including Wisconsin's adopted Mercury Rule and the EPA's adopted Mercury and Air Toxics Standards.
• The EPA's proposed cooling water intake rules. The EPA issued a proposed Phase II rule and alternative compliance strategies for existing facilities in April 2011 and has announced that it intends to release the final rule in November 2013.

The matters in the second, third, and fourth bullet points are discussed further in Footnote 18.e. in MGE Energy's and MGE's 2012 Annual Report on Form 10-K. In addition to the developments noted above, the following discussion is an update to the current status of environmental matters set forth in that Footnote.

Water Quality

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

In June 2013, the EPA published a proposed rule focusing on the reduction of metals and other pollutants in wastewater from new and existing coal-burning electric generation plants. The proposed rule is technology-driven in that specific technologies may need to be installed and sites that already have these technologies will be deemed to meet the requirements of the rule. The proposed rule as written will likely affect Columbia and the Elm Road Units. The EPA has announced that it plans to finalize the rule by May 22, 2014 and that it expects the rule to affect power plants as they renew their water discharge permits beginning in July 2017. We are currently evaluating the rule's specific impacts at these sites and will not know the full extent of those impacts until the rule is finalized.

Air Quality

Greenhouse Gas Regulation

President Obama's Executive Order Regarding Climate Change and his Directive to the EPA Regarding Power Sector Pollution Standards

In June 2013, President Obama introduced his “National Climate Action Plan.” The plan consists of planned federal actions and directives to several federal agencies, including the EPA, on a range of activities and policies designed to reduce greenhouse gas emissions in the United States. The directive to the EPA, which President Obama provided to the EPA in a memo, to develop carbon pollution standards for the electric power sector, has the greatest potential effect on MGE's operations. See the GHG New Performance Standards discussion below for additional details.

GHG New Source Performance Standards (NSPS)

In a June 2013 directive, President Obama instructed the EPA to re-propose greenhouse gas standards for new power plants by September 20, 2013, based on comments received on their original rule proposal issued in March 2012, and to finalize those standards in a timely manner. The EPA met the President's directive and published revised proposed standards for new power plants in September 2013, that would require, if finalized, that new coal-fired units and small natural gas units meet carbon dioxide emission levels significantly below current levels.

The June 2013 directive also instructed the EPA to propose standards, regulations or guidelines for modified, reconstructed and existing power plants under Sections 111(b) and 111(d) of the Clean Air Act no later than June 2014 and to finalize those standards by June 2015. The directive further instructs the EPA to require states to submit implementation plans for this rule by June 30, 2016. The Directive asks the EPA to aim to develop a market-based approach towards carbon reduction, promote cleaner technologies while keeping energy options diverse, work with other government agencies to keep energy affordable and improve energy efficiencies, and engage States, the power industry, and the other key stakeholders in establishing and implementing strategies for greenhouse gas reductions.

While it is too early to predict with any certainty the specific costs that MGE will incur with implementation of a greenhouse gas reduction rule introduced under Section 111 of the Clean Air Act, it is reasonable to assume that costs of implementation of this rule could be significant depending on the approach taken.

Columbia

MGE and two other utilities jointly own Columbia, a coal-fired generating facility, which accounts for 225 MW (29%) of MGE's net summer generating capability. WPL is the plant operator and permit holder, and owns 46.2% of Columbia. Wisconsin Public Service Corporation (WPSC) owns a 31.8% interest, and MGE owns a 22% interest in Columbia. Based upon current available information, compliance with various environmental requirements and initiatives is expected to result in significant additional operating and capital expenditures at Columbia as noted below.

Columbia Environmental Project

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

Title V Operating Permit Petition

As discussed in Footnote 18.e. in MGE Energy's and MGE's 2012 Annual Report on Form 10-K, the WDNR's renewal of WPL's Title V operating permit for Columbia has been the subject of litigation initiated by a citizen group. On February 4, 2013, the parties involved dismissed the litigation without prejudice. The resolution of the Clean Air Act litigation, discussed below, included resolution of the citizen group's challenge to the renewal of the Columbia Title V operating permit. By letter dated July 30, 2013, the EPA withdrew its proposal that WPL apply to the EPA for the issuance of the renewed Columbia Title V permit. MGE believes the permits currently in effect for Columbia remain in effect at this time and will now be renewed by the WDNR. MGE continues to follow these developments and is unable to predict the outcome of this matter and its impact on its operations or financial condition.

Columbia Clean Air Act Litigation

In December 2009, the EPA sent a notice of violation (NOV) to MGE as one of the co-owners of Columbia. The NOV alleges that WPL, as owner-operator, and the other co-owners failed to comply with appropriate pre-construction review and permitting requirements and, as a result, violated the PSD program requirements, the Title V operating permit requirements of the CAA and the Wisconsin State Implementation Plan (SIP). In April 2013, the EPA filed a lawsuit against the co-owners of Columbia asserting similar allegations. In September 2010 and April 2013, Sierra Club filed lawsuits against WPL alleging violations of the CAA at Columbia and other WPL-operated Wisconsin facilities.

In April 2013, WPL, as owner-operator, along with the other owners of Columbia, entered into a consent decree with the EPA and the Sierra Club to resolve these claims, while admitting no liability. In June 2013, the consent decree was approved and entered by the Court. The consent decree requires installation of the following emission controls at Columbia: scrubbers and baghouses at Columbia Units 1 and 2 by December 31, 2014, and an SCR system at Columbia Unit 2 by December 31, 2018.In addition, the consent decree establishes emission rate limits for SO2, nitrogen oxide (NOx), and particulate matter for Columbia Units 1 and 2. The consent decree also includes annual plant-wide emission caps for SO2 and NOx for Columbia. MGE also paid approximately $0.2 million as its share of a civil penalty and will complete approximately $0.6 million in environmental mitigation projects. MGE intends to seek recovery in rates of the costs associated with its compliance with the terms of the final consent decree and currently expects to recover any material compliance costs.

b.       Chattel Paper Agreement and Other Guarantees - MGE 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. MGE is party to a chattel paper purchase agreement with a financial institution under which it can sell or finance an undivided interest with recourse, in up to $10.0 million of the financing program receivables, until July 31, 2014. At September 30, 2013, MGE has outstanding a $5.0 million interest in these receivables. MGE retains the servicing responsibility for these receivables. As of September 30, 2013, the servicing asset recognized by MGE is $0.3 million.

MGE accounts for servicing rights under the amortization method. Initial determination of the servicing asset fair value is based on the present value of the estimated future cash flows. The discount rate is based on the PSCW authorized weighted cost of capital.

MGE would be required to perform under its guarantee if a customer defaulted on its loan. The energy-related equipment installed at the customer sites is used to secure the customer loans. The loan balances outstanding at September 30, 2013, approximate the fair value of the energy-related equipment acting as collateral. The length of the MGE guarantee to the financial institution varies from one to ten years depending on the term of the underlying customer loan. Principal payments for the remainder of 2013 and the next four years on the loans are:

(In thousands)		2013		2014		2015		2016		2017
Chattel Paper	$	213	$	621	$	937	$	862	$	455

c.       Legal Matters - MGE Energy and MGE.

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

d.       Purchase Contracts - MGE Energy and MGE.

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, 2013, the future commitments related to these purchase contracts were as follows:

(In thousands)		2013		2014		2015		2016		2017
Coal(a)	$	7,407	$	17,705	$	9,921	$	3,770	$	1,040
Natural gas
Transportation & storage
Natural gas supply(b)		14,549		13,601		0		0		0
Purchase power(c)		49,397		49,262		47,776		48,795		49,816
Other		1,691		0		0		0		0
	$	73,044	$	80,568	$	57,697	$	52,565	$	50,856

(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 are 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)These commitments include market-based pricing. Management expects to recover these costs in future customer rates.

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