10-K

United States

SECURITIES AND EXCHANGE COMMISSION

Washington, D.C. 20549

FORM 10-K

[X] Annual Report Pursuant to Section 13 or 15(d) of the Securities Exchange Act of 1934

For the fiscal year ended:

December 31, 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

SECURITIES REGISTERED PURSUANT TO SECTION 12(b) OF THE ACT:

	Title of Class	Name of Each Exchange on which Registered
MGE Energy, Inc.	Common Stock, $1 Par Value Per Share	The Nasdaq Stock Market

SECURITIES REGISTERED PURSUANT TO SECTION 12(g) OF THE ACT:

	Title of Class
Madison Gas and Electric Company	Common Stock, $1 Par Value Per Share

Indicate by checkmark if the registrant is a well-known seasoned issuer, as defined in Rule 405 of the Securities Act.

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

Indicate by checkmark if the registrant is not required to file reports pursuant to Section 13 or Section 15(d) of the Act.

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

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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 registrants were 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 if disclosure of delinquent filers pursuant to Item 405 of Regulation S-K is not contained herein, and will not be contained, to the best of registrants' knowledge, in definitive proxy or information statements incorporated by reference in Part III of this Form 10-K or any amendment to this Form 10-K. [X]

Indicate by check mark if the registrant is a large accelerated filer, an accelerated filer, a non-accelerated filer, or a smaller reporting company. See definition 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 checkmark whether the registrant is a shell company (as defined in Rule 12b-2 of the Exchange Act).

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

The aggregate market value of the voting and nonvoting common equity held by nonaffiliates of each registrant as of June 30, 2013, was as follows:

MGE Energy, Inc.	$1,262,041,684
Madison Gas and Electric Company	$0

The number of shares outstanding of each registrant's common stock as of February 1, 2014, were as follows:

MGE Energy, Inc.	34,668,370
Madison Gas and Electric Company	17,347,894

DOCUMENTS INCORPORATED BY REFERENCE

Portions of MGE Energy, Inc.'s definitive proxy statement to be filed on or before March 28, 2014, relating to its annual meeting of shareholders, are incorporated by reference into Part III of this annual report on Form 10-K.

Madison Gas and Electric Company meets the conditions set forth in General Instruction (I)(1)(a) and (b) of Form 10-K and is therefore omitting (i.) the information otherwise required by Item 601 of Regulation S-K relating to a list of subsidiaries of the registrant as permitted by General Instruction (I)(2)(b), (ii.) the information otherwise required by Item 6 relating to Selected Financial Data as permitted by General Instruction (I)(2)(a), (iii.) the information otherwise required by Item 10 relating to Directors and Executive Officers as permitted by General Instruction (I)(2)(c), (iv.) the information otherwise required by Item 11 relating to executive compensation as permitted by General Instruction (I)(2)(c), (v.) the information otherwise required by Item 12 relating to Security Ownership of Certain Beneficial Owners and Management as permitted by General Instruction (I)(2)(c), and (vi.) the information otherwise required by Item 13 relating to Certain Relationships and Related Transactions as permitted by General Instruction (I)(2)(c).

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Table of Contents

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Filing Format

This combined Form 10-K is being filed separately by MGE Energy, Inc. (MGE Energy) and Madison Gas and Electric Company (MGE). MGE is a wholly owned subsidiary of MGE Energy and represents a majority of its assets, liabilities, revenues, expenses, and operations. Thus, all information contained in this report relates to, and is filed by, MGE Energy. Information that is specifically identified in this report as relating solely to MGE Energy, such as its financial statements and information relating to its nonregulated business, does not relate to, and is not filed by, MGE. MGE makes no representation as to that information. The terms "we" and "our," as used in this report, refer to MGE Energy and its consolidated subsidiaries, unless otherwise indicated.

Forward-Looking Statements

This report, and other documents filed by MGE Energy and MGE with the Securities and Exchange Commission (SEC) from time to time, contain forward-looking statements that reflect management's current assumptions and estimates regarding future performance and economic conditions—especially as they relate to economic conditions, future load growth, revenues, expenses, capital expenditures, financial resources, regulatory matters, and the scope and expense associated with future environmental regulation. These forward-looking statements are made pursuant to the provisions of the Private Securities Litigation Reform Act of 1995. Words such as "believe," "expect," "anticipate," "estimate," "could," "should," "intend," "will," and other similar words generally identify forward-looking statements. Both MGE Energy and MGE caution investors that these forward-looking statements are subject to known and unknown risks and uncertainties that may cause actual results to differ materially from those projected, expressed, or implied.

The factors that could cause actual results to differ materially from the forward-looking statements made by a registrant include (a) those factors discussed in Item 1A. Risk Factors, Item 7. Management's Discussion and Analysis of Financial Condition and Results of Operations, and Item 8. Financial Statements and Supplementary Data, Footnote 18. Commitments and Contingencies, 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.

Stock Split

On December 20, 2013, MGE Energy's Board of Directors declared a three-for-two stock split of MGE Energy's outstanding shares of common stock, effective in the form of a stock dividend. Shareholders of record at the close of business on January 24, 2014, received one additional share of MGE Energy common stock for every two shares of common stock owned on that date. The additional shares were distributed on February 7, 2014. All share and per share data provided in this report give effect to this stock split.

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.

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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
NGV Fueling Services	NGV Fueling Services, LLC
North Mendota	North Mendota Energy & Technology Park, LLC
Other Defined Terms:
AFUDC	Allowance for Funds Used During Construction
Alliant	Alliant Energy Corporation
ANR	ANR Pipeline Company
ARO	Asset Retirement Obligation
ATC	American Transmission Company LLC
BART	Best Available Retrofit Technology
Bechtel	Bechtel Power Corporation
Blount	Blount Station
CAA	Clean Air Act
CAIR	Clean Air Interstate Rule
CAVR	Clean Air Visibility Rule
CO2	Carbon Dioxide
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
COSO	Committee of Sponsoring Organizations
CSAPR	Cross-State Air Pollution Rule
CWA	Clean Water Act
DATC	Duke-American Transmission Company
Dth	Dekatherms
EEI	Edison Electric Institute
EGUs	Electric Generating Units
Elm Road Units	Elm Road Generating Station
EPA	United States Environmental Protection Agency
FASB	Financial Accounting Standards Board
FERC	Federal Energy Regulatory Commission
FTR	Financial Transmission Rights
GAAP	Generally Accepted Accounting Principles
GHG	Greenhouse Gas
HAPs	Hazardous Air Pollutants
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
ICF	Insurance Continuance Fund
IRS	Internal Revenue Service
kVA	Kilovolt Ampere
kWh	Kilowatt-hour
LIBOR	London Inter Bank Offer Rate
MACT	Maximum Achievable Control Technology
MATS	Mercury and Air Toxins Standards

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MISO	Midcontinent Independent System Operator Inc. (a regional transmission organization)
MW	Megawatt
MWh	Megawatt-hour
NAAQS	National Ambient Air Quality Standards
Nasdaq	The Nasdaq Stock Market
NERC	North American Electric Reliability Corporation
NNG	Northern Natural Gas Company
NOV	Notice of Violation
NOx	Nitrogen Oxides
NSPS	New Source Performance Standards
NYSE	New York Stock Exchange
OPRB	Other Postretirement Benefits
PCBs	Polychlorinated Biphenyls
PGA	Purchased Gas Adjustment clause
PJM	PJM Interconnection, LLC (a regional transmission organization)
PM	Particulate Matter
PPA	Purchased power agreement
PPACA	Patient Protection and Affordable Care Act
PSCW	Public Service Commission of Wisconsin
PSD	Prevention of Significant Deterioration
REC	Renewable Energy Credit
RICE	Reciprocating Internal Combustion Engine
RTO	Regional Transmission Organization
SCR	Selective Catalytic Reduction
SEC	Securities and Exchange Commission
SIP	State Implementation Plan
SO2	Sulfur Dioxide
the State	State of Wisconsin
Stock Plan	Direct Stock Purchase and Dividend Reinvestment Plan of MGE Energy
UW	University of Wisconsin at Madison
VIE	Variable Interest Entity
WCCF	West Campus Cogeneration Facility
WDNR	Wisconsin Department of Natural Resources
WEPCO	Wisconsin Electric Power Company
Working capital	Current assets less current liabilities
WPDES	Wisconsin Pollutant Discharge Elimination System
WPL	Wisconsin Power and Light Company
WPSC	Wisconsin Public Service Corporation
WRERA	Worker, Retiree and Employer Recovery Act of 2008

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PART I.

Item 1. Business.

MGE Energy operates in the following business segments:

·

Regulated electric utility operations – generating, purchasing, and distributing electricity through MGE.

·

Regulated gas utility operations – purchasing and distributing natural gas through MGE.

·

Nonregulated energy operations – owning and leasing electric generating capacity that assists MGE through MGE Energy's wholly owned subsidiaries MGE Power Elm Road and MGE Power West Campus.

·

Transmission investments – representing our investment in American Transmission Company LLC, a company engaged in the business of providing electric transmission services primarily in Wisconsin.

·

All other – investing in companies and property that relate to the regulated operations and financing the regulated operations, through its wholly owned subsidiaries MAGAEL, CWDC, NGV Fueling Services, North Mendota, and Corporate functions.

MGE's utility operations represent a majority of the assets, liabilities, revenues, expenses, and operations of MGE Energy. MGE Energy's nonregulated energy operations currently include an undivided interest in two coal-fired generating units located in Oak Creek, Wisconsin, which we refer to as the Elm Road Units, and an undivided interest in a cogeneration facility located on the Madison campus of the University of Wisconsin, which we refer to as the West Campus Cogeneration Facility or WCCF.

As a public utility, MGE is subject to regulation by the PSCW and the FERC. The PSCW has authority to regulate most aspects of MGE's business including rates, accounts, issuance of securities, and plant siting. The PSCW also has authority over certain aspects of MGE Energy as a holding company of a public utility. FERC has jurisdiction, under the Federal Power Act, over certain accounting practices and certain other aspects of MGE's business.

MGE Energy's subsidiaries are also subject to regulation under local, state, and federal laws regarding air and water quality and solid waste disposal. See "Environmental" below.

MGE Energy was organized as a Wisconsin corporation in 2001. MGE was organized as a Wisconsin corporation in 1896. Their principal offices are located at 133 South Blair Street, Madison, Wisconsin 53788, and their telephone number is (608) 252-7000.

Electric Utility Operations

MGE distributes electricity in a service area covering a 316 square-mile area of Dane County, Wisconsin. The service area includes the city of Madison, Wisconsin. It owns or leases ownership interests in electric generation facilities located in Wisconsin and Iowa.

At December 31, 2013, MGE supplied electric service to approximately 141,000 customers, with approximately 90% located in the cities of Fitchburg, Madison, Middleton, and Monona and 10% in adjacent areas. Of the total number of customers, approximately 86% were residential and 14% were commercial or industrial. Electric retail revenues for 2013, 2012, and 2011 were comprised of the following:

	Year Ended December 31,
	2013	2012	2011
Residential	33.2%	32.9%	32.9%
Commercial	52.4%	52.4%	52.2%
Industrial	4.8%	4.9%	5.1%
Public authorities (including the UW)	9.6%	9.8%	9.8%
Total	100.0%	100.0%	100.0%

Electric operations accounted for approximately 69.0%, 73.7%, and 69.5% of MGE's total 2013, 2012, and 2011 regulated revenues, respectively.

See Item 2. Properties, for a description of MGE's electric utility plant.

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MGE is registered with a regional entity, The Midwest Reliability Organization. The essential purposes of this entity are the development and implementation of regional and NERC reliability standards; and determining compliance with those standards, including enforcement mechanisms.

Transmission

American Transmission Company LLC (ATC) is owned by the utilities that contributed facilities or capital to it in accordance with Wisconsin law. ATC's purpose is to provide reliable, economic transmission service to all customers in a fair and equitable manner. ATC plans, constructs, operates, maintains, and expands transmission facilities that it owns to provide adequate and reliable transmission of power. ATC is regulated by FERC for all rate terms and conditions of service and is a transmission-owning member of the MISO.

Regional Transmission Organizations

MISO

MGE is a nontransmission owning member of the MISO. MISO, a FERC approved RTO, is responsible for monitoring the electric transmission system that delivers power from generating plants to wholesale power transmitters. MISO's role is to ensure equal access to the transmission system and to maintain or improve electric system reliability in the Midwest.

MISO maintains a bid-based energy market. MGE offers substantially all of its generation on the MISO market and purchases much of its load requirement from the MISO market in accordance with the MISO Tariff. MGE participates in the ancillary services market operated by MISO. That market is an extension of the existing energy market in which MISO assumes the responsibility of maintaining sufficient generation reserves. In the ancillary services market, MISO provides the reserves for MGE's load, and MGE may offer to sell reserves from its generating units.

MGE participates in the voluntary capacity auction, which provides an optional monthly forum for buyers and sellers of aggregate planning resource credits to interact. Load serving entities, such as MGE, may participate in the voluntary capacity auction potentially to obtain the necessary aggregate planning resource credits needed to meet their planning reserve margin requirement established by the PSCW. Generator owners may participate to sell any excess aggregate planning resource credits that are not needed by them.

PJM

MGE is a member of PJM. PJM, an RTO, is a neutral and independent party that coordinates and directs the operation of the transmission grid within its area of coverage, administers a competitive wholesale electricity market, and plans regional transmission expansion improvements to maintain grid reliability and relieve congestion.

Fuel supply and generation

MGE satisfies its customers' electric demand with internal generation and purchased power. During the years ended December 31, 2013, 2012, and 2011, MGE's electric energy delivery requirements were satisfied by the following sources:

	Year Ended December 31,
	2013	2012	2011
Coal	54.1%	50.1%	54.8%
Natural gas	5.8%	8.7%	4.7%
Fuel oil	0.1%	0.1%	0.1%
Renewable sources	2.9%	2.7%	2.8%
Purchased power
Renewable	7.6%	8.4%	7.9%
Other	29.5%	30.0%	29.7%
Total	100.0%	100.0%	100.0%

Sources used depend on market prices, generating unit availability, weather, and customer demand.

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Coal

MGE and two other utilities jointly own Columbia, a coal-fired generating facility, which accounts for 31% (245 MW) of MGE's net summer rated capacity. Power from this facility is shared in proportion to each owner's ownership interest. MGE has a 22% ownership interest in Columbia. The other owners are WPL (a subsidiary of Alliant), which operates Columbia, and WPSC. The Columbia units burn low-sulfur coal obtained from the Powder River Basin coal fields located in Wyoming. The coal inventory supply for the Columbia units decreased from approximately 37 days on December 31, 2012, to approximately 28 days on December 31, 2013.

MGE Power Elm Road and two other owners own undivided interests in the coal-fired Elm Road Units in Oak Creek, Wisconsin, which accounts for 14% (106 MW) of MGE's net summer rated capacity. Power from this facility is shared in proportion to each owner's ownership interest. MGE Power Elm Road owns an 8.33% ownership interest in the Elm Road Units and its interest in the Elm Road Units is leased to MGE. The other owners are Wisconsin Energy Corporation, which operates the Units, and WPPI Energy, Inc. The Elm Road Units burn bituminous coal obtained from northern West Virginia and southwestern Pennsylvania, and Powder River Basin coal from Wyoming. MGE's share of the coal inventory supply for the Elm Road Units decreased from approximately 49 days on December 31, 2012, to approximately 40 days on December 31, 2013.

See discussion below under Nonregulated Operations regarding MGE's interest in the Elm Road Units.

Natural gas and oil

MGE owns gas fired combustion turbines. These turbines are primarily located in Madison and Marinette, Wisconsin and have a total of 154 MW of net summer rated capacity.

MGE also owns the Blount Generating Facility located in Madison, Wisconsin, which is fueled by gas and other alternative renewable sources. As planned, capacity was reduced at Blount from 190 MW to 100 MW as of December 31, 2011.

See discussion below under Nonregulated Operations regarding MGE's interest in the West Campus Cogeneration Facility.

Renewable generation sources

MGE owns 30 MW, consisting of 18 turbines, in a wind-powered electric generating facility in Worth County, Iowa. MGE also owns 11 MW, consisting of 17 turbines, in a wind-powered electric generating facility in Kewaunee County, Wisconsin.

Purchased power

MGE enters into short and long-term purchase power commitments with third parties to meet a portion of its anticipated electric energy supply needs. The following table identifies purchase power commitments at December 31, 2013, with unaffiliated parties for the next five years.

(Megawatts)	2014	2015	2016	2017	2018
Purchase Power Commitments	162.4	162.4	162.4	152.5	152.5

Gas Utility Operations

MGE transports and distributes natural gas in a service area covering 1,649 square miles in seven south-central Wisconsin counties. The service area includes the city of Madison, Wisconsin and surrounding areas.

At December 31, 2013, MGE supplied natural gas service to approximately 147,000 customers in the cities of Elroy, Fitchburg, Lodi, Madison, Middleton, Monona, Prairie du Chien, Verona, and Viroqua; 24 villages; and all or parts of 45 townships. Of the total number of customers, approximately 89% were residential and 11% were commercial or industrial. Gas revenues for 2013, 2012, and 2011 were comprised of the following:

	Year Ended December 31,
	2013	2012	2011
Residential	54.3%	56.1%	56.5%
Commercial	33.4%	32.9%	34.4%
Industrial	10.3%	8.9%	7.2%
Transportation service and other	2.0%	2.1%	1.9%
Total	100.0%	100.0%	100.0%

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Gas operations accounted for approximately 31.0%, 26.3%, and 30.5% of MGE's total 2013, 2012, and 2011 regulated revenues, respectively.

MGE can curtail gas deliveries to its interruptible customers. Approximately 20% of retail gas deliveries in both 2013 and 2012 were to interruptible customers.

Gas supply

MGE has physical interconnections with ANR and NNG. MGE's primary service territory, which includes Madison and the surrounding area, receives deliveries at one NNG and four ANR gate stations. MGE also receives deliveries at NNG gate stations located in Elroy, Prairie du Chien, Viroqua, and Crawford County. Interconnections with two major pipelines provide competition in interstate pipeline service and a more reliable and economical gas supply mix, which includes gas from Canada and from the mid-continent and Gulf/offshore regions in the United States.

During the winter months, when customer demand is high, MGE is primarily concerned with meeting its obligation to firm customers. MGE meets customer demand by using firm supplies under contracts finalized before the heating season, supplies in storage (injected during the summer), and other firm supplies purchased during the winter period.

By contract, a total of 5,405,942 Dth of gas can be injected into ANR's storage fields in Michigan from April 1 through October 31. These gas supplies are then available for withdrawal during the subsequent heating season, November 1 through March 31. Using storage allows MGE to buy gas supplies during the summer season, when prices are normally lower, and withdraw these supplies during the winter season, when prices are typically higher. Storage also gives MGE more flexibility in meeting daily load fluctuations.

MGE's contracts for firm transportation service of gas include winter maximum daily quantities of:

·

162,150 Dth (including 96,078 Dth of storage withdrawals) on ANR.

·

60,108 Dth on NNG.

Nonregulated Energy Operations

MGE Energy, through its subsidiaries, has developed generation sources that assist MGE in meeting the electricity needs of its customers.

Elm Road

MGE Power Elm Road owns an 8.33% interest in the coal-fired Elm Road Units in Oak Creek, Wisconsin. Unit 1 entered commercial operation in February 2010, and has the capacity to produce 615 MW of electricity. Unit 2 entered commercial operation in January 2011, and has the capacity to produce 615 MW of electricity. Wisconsin Energy Corporation owns approximately 83% of the Elm Road Units and is the operator for those units. Both units are used to provide electricity to MGE's customers.

MGE leases MGE Power Elm Road's ownership interest in the Elm Road Units pursuant to two separate facility leases. The financial terms of each facility lease include a capital structure of 55% equity and 45% long-term debt, return on equity of 12.7%, and a lease term of 30 years. At the end of the respective lease terms, MGE may, at its option, renew the facility lease for an additional term, purchase the leased ownership interest at fair market value or allow the lease to end. The Unit 1 and Unit 2 leases commenced with the commercial operation of each respective unit.

WCCF

MGE Power West Campus and the UW jointly own undivided interests in a natural gas-fired cogeneration facility on the UW campus. The facility has the capacity to produce 20,000 tons of chilled water, 500,000 pounds per hour of steam, and approximately 150 MW of electricity. The UW owns 45% of the facility, which represents its interest in the chilled-water and steam assets. These assets are used to meet the UW's growing need for air-conditioning and steam-heat capacity. MGE Power West Campus owns 55% of the facility, which represents its interest in the electric generating assets. These assets are used to provide electricity to MGE's customers. The UW's share of the plant and portion of the earnings from the WCCF are not reflected in the consolidated financial statements of MGE Energy or MGE. MGE Power West Campus' share of the cost of this project is reflected in property, plant, and equipment on MGE Energy's and MGE's consolidated balance sheets.

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MGE leases the electric generating assets owned by MGE Power West Campus and is responsible for operating the entire facility. The financial terms of the facility lease include a capital structure of 53% equity and 47% long-term debt, return on equity of 12.1%, and a lease term of 30 years. At the end of the lease term in 2035, MGE may, at its option, renew the facility lease for an additional term, purchase the generating facility at fair market value or allow the lease contract to end.

Transmission Investments

American Transmission Company owns and operates electric transmission facilities primarily in Wisconsin. MGE received an interest in ATC when it, like other Wisconsin electric utilities, contributed its electric transmission facilities to ATC as required by Wisconsin law. That interest is presently held by MGE Transco, which is jointly owned by MGE Energy and MGE. At December 31, 2013, MGE Transco held a 3.6% ownership interest in ATC.

In April 2011, ATC and Duke Energy announced the creation of a joint venture, Duke-American Transmission Company, that seeks to build, own, and operate new electric transmission infrastructure in North America to address increasing demand for affordable, reliable transmission capacity.

Environmental

MGE Energy and MGE are subject to frequently changing local, state, and federal regulations concerning air quality, water quality, land use, threatened and endangered species, hazardous materials handling, and solid waste disposal. These regulations affect the manner in which they conduct their operations, the costs of those operations, as well as capital and operating expenditures. Regulatory initiatives, proposed rules, and court challenges to adopted rules, have the potential to have a material effect on our capital expenditures and operating costs. In addition to the regulations discussed below, MGE continues to track state and federal initiatives such as potential changes to regulations governing polychlorinated biphenyl (PCB), potential changes to regulations governing coal-combustion byproducts, and potential climate change legislation.  

Energy Efficiency and Renewables

The Wisconsin Energy Efficiency and Renewables Act requires that, by 2015, 10% of the state's electricity be generated from renewable resources. MGE is in compliance with the 2015 requirement. The costs to comply with the Act and its accompanying regulations are being recovered.

Air Quality

Air quality regulations promulgated by the U.S. Environmental Protection Agency (EPA) and Wisconsin Department of Natural Resources (WDNR) in accordance with the Federal Clean Air Act and the Clean Air Act Amendments of 1990 impose restrictions on emission of particulates, sulfur dioxide (SO₂), nitrogen oxides (NO_x), hazardous air pollutants and other pollutants, and require permits for operation of emission sources. These permits must be renewed periodically. Various newly enacted and/or proposed federal and state initiatives are expected to result in additional operating and capital expenditure costs for fossil-fueled electric generating units.

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

In 2005, the 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 and fine particulate matter pollution from NO_x and/or 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. Phase I (currently in place) requires annual regional emission reductions from 2003 levels of 55% for NO_x and 40% for SO₂. Phase II begins in 2015 and requires regional NO_x and SO₂ emissions reductions 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.

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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 was argued before the U.S. Supreme Court in December 2013, and a decision from that Court is pending. Thus, at this time, the CAIR remains effective.

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.

Global climate change

MGE is a producer of GHG emissions, primarily from the fossil fuel generating facilities it utilizes to meet customers' energy needs, as well as from its natural gas pipeline system and fleet vehicles. Climate change and the regulatory response to it could significantly affect our operations in a number of ways, including increased operating costs and capital expenditures, restrictions on energy supply options, permitting difficulties, and emission limits. MGE management would expect to seek and receive rate recovery of such compliance costs, if and when required. MGE will continue to monitor proposed climate change legislation and regulation.

MGE is already addressing GHG emissions through voluntary actions. In 2005, MGE announced its Energy 2015 Plan, which commits to ensuring a balanced, economic energy supply with reduced environmental emissions. The Plan emphasizes increased renewable energy, energy efficiency, and new cleaner generation – three strategies that reduce GHG emissions. Under MGE's Energy 2015 Plan and other actions, our CO₂ emissions are currently projected to decline from 2005 to 2015 even though total system energy is estimated to increase.

Climate Change Legislation

Federal Legislative Actions on Climate Change

Several bills and/or actions related to GHG regulation, including those to limit, prevent or delay the EPA's regulation of GHGs under the current Clean Air Act, have been proposed in both the House and the Senate. It is not anticipated that Congress will enact broad GHG reduction legislation in 2014.

State and Regional Legislative Actions on Climate Change

It is not expected that the Wisconsin Legislature will enact broad GHG regulation in 2014. MGE continues to monitor legislative developments.

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. See the GHG New Performance Standards discussion below for additional details.

GHG New Source Performance Standards (NSPS) for New and Existing Electric Generating Units

In his June 2013 directive, President Obama instructed the EPA to re-propose greenhouse gas standards for new power plants, and to finalize those standards in a timely manner. The EPA published revised proposed standards for new power plants in September 2013, which 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.

It is reasonable to assume that costs of implementation of these directives, when final rules are adopted, could be significant depending on the approach taken. We will continue to monitor the actions taken in response to the President's directives in 2014.

12

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 alleged that WPL and the Columbia co-owners failed to comply with appropriate pre-construction review and permitting requirements and, as a result, violated the Prevention of Significant Deterioration program requirements, Title V Operating Permit requirements of the CAA, and the Wisconsin SIP. In April 2013, the EPA filed a lawsuit against the co-owners of Columbia asserting similar allegations. In September 2010 and April 2013, the Sierra Club filed civil lawsuits against WPL alleging violations of the CAA at Columbia and other Wisconsin facilities operated by WPL. In June 2013, the court approved and entered a consent decree entered by the EPA, Sierra Club, and the co-owners of Columbia to resolve these claims, while admitting no liability. One of the requirements of the consent decree requires installation of a SCR system at Columbia Unit 2 by December 31, 2018. 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 18.d. of the Notes to Consolidated Financial Statements for additional information regarding this matter.

Employees

As of December 31, 2013, MGE had 695 employees. MGE employs 211 employees who are covered by a collective bargaining agreement with Local Union 2304 of the International Brotherhood of Electrical Workers and 94 employees who are covered by a collective bargaining agreement with Local Union No. 39 of the Office and Professional Employees International Union. Both of these collective bargaining agreements expire on April 30, 2015. There are also 5 employees covered by a collective bargaining agreement with Local Union No. 2006, Unit 6 of the United Steel, Paper and Forestry, Rubber, Manufacturing, Energy, Allied Industrial, and Service Workers International Union. This collective bargaining agreement expires on October 31, 2015.

Financial Information About Segments

See Footnote 22 of the Notes to the Consolidated Financial Statements for financial information relating to MGE Energy's and MGE's business segments.

Executive Officers of the Registrants

Executive	Title	Effective Date	Service Years as an Officer
Gary J. Wolter(a) Age: 59	Chairman of the Board, President and Chief Executive Officer	02/01/2002	24
Lynn K. Hobbie(b) Age: 55	Senior Vice President	02/01/2000	19
Scott A. Neitzel(b) Age: 53	Senior Vice President Vice President - Energy Supply	01/01/2012 09/01/2006	16
Kristine A. Euclide(b) Age: 61	Vice President and General Counsel	11/15/2001	12
Craig A. Fenrick(b) Age: 54	Vice President - Electric Transmission and Distribution Assistant VP - Electric Transmission and Distribution	01/01/2012 09/01/2006	7
Jeffrey C. Newman(a) Age: 51	Vice President, Chief Financial Officer, Secretary and Treasurer	01/01/2009	16
Peter J. Waldron(b) Age: 56	Vice President and Chief Information Officer Vice President and Operations Officer	01/01/2012 09/01/2006	17

Note: Ages, years of service, and positions as of December 31, 2013.

(a) Executive officer of MGE Energy and MGE.

(b) Executive officer of MGE.

Item 1A. Risk Factors.

MGE Energy and its subsidiaries, including MGE, operate in a market environment that involves significant risks, many of which are beyond their control. The following risk factors may adversely affect their results of operations, cash flows and market price for their publicly traded securities. While MGE Energy and MGE believe they have identified and discussed below the key risk factors affecting their business, there may be additional risks and uncertainties that are not presently known or that are not currently believed to be significant that may adversely affect their performance or financial condition in the future.

13

Regulatory Risk

We are subject to extensive government regulation in our business, which affects our costs and responsiveness to changing events and circumstances.

Our business is subject to regulation at the State and Federal levels. We are subject to regulation as a holding company by the PSCW. MGE is regulated by the PSCW as to its rates, terms and conditions of service; various business practices and transactions; financing; and transactions between it and its affiliates, including MGE Energy. MGE is also subject to regulation by the FERC, which regulates certain aspects of its business. The regulations adopted by the State and Federal agencies affect the manner in which we do business, our ability to undertake specified actions since pre-approval or authorization may be required, the costs of operations, and the level of rates charged to recover such costs. Our ability to attract capital is also dependent in part, upon our ability to obtain a fair return from the PSCW.

We could be subject to higher costs and potential penalties resulting from mandatory reliability standards.

MGE must adhere to mandatory reliability standards for its electric distribution system established by NERC. These standards cover areas such as critical infrastructure protection, emergency preparedness, facility design, and transmission operations, among others. The critical infrastructure protection standards focus on physical and access security of cyber assets, as well as incident response and recovery planning. MGE could be subject to higher operating costs in order to maintain compliance with the mandatory reliability standards, and any noncompliance could result in sanctions including monetary penalties.

We face risk for the recovery of fuel and purchased power costs.

MGE burns natural gas in several of its peak electric generation facilities, and in many cases, the cost of purchased power is tied to the cost of natural gas. Under the electric fuel rules, MGE would defer electric fuel-related costs that fall outside a symmetrical cost tolerance band that is currently plus or minus 2% around the amount approved in its most recent rate order. Any over/under recovery of the actual costs is determined on an annual basis and will be adjusted in future billings to its electric retail customers. Under the electric fuel rules, MGE is required to defer the benefit of lower costs, if its actual fuel costs fall outside the lower end of the range, and would defer costs, less any excess revenues, if its actual fuel 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. MGE assumes the risks and benefits of variances that are within the cost tolerance band.

We are subject to changing environmental laws and regulations that may affect our costs and business plans.

Our subsidiaries are subject to environmental laws and regulations that affect the manner in which they conduct business, including capital expenditures, operating costs and potential liabilities. Changes and developments in these laws and regulations may alter or limit our business plans, make them more costly, or expose us to liabilities for past or current operations.

Numerous environmental laws and regulations govern many aspects of our present and future operations, including air emissions, water quality, wastewater discharges, solid waste, threatened and endangered species and hazardous waste. These evolving regulations can introduce uncertainty with respect to capital expenditures and operational planning, and can introduce costly delays if previous decisions need to be revisited as a result of judicial mandate or regulatory change. These regulations generally require us to obtain and comply with a wide variety of environmental permits and approvals, and can result in increased capital, operating, and other costs and operating restrictions, particularly with regard to enforcement efforts focused on obligations under existing regulations with respect to power plant emissions and compliance costs associated with regulatory requirements. These effects can be seen not only with respect to new construction but could also require the installation of additional control equipment or other compliance measures such as altered operating conditions at existing facilities.

In addition, we may be a responsible party for environmental clean-up at current or future sites identified as containing hazardous materials or to which waste was sent that is subsequently determined to be hazardous. It is difficult to predict the costs potentially associated with a site clean-up due to the potential joint and several liability for all potentially responsible parties, the nature of the clean-up required and the availability of recovery from other potentially responsible parties.

Additionally, depending on their form and phase-in provisions, GHG emission restrictions could have the potential for a significant financial impact on MGE, including the cost to purchase allowances or do fuel switching.

14

Operating Risk

We are affected by weather, which affects customer demand and can affect the operation of our facilities.

The demand for electricity and gas is affected by weather. Very warm and very cold temperatures, especially for prolonged periods, can dramatically increase the demand for electricity and gas for cooling and heating, respectively, as opposed to the softening effect of more moderate temperatures. Our electric revenues are sensitive to the summer cooling season and, to a lesser extent, the winter heating season. Similarly, very cold temperatures can dramatically increase the demand for gas for heating. A significant portion of our gas system demand is driven by heating. Extreme summer conditions or storms may stress electric transmission and distribution systems, resulting in increased maintenance costs and limiting the ability to meet peak customer demand.

We could be adversely affected by changes in the development, and utilization by our customers, of power generation and storage technology.

Developments in power generation and storage could affect our revenues and the timing of the recovery of our costs. Advancements in power generation technology, including commercial and residential solar generation installations and commercial micro turbine installations, are improving the cost-effectiveness of customer self-supply of electricity. Improvements in energy storage technology, including batteries and fuel cells, could also better position customers to meet their around-the-clock electricity requirements. Such developments could reduce customer purchases of electricity, but may not necessarily reduce our investment and operating requirements due to our obligation to serve customers, including those self-supply customers whose equipment has failed for any reason to provide the power they need. In addition, since a portion of our costs are recovered through charges based upon the volume of power delivered, reductions in electricity deliveries will affect the timing of our recovery of those costs and may require changes to our rate structures.

We are affected by economic activity within our service area.

Higher levels of development and business activity generally increase the numbers of customers and their use of electricity and gas. Likewise, periods of recessionary economic conditions generally adversely affect our results of operations.

Our ability to manage our purchased power costs is influenced by a number of uncontrollable factors.

We are exposed to additional purchased power costs to the extent that our power needs cannot be fully covered by the supplies available from our existing facilities and contractual arrangements. Those needs, and our costs, could be affected by:

·

Increased demand due to, for example, abnormal weather, customer growth, or customer obligations,

·

The inability to transmit our contracted power from its generation source to our customers due to transmission line constraints, outages, or equipment failures,

·

Reductions in the availability of power from our owned or contracted generation sources due to equipment failures, shortages of fuel or environmental limitations on operations, and

·

Failure to perform on the part of any party from which we purchase capacity or energy, whether due to equipment failures or other causes.

An unexpected change in demand or the availability of generation or transmission facilities can expose us to increased costs of sourcing electricity in the short-term market where pricing may be more volatile.

The equipment and facilities in our operational system are subject to risks which may adversely affect our financial performance.

Weather conditions, accidents, and catastrophic events, including terrorism and acts of sabotage or war, can result in damage or failures of equipment or facilities and disrupt or limit our ability to generate, transmit, transport, purchase, or distribute electricity and gas. Efforts to repair or replace equipment and facilities may take prolonged periods or may be unsuccessful, or we may be unable to make the necessary improvements to our operational system, causing service interruptions. The resulting interruption of services would result in lost revenues and additional costs. We are also

15

exposed to the risk of accidents or other incidents that could result in damage to or destruction of our facilities or damage to persons or property. Such issues could adversely affect revenues or increase costs to repair and maintain our systems.

Our electricity and gas operations, as well as our confidential information, are subject to the risks of cyber attacks.

Our electricity and gas operations rely on sophisticated information technology systems and networks. Cyber attacks could disrupt or limit our electricity and gas operations, leading to potential lost revenues and additional costs. In addition, we may be required to incur significant development costs in order to strengthen the protection of our information technology systems and networks from outside attacks.

Cyber attacks resulting in the theft, loss, or fraudulent use of customer, stockholder, employee, or proprietary data could result in litigation and/or monetary liability. In addition, our reputation could be adversely affected among customers, stockholders, regulators, and others as a result of a cyber attack.

Failure to attract and retain an appropriately qualified workforce could affect our operations.

Events such as an aging workforce and retirement of key employees without appropriate replacements may lead to operating challenges and increased costs. Some of the challenges include lack of resources, loss of knowledge, and length of time period associated with skill development. Failure to identify qualified replacement employees could result in decreased productivity and increased safety costs. If we are unable to attract and retain an appropriately qualified workforce, our operations could be negatively affected.

We face construction risk in connection with the completion of the Columbia environmental project.

The large-scale environmental project at the Columbia generating facility, which is being managed by WPL as plant operator, is subject to various risks that could cause costs to increase or delays in completion. These risks include shortages of, the inability to obtain, the cost of, and the consistency of, labor, materials and equipment; the inability of the general contractor or subcontractors to perform under their contracts; the inability to agree to terms of contracts or disputes in contract terms; work stoppages; adverse weather conditions; the inability to obtain necessary permits in a timely manner; changes in applicable laws or regulations; adverse interpretation or enforcement of permit conditions; governmental actions; legal action; and unforeseen engineering or technology issues. If the construction project is over budget, we may not be able to recover those excess costs. Inability to recover excess costs, or inability to complete the project in a timely manner, could adversely impact our financial condition and results of operations.

Financial Risk

We are exposed to commodity price risk relating to our purchases of natural gas, electricity, coal and oil.

We face commodity price risk exposure with respect to our purchases of natural gas, electricity, coal and oil, SO₂ allowances and risk through our use of derivatives, such as futures, forwards and swaps, to manage that commodity price risk. We could experience increased costs as a result of volatility in the market values of those commodities. We could also experience losses on our derivative contracts as a result of that market value volatility or if a counterparty fails to perform under a contract. In the absence of actively quoted market prices and pricing information from external sources, the valuation of these derivative contracts involves our exercise of judgment and use of estimates. As a result, changes in the underlying assumptions or use of alternative valuation methods could affect the reported fair value of these contracts.

We are exposed to interest rate risk.

We are exposed to interest rate risk on our variable rate financing. Borrowing levels under commercial paper arrangements vary from period to period depending upon capital investments and other factors. Such interest rate risk means that we are exposed to increased financing costs and associated cash payments as a result of changes in the short-term interest rates.

Interest rate movements and market performance affects our employee benefit plan costs.

Prevailing interest rates affect our assessment and determination of discount rates that are a key assumption in the determination of the costs and funding of our defined benefit pension plans and may impact the amount of expense and timing of contributions to those plans. The performance of the capital markets affects the values of the assets that are held in trust to satisfy the future obligations under our pension and postretirement benefit plans. We have significant obligations in these areas and hold significant assets in these trusts. A decline in the market value of those assets may

16

increase our current and longer-term funding requirements for these obligations. Changes in the value of trust fund assets may affect the level of required contributions to these trusts to meet benefit obligations. Reduced benefit plan assets could result in increased benefit costs in future years and may increase the amount and accelerate the timing of required future funding contributions.

We are exposed to credit risk primarily through our regulated energy business.

Credit risk is the loss that may result from counterparty nonperformance. We face credit risk primarily through MGE's regulated energy business. Failure of contractual counterparties to perform their obligations under purchase power agreements, commodity supply arrangements or other agreements may result in increased expenses for MGE as a result of being forced to cover the shortfall in the spot or short-term market, where prices may be more volatile.

As a holding company, we are dependent on upstream cash flows from our subsidiaries for the payment of dividends on our common stock.

As a holding company, we have no operations of our own, and our ability to pay dividends on our common stock is dependent on the earnings and cash flows of our operating subsidiaries and their ability to pay upstream dividends or to repay funds to us. Prior to funding us, our subsidiaries have financial obligations that must be satisfied, including among others, debt service and obligations to trade creditors, and are subject to contractual and regulatory restrictions on the payment of dividends.

Disruptions in the financial markets or changes to our credit ratings may affect our ability to finance at a reasonable cost and in accordance with our planned schedule.

The credit markets have experienced disruption and uncertainty in recent years. To the extent that such issues affect the ability or willingness of credit providers or investors to participate in the credit markets or particular types of investments, or affect their perception of the risk associated with particular types of investments, our cost of borrowing could be affected. We also rely on our strong credit ratings to access the credit markets. If our credit ratings are downgraded for any reason, borrowing costs could increase, potential investors could decrease, or we could be required to provide additional credit assurance, including cash collateral, to contract counterparties.

General economic conditions may affect our operating revenues and our counterparty risks.

Operational

MGE Energy's and MGE's operations are affected by local, national and worldwide economic conditions. The consequences of a prolonged period of reduced economic activity may include lower demand for energy, uncertainty regarding energy prices and the capital and commodity markets, and increased credit risk. A decline in energy consumption may adversely affect our revenues and future growth. Increased credit risk reflects the risk that our retail customers will not pay their bills in a timely manner or at all, which may lead to a reduction in liquidity and an eventual increase in bad debt expense.

Counterparty creditworthiness

Credit risk also includes the risk that trading counterparties that owe us money or product will breach their obligations. MGE's risk management policy is to limit transactions to a group of high quality counterparties. Should the counterparties to these arrangements fail to perform, we may be forced to enter into alternative arrangements. In that event, our financial results could be adversely affected and we could incur losses.

Item 1B. Unresolved Staff Comments.

MGE Energy and MGE

None.

17

Item 2. Properties.

Electric Generation

Net summer rated capacity in service at December 31, 2013, was as follows:

				Net Summer
		Commercial		Rated
		Operation		Capacity(1)	No. of
Plants	Location	Date	Fuel	(MW)	Units
Steam plants:
Columbia	Portage, WI	1975 & 1978	Low-sulfur coal	245(2,3)	2
Blount	Madison, WI	1957 & 1961	Gas	99(7)	2
WCCF	Madison, WI	2005	Gas/oil	125(4)	2
Elm Road Units	Oak Creek, WI	2010 & 2011	Coal	106(2,5)	2
Combustion turbines	Madison, WI	1964-2000	Gas/oil	154(6)	6
	Marinette, WI
Portable generators	Madison, WI	1998-2001	Diesel	50(7)	54
Wind turbines	Townships of Lincoln
	and Red River, WI	1999	Wind	1(7,8)	17
	Township of
	Brookfield, IA	2008	Wind	3(7,9)	18
Total				783

(1)

Net summer rated capacity is determined by annual testing and may vary from year to year due to, among other things, the operating and physical conditions of the units.

(2)

Baseload generation.

(3)

MGE's 22% share of two 512-MW units. The other owners are WPL (a subsidiary of Alliant), which operates Columbia, and WPSC.

(4)

Facility is jointly owned. MGE Power West Campus owns a controlling interest in the electric generation plant and the UW owns a controlling interest in the chilled-water and steam plants. MGE leases the electric generating assets owned by MGE Power West Campus and is responsible for operating the facility. Amounts shown represent MGE's share of the net summer rated capacity. Based on the terms of the joint plant agreement between MGE and the UW, the UW has the ability to reduce net capability of these units by approximately 17 MW in the summer. The net summer rated capacity shown reflects this decrease.

(5)

MGE's 8.33% share in each of two 615 MW coal-fired generating units. The other owners are Wisconsin Energy Corporation, which operates the units, and WPPI Energy, Inc. MGE leases the electric generating assets owned by MGE Power Elm Road. Amounts shown represent MGE's share of the net summer rated capacity of the Units.

(6)

Three facilities are owned by MGE and three facilities are leased.

(7)

These facilities are owned by MGE.

(8)

Nameplate capacity rating is 11 MW.

(9)

Nameplate capacity rating is 30 MW.

Electric and Gas Distribution Facilities

At December 31, 2013, MGE owned 890 miles of overhead electric distribution line and 1,157 miles of underground electric distribution cable, all of which are located in Wisconsin. These electric distribution facilities are connected by approximately 45 substations, installed with a capacity of 1,244,550 kVA. MGE's gas facilities include 2,536 miles of distribution mains, which are all owned by MGE.

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A significant portion of MGE's electric and gas distribution facilities are located above or underneath highways, streets, other public places or property that others own. MGE believes that it has satisfactory rights to use those places or property in the form of permits, grants, easements, and licenses; however, it has not necessarily undertaken to examine the underlying title to the land upon which the rights rest.

Encumbrances

The principal plants and properties of MGE are subject to the lien of its Indenture of Mortgage and Deed of Trust dated as of January 1, 1946, as amended and supplemented, under which MGE's first mortgage bonds are issued. As of December 31, 2013, there were $1.2 million of first mortgage bonds outstanding. See Footnote 9 of Notes to Consolidated Financial Statements for additional information regarding MGE's first mortgage bonds.

MGE Power Elm Road has collaterally assigned its right to lease payments from MGE for the Elm Road Units in order to secure the repayment of $70.6 million of senior secured notes issued by MGE Power Elm Road. See Footnote 9 of Notes to Consolidated Financial Statements for additional information regarding these senior notes.

MGE Power West Campus has collaterally assigned its right to lease payments from MGE for the WCCF in order to secure the repayment of $49.7 million of senior secured notes issued by MGE Power West Campus. See Footnote 9 of Notes to Consolidated Financial Statements for additional information regarding these senior notes.

Item 3. 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 "Environmental" under Item 1, Business, and Footnote 18.d. of the Notes to Consolidated Financial Statements for a description of several environmental proceedings involving MGE. See Footnote 18.e. of the Notes to Consolidated Financial Statements for a description of other legal matters.

Item 4. Mine Safety Disclosures.

MGE Energy and MGE

Not applicable.

19

PART II.

Item 5. Market for Registrants' Common Equity, Related Stockholder Matters, and Issuer Purchases of Equity Securities.

Market for Common Equity

MGE Energy

MGE Energy common stock is traded on Nasdaq under the symbol MGEE. On February 1, 2014, there were approximately 36,568 shareholders of record. The following table shows high and low sale prices for the common stock on Nasdaq for each quarter over the past two years, adjusted for the three-for-two stock split declared December 20, 2013.

		Common stock price range
		2013				2012
		High		Low		High		Low
Fourth quarter	$	38.94	$	34.98	$	35.98	$	31.49
Third quarter	$	40.46	$	33.39	$	37.37	$	31.19
Second quarter	$	38.63	$	34.75	$	31.88	$	28.73
First quarter	$	37.25	$	33.93	$	31.49	$	28.69

MGE

As of February 1, 2014, there were 17,347,894 outstanding shares of common stock, all of which were held by MGE Energy. There is no market for shares of common stock of MGE.

Dividends

MGE Energy

The following table sets forth MGE Energy's quarterly cash dividends per share declared during 2013 and 2012, adjusted for the three-for-two stock split declared December 20, 2013:

(Per share)		2013		2012
Fourth quarter	$	0.272	$	0.263
Third quarter	$	0.272	$	0.263
Second quarter	$	0.263	$	0.255
First quarter	$	0.263	$	0.255

MGE

The following table sets forth MGE's quarterly cash dividends declared during 2013 and 2012:

(In thousands)		2013		2012
Fourth quarter	$	25,000	$	6,948
Third quarter	$	-	$	-
Second quarter	$	-	$	6,728
First quarter	$	-	$	6,728

See discussion below as well as "Liquidity and Capital Resources - Financing Activities" under Item 7, Management's Discussion and Analysis of Financial Condition and Results of Operations, for a description of restrictions applicable to dividend payments by MGE.

Dividend Restrictions

Dividend payments by MGE to MGE Energy are subject to restrictions arising under a PSCW rate order and, to a lesser degree, MGE's first mortgage bonds. The PSCW order restricts any dividends that MGE may pay MGE Energy if its common equity ratio, calculated in the manner used in the rate proceeding, is less than 55%. MGE's thirteen month rolling average common equity ratio at December 31, 2013, is 57.6%, as determined under the calculation used in the rate proceeding. MGE paid cash dividends of $25.0 million to MGE Energy in 2013. The rate proceeding calculation

20

includes as indebtedness imputed amounts for MGE's outstanding purchase power capacity payments and other PSCW adjustments, but does not include the indebtedness associated with MGE Power Elm Road and MGE Power West Campus, which are consolidated into MGE's financial statements but are not direct obligations of MGE.

MGE has covenanted with the holders of its first mortgage bonds not to declare or pay any dividend or make any other distribution on or purchase any shares of its common stock unless, after giving effect thereto, the aggregate amount of all such dividends and distributions and all amounts applied to such purchases, after December 31, 1945, shall not exceed the earned surplus (retained earnings) accumulated subsequent to December 31, 1945. As of December 31, 2013, approximately $305.6 million was available for the payment of dividends under this covenant.

Stock Split

On December 20, 2013, MGE Energy's Board of Directors declared a three-for-two stock split of MGE Energy's outstanding shares of common stock, effective in the form of a stock dividend. Shareholders of record at the close of business on January 24, 2014, received one additional share of MGE Energy common stock for every two shares of common stock owned on that date. The additional shares were distributed on February 7, 2014. Shareholders received cash in lieu of any fractional shares of common stock they otherwise would have received in connection with the dividend. All share and per share data provided in this report give effect to this stock split.

Issuer Purchases of Equity Securities

MGE Energy

					Maximum number (or
					Approximate Dollar
	Total			Total Number	Value) of Shares That
	Number		Average	of Shares	May Yet Be
	of		Price	Purchased as Part of	Purchased
	Shares		Paid	Publicly Announced	Under the Plans or
Period	Purchased*		per Share*	Plans or Programs**	Programs**
October 1-31, 2013	34,613	$	36.28	-	-
November 1-30, 2013	28,088		37.53	-	-
December 1-31, 2013	82,061		36.81	-	-
Total	144,762	$	36.82	-	-

*

Adjusted for the three-for-two stock split declared December 20, 2013.

**

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. MGE Energy uses 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 by MGE Energy pursuant to a registration statement that was filed with the SEC and is currently effective.

MGE

None.

21

Stock Performance Graph

The performance graph below illustrates a five-year comparison of cumulative total returns based on an initial investment of $1,000 in MGE Energy common stock, as compared with the Russell 2000 and the EEI Index for the period 2009 through 2013. The EEI Index reflects the consolidated performance of Edison Electric Institute investor-owned electric utilities.

Value of Investment at December 31,

		2008		2009		2010		2011		2012		2013
MGEE	$	1,000	$	1,132	$	1,411	$	1,600	$	1,801	$	2,101
Russell 2000		1,000		1,272		1,613		1,546		1,799		2,497
EEI Index		1,000		1,107		1,185		1,422		1,452		1,640

22

Item 6. Selected Financial Data.

MGE Energy

(In thousands, except per share amounts)

		For the years ended December 31,
		2013		2012		2011		2010		2009
Summary of Operations
Operating revenues:
Regulated electric	$	403,957	$	392,365	$	375,858	$	360,729	$	332,324
Regulated gas		181,462		139,727		165,271		165,915		192,334
Nonregulated		5,468		9,231		5,253		5,947		9,161
Total operating revenues		590,887		541,323		546,382		532,591		533,819
Operating expenses		444,293		410,200		421,170		418,931		431,296
Other general taxes		18,607		18,360		17,344		17,058		17,858
Operating income		127,987		112,763		107,868		96,602		84,665
Other income, net		10,701		10,069		9,214		11,093		8,096
Interest expense, net		(18,924)		(19,467)		(20,162)		(16,157)		(13,594)
Income before taxes		119,764		103,365		96,920		91,538		79,167
Income tax provision		(44,859)		(38,919)		(35,992)		(33,820)		(28,170)
Net income	$	74,905	$	64,446	$	60,928	$	57,718	$	50,997
Average shares outstanding**		34,668		34,668		34,668		34,668		34,605
Basic and diluted earnings per share**	$	2.16	$	1.86	$	1.76	$	1.66	$	1.47
Dividends declared per share**	$	1.07	$	1.04	$	1.01	$	0.99	$	0.97
Assets
Electric	$	899,257	$	888,444	$	794,738	$	721,721	$	695,897
Gas		265,694		285,468		285,702		257,505		249,610
Assets not allocated		19,853		18,559		32,882		22,079		22,342
Nonregulated energy operations		288,116		323,216		299,421		300,862		292,101
Transmission investments		64,504		61,064		57,006		54,241		51,728
All others		431,436		413,291		401,862		376,219		389,744
Eliminations		(389,800)		(403,118)		(412,729)		(414,734)		(419,537)
Total assets	$	1,579,060	$	1,586,924	$	1,458,882	$	1,317,893	$	1,281,885
Capitalization including Short-Term Debt
Common shareholders' equity	$	617,510	$	579,429	$	550,952	$	525,080	$	501,795
Long-term debt*		403,516		361,504		363,570		336,018		322,470
Short-term debt		-		-		-		22,500		64,500
Total capitalization and short-term debt	$	1,021,026	$	940,933	$	914,522	$	883,598	$	888,765

*

Includes current maturities

**

Average shares outstanding and per share amounts for all periods presented reflect the three-for-two stock split declared on December 20, 2013, effective in the form of a stock dividend distributed on February 7, 2014.

23

Item 7. 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 141,000 customers in Dane County, Wisconsin, including the city of Madison, and purchases and distributes natural gas to approximately 147,000 customers in the Wisconsin counties of Columbia, Crawford, Dane, Iowa, Juneau, Monroe, and Vernon.

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

Executive Overview

Our primary focus today and for the foreseeable future is our core utility customers at MGE as well as creating long-term value for our shareholders. MGE continues to face the challenge of providing its customers with reliable power at competitive prices. MGE meets this challenge by investing in more efficient generation projects, including renewable energy sources. 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.

For the year ended December 31, 2013, MGE Energy's earnings were $74.9 million or $2.16 per share compared to $64.4 million or $1.86 per share for the same period in the prior year. MGE's earnings for the year ended December 31, 2013, were $49.0 million compared to $40.8 million for the same period in the prior year.

24

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

(In millions)		Year Ended December 31,
Business Segment:		2013		2012		2011
Electric Utility	$	36.7	$	36.7	$	29.8
Gas Utility		13.4		5.1		8.4
Nonregulated Energy		20.7		18.1		17.9
Transmission Investments		5.6		5.4		5.1
All Other		(1.5)		(0.9)		(0.3)
Net Income	$	74.9	$	64.4	$	60.9

Our net income during 2013 compared to 2012 primarily reflects the effects of the following factors:

·

Retail electric sales decreased 0.8% 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. The decrease in sales was partially offset by $2.7 million (after tax) recognized in AFUDC equity related to the Columbia environmental project for the year ended December 31, 2013.

·

Gas net income increased due to a 25.7% 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 27.9% compared to the prior period. In addition, operating and maintenance expenditures decreased over the prior period.

·

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 2012 compared to 2011 primarily reflects the effects of the following factors:

·

A 4.7% increase in retail electric revenues, driven by increased residential customer demand primarily as a result of warmer-than-normal weather. Cooling degree days (a measure for determining the impact of weather during the cooling season) increased by 31% compared to the prior period.

·

A 5.5% decrease in gas sales reflecting lower customer demand due to a milder winter. Heating degree days decreased by 15% compared to the prior period.

·

MGE has recognized $1.4 million (after tax) in AFUDC equity related to the Columbia environmental project for the year ended December 31, 2012.

During 2013, the following events occurred:

Stock Split: On December 20, 2013, MGE Energy's Board of Directors declared a three-for-two stock split of MGE Energy's common stock in the form of a stock dividend. The additional shares were distributed February 7, 2014 to all shareholders of record as of January 24, 2014. All share and per share data provided in this report give effect to this stock split.

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 is approximately $135 million. As of December 31, 2013, MGE has accumulated $120.9 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 $60.9 million in 2013. MGE has recognized $2.7 million (after tax) in AFUDC equity related to this project for the year ended December 31, 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.

25

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 were used and are expected to continue to be used to help finance the Columbia environmental project. In July 2013, MGE refinanced $40 million of long-term debt.

During 2014, several items may affect us, including:

2014 Rate Filing: In July 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 18.d. in the Notes to Consolidated Financial Statements.

Columbia Environmental Project: During 2014, our share of the capital expenditures associated with the Columbia environmental project will be approximately $14 million.

Commodity Prices: Natural gas and purchased power prices have increased in the first part of 2014 as a result of the unusually cold weather. The commodity price changes may result in increased costs for the Company. The increased commodity prices are mitigated through certain regulatory mechanisms in the natural gas business (PGA) and electric business (fuel rules). See Item 7A. Commodity Price Risk for further information.

Pension and Other Postretirement Benefit Costs: Costs for pension and other postretirement benefits are affected by actual investment returns on the assets held for those benefits and by the discount rate, which is sensitive to interest rates, used to calculate those benefits. Investment assets for MGE's pension and other postretirement benefits have experienced market declines through February 2014. Also, interest rates have declined since the end of the year that could cause discount rates used to value the pension and postretirement benefit obligations to decline. The change in the value of the plan assets and the change in the discount rate are not expected to have an impact on the income statement for 2014. However, these changes may increase benefit costs in future years. MGE expects any changes in the cost for employee benefit plans will be factored into future rate actions.

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 December 31, 2013, there were no borrowings outstanding under our lines of credit.

The following discussion is based on the business segments as discussed in Footnote 22 of the Notes to Consolidated Financial Statements.

26

Results of Operations

Year Ended December 31, 2013, Versus the Year Ended December 31, 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:

		Revenues				Sales (kWh)
(In thousands, except cooling degree days)		2013		2012	% Change	2013	2012	% Change
Residential	$	135,597	$	130,581	3.8 %	819,012	826,766	(0.9)%
Commercial		214,033		207,574	3.1 %	1,821,966	1,825,701	(0.2)%
Industrial		19,872		19,437	2.2 %	250,229	247,179	1.2 %
Other-retail/municipal		39,143		38,805	0.9 %	423,261	442,906	(4.4)%
Total retail		408,645		396,397	3.1 %	3,314,468	3,342,552	(0.8)%
Sales to the market		1,134		991	14.4 %	50,606	31,588	60.2 %
Other revenues		1,312		1,811	(27.6)%	-	-	- %
Adjustments to revenues		(7,134)		(6,834)	(4.4)%	-	-	- %
Total	$	403,957	$	392,365	3.0 %	3,365,074	3,374,140	(0.3)%
Cooling degree days (normal 663)						709	1,068	(33.6)%

Electric operating revenues increased $11.6 million or 3.0% for the year ended December 31, 2013, due to the following:

(In millions)
Rate changes	$	15.6
Sales to the market		0.1
Volume		(3.3)
Other revenues		(0.5)
Adjustments to revenues		(0.3)
Total	$	11.6

·

Rates changes. Rate changes have resulted in $15.6 million of additional revenue in 2013 compared to the same period in the prior year. The change is primarily a result of an electric retail rate increase which was authorized by the PSCW. Effective January 1, 2013, the retail rate increased 3.8% or $14.9 million for electric retail customers. 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 year ended December 31, 2013, there was a 0.8% 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.

·

Adjustments to revenues. The adjustments to revenues amount includes the elimination of carrying costs for the Elm Road Units and the WCCF that were collected in electric rates, 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 $0.4 million or 0.9% during the year ended December 31, 2013, compared to the same period in the prior year. Internal electric generation costs decreased $1.1 million as a result of a 2.5% decrease in the per-unit cost (largely due to lower Elm Road coal costs). Internal electric generated volume delivered to the system increased 1.6%, which resulted in $0.7 million of increased expense.

27

Excluding the fuel rules adjustments discussed below, purchased power expense increased $6.5 million during the year ended December 31, 2013, compared to the same period in the prior year. This increase in expense reflects an $8.9 million or 13.6% increase in per-unit cost of purchased power, partially offset by a $2.4 million or 3.6% 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 years ended December 31, 2013 and 2012, MGE's actual fuel costs fell below the lower end of this tolerance band, which resulted in MGE deferring $6.7 million and $6.2 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 $7.0 million ($6.5 million increase discussed above plus $0.5 million fuel rules difference) during the year ended December 31, 2013, compared to the prior year.

Electric operating and maintenance expenses

Electric operating and maintenance expenses increased $1.2 million during the year ended December 31, 2013, compared to the same period in 2012. The following changes contributed to the net change:

(In millions)
Increased transmission costs	$	3.4
Increased production costs		1.1
Increased distribution costs		1.0
Increased customer accounts costs		0.1
Decreased administrative and general costs		(3.6)
Decreased customer service costs		(0.8)
Total	$	1.2

For the year ended December 31, 2013, increased transmission costs are primarily due to an increase in transmission reliability enhancements, increased production costs are primarily due to increased costs at Columbia, and increased distribution costs are primarily due to increased conversion and overhead line maintenance expenses. The increase in costs was partially offset by decreased administrative and general costs which are 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
		2013		2012	% Change	2013	2012	% Change
Residential	$	98,578	$	78,411	25.7 %	102,599	79,936	28.4 %
Commercial/Industrial		79,344		58,374	35.9 %	134,619	106,653	26.2 %
Total retail		177,922		136,785	30.1 %	237,218	186,589	27.1 %
Gas transportation		3,025		2,465	22.7 %	37,778	32,202	17.3 %
Other revenues		515		477	8.0 %	-	-	- %
Total	$	181,462	$	139,727	29.9 %	274,996	218,791	25.7 %
Heating degree days (normal 7,024)						7,628	5,964	27.9 %
Average rate per therm of
retail customer	$	0.750	$	0.733	2.3 %

28

Gas revenues increased $41.7 million or 29.9% for the year ended December 31, 2013. These changes are related to the following factors:

(In millions)
Volume	$	37.1
Rate changes		4.0
Transportation and other effects		0.6
Total	$	41.7

·

Volume. For the year ended December 31, 2013, retail gas deliveries increased 27.1% 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.

·

Rate changes. The average retail rate per therm for the year ended December 31, 2013, increased 2.3% compared to the same period in 2012, reflecting higher natural gas commodity costs.

Cost of gas sold

For the year ended December 31, 2013, cost of gas sold increased by $29.2 million, compared to the same period in the prior year. The volume of purchased gas increased 27.4%, which resulted in $21.4 million of increased expense. In addition, the cost per therm of natural gas increased 7.8%, which resulted in $7.8 million of increased expense.

Gas operating and maintenance expenses

Gas operating and maintenance expenses decreased $2.7 million for the year ended December 31, 2013, compared to the same period in 2012. The following changes contributed to the net change.

(In millions)
Decreased administrative and general costs	$	(2.0)
Decreased customer service costs		(1.3)
Increased distribution costs		0.4
Increased customer accounts costs		0.2
Total	$	(2.7)

For the year ended December 31, 2013, decreased administrative and general costs are primarily due to decreased pension costs, and decreased customer service costs are primarily due to lower energy conservation spending.

Other Income (Deductions), Net - MGE Energy and MGE

For the year ended December 31, 2013, other income, net for the electric and gas segments increased by $1.7 million, compared to the same period in the prior year primarily related to AFUDC equity recognized on the Columbia environmental project.

Nonregulated Energy Operations - MGE Energy and MGE

For the years ended December 31, 2013 and 2012, net income at the nonregulated energy operations segment was $20.7 million and $18.1 million, respectively. The nonregulated energy operations are conducted through MGE Energy's subsidiaries: MGE Power Elm Road and MGE Power West Campus which have been formed to own and lease electric generating capacity to assist MGE.

Results for the years ended December 31, 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.

29

Transmission Investment Operations - MGE Energy and MGE

Transmission investment other income

For the years ended December 31, 2013 and 2012, other income at the transmission investment segment was $9.4 million and $9.1 million, respectively. The transmission investment segment holds our interest in ATC, and its income reflects our equity in the earnings of ATC. See Footnote 4.b. of the Notes to Consolidated Financial Statements for additional information concerning ATC and summarized financial information regarding ATC.

Consolidated Income Taxes - MGE Energy and MGE

Both MGE Energy's and MGE's effective income tax rate for the years ended December 31, 2013 and 2012, was 37.5% and 37.7%, respectively.

For 2011 tax return purposes, MGE Energy and MGE changed their income tax method of accounting for electric transmission and distribution repairs and accounting for depreciation. The 2012 financial statement impact pertaining to finalization of the electric transmission and distribution repairs is an increase to deferred tax expense and a corresponding decrease in the current tax provision in the amount of $4.8 million. The 2012 financial statement impact pertaining to finalization of the depreciation adjustment is an increase to deferred tax expense and a corresponding decrease in the current tax provision in the amount of $38.6 million.

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:

		Year Ended December 31,
(In millions)		2013		2012
MGE Power Elm Road	$	17.4	$	14.8
MGE Power West Campus	$	7.7	$	7.5
MGE Transco	$	2.4	$	2.1

Results of Operations

Year Ended December 31, 2012, Versus the Year Ended December 31, 2011

Electric Utility Operations - MGE Energy and MGE

Electric sales and revenues

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

		Revenues				Sales (kWh)
(In thousands, except cooling degree days)		2012		2011	% Change	2012	2011	% Change
Residential	$	130,581	$	124,524	4.9 %	826,766	821,543	0.6 %
Commercial		207,574		197,621	5.0 %	1,825,701	1,826,636	(0.1)%
Industrial		19,437		19,427	0.1 %	247,179	263,224	(6.1)%
Other-retail/municipal		38,805		36,990	4.9 %	442,906	442,066	0.2 %
Total retail		396,397		378,562	4.7 %	3,342,552	3,353,469	(0.3)%
Sales to the market		991		1,711	(42.1)%	31,588	61,034	(48.2)%
Other revenues		1,811		1,584	14.3 %	-	-	- %
Adjustments to revenues		(6,834)		(5,999)	(13.9)%	-	-	- %
Total	$	392,365	$	375,858	4.4 %	3,374,140	3,414,503	(1.2)%
Cooling degree days (normal 630)						1,068	814	31.2 %

30

Electric operating revenues increased $16.5 million or 4.4% for the year ended December 31, 2012, due to the following:

(In millions)
Rate changes	$	19.0
Other revenues		0.2
Volume		(1.2)
Adjustments to revenues		(0.8)
Sales to the market		(0.7)
Total	$	16.5

·

Rates changes. Rate changes have resulted in $19.0 million of additional revenue in 2012 compared to the same period in the prior year. The change is primarily a result of an electric retail rate increase which was authorized by the PSCW. Effective January 1, 2012, the retail rate increased 4.3% or $15.7 million for electric retail customers. The increase in 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. Other factors also contributed to the revenue increase over the prior year, including customer mix (sales to various customer classes), demand charges, and customer fixed charges.

·

Volume. During the year ended December 31, 2012, there was a 0.3% decrease in total retail sales volumes compared to the same period in the prior year, reflecting decreased industrial customer demand, offset in part by an increase in residential demand.

·

Adjustments to revenues. The adjustments to revenues amount includes the elimination of carrying costs for 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.

·

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.

Electric fuel and purchased power

The expense for fuel for electric generation decreased $4.3 million or 8.5% during the year ended December 31, 2012, compared to the same period in the prior year. Internal electric generation costs decreased $3.2 million as a result of a 6.3% decrease in the per-unit cost (largely due to lower natural gas prices), and lower generation volumes of 1.1% or $1.1 million.

Excluding the fuel rules adjustments discussed below, purchased power expense increased $3.6 million during the year ended December 31, 2012, compared to the same period in the prior year. This increase in expense reflects a $3.0 million or 4.7% increase in per-unit cost of purchased power and a $0.6 million or 0.9% increase in the volume of power purchased from third parties.

The PSCW adopted new fuel rules effective January 1, 2011, that require MGE 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 year ended December 31, 2012, MGE's actual fuel costs fell below the lower end of this tolerance band, which resulted in MGE deferring $6.2 million in fuel-related cost savings to be returned to customers and increased 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 $9.8 million ($6.2 million fuel rules difference plus the $3.6 million purchased power expense increase discussed above) during the year ended December 31, 2012, compared to the prior year.

31

Electric operating and maintenance expenses

Electric operating and maintenance expenses increased $4.7 million during the year ended December 31, 2012, compared to the same period in 2011. The following changes contributed to the net change:

(In millions)
Increased administrative and general costs	$	4.7
Increased customer service costs		0.9
Increased transmission costs		0.6
Increased distribution costs		0.2
Decreased production costs		(1.7)
Total	$	4.7

For the year ended December 31, 2012, increased administrative and general costs are primarily due to increased pension costs, reflecting changes in the discount rate and assumptions regarding investment returns used in calculating such costs. Increased customer service costs are due to higher energy conservation spending. Increased transmission costs are due to higher transmission network costs. Production costs decreased primarily due to decreased costs at Columbia and Blount.

Electric depreciation expense

Electric depreciation expense decreased $2.3 million for the year ended December 31, 2012, compared to the same period in the prior year. This decrease is related to the retirement of Blount assets at the end of 2011 due to the switch from operating with coal to natural gas.

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
		2012		2011	% Change	2012	2011	% Change
Residential	$	78,411	$	93,373	(16.0)%	79,936	91,663	(12.8)%
Commercial/Industrial		58,374		68,729	(15.1)%	106,653	104,254	2.3 %
Total retail		136,785		162,102	(15.6)%	186,589	195,917	(4.8)%
Gas transportation		2,465		2,586	(4.7)%	32,202	35,531	(9.4)%
Other revenues		477		583	(18.2)%	-	-	- %
Total	$	139,727	$	165,271	(15.5)%	218,791	231,448	(5.5)%
Heating degree days (normal 7,122)						5,964	6,993	(14.7)%
Average rate per therm of
retail customer	$	0.733	$	0.827	(11.4)%

Gas revenues decreased $25.5 million or 15.5% for the year ended December 31, 2012. These changes are related to the following factors:

(In millions)
Rate changes	$	(17.6)
Volume		(7.7)
Transportation and other effects		(0.2)
Total	$	(25.5)

·

Rate changes. The average retail rate per therm for the year ended December 31, 2012, decreased 11.4% compared to the same period in 2011, reflecting lower natural gas commodity costs.

·

Volume. For the year ended December 31, 2012, retail gas deliveries decreased 4.8% compared to the same period in 2011, as a result of milder weather during the winter months.

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Cost of gas sold

For the year ended December 31, 2012, cost of gas sold decreased by $21.3 million, compared to the same period in the prior year. The cost per therm of natural gas decreased 17.2%, which resulted in $16.2 million of reduced expense. In addition, the volume of purchased gas decreased 5.1%, which resulted in $5.1 million of reduced expense.

Gas operating and maintenance expenses

Gas operating and maintenance expenses increased $2.4 million for the year ended December 31, 2012, compared to the same period in 2011. The following changes contributed to the net change.

(In millions)
Increased administrative and general costs	$	1.3
Increased customer service costs		0.6
Increased customer accounts costs		0.3
Increased distribution costs		0.2
Total	$	2.4

For the year ended December 31, 2012, increased administrative and general costs were primarily due to increased pension costs, reflecting changes in the discount rate and assumptions regarding investment returns used in calculating such costs. Increased customer service costs are due to higher energy conservation spending.

Other Income (Deductions), Net - MGE Energy and MGE

For the year ended December 31, 2012, other income, net for the electric and gas segments increased by $1.4 million, compared to the same period in the prior year related to AFUDC equity recognized on the Columbia environmental project.

Nonregulated Energy Operations - MGE Energy and MGE

For the years ended December 31, 2012 and 2011, net income at the nonregulated energy operations segment was $18.1 million and $17.9 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 own and lease electric generating capacity to assist MGE.

Transmission Investment Operations - MGE Energy and MGE

Transmission investment other income

For the years ended December 31, 2012 and 2011, other income at the transmission investment segment was $9.1 million and $8.6 million, respectively. The transmission investment segment holds our interest in ATC, and its income reflects our equity in the earnings of ATC. See Footnote 4.b. for additional information concerning ATC and summarized financial information regarding ATC.

Consolidated Other General Taxes - MGE Energy and MGE

MGE Energy's and MGE's other general taxes increased $1.0 million or 5.9% for the year ended December 31, 2012, when compared to the same period in 2011, partially due to increased Wisconsin license fee tax. The annual license fee tax expense is based on the prior year's adjusted operating revenues. Tax rates have not changed.

Consolidated Income Taxes - MGE Energy and MGE

MGE Energy's effective income tax rate for the year ended December 31, 2012, was 37.7% compared to 37.1% for the same period in 2011, and MGE's effective income tax rate for the year ended December 31, 2012, was 37.7% compared to 37.0% for the same period in 2011. The effective income tax rate differences for both MGE Energy and MGE are primarily due to a lower estimated domestic manufacturing deduction.

For 2011 tax return purposes, MGE Energy and MGE changed their income tax method of accounting for electric transmission and distribution repairs and accounting for depreciation. The 2012 financial statement impact pertaining to finalization of the electric transmission and distribution repairs is an increase to deferred tax expense and a corresponding decrease in the current tax provision in the amount of $4.8 million. The 2012 financial statement impact

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pertaining to finalization of the depreciation adjustment is an increase to deferred tax expense and a corresponding decrease in the current tax provision in the amount of $38.6 million.

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:

		Year Ended
		December 31,
(In millions)		2012		2011
MGE Power Elm Road	$	14.8	$	14.6
MGE Power West Campus	$	7.5	$	7.5
MGE Transco	$	2.1	$	1.9

Liquidity and Capital Resources

Cash Flows

The following summarizes cash flows for MGE Energy and MGE during the years ended 2013, 2012, and 2011:

		MGE Energy						MGE
(In thousands)		2013		2012		2011		2013		2012		2011
Cash provided by/(used for):
Operating activities	$	140,267	$	146,004	$	130,772	$	138,684	$	138,772	$	129,683
Investing activities		(121,922)		(101,353)		(66,351)		(120,597)		(101,083)		(65,722)
Financing activities		4,111		(39,463)		(30,362)		(9,629)		(45,237)		(54,557)

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.

2013 vs. 2012

Cash provided by operating activities for the year ended December 31, 2013, was $140.3 million, a decrease of $5.7 million when compared to the same period in the prior year, primarily related to the debt make-whole premium paid in 2013.

MGE Energy's net income increased $10.5 million for the year ended December 31, 2013, when compared to the same period in the prior year.

Working capital accounts resulted in $5.0 million in cash provided by operating activities for the year ended December 31, 2013, primarily due to increased other current liabilities and decreased gas inventories, partially offset by increased receivables and increased unbilled revenues. Working capital accounts resulted in $0.3 million in cash used for operating activities for the year ended December 31, 2012, primarily due to increased accounts receivable and increased unbilled revenues, partially offset by a decreased receivable – margin account and decreased prepaid taxes.

An increase in pension contribution resulted in an additional $5.9 million in cash used for operating activities for the year ended December 31, 2013, when compared to the same period in the prior year. These contributions reflect amounts required by law and discretionary amounts. See Footnote 13 of Notes to Consolidated Financial Statements for further discussion of MGE Energy's pension and other postretirement benefits.

For the year ended December 31, 2013, MGE paid a make-whole premium equal to $6.8 million related to the redemption of $40 million of long-term debt.

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2012 vs. 2011

Cash provided by operating activities for the year ended December 31, 2012, was $146.0 million, an increase of $15.2 million when compared to the same period in the prior year, primarily related to lower income taxes and fuel related cost savings to be returned to customers.

MGE Energy's net income increased $3.5 million for the year ended December 31, 2012, when compared to the same period in the prior year.

The cash flows for the year ended December 31, 2012, reflect an $11.1 million benefit of lower taxes payable, compared to the same period in the prior year, primarily due to the additional benefit from the income tax method change in accounting for repairs and bonus depreciation.

Working capital accounts resulted in $0.3 million in cash used for operating activities for the year ended December 31, 2012, primarily due to increased accounts receivable and increased unbilled revenues, partially offset by a decreased receivable – margin account and decreased prepaid taxes. Working capital accounts resulted in $7.0 million in cash provided by operating activities for the year ended December 31, 2011, primarily due to decreased inventories (due to lower natural gas costs), decreased unbilled revenues and increased accounts payable, partially offset by an increased receivable – margin account.

An increase in pension contribution resulted in an additional $5.2 million in cash used for operating activities for the year ended December 31, 2012, when compared to the same period in the prior year. These contributions reflect amounts required by law and discretionary amounts. See Footnote 13 for further discussion of MGE Energy's pension and other postretirement benefits.

MGE Energy's other noncurrent items, net resulted in $7.0 million of operating cash inflows for the year ended December 31, 2012, compared to $3.9 million of operating cash outflows in the prior year. This increase in cash inflows is a result of fuel related cost savings to be returned to customers.

MGE

2013 vs. 2012

Cash provided by operating activities for the year ended December 31, 2013, was $138.7 million, a decrease of $0.1 million when compared to the same period in the prior year, primarily related to the debt make-whole premium paid in 2013.

Net income increased $11.1 million for the year ended December 31, 2013, when compared to the same period in the prior year.

Working capital accounts resulted in $2.4 million in cash provided by operating activities for the year ended December 31, 2013, primarily due to decreased gas inventories and increased other current liabilities, partially offset by increased receivables and increased unbilled revenues. Working capital accounts resulted in $7.9 million in cash used for operating activities for the year ended December 31, 2012, primarily due to increased accounts receivable, increased unbilled revenues, and increased prepaid taxes, partially offset by decreased receivable – margin account and decreased accounts payable.

An increase in pension contribution resulted in an additional $5.9 million in cash used for operating activities for the year ended December 31, 2013, when compared to the same period in the prior year. These contributions reflect amounts required by law and discretionary amounts. See Footnote 13 of Notes to Consolidated Financial Statements for further discussion of MGE's pension and other postretirement benefits.

For the year ended December 31, 2013, MGE paid a make-whole premium equal to $6.8 million related to the redemption of $40 million of long-term debt.

2012 vs. 2011

Cash provided by operating activities for the year ended December 31, 2012, was $138.8 million, an increase of $9.1 million when compared to the same period in the prior year, primarily related to lower income taxes and fuel related cost savings to be returned to customers.

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Net income increased $4.1 million for the year ended December 31, 2012, when compared to the same period in the prior year.

The cash flows for the year ended December 31, 2012, reflect an $11.3 million benefit of lower taxes payable, compared to the same period in the prior year, primarily due to the additional benefit from the income tax method change in accounting for repairs and bonus depreciation.

Working capital accounts resulted in $7.9 million in cash used for operating activities for the year ended December 31, 2012, primarily due to increased accounts receivable, increased unbilled revenues, and increased prepaid taxes, partially offset by decreased receivable – margin account and decreased accounts payable. Working capital accounts resulted in $6.0 million in cash provided by operating activities for the year ended December 31, 2011, primarily due to decreased inventories (due to lower natural gas costs), decreased unbilled revenues, and increased accounts payable, partially offset by decreased accrued taxes and an increased receivable – margin account.

An increase in pension contribution resulted in an additional $5.2 million in cash used for operating activities for the year ended December 31, 2012, when compared to the same period in the prior year. These contributions reflect amounts required by law and discretionary amounts. See Footnote 13 for further discussion of MGE's pension and other postretirement benefits.

MGE's other noncurrent items, net resulted in $6.7 million of operating cash inflows for the year ended December 31, 2012, compared to $3.9 million of operating cash outflows in the prior year. This increase in cash inflows is a result of fuel related cost savings to be returned to customers.

Capital Requirements and Investing Activities

MGE Energy

2013 vs. 2012

MGE Energy's cash used for investing activities increased $20.6 million for the year ended December 31, 2013, when compared to the same period in the prior year.

Capital expenditures for the year ended December 31, 2013, were $119.0 million. This amount represents a $20.6 million increase from the expenditures made in the same period in the prior year. This increase is due to increased expenditures on the Columbia environmental project.

2012 vs. 2011

MGE Energy's cash used for investing activities increased $35.0 million for the year ended December 31, 2012, when compared to the same period in the prior year.

Capital expenditures for the year ended December 31, 2012, were $98.4 million. This amount represents a $33.3 million increase from the expenditures made in the same period in the prior year. This increase is due to increased expenditures on the Columbia environmental project of $43.0 million offset by a decrease in electric utility capital expenditures in 2012.

Cash used for investment activities increased $1.4 million for the year ended December 31, 2012, when compared to the same period in the prior year as a result of increased capital contributions to ATC and other investments.

Cash used for investing activities was decreased by land purchased for investing purposes of $2.2 million in 2011.

MGE

2013 vs. 2012

MGE's cash used for investing activities increased $19.5 million for the year ended December 31, 2013, when compared to the same period in the prior year.

Capital expenditures for the year ended December 31, 2013, were $119.0 million. This amount represents a $20.6 million increase from the expenditures made in the same period in the prior year. This increase is due to increased expenditures on the Columbia environmental project.

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2012 vs. 2011

MGE's cash used for investing activities increased $35.4 million for the year ended December 31, 2012, when compared to the same period in the prior year.

Capital expenditures for the year ended December 31, 2012, were $98.4 million. This amount represents a $33.3 million increase from the expenditures made in the same period in the prior year. This increase is due to increased expenditures on the Columbia environmental project of $43.0 million offset by a decrease in electric utility capital expenditures in 2012.

Cash used for investment activities increased $1.3 million for the year ended December 31, 2012, when compared to the same period in the prior year as a result of increased capital contributions to ATC and other investments.

Capital expenditures

The following table shows MGE Energy's budgeted capital expenditures for 2014 and actual capital expenditures for both 2013 and 2012:

(In thousands)		2014		2013		2012
For the years ended December 31,		(Budget)		(Actual)		(Actual)
Electric	$	64,413	$	100,146	$	81,965
Gas		20,263		15,554		13,812
Utility plant total		84,676		115,700		95,777
Nonregulated		1,933		3,347		2,658
MGE Energy total	$	86,609	$	119,047	$	98,435

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 $135 million. MGE's share of the capital expenditures associated with the Columbia environmental project will be approximately $14 million in 2014. During the year ended December 31, 2013, MGE had incurred $112.8 million (excluding carrying costs) in construction expenditures at Columbia related to the project and had accrued $8.1 million in incurred, but unpaid capital expenditures. MGE has recognized $2.7 million (after tax) in AFUDC equity related to this project for the year ended December 31, 2013.

MGE Energy used funds received as dividend payments from MGE Power West Campus and MGE Power Elm Road as well as internally generated cash to meet its 2013 capital requirements and cash obligations, including dividend payments.

Financing Activities

MGE Energy

2013 vs. 2012

Cash provided by MGE Energy's financing activities was $4.1 million for the year ended December 31, 2013, compared to $39.5 million of cash used for the year ended December 31, 2012.

For the year ended December 31, 2013, dividends paid were $37.1 million compared to $36.0 million in the prior year. This increase was a result of a higher dividend per share ($1.07 vs. $1.04).

During the year ended December 31, 2013, MGE issued $85.0 million of long-term debt, which was used to retire $40.0 million of long-term debt and to assist with the funding for the Columbia environmental project. During the year ended December 31, 2012, MGE issued and retired $28.0 million of long-term debt.

2012 vs. 2011

Cash used for MGE Energy's financing activities was $39.5 million for the year ended December 31, 2012, compared to $30.4 million of cash used for the year ended December 31, 2011.

For the year ended December 31, 2012, dividends paid were $36.0 million compared to $35.0 million in the prior year. This increase was a result of a higher dividend per share ($1.04 vs. $1.01).

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During the year ended December 31, 2012, MGE issued and retired $28.0 million of long-term debt. During the year ended December 31, 2011, MGE Power Elm Road issued $30.0 million of long-term debt.

For the year ended December 31, 2011, net short-term debt repayments were $22.5 million reflecting the use of proceeds from the MGE Power Elm Road long-term debt issue.

MGE

2013 vs. 2012

During the year ended December 31, 2013, cash used for MGE's financing activities was $9.6 million compared to $45.2 million of cash used for MGE's financing activities in the prior year.

Dividends paid from MGE to MGE Energy were $25.0 million for the year ended December 31, 2013, compared to $20.4 million in the prior year.

During the year ended December 31, 2013, MGE issued $85.0 million of long-term debt, which was used to retire $40.0 million of long-term debt and to assist with the funding for the Columbia environmental project. During the year ended December 31, 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 $27.4 million for the year ended December 31, 2013, compared to $23.5 million in the prior year.

2012 vs. 2011

During the year ended December 31, 2012, cash used for MGE's financing activities was $45.2 million compared to $54.6 million of cash used for MGE's financing activities in the prior year.

Dividends paid from MGE to MGE Energy were $20.4 million for the year ended December 31, 2012, compared to $26.6 million in the prior year.

During the year ended December 31, 2012, MGE issued and retired $28.0 million of long-term debt. During the year ended December 31, 2011, MGE Power Elm Road issued $30.0 million of long-term debt.

Distributions to parent from noncontrolling interest decreased $29.0 million for the year ended December 31, 2012. As a result of long-term debt financing by MGE Power Elm Road, distributions to parent from noncontrolling interest were $43.0 million for the year ended December 31, 2011. The proceeds from the financing were used to repay MGE Energy, which had been using its short-term credit facilities to help finance the Elm Road Units.

In addition, for the year ended December 31, 2011, net short-term debt repayments were $3.5 million.

Dividend Restrictions

Dividend payments by MGE to MGE Energy are subject to restrictions arising under a PSCW rate order and, to a lesser degree, MGE's first mortgage bonds. The PSCW order restricts any dividends that MGE may pay MGE Energy if its common equity ratio, calculated in the manner used in the rate proceeding, is less than 55%. MGE's thirteen month rolling average common equity ratio at December 31, 2013, is 57.6% as determined under the calculation used in the rate proceeding. MGE was not restricted from paying cash dividends in 2013. Cash dividends of $25.0 million and $20.4 million were paid by MGE to MGE Energy in 2013 and 2012, respectively. The rate proceeding calculation includes as indebtedness imputed amounts for MGE's outstanding purchase power capacity payments and other PSCW adjustments, but does not include the indebtedness associated with MGE Power Elm Road and MGE Power West Campus, which are consolidated into MGE's financial statements but are not direct obligations of MGE.

MGE has covenanted with the holders of its first mortgage bonds not to declare or pay any dividend or make any other distribution on or purchase any shares of its common stock unless, after giving effect thereto, the aggregate amount of all such dividends and distributions and all amounts applied to such purchases, after December 31, 1945, shall not exceed the earned surplus (retained earnings) accumulated subsequent to December 31, 1945. As of December 31, 2013, approximately $305.6 million was available for the payment of dividends under this covenant.

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Credit Facilities

At December 31, 2013, MGE Energy and MGE had the following aggregate bank commitments and available capacity under their credit agreements and the indicated amounts of outstanding commercial paper:

		Aggregate Bank Commitments		Outstanding Commercial Paper		Outstanding Borrowings		Available Capacity
Borrower									Expiration Date
		(Dollars in millions)
MGE Energy	$	50.0	$	-	$	-	$	50.0	July 31, 2017
MGE	$	100.0	$	-	$	-	$	100.0	July 31, 2017

Borrowings under each credit agreement may bear interest at a rate that floats daily based upon a prime rate or at a rate fixed for a specified interest period based upon a LIBOR-based index, plus an adder. In the case of the LIBOR-based rates, the adder is based upon the senior unsecured credit rating for MGE and does not exceed 0.75%.

The agreements require the borrower to maintain a ratio of consolidated debt to consolidated total capitalization not to exceed a maximum of 65%. The ratio calculation excludes assets, liabilities, revenues, and expenses included in MGE's financial statements as a result of the consolidation of VIEs, such as MGE Power Elm Road and MGE Power West Campus. At December 31, 2013, the ratio of consolidated debt to consolidated total capitalization for each of MGE Energy and MGE, as calculated under the credit agreements' covenant, were 39.5% and 38.2%, respectively. See Footnote 10 of Notes to Consolidated Financial Statements for additional information regarding the credit facilities.

Capitalization Ratios

MGE Energy's capitalization ratios were as follows:

	MGE Energy
	2013	2012
Common shareholders' equity	60.5 %	61.6 %
Long-term debt*	39.5 %	38.4 %
*Includes the current portion of long-term debt.

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.

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Contractual Obligations and Commercial Commitments for MGE Energy and MGE

MGE Energy's and MGE's contractual obligations as of December 31, 2013, representing cash obligations that are considered to be firm commitments, are as follows:

				Payment due within:						Due after
(In thousands)		Total		1 Year		2-3 Years		4-5 Years		5 Years
MGE Energy
Long-term debt(a)	$	403,793	$	4,102	$	8,450	$	58,810	$	332,431
Short-term debt(b)		-		-		-		-		-
Interest expense(c)		317,402		20,233		39,005		34,689		223,475
Operating leases(d)		13,444		1,668		2,461		1,136		8,179
Purchase obligations(e)		527,308		107,649		143,894		103,087		172,678
Other obligations(f)		32,525		19,903		3,987		1,674		6,961
Purchase obligations - Columbia(g)		14,696		14,696		-		-		-
Total MGE Energy contractual obligations	$	1,309,168	$	168,251	$	197,797	$	199,396	$	743,724
MGE
Long-term debt(a)	$	403,793	$	4,102	$	8,450	$	58,810	$	332,431
Short-term debt(b)		-		-		-		-		-
Interest expense(c)		317,402		20,233		39,005		34,689		223,475
Operating leases(d)		13,444		1,668		2,461		1,136		8,179
Purchase obligations(e)		525,731		106,072		143,894		103,087		172,678
Other obligations(f)		30,334		17,712		3,987		1,674		6,961
Purchase obligations - Columbia(g)		14,696		14,696		-		-		-
Total MGE contractual obligations	$	1,305,400	$	164,483	$	197,797	$	199,396	$	743,724

(a)

Long-term debt consisting of secured first mortgage bonds, unsecured medium-term notes, Industrial Development Revenue Bonds issued by MGE, and private placement debt issued by MGE, MGE Power Elm Road, and MGE Power West Campus.

(b)

No short-term debt outstanding. See Footnote 10 of the Notes to Consolidated Financial Statements.

(c)

Amount represents interest expense on long-term debt. See Footnote 9 of the Notes to Consolidated Financial Statements for further discussion of the long-term debt outstanding at December 31, 2013.

(d)

Operating leases. See Footnote 18 of the Notes to Consolidated Financial Statements.

(e)

Purchase obligations for MGE Energy and MGE consist primarily of the purchase of electricity and natural gas, electric transmission, natural gas storage capacity, natural gas pipeline transportation, and the purchase and transport of coal. See Footnote 18 of the Notes to Consolidated Financial Statements.

(f)

Other obligations are primarily related to investment commitments, easements, maintenance and service agreements, smart grid projects, green energy projects, water quality environmental projects, fuel credit, and uncertain tax positions.

(g)

Purchase obligations for MGE Energy and MGE related to contracts for equipment and services related to the construction of the Columbia environmental project. See Footnote 18 of the Notes to Consolidated Financial Statements.

The above amounts do not include any contributions for MGE's pension and postretirement plans. MGE does not expect to make contributions to the plans for 2014 or 2015. The contributions for years after 2015 are not yet currently estimated. Due to uncertainties in the future economic performance of plan assets, discount rates, and other key assumptions, estimated contributions are subject to change. MGE may also elect to make additional discretionary contributions. These contributions reflect amounts required by law and discretionary amounts.

The above amounts do not include future voluntary capital calls to ATC. On January 31, 2014, MGE Transco made a voluntary $0.5 million capital contribution to ATC. The amount and timing of future voluntary capital calls is uncertain and primarily dependent on the operations and expansion of ATC.

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MGE Energy's and MGE's commercial commitments as of December 31, 2013, representing commitments triggered by future events and including financing arrangements to secure obligations of MGE Energy and MGE, and guarantees by MGE, are as follows:

				Expiration within:						Due after
(In thousands)		Total		1 Year		2-3 Years		4-5 Years		5 Years
MGE Energy
Available Lines of Credit(a)	$	150,000	$	-	$	-	$	150,000	$	-
Guarantees(b)		5,378		714		1,917		955		1,792
MGE
Available Lines of Credit(c)	$	100,000	$	-	$	-	$	100,000	$	-
Guarantees(b)		5,378		714		1,917		955		1,792

(a)

Amount includes the facility discussed in (c) plus an additional line of credit. MGE Energy has available at any time a $50 million committed revolving credit agreement, expiring in July 2017. At December 31, 2013, MGE Energy had no borrowings under this credit facility.

(b)

MGE has guaranteed repayment of certain receivables it sold to a financial institution under a chattel paper agreement. See Footnote 18 of the Notes to Consolidated Financial Statements.

(c)

Amount includes a $100 million committed revolving credit agreement expiring in July 2017. This credit facility is used to support commercial paper issuances. At December 31, 2013, there were no borrowings under this facility.

Other Matters

Elm Road

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. In addition, the PSCW deferred the final decision regarding the $1.8 million fuel flexibility project (MGE Power Elm Road's share) until a future rate proceeding.

The warranty periods for both of the Elm Road Units have expired. During 2013, WEPCO and Bechtel (the construction contractor for the Elm Road Units) were working through the outstanding warranty claims. The warranty claim for the costs incurred to repair steam turbine corrosion damage identified on both units was resolved through a binding arbitration in June 2013. Final acceptance of the Elm Road Units occurred in June 2013 after all requirements stated in the contract with Bechtel were satisfied.

ATC

On November 12, 2013, MISO and numerous other MISO transmission owners, including ATC, were named as respondents in a complaint filed at FERC. The complainants argue that the respondents' transmission rates are no longer just and reasonable "due to changes in the capital markets," and that the MISO base return on equity (ROE) should not exceed 9.15%, equity components of hypothetical capital structures should be restricted to 50%, and that relevant incentive ROE adders should be discontinued. MISO's base ROE is 12.38% and ATC's base ROE is 12.2%. MISO and the other MISO transmission owners filed a motion to dismiss the complaint.

In April 2011, ATC and Duke Energy announced the creation of a joint venture, Duke-American Transmission Company (DATC), that seeks to build, own and operate new electric transmission infrastructure in North America to address increasing demand for affordable, reliable transmission capacity. DATC has announced various transmission projects to be constructed over the next 10 years. These projects are subject to approval by various regulatory agencies. At December 31, 2013, MGE Transco held a 3.6% ownership interest in ATC. Additional capital contributions by MGE Transco to ATC may be required.

Critical Accounting Estimates - MGE Energy and MGE

The preparation of financial statements in conformity with accounting principles generally accepted in the United States of America requires management to make estimates and judgments that affect the reported amounts of assets, liabilities, revenues and expenses, and related disclosure of contingent assets and liabilities. On an on-going basis, we evaluate our estimates, including those related to unbilled revenues, allowance for doubtful accounts, pension obligations, income

41

taxes, derivatives, and regulatory assets and liabilities. We base our estimates on historical experience and on various assumptions that are believed to be reasonable under the circumstances, the results of which form the basis for making judgments about the carrying values of assets and liabilities that are not readily apparent from other sources. Those values may differ from these estimates under different assumptions or conditions. We believe the following critical accounting estimates affect our more significant judgments used in the preparation of our consolidated financial statements.

Unbilled Revenues

Revenues from the sale of electricity and gas to customers are recorded when electricity/gas is delivered to those customers. The quantity of those sales is measured by customers' meters. Due to the large volume of those meters, it is impractical to read all of them at month end. Meters are read on a systematic basis throughout the month based on established meter-reading schedules. Consequently, at the end of any month, there exists a quantity of electricity and gas that has been delivered to customers but has not been captured by the meter readings. As a result, management must estimate revenue related to electricity and gas delivered to customers between their meter-read dates and the end of the period. These estimates include:

·

The amount of electricity expected to be lost in the process of its transmission and distribution to customers (line loss) and the amount of electricity actually delivered to customers.

·

The amount of gas expected to be lost in the process of its distribution to customers and the amount of gas actually delivered to customers.

·

The mix of sales between customer rate classes, which is based upon historical utilization assumptions.

MGE monitors the reasonableness of the unbilled revenue estimate through the review of ratios such as unbilled electric consumption compared to billed electric sales. In the case of unbilled gas, the estimated unbilled consumption is compared to various other statistics, including percent of gas available for sale, change in unbilled month to month and change in unbilled compared to the prior year in order to confirm its reasonableness.

Allowance for Doubtful Accounts

MGE maintains allowances for doubtful accounts for estimated losses resulting from the inability of its customers to make required payments. It determines the allowance based on historical write-off experience, regional economic data, and review of the accounts receivable aging. MGE reviews its allowance for doubtful accounts monthly. Although management believes that the allowance for doubtful accounts is MGE's best estimate of the amount of probable credit losses, if the financial condition of MGE's customers were to deteriorate, resulting in an impairment of their ability to make payments, additional allowances may be required.

Pension and Other Postretirement Benefit Plans

MGE provides employees with certain retirement (pension) and postretirement (health care and life insurance) benefits. In order to measure the expense and obligations associated with these benefits, management must make a variety of estimates, including discount rates used to value certain liabilities, the expected return on plan assets set aside to fund these costs, the rate of compensation increase, employee turnover rates, retirement rates, health care trends, mortality rates, and other factors. These accounting estimates bear the risk of change due to the uncertainty attached to the estimate as well as the fact that these estimates are difficult to measure. Different estimates used by us could result in recognizing different amounts of expense over different periods of time and recovery in rates is expected.

We use third-party specialists to assist us in evaluating our assumptions as well as appropriately measure the costs and obligations associated with these retirement benefits. The discount rate and expected return on plan assets are based primarily on available investment yields and the historical performance of our plan assets. They are critical accounting estimates because they are subject to management's judgment and can materially affect net income.

·

Assumed return on assets. This assumption represents the rate of return on plan assets reflecting the average rate of earnings expected on the funds invested (or to be invested) to provide for the benefits included in the projected benefit obligation. For 2013, MGE used an assumed return on assets of 8.10% for pension and 6.79% for other postretirement benefits. In 2014, the pension asset assumption will remain at 8.10%. MGE will increase the postretirement benefit assumption from 6.79% to 7.07% in 2014. The annual expected rate of return is based on projected long-term equity and bond returns, maturities and asset allocations. Holding other assumptions constant, for every 1% reduction in the expected rate of return on plan assets, annual pension and other postretirement cost would increase by approximately $2.7 million, before taxes.

42

·

Discount rate. The discount rate represents the rate at which pension obligations could effectively be settled on a present-value basis. MGE uses high-grade bond yields as a benchmark for determining the appropriate discount rate.

·

Medical trend assumptions. The health care cost trend rate is the assumed rate of increase in per-capita health care charges.

See Footnote 13 of the Notes to Consolidated Financial Statements for additional discussion of these plans.

Income Tax Provision

MGE Energy's and MGE's income tax provisions, including both current and deferred components, are based on estimates, assumptions, calculations, and interpretation of tax statutes for the current and future years. Determination of current-year federal and state income tax will not be settled for years.

Management regularly makes assessments of tax return outcomes relative to financial statement tax provisions and adjusts the tax provisions in the period when facts become final.

Additionally, in determining our current income tax provision we assess temporary differences resulting from differing treatments of items for tax and accounting purposes. These differences result in deferred tax assets and liabilities, which are recorded in our balance sheets. When we maintain deferred tax assets, we assess the likelihood that these assets will be recovered through adjustments to future taxable income. To the extent we believe recovery is not more likely than not, we establish a valuation allowance. We record an allowance reducing the asset to a value we believe will be recoverable based on our expectation of future taxable income. We believe the accounting estimate related to the valuation allowance is a critical accounting estimate because it is highly susceptible to change from period to period as it requires management to make assumptions about our future income over the lives of the deferred tax assets, and the impact of increasing or decreasing the valuation allowance is potentially material to our results of operations.

Accounting for uncertainty in income taxes applies to all tax positions and requires a recognition threshold and measurement standard for the financial statement recognition and measurement of a tax position taken, or expected to be taken, in an income tax return. The threshold is defined for recognizing tax return positions in the financial statements as "more likely than not" that the position is sustainable, based on its merits. Subsequent recognition, derecognition, and measurement is based on management's best judgment given the facts, circumstances and information available at the reporting date.

Accounting for Derivative Instruments

MGE accounts for derivative financial instruments, except those qualifying for the normal purchase normal sale exception, at their fair value on the balance sheet. Fair value is determined using current quoted market prices, except for the ten-year PPA which is valued utilizing an internally-developed pricing model. This model includes observable and unobservable inputs.

MGE received approval from the PSCW to establish a regulatory asset or liability for the deferral of the effects of mark-to-market accounting on contracts related to MGE's regulated operations.

Regulatory Assets/Liabilities

Regulatory assets represent costs that have been deferred to future periods when it is probable that the regulator will allow future recovery of those costs through rates. MGE bases its assessment of recovery on precedents established by the regulatory body. Regulatory liabilities represent previous collections from customers that are expected to be refunded to customers in future periods. Regulatory assets and regulatory liabilities typically include deferral of energy costs, the normalization of income taxes, the deferral of certain operating expenses, and non-ARO removal cost. The accounting for these regulatory assets and liabilities is in accordance with regulatory accounting standards.

MGE continually assesses whether the regulatory assets and liabilities meet the criteria for probability of future recovery or deferral. This assessment considers factors such as changes in the regulatory environment, recent rate orders to other regulated entities under the same jurisdiction, and the status of any pending or potential deregulation legislation. If future recovery of costs becomes no longer probable, the assets and liabilities would be recognized as current-period revenues or expenses.

Amortization of regulatory assets and liabilities is provided over the recovery or deferral period as allowed in the related regulatory agreement.

43

Adoption of Accounting Principles and Recently Issued Accounting Pronouncements - MGE Energy and MGE

See Footnote 21 of the Notes to Consolidated Financial Statements for discussion of new accounting pronouncements.

Item 7A. 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 costs fall outside the lower end of the range and would defer costs, less any excess revenues, if the actual electric fuel 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 17 of the Notes to Consolidated Financial Statements for additional information.

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

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

MGE has financial gas and electric commodity contracts to hedge commodity price risk in the gas and electric segments. These contracts are primarily comprised of exchange-traded option and future contracts. MGE also holds FTRs, which are used to hedge the risk of increased transmission congestion charges. At December 31, 2013, the fair value of these instruments exceeded their cost basis by $1.8 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 an option to extend the contract after the base term. The agreement is considered a derivative contract and is recognized at its fair value on the consolidated balance sheet. However, the derivative qualifies for regulatory deferral and is recognized with a corresponding regulatory asset or liability depending on whether the fair value is in a loss or gain position. The fair value of the contract at December 31, 2013, reflects a loss position of $65.7 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 (see Footnote 10 of the Notes to Consolidated Financial Statements). 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. Holding other assumptions constant, for every 1% reduction in the expected rate of return on plan assets, annual pension and other postretirement cost would increase by approximately $2.7 million, before taxes. MGE's risk of expense and annuity payments, as a result of changes in the market value of the trust funds, is mitigated in part through future rate actions by the PSCW. The value of employee benefit plans trusts' assets have increased in value by approximately 19.4% during the year ended December 31, 2013, and 14.5% during the year ended December 31, 2012.

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 December 31, 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 1,649 square miles in Wisconsin. Based on results for the year ended December 31, 2013, 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.

45

Item 8. Financial Statements and Supplementary Data.

MGE Energy

Management's Report on Internal Control Over Financial Reporting

Our management is responsible for establishing and maintaining adequate internal control over financial reporting, as such term is defined in Exchange Act Rule 13a-15(f). Under the supervision and with the participation of our management, including our principal executive officer and principal financial officer, we conducted an assessment of the effectiveness of our internal control over financial reporting based on the framework in the Internal Control - Integrated Framework (1992) issued by the Committee of Sponsoring Organizations of the Treadway Commission. Based on our assessment under the framework in the Internal Control - Integrated Framework (1992), our management concluded that our internal control over financial reporting was effective as of December 31, 2013.

Because of its inherent limitations, internal control over financial reporting may not prevent or detect misstatements. Also, projections of any evaluation of effectiveness to future periods are subject to the risk that controls may become inadequate because of changes in conditions, or that the degree of compliance with the policies or procedures may deteriorate.

The effectiveness of MGE Energy's internal control over financial reporting as of December 31, 2013, has been audited by PricewaterhouseCoopers LLP, an independent registered public accounting firm, as stated in their report which appears herein.

February 27, 2014

MGE

Management's Report on Internal Control Over Financial Reporting

Our management is responsible for establishing and maintaining adequate internal control over financial reporting, as such term is defined in Exchange Act Rule 13a-15(f). Under the supervision and with the participation of our management, including our principal executive officer and principal financial officer, we conducted an assessment of the effectiveness of our internal control over financial reporting based on the framework in the Internal Control - Integrated Framework (1992) issued by the Committee of Sponsoring Organizations of the Treadway Commission. Based on our assessment under the framework in the Internal Control - Integrated Framework (1992), our management concluded that our internal control over financial reporting was effective as of December 31, 2013.

Because of its inherent limitations, internal control over financial reporting may not prevent or detect misstatements. Also, projections of any evaluation of effectiveness to future periods are subject to the risk that controls may become inadequate because of changes in conditions, or that the degree of compliance with the policies or procedures may deteriorate.

February 27, 2014

46

Report of Independent Registered Public Accounting Firm

To the Board of Directors and Shareholders of MGE Energy, Inc.:

In our opinion, the consolidated financial statements listed in the index appearing under Item 15(a)(1) present fairly, in all material respects, the financial position of MGE Energy, Inc. and its subsidiaries at December 31, 2013 and 2012, and the results of their operations and their cash flows for each of the three years in the period ended December 31, 2013, in conformity with accounting principles generally accepted in the United States of America. In addition, in our opinion, the financial statement schedules listed in the index appearing under Item 15(a)(2) present fairly, in all material respects, the information set forth therein when read in conjunction with the related consolidated financial statements. Also in our opinion, the Company maintained, in all material respects, effective internal control over financial reporting as of December 31, 2013, based on criteria established in the Internal Control - Integrated Framework (1992) issued by the Committee of Sponsoring Organizations of the Treadway Commission (COSO). The Company's management is responsible for these financial statements and financial statement schedules, for maintaining effective internal control over financial reporting and for its assessment of the effectiveness of internal control over financial reporting, included in the accompanying Management's Report on Internal Control Over Financial Reporting. Our responsibility is to express opinions on these financial statements, on the financial statement schedules, and on the Company's internal control over financial reporting based on our integrated audits. We conducted our audits in accordance with the standards of the Public Company Accounting Oversight Board (United States). Those standards require that we plan and perform the audits to obtain reasonable assurance about whether the financial statements are free of material misstatement and whether effective internal control over financial reporting was maintained in all material respects. Our audits of the financial statements included examining, on a test basis, evidence supporting the amounts and disclosures in the financial statements, assessing the accounting principles used and significant estimates made by management, and evaluating the overall financial statement presentation. Our audit of internal control over financial reporting included obtaining an understanding of internal control over financial reporting, assessing the risk that a material weakness exists, and testing and evaluating the design and operating effectiveness of internal control based on the assessed risk. Our audits also included performing such other procedures as we considered necessary in the circumstances. We believe that our audits provide a reasonable basis for our opinions.

A company's internal control over financial reporting is a process designed 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. A company's internal control over financial reporting includes those policies and procedures that (i) pertain to the maintenance of records that, in reasonable detail, accurately and fairly reflect the transactions and dispositions of the assets of the company; (ii) provide reasonable assurance that transactions are recorded as necessary to permit preparation of financial statements in accordance with generally accepted accounting principles, and that receipts and expenditures of the company are being made only in accordance with authorizations of management and directors of the company; and (iii) provide reasonable assurance regarding prevention or timely detection of unauthorized acquisition, use, or disposition of the company's assets that could have a material effect on the financial statements.

Because of its inherent limitations, internal control over financial reporting may not prevent or detect misstatements. Also, projections of any evaluation of effectiveness to future periods are subject to the risk that controls may become inadequate because of changes in conditions, or that the degree of compliance with the policies or procedures may deteriorate.

/s/ PricewaterhouseCoopers LLP

Boston, Massachusetts

February 27, 2014

47

Report of Independent Registered Public Accounting Firm

To the Board of Directors and Shareholder of Madison Gas and Electric Company:

In our opinion, the consolidated financial statements listed in the index appearing under Item 15(a)(1) present fairly, in all material respects, the financial position of Madison Gas and Electric Company and its subsidiaries at December 31, 2013 and 2012, and the results of their operations and their cash flows for each of the three years in the period ended December 31, 2013, in conformity with accounting principles generally accepted in the United States of America. In addition, in our opinion, the financial statement schedule listed in the index appearing under Item 15(a)(2) presents fairly, in all material respects, the information set forth therein when read in conjunction with the related consolidated financial statements. These financial statements and financial statement schedule are the responsibility of the Company's management. Our responsibility is to express an opinion on these financial statements and financial statement schedule based on our audits. We conducted our audits of these statements in accordance with the standards of the Public Company Accounting Oversight Board (United States). Those standards require that we plan and perform the audit to obtain reasonable assurance about whether the financial statements are free of material misstatement. An audit includes examining, on a test basis, evidence supporting the amounts and disclosures in the financial statements, assessing the accounting principles used and significant estimates made by management, and evaluating the overall financial statement presentation. We believe that our audits provide a reasonable basis for our opinion.

/s/ PricewaterhouseCoopers LLP

Boston, Massachusetts

February 27, 2014

48

MGE Energy, Inc.

Consolidated Statements of Income

(In thousands, except per share amounts)

		For the years ended December 31,
		2013		2012		2011
Operating Revenues:
Regulated electric revenues	$	403,957	$	392,365	$	375,858
Regulated gas revenues		181,462		139,727		165,271
Nonregulated revenues		5,468		9,231		5,253
Total Operating Revenues		590,887		541,323		546,382
Operating Expenses:
Fuel for electric generation		46,062		46,499		50,819
Purchased power		80,830		73,842		64,085
Cost of gas sold		107,315		78,156		99,465
Other operations and maintenance		171,248		172,996		165,859
Depreciation and amortization		38,838		38,707		40,942
Other general taxes		18,607		18,360		17,344
Total Operating Expenses		462,900		428,560		438,514
Operating Income		127,987		112,763		107,868
Other income, net		10,701		10,069		9,214
Interest expense, net		(18,924)		(19,467)		(20,162)
Income before income taxes		119,764		103,365		96,920
Income tax provision		(44,859)		(38,919)		(35,992)
Net Income	$	74,905	$	64,446	$	60,928
Earnings Per Share of Common Stock
(basic and diluted)	$	2.16	$	1.86	$	1.76
Dividends per share of common stock	$	1.07	$	1.04	$	1.01
Weighted Average Shares Outstanding
(basic and diluted)		34,668		34,668		34,668
The accompanying notes are an integral part of the above consolidated financial statements.

MGE Energy, Inc.

Consolidated Statements of Comprehensive Income

(In thousands)

		For the years ended December 31,
		2013		2012		2011
Net Income	$	74,905	$	64,446	$	60,928
Other comprehensive income (loss), net of tax:
Unrealized gain (loss) on available-for-sale securities, net of
tax ($189, $12, and $10)		283		(18)		(15)
Reclassification of realized gain on available-for-sale
securities, net of tax ($-, $-, and $10)		-		-		(15)
Comprehensive Income	$	75,188	$	64,428	$	60,898
The accompanying notes are an integral part of the above consolidated financial statements.

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MGE Energy, Inc.

Consolidated Statements of Cash Flows

(In thousands)

		For the years ended December 31,
		2013		2012		2011
Operating Activities:
Net income	$	74,905	$	64,446	$	60,928
Items not affecting cash:
Depreciation and amortization		38,838		38,707		40,942
Deferred income taxes		38,365		44,797		33,698
Provision for doubtful receivables		2,448		2,498		2,312
Employee benefit plan expenses		13,303		18,353		13,703
Equity earnings in ATC		(9,434)		(9,079)		(8,615)
Other items		117		1,283		1,616
Changes in working capital items:
Receivable - margin account		1,444		3,726		(2,609)
Trade and other receivables		(3,827)		(6,208)		173
Inventories		2,488		1,457		7,438
Unbilled revenues		(3,720)		(2,508)		3,466
Prepaid taxes		414		2,731		245
Other current assets		1,070		367		538
Accounts payable		858		(272)		2,055
Other current liabilities		6,271		425		(4,300)
Dividend income from ATC		7,404		7,146		6,728
Cash contributions to pension and other postretirement plans		(34,765)		(28,857)		(23,670)
Debt make-whole premium		(6,757)		-		-
Other noncurrent items, net		10,845		6,992		(3,876)
Cash Provided by Operating Activities		140,267		146,004		130,772
Investing Activities:
Capital expenditures		(119,047)		(98,435)		(65,176)
Capital contributions to investments		(1,660)		(2,419)		(1,008)
Purchase of investment - land		(10)		(3)		(2,152)
Other		(1,205)		(496)		1,985
Cash Used for Investing Activities		(121,922)		(101,353)		(66,351)
Financing Activities:
Cash dividends paid on common stock		(37,107)		(35,951)		(35,026)
Repayment of long-term debt		(43,012)		(30,668)		(2,500)
Issuance of long-term debt		85,000		28,000		30,000
Decrease in short-term debt		-		-		(22,500)
Other		(770)		(844)		(336)
Cash Provided by (Used for) Financing Activities		4,111		(39,463)		(30,362)
Change in Cash and Cash Equivalents:		22,456		5,188		34,059
Cash and cash equivalents at beginning of period		46,357		41,169		7,110
Cash and cash equivalents at end of period	$	68,813	$	46,357	$	41,169
Supplemental disclosures of cash flow information:
Interest paid	$	17,991	$	19,499	$	19,788
Income taxes paid	$	8,046	$	3,544	$	5,537
Income taxes received	$	(1,339)	$	(12,536)	$	(4,370)
Significant noncash investing activities:
Accrued capital expenditures	$	9,892	$	10,317	$	684
The accompanying notes are an integral part of the above consolidated financial statements.

50

MGE Energy, Inc.

Consolidated Balance Sheets

(In thousands)

		At December 31,
ASSETS		2013		2012
Current Assets:
Cash and cash equivalents	$	68,813	$	46,357
Accounts receivable, less reserves of $4,219 and $3,885, respectively		44,890		41,386
Other accounts receivable, less reserves of $750 and $931, respectively		5,352		6,746
Unbilled revenues		31,982		28,262
Materials and supplies, at average cost		16,662		16,997
Fossil fuel		5,206		6,367
Stored natural gas, at average cost		13,988		14,980
Prepaid taxes		19,106		19,520
Regulatory assets - current		6,377		10,327
Deferred income taxes		-		23,483
Other current assets		8,225		8,512
Total Current Assets		220,601		222,937
Other long-term receivables		2,193		1,102
Regulatory assets		107,166		218,853
Pension and other postretirement benefits		15,071		-
Other deferred assets and other		5,853		5,973
Property, Plant, and Equipment:
Property, plant, and equipment, net		1,018,809		975,053
Construction work in progress		141,415		98,411
Total Property, Plant, and Equipment		1,160,224		1,073,464
Investments		67,952		64,595
Total Assets	$	1,579,060	$	1,586,924
LIABILITIES AND CAPITALIZATION
Current Liabilities:
Long-term debt due within one year	$	4,102	$	3,013
Accounts payable		43,684		43,518
Accrued interest and taxes		5,661		4,296
Accrued payroll related items		10,731		10,063
Deferred income taxes		1,711		-
Regulatory liabilities - current		13,538		-
Derivative liabilities		7,750		9,270
Other current liabilities		9,489		5,637
Total Current Liabilities		96,666		75,797
Other Credits:
Deferred income taxes		284,791		270,410
Investment tax credit - deferred		1,413		1,520
Regulatory liabilities		19,792		24,538
Accrued pension and other postretirement benefits		49,184		162,835
Derivative liabilities		57,930		63,320
Other deferred liabilities and other		52,360		50,584
Total Other Credits		465,470		573,207
Capitalization:
Common shareholders' equity:
Common Stock - $1 par value - 50,000 shares authorized;
34,668 shares issued and outstanding		34,668		34,668
Additional paid-in capital		316,268		316,268
Retained earnings		266,197		228,399
Accumulated other comprehensive income, net of tax		377		94
Total Common Shareholders' Equity		617,510		579,429
Long-term debt		399,414		358,491
Total Capitalization		1,016,924		937,920
Commitments and contingencies (see Footnote 18)		-		-
Total Liabilities and Capitalization	$	1,579,060	$	1,586,924
The accompanying notes are an integral part of the above consolidated financial statements.

51

MGE Energy, Inc.

Consolidated Statements of Common Equity

(In thousands, except per share amounts)

	Common Stock				Additional Paid-in Capital		Retained Earnings		Accumulated Other Comprehensive (Loss)/Income		Total
	Shares		Value
2011
Beginning balance - December 31, 2010	34,668	$	34,668	$	316,268	$	174,002	$	142	$	525,080
Net income							60,928				60,928
Other comprehensive income/(loss)									(30)		(30)
Common stock dividends declared
($1.01 per share)							(35,026)				(35,026)
Ending balance - December 31, 2011	34,668	$	34,668	$	316,268	$	199,904	$	112	$	550,952
2012
Net income							64,446				64,446
Other comprehensive income/(loss)									(18)		(18)
Common stock dividends declared
($1.04 per share)							(35,951)				(35,951)
Ending balance - December 31, 2012	34,668	$	34,668	$	316,268	$	228,399	$	94	$	579,429
2013
Net income							74,905				74,905
Other comprehensive income/(loss)									283		283
Common stock dividends declared
($1.07 per share)							(37,107)				(37,107)
Ending balance - December 31, 2013	34,668	$	34,668	$	316,268	$	266,197	$	377	$	617,510
The accompanying notes are an integral part of the above consolidated financial statements.

52

Madison Gas and Electric Company

Consolidated Statements of Income

(In thousands)

		For the years ended December 31,
		2013		2012		2011
Operating Revenues:
Regulated electric revenues	$	403,980	$	392,365	$	375,858
Regulated gas revenues		181,477		139,727		165,271
Nonregulated revenues		5,468		9,231		5,253
Total Operating Revenues		590,925		541,323		546,382
Operating Expenses:
Fuel for electric generation		46,070		46,499		50,819
Purchased power		80,844		73,842		64,085
Cost of gas sold		107,330		78,156		99,465
Other operations and maintenance		170,498		171,965		164,903
Depreciation and amortization		38,834		38,707		40,942
Other general taxes		18,607		18,360		17,344
Income tax provision		41,519		35,334		32,287
Total Operating Expenses		503,702		462,863		469,845
Operating Income		87,223		78,460		76,537
Other Income and Deductions:
AFUDC - equity funds		3,140		1,731		413
Equity in earnings in ATC		9,434		9,079		8,615
Income tax provision		(4,303)		(4,101)		(3,752)
Other deductions, net		(18)		(263)		(321)
Total Other Income and Deductions		8,253		6,446		4,955
Income before interest expense		95,476		84,906		81,492
Interest Expense:
Interest on long-term debt		20,087		20,386		20,634
Other interest, net		(21)		(82)		(226)
AFUDC - borrowed funds		(1,035)		(704)		(168)
Net Interest Expense		19,031		19,600		20,240
Net Income	$	76,445	$	65,306	$	61,252
Less Net Income Attributable to Noncontrolling Interest, net of tax		(27,438)		(24,489)		(23,970)
Net Income Attributable to MGE	$	49,007	$	40,817	$	37,282
The accompanying notes are an integral part of the above consolidated financial statements.

Madison Gas and Electric Company

Consolidated Statements of Comprehensive Income

(In thousands)

		For the years ended December 31,
		2013		2012		2011
Net Income	$	76,445	$	65,306	$	61,252
Other comprehensive income (loss), net of tax:
Unrealized gain (loss) on available-for-sale securities, net of
tax ($126, $29, and $7)		188		(43)		(9)
Reclassification of realized gain on available-for-sale
securities, net of tax ($-, $-, and $10)		-		-		(15)
Comprehensive Income	$	76,633	$	65,263	$	61,228
Less: Comprehensive Income Attributable to Noncontrolling
Interest, net of tax		(27,438)		(24,489)		(23,970)
Comprehensive Income Attributable to MGE	$	49,195	$	40,774	$	37,258
The accompanying notes are an integral part of the above consolidated financial statements.

53

Madison Gas and Electric Company

Consolidated Statements of Cash Flows

(In thousands)

		For the years ended December 31,
		2013		2012		2011
Operating Activities:
Net income	$	76,445	$	65,306	$	61,252
Items not affecting cash:
Depreciation and amortization		38,834		38,707		40,942
Deferred income taxes		37,462		44,112		32,773
Provision for doubtful receivables		2,448		2,498		2,312
Employee benefit plan expenses		13,303		18,353		13,703
Equity earnings in ATC		(9,434)		(9,079)		(8,615)
Other items		651		1,813		2,172
Changes in working capital items:
Receivable - margin account		1,444		3,726		(2,609)
Trade and other receivables		(3,699)		(7,219)		1,183
Inventories		2,488		1,457		7,438
Unbilled revenues		(3,720)		(2,508)		3,466
Prepaid taxes		(373)		(1,584)		(477)
Other current assets		1,074		366		536
Accounts payable		126		(1,658)		4,214
Accrued interest and taxes		2,065		211		(3,741)
Other current liabilities		2,975		(714)		(4,027)
Dividend income from ATC		7,404		7,146		6,728
Cash contributions to pension and other postretirement plans		(34,765)		(28,857)		(23,670)
Debt make-whole premium		(6,757)		-		-
Other noncurrent items, net		10,713		6,696		(3,897)
Cash Provided by Operating Activities		138,684		138,772		129,683
Investing Activities:
Capital expenditures		(119,047)		(98,435)		(65,176)
Capital contributions to investments		(1,420)		(2,140)		(888)
Other		(130)		(508)		342
Cash Used for Investing Activities		(120,597)		(101,083)		(65,722)
Financing Activities:
Cash dividends paid to parent by MGE		(25,000)		(20,404)		(26,648)
Distributions to parent from noncontrolling interest		(27,365)		(23,500)		(52,500)
Equity contribution received by noncontrolling interest		1,420		2,130		888
Repayment of long-term debt		(43,012)		(30,668)		(2,500)
Issuance of long-term debt		85,000		28,000		30,000
Decrease in short-term debt		-		-		(3,500)
Other		(672)		(795)		(297)
Cash Used for Financing Activities		(9,629)		(45,237)		(54,557)
Change in Cash and Cash Equivalents:		8,458		(7,548)		9,404
Cash and cash equivalents at beginning of period		6,350		13,898		4,494
Cash and cash equivalents at end of period	$	14,808	$	6,350	$	13,898
Supplemental disclosures of cash flow information:
Interest paid	$	17,991	$	19,499	$	19,731
Income taxes paid	$	144	$	44	$	28
Income taxes received	$	-	$	(448)	$	(10)
Significant noncash investing activities:
Accrued capital expenditures	$	9,892	$	10,317	$	684
The accompanying notes are an integral part of the above consolidated financial statements.

54

Madison Gas and Electric Company

Consolidated Balance Sheets

(In thousands)

		At December 31,
ASSETS		2013		2012
Current Assets:
Cash and cash equivalents	$	14,808	$	6,350
Accounts receivable, less reserves of $4,219 and $3,885, respectively		44,890		41,386
Affiliate receivables		534		634
Other accounts receivable, less reserves of $750 and $931, respectively		5,274		6,732
Unbilled revenues		31,982		28,262
Materials and supplies, at average cost		16,662		16,997
Fossil fuel		5,206		6,367
Stored natural gas, at average cost		13,988		14,980
Prepaid taxes		23,934		23,561
Regulatory assets - current		6,377		10,327
Deferred income taxes		-		23,305
Other current assets		8,197		8,488
Total Current Assets		171,852		187,389
Affiliate receivable long-term		5,825		6,354
Regulatory assets		107,166		218,853
Pension and other postretirement benefits		15,071		-
Other deferred assets and other		6,138		6,540
Property, Plant, and Equipment:
Property, plant, and equipment, net		1,017,877		974,549
Construction work in progress		141,415		98,411
Total Property, Plant, and Equipment		1,159,292		1,072,960
Investments		65,299		61,555
Total Assets	$	1,530,643	$	1,553,651
LIABILITIES AND CAPITALIZATION
Current Liabilities:
Long-term debt due within one year	$	4,102	$	3,013
Accounts payable		43,684		43,517
Affiliate payables		34		767
Accrued interest and taxes		6,040		4,248
Accrued payroll related items		10,731		10,063
Deferred income taxes		2,723		-
Regulatory liabilities - current		13,538		-
Derivative liabilities		7,750		9,270
Other current liabilities		6,412		4,491
Total Current Liabilities		95,014		75,369
Other Credits:
Deferred income taxes		279,085		266,231
Investment tax credit - deferred		1,413		1,520
Regulatory liabilities		19,792		24,538
Accrued pension and other postretirement benefits		49,184		162,835
Derivative liabilities		57,930		63,320
Other deferred liabilities and other		52,357		50,581
Total Other Credits		459,761		569,025
Capitalization:
Common shareholder's equity:
Common Stock - $1 par value - 50,000 shares authorized; 17,348 shares outstanding		17,348		17,348
Additional paid-in capital		192,417		192,417
Retained earnings		247,534		223,527
Accumulated other comprehensive income, net of tax		192		4
Total Common Shareholder's Equity		457,491		433,296
Noncontrolling interest		118,963		117,470
Total Equity		576,454		550,766
Long-term debt		399,414		358,491
Total Capitalization		975,868		909,257
Commitments and contingencies (see Footnote 18)		-		-
Total Liabilities and Capitalization	$	1,530,643	$	1,553,651
The accompanying notes are an integral part of the above consolidated financial statements.

55

Madison Gas and Electric Company

Consolidated Statements of Common Equity

(In thousands)

	Common Stock				Additional Paid-in Capital		Retained Earnings	Accumulated Other Comprehensive (Loss)/Income			Non- Controlling Interest		Total
	Shares		Value
2011
Beginning balance - December 31, 2010	17,348	$	17,348	$	192,417	$	192,480	$	71	$	141,993	$	544,309
Net income							37,282				23,970		61,252
Other comprehensive income/(loss)									(24)				(24)
Cash dividends paid to parent by MGE							(26,648)						(26,648)
Equity contribution received by
noncontrolling interest											888		888
Distributions to parent from
noncontrolling interest											(52,500)		(52,500)
Ending balance - December 31, 2011	17,348	$	17,348	$	192,417	$	203,114	$	47	$	114,351	$	527,277
2012
Net income							40,817				24,489		65,306
Other comprehensive income/(loss)									(43)				(43)
Cash dividends paid to parent by MGE							(20,404)						(20,404)
Equity contribution received by
noncontrolling interest											2,130		2,130
Distributions to parent from
noncontrolling interest											(23,500)		(23,500)
Ending balance - December 31, 2012	17,348	$	17,348	$	192,417	$	223,527	$	4	$	117,470	$	550,766
2013
Net income							49,007				27,438		76,445
Other comprehensive income/(loss)									188				188
Cash dividends paid to parent by MGE							(25,000)						(25,000)
Equity contribution received by
noncontrolling interest											1,420		1,420
Distributions to parent from
noncontrolling interest											(27,365)		(27,365)
Ending balance - December 31, 2013	17,348	$	17,348	$	192,417	$	247,534	$	192	$	118,963	$	576,454
The accompanying notes are an integral part of the above consolidated financial statements.

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Notes to Consolidated Financial Statements

December 31, 2013, 2012, and 2011

This report is a combined report of MGE Energy and MGE. The notes to the consolidated financial statements that follow include consolidated MGE Energy footnotes and certain footnotes related to MGE as signified below.

1.

Summary of Significant Accounting Policies.

a.

Basis of Presentation - MGE Energy and MGE.

The consolidated financial statements are prepared in conformity with accounting principles generally accepted in the United States of America (GAAP), which give recognition to the rate making accounting policies for regulated operations prescribed by the regulatory authorities having jurisdiction, principally the PSCW and FERC. MGE's accounting records conform to the FERC uniform system of accounts.

On December 20, 2013, MGE Energy's Board of Directors declared a three-for-two stock split of MGE Energy's common stock in the form of a stock dividend. The additional shares were distributed February 7, 2014 to all shareholders of record as of January 24, 2014. All shares and per share data provided in this report give effect to this stock split.

b.

Principles of Consolidation - MGE Energy and MGE.

MGE, a wholly owned subsidiary of MGE Energy, is a regulated electric and gas utility headquartered in Madison, Wisconsin. MGE Energy and MGE consolidate all majority owned subsidiaries in which it has controlling influence. MGE is the majority owner of MGE Transco. MGE Transco is a nonregulated entity formed to manage the investment in ATC.

Wholly owned subsidiaries of MGE Energy include CWDC, MAGAEL, MGE Construct, MGE Power, NGV Fueling Services, and North Mendota. MGE Power owns 100% of MGE Power Elm Road and MGE Power West Campus. MGE Power and its subsidiaries are part of MGE Energy's nonregulated energy operations, which were formed to own and lease electric generation projects to assist MGE.

MGE Energy and MGE consolidate variable interest entities (VIEs) for which it is the primary beneficiary. Variable interest entities are legal entities that possess any of the following characteristics: equity investors who have an insufficient amount of equity at risk to finance their activities, equity owners who do not have the power to direct the significant activities of the entity (or have voting rights that are disproportionate to their ownership interest), or equity holders who do not receive expected losses or returns significant to the VIE. If MGE Energy or MGE is not the primary beneficiary and an ownership interest is held, the VIE is accounted for under the equity method of accounting. When assessing the determination of the primary beneficiary, all relevant facts and circumstances are considered, including: the power, through voting or similar rights, to direct the activities of the VIE that most significantly impact the VIE's economic performance and the obligation to absorb the expected losses and/or the right to receive the expected returns of the VIE. Ongoing reassessments of all VIEs are performed to determine if the primary beneficiary status has changed. MGE has consolidated MGE Power Elm Road and MGE Power West Campus. Both entities are VIEs. MGE is considered the primary beneficiary of these entities as a result of contractual agreements. See Footnote 2 for more discussion of these entities.

The consolidated financial statements reflect the application of certain accounting policies described in this note. All significant intercompany accounts and transactions have been eliminated in consolidation.

c.

Use of Estimates - MGE Energy and MGE.

In order to prepare consolidated financial statements in conformity with GAAP, management must make estimates and assumptions. These estimates could affect reported amounts of assets, liabilities, and disclosures at the date of the financial statements, as well as the reported amounts of revenues and expenses during the reporting periods. Actual results could differ from management's estimates.

57

d.

Cash Equivalents and Restricted Cash - MGE Energy and MGE.

MGE Energy and MGE consider all highly liquid investments purchased with an original maturity of three months or less to be cash equivalents.

MGE has certain cash accounts that are restricted to uses other than current operations and designated for a specific purpose. MGE's restricted cash accounts include cash held by trustees for certain employee benefits. These are included in other current assets.

e.

Receivable – Margin Account - MGE Energy and MGE.

Cash amounts held by counterparties as margin for certain financial transactions are recorded as receivable – margin account. The balance is shown net of any collateral posted against derivative positions. As of December 31, 2013, there was $0.2 million collateral posted against derivative positions. As of December 31, 2012, there was no collateral posted against derivative positions. Changes in this cash account are considered cash flows from operating activities to match with the costs being hedged. The costs being hedged are fuel for electric generation, purchased power, and cost of gas sold.

f.

Trade Receivables, Allowance for Doubtful Accounts, and Concentration Risk - MGE Energy and MGE.

Trade accounts receivable are recorded at the invoiced amount and do not bear interest. However, a 1% late payment charge is recorded on all receivables unpaid after the due date. The allowance for doubtful accounts associated with these receivables represents our best estimate of the amount of probable credit losses in our existing accounts receivable. We determine our allowance for doubtful accounts based on historical write-off experience, regional economic data, and review of the accounts receivable aging.

MGE is obligated to provide service to all electric and gas customers within its franchised territories. MGE's franchised electric territory includes a 316 square-mile area in Dane County, Wisconsin, and MGE's franchised gas territory includes a service area covering 1,649 square-miles in Wisconsin. MGE manages this concentration and the related credit risk through its credit and collection policies, which are consistent with state regulatory requirements.

g.

Inventories - MGE Energy and MGE.

Inventories consist of natural gas in storage, fossil fuels, materials and supplies, SO₂ allowances, and renewable energy credits (RECs). MGE values natural gas in storage, fossil fuels, and materials and supplies using average cost.

SO₂ emission allowances are included in inventory and are recorded at weighted average cost. These allowances are charged to fuel expense as they are used in operations. MGE's emission allowance balances as of December 31, 2013 and 2012, were $0.1 million.

REC allowances are included in inventory and are recorded based on specific identification. These allowances are charged to purchase power expense as they are used in operations. MGE's REC allowance balances as of December 31, 2013 and 2012, were $0.6 million and $0.5 million, respectively.

h.

Regulatory Assets and Liabilities - MGE Energy and MGE.

Regulatory assets and regulatory liabilities are recorded consistent with regulatory treatment. Regulatory assets represent costs which are deferred due to the probable future recovery from customers through regulated rates. Regulatory liabilities represent the excess recovery of costs or accrued credits which were deferred because MGE believes it is probable such amounts will be returned to customers through future regulated rates. Regulatory assets and liabilities are amortized in the consolidated statements of income consistent with the recovery or refund included in customer rates. MGE believes that it is probable that its recorded regulatory assets and liabilities will be recovered and refunded, respectively, in future rates. See Footnote 6 for further information.

58

i.

Debt Issuance Costs - MGE Energy and MGE.

Premiums, discounts, and expenses incurred with the issuance of outstanding long-term debt are amortized over the life of the debt issue. Any call premiums or unamortized expenses associated with refinancing higher-cost debt obligations used to finance utility-regulated assets and operations are amortized consistent with regulatory treatment of those items.

j.

Property, Plant, and Equipment - MGE Energy and MGE.

Property, plant, and equipment is recorded at original cost. Cost includes indirect costs consisting of payroll taxes, pensions, postretirement benefits, other fringe benefits, and administrative and general costs. Also, included in the cost is AFUDC for utility property and capitalized interest for nonregulated property. Additions for significant replacements of property are charged to property, plant, and equipment at cost; and minor items are charged to maintenance expense. Depreciation rates on utility property are approved by the PSCW, based on the estimated economic lives of property, and include estimates for salvage value and removal costs. Removal costs of utility property, less any salvage value, are adjusted through regulatory liabilities. Depreciation rates on nonregulated property are based on the estimated economic lives of the property. See Footnote 3 for further information.

Provisions at composite straight-line depreciation rates approximate the following percentages for the cost of depreciable property:

	2013	2012	2011
Electric	2.7 %	2.9 %	3.2 %
Gas	1.7 %	1.7 %	1.6 %
Nonregulated	2.3 %	2.3 %	2.3 %

k.

Asset Retirement Obligations - MGE Energy and MGE.

MGE Energy and MGE are required to record a liability for the fair value of an ARO to be recognized in the period in which it is incurred if it can be reasonably estimated. The offsetting associated asset retirement costs are capitalized as a long-lived asset and depreciated over the asset's useful life. The expected present value technique used to calculate the fair value of ARO liabilities includes assumptions about costs, probabilities, settlement dates, interest accretion, and inflation. Revisions to the assumptions, including the timing or amount of expected asset retirement costs, could result in increases or decreases to the AROs. All asset retirement obligations are recorded as other long-term liabilities on our balance sheets. MGE has regulatory treatment and recognizes regulatory assets or liabilities for the timing differences between when we recover legal AROs in rates and when we would recognize these costs. See Footnote 19 for further information.

l.

Repairs and Maintenance Expense - MGE Energy and MGE.

MGE utilizes the direct expensing method for planned major maintenance projects. Under this method, MGE expenses all costs associated with major planned maintenance activities as incurred.

m.

Purchased Gas Adjustment Clause - MGE Energy and MGE.

MGE's natural gas rates are subject to a fuel adjustment clause designed to recover or refund the difference between the actual cost of purchased gas and the amount included in rates. Differences between the amounts billed to customers and the actual costs recoverable are deferred and recovered or refunded in future periods by means of prospective monthly adjustments to rates. At December 31, 2013, MGE had over collected $1.7 million. At December 31, 2012, MGE had under collected $0.1 million. These amounts are netted in other current liabilities on the consolidated balance sheet.

n.

Revenue Recognition - MGE Energy and MGE.

Operating revenues are recorded as service is rendered or energy is delivered to customers. Meters are read on a systematic basis throughout the month based on established meter-reading schedules. At the end of the month, MGE accrues an estimate for the unbilled amount of energy delivered to customers. The unbilled revenue estimate is based on daily system demand volumes, weather factors, estimated line losses, estimated customer usage by class, and applicable customer rates.

59

o.

Utility Cost Recovery - MGE Energy and MGE.

MGE's rates include a provision for fuel costs. The PSCW allows Wisconsin utilities to defer electric fuel-related costs, less excess revenues, 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. Such deferred amounts will be recognized in "Purchased Power Expense" in MGE Energy's and MGE's income statement each period. The cumulative effects of these deferred amounts will be recorded in "Regulatory assets" or "Regulatory liabilities" on MGE Energy's and MGE's consolidated balance sheets until they are reflected in future billings to customers. See Footnote 17.b. for further information regarding the regulatory rules applicable to the recovery of electric fuel costs.

p.

Allowance for Funds Used During Construction - MGE Energy and MGE.

Allowance for funds used during construction is included in utility plant accounts and represents the cost of borrowed funds used during plant construction and a return on shareholders' capital used for construction purposes. In the consolidated income statements, the cost of borrowed funds (AFUDC-debt) is presented as an offset to interest expense and the return on shareholders' capital (AFUDC-equity funds) is shown as an item within other income. For both 2012 and 2011, as approved by the PSCW, MGE capitalized AFUDC-debt and equity on 50% of applicable average construction work in progress at 8.36%. For 2013, MGE capitalized AFUDC-debt and equity on 50% of applicable average construction work in progress at 8.21%. For both 2012 and 2011, MGE received specific approval to recover 100% AFUDC on certain environmental costs for Columbia and 50% in 2013. Although the allowance does not represent current cash income, it is recovered under the ratemaking process over the service lives of the related properties. See Footnote 20 for further information regarding Columbia AFUDC.

q.

Investments - MGE Energy and MGE.

Investments in limited liability companies that have specific ownership accounts in which MGE Energy or MGE's ownership interest is more than minor are accounted for using the equity method. All other investments are carried at fair value or at cost, as appropriate. See Footnote 4 for further information.

r.

Capitalized Software Costs - MGE Energy and MGE.

Property, plant, and equipment includes the capitalized costs of internal use software totaling $20.9 million and $14.5 million at December 31, 2013 and 2012, respectively. During 2013 and 2012, MGE recorded $1.5 million and $1.3 million, respectively, of amortization expense related to these costs. These costs are amortized on a straight-line basis over the estimated useful lives of the assets. For internal use software, the useful lives range from five to ten years.

s.

Impairment of Long-Lived Assets - MGE Energy and MGE.

MGE reviews plant and equipment and other property for impairment when events or changes in circumstances indicate that the carrying amount of the assets may not be recoverable. MGE's policy for determining when long-lived assets are impaired is to recognize an impairment loss if the sum of the expected future cash flows (undiscounted and without interest charges) from an asset are less than the carrying amount of that asset. If an impairment loss is recognized, the amount that will be recorded will be measured as the amount by which the carrying amount of the asset exceeds the fair value of the asset. There is no impairment of long-lived assets at December 31, 2013, 2012, and 2011.

t.

Income Taxes and Excise Taxes - MGE Energy and MGE.

Income taxes

Under the liability method, income taxes are deferred for all temporary differences between pretax financial and taxable income and between the book and tax basis of assets and liabilities using the tax rates scheduled by law to be in effect when the temporary differences reverse. Future tax benefits are recognized to the extent that realization of such benefits is more likely than not. A valuation allowance is recorded for those benefits that do not meet this criterion.

Accounting for uncertainty in income taxes applies to all tax positions and requires a recognition threshold and measurement standard for the financial statement recognition and measurement of a tax position taken, or expected to be taken, in an income tax return. The threshold is defined for recognizing tax return positions in the financial statements as "more likely than not" that the position is sustainable, based on its merits.

60

Subsequent recognition, derecognition, and measurement is based on management's best judgment given the facts, circumstances, and information available at the reporting date.

Regulatory and accounting principles have resulted in a regulatory liability related to income taxes. Excess deferred income taxes result from past taxes provided at rates higher than current rates. The income tax regulatory liability and deferred investment tax credit reflect the revenue requirement associated with the return of these tax benefits to customers.

Investment tax credits from regulated operations are amortized over related property service lives.

Excise taxes

MGE Energy, through its utility operations, pays a state license fee tax in lieu of property taxes on property used in utility operations. License fee tax is calculated as a percentage of adjusted operating revenues of the prior year. The electric tax rate is 3.19% for retail sales and 1.59% for sales of electricity for resale by the purchaser. The tax rate on sales of natural gas is 0.97%. The tax is required to be estimated and prepaid in the year prior to its computation and expensing. License fee tax expense, included in other general taxes, was $13.8 million, $13.5 million, and $12.9 million for the years ended December 31, 2013, 2012, and 2011, respectively.

Operating income taxes, including tax credits and license fee tax are included in rates for utility related items.

u.

Share-Based Compensation - MGE Energy and MGE.

Under two separate incentive plans, eligible participants, including employees and non-employee directors, 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. Under the plans, these awards are subject to a prescribed vesting schedule and must be settled in cash. Accordingly, no new shares of common stock are issued in connection with the plans.

MGE Energy and MGE initially measure the cost of the employee or director 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 award is subsequently re-measured at each reporting date through the settlement date. Changes in fair value during the requisite period are recognized as compensation cost over that period.

See Footnote 14 for additional information regarding the plans.

v.

Treasury Stock - MGE Energy.

Treasury shares are recorded at cost. Any shares of common stock repurchased are held as treasury shares unless cancelled or reissued. No treasury shares are held as of December 31, 2013.

w.

Comprehensive Income - MGE Energy and MGE.

Total comprehensive income includes all changes in equity during a period except those resulting from investments by and distributions to shareholders. Comprehensive income is reflected in the consolidated statements of comprehensive income.

x.

Derivative and Hedging Instruments - MGE Energy and MGE.

As part of regular operations, MGE enters into contracts, including options, swaps, futures, forwards, and other contractual commitments, to manage its exposure to interest rates, commodity prices, and gas revenues. MGE recognizes all derivatives in the consolidated balance sheets at fair value, with changes in the fair value of derivative instruments to be recorded in current earnings or deferred in accumulated other comprehensive income (loss), depending on whether a derivative is designated as, and is effective as, a hedge and on the type of hedge transaction. Derivative activities are in accordance with the company's risk management policy.

If the derivative qualifies for regulatory deferral, the derivatives are marked to fair value and any resulting loss or gain is offset with a corresponding regulatory asset or liability. Cash flows from such derivative instruments are classified on a basis consistent with the nature of the underlying hedged item.

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2.

Variable Interest Entities - MGE Energy and MGE.

a.

MGE Power Elm Road.

MGE Power Elm Road is not a subsidiary of MGE; however, it has been consolidated in the financial statements of MGE. MGE Power Elm Road was created for the purpose of owning new generating assets. Its sole principal assets are an undivided ownership interest in two coal-fired generating plants located in Oak Creek, Wisconsin, which it leases to MGE pursuant to long-term leases. Based on the nature and terms of the contractual agreements, MGE is expected to absorb a majority of the expected losses, residual value, or both, associated with the ownership of MGE Power Elm Road and therefore holds a variable interest in MGE Power Elm Road, even though it has no equity interest in MGE Power Elm Road. MGE Energy and MGE consolidate VIEs for which they are the primary beneficiary. MGE has the power to direct the activities that most significantly impact the Elm Road Units' economic performance and is also the party most closely associated with MGE Power Elm Road. As a result, MGE is the primary beneficiary. At December 31, MGE has included the following significant accounts on its consolidated balance sheet related to its interest in this VIE:

(In thousands)		2013		2012
Property, plant, and equipment, net	$	182,657	$	185,020
Construction work in progress		1,115		1,440
Deferred income tax asset - current		219		30,842
Deferred income tax liability		34,141		56,434
Long-term debt		70,639		73,306
Noncontrolling interest		69,876		69,803

Long-term debt consists of $70.6 million of senior secured notes that require that MGE Power Elm Road maintain a projected and actual debt service coverage ratio at the end of any calendar quarter of not less than 1.25 to 1.00 for the trailing 12-month period. The debt is secured by a collateral assignment of lease payments that MGE is making to MGE Power Elm Road for use of the Elm Road Units pursuant to the related long-term leases. As of December 31, 2013, MGE Power Elm Road is in compliance with the covenant requirements.

MGE has been and will continue to recover in rates the lease payments made to MGE Power Elm Road. MGE received approval from the PSCW to collect in rates the carrying costs incurred by MGE Power Elm Road. The total carrying costs on the Elm Road Units is $62.5 million. MGE is collecting carrying costs in rates over a six year period that began in 2010. Of these costs, $17.0 million relates to the capitalized interest and the debt portion of the units. These costs will be recognized over the period in which the generating units will be depreciated. The remaining $45.5 million represents the equity portion and is being recognized over the period allowed for recovery in rates.

b.

MGE Power West Campus.

MGE Power West Campus is not a subsidiary of MGE; however, it has been consolidated in the financial statements of MGE. MGE Power West Campus was created for the purpose of owning new generating assets. Its sole principal asset is the WCCF, which it leases to MGE pursuant to a long-term lease. MGE is responsible for operation of the plant during the term of the lease. Based on the nature and terms of these contractual relationships, MGE absorbs a majority of the expected losses, residual value, or both, associated with the ownership and operation of the WCCF and therefore holds a variable interest in MGE Power West Campus, even though it has no equity interest in MGE Power West Campus. MGE has the power to direct the activities that most significantly impact WCCF's economic performance and is also the party most closely associated with MGE Power West Campus. As a result, MGE is the primary beneficiary.

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At December 31, MGE has included the following significant accounts on its consolidated balance sheet related to its interest in this VIE:

(In thousands)		2013		2012
Property, plant, and equipment, net	$	89,564	$	90,339
Affiliate receivables		6,767		6,912
Accrued interest and taxes		4,888		3,327
Deferred income taxes		23,154		21,410
Long-term debt		49,653		50,000
Noncontrolling interest		29,089		30,682

Long-term debt consists of $49.7 million of senior secured notes that require that MGE Power West Campus maintain a projected debt service coverage ratio of not less than 1.25 to 1.00 and debt to total capitalization ratio of not more than .65 to 1.00. The debt is secured by a collateral assignment of lease payments that MGE is making to MGE Power West Campus for use of the cogeneration facility pursuant to the long-term lease. As of December 31, 2013, MGE Power West Campus is in compliance with the covenant requirements.

MGE has been and will continue to recover lease payments made to MGE Power West Campus in rates. Also, MGE received approval from the PSCW to collect approximately $12.1 million in carrying costs incurred by MGE Power West Campus during construction of the facility. The carrying costs are being recovered in rates over a 10 year period that started in 2005.

c.

Other Variable Interest Entities.

MGE has a variable interest in entities through purchase power agreements relating to purchased energy from the facilities. As of December 31, 2013 and 2012, MGE had 61 megawatts and 65 megawatts, respectively, of capacity available under these agreements. MGE evaluated the variable interest entities for possible consolidation. The interest holder is considered the primary beneficiary of the entity and is required to consolidate the entity if the interest holder has the power to direct the activities that most significantly impact the economics of the variable interest entity. MGE examined qualitative factors such as the length of the remaining term of the contracts compared with the remaining lives of the plants, who has the power to direct the operations and maintenance of the facilities, and other factors, and determined MGE is not the primary beneficiary of the variable interest entities. There is not a significant potential exposure to loss as a result of involvement with these variable interest entities.

3.

Property, Plant, and Equipment - MGE Energy and MGE.

Property, plant, and equipment consisted of the following at December 31:

		MGE Energy				MGE
(In thousands)		2013		2012		2013		2012
Utility:
Electric	$	953,290	$	912,273	$	953,307	$	912,289
Gas		351,694		332,767		351,705		332,779
Total utility plant		1,304,984		1,245,040		1,305,012		1,245,068
Less: Accumulated depreciation and amortization		560,066		546,483		560,066		546,483
In-service utility plant, net		744,918		698,557		744,946		698,585
Nonregulated:
Nonregulated		311,742		308,043		310,745		307,511
Less: Accumulated depreciation and amortization		37,851		31,547		37,814		31,547
In-service nonregulated plant, net		273,891		276,496		272,931		275,964
Construction work in progress:
Utility construction work in progress		140,301		96,863		140,301		96,863
Nonregulated construction work in progress		1,114		1,548		1,114		1,548
Total property, plant, and equipment	$	1,160,224	$	1,073,464	$	1,159,292	$	1,072,960

MGE's utility plant is subject to the lien of its Indenture of Mortgage and Deed of Trust. As of December 31, 2013, there was $1.2 million of bonds outstanding under that indenture. See Footnote 9 for further discussion of the mortgage indenture.

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4.

Investments - MGE Energy and MGE.

a.

Equity Method Investments, Available for Sale Securities, and Other Investments.

		MGE Energy				MGE
(In thousands)		2013		2012		2013		2012
Available for sale securities:
Cost basis	$	1,736	$	1,575	$	490	$	490
Gross unrealized gains		629		161		321		10
Gross unrealized losses		-		(3)		-		(3)
Fair value		2,365		1,733		811		497
Equity method investments:
ATC		64,488		61,038		64,488		61,038
Other		1,099		20		-		20
Total equity method investments		65,587		61,058		64,488		61,058
Other investments		-		1,804		-		-
Total	$	67,952	$	64,595	$	65,299	$	61,555

MGE Energy's and MGE's available for sale securities represent publicly traded securities and private equity investments in common stock of companies in various industries.

During the year ended December 31, certain investments were liquidated. As a result of these liquidations, MGE Energy and MGE received the following:

		MGE Energy						MGE
(In thousands)		2013		2012		2011		2013		2012		2011
Cash proceeds	$	39	$	-	$	260	$	16	$	-	$	223
Gain (loss) on sale		2		-		198		(3)		-		171

b.

ATC.

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

MGE Transco has accounted for its investment in ATC under the equity method of accounting. For the years ended December 31, 2013, 2012, and 2011, MGE Transco recorded equity earnings from the investment in ATC of $9.4 million, $9.1 million, and $8.6 million, respectively. Dividends received from ATC were $7.4 million, $7.1 million, and $6.7 million for the years ended December 31, 2013, 2012, and 2011, respectively. During the years ended December 31, 2013, 2012, and 2011, MGE Transco made $1.4 million, $2.1 million, and $0.9 million, respectively, in capital contributions to ATC. On January 31, 2014, MGE Transco made a $0.5 million capital contribution to ATC.

At December 31, 2013 and 2012, MGE Transco held a 3.6% ownership interest in ATC. MGE Transco's investment balance is different from the amount of the underlying equity in the net assets of ATC. This difference is attributable to the allocation of certain tax impacts related to the initial asset transfer.

At December 31, 2013 and 2012, 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.

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ATC's summarized financial data for the years ended December 31, 2013, 2012, and 2011 is as follows:

(In thousands)
Income statement data for the year ended December 31,		2013		2012		2011
Operating revenues	$	626,336	$	603,254	$	567,174
Operating expenses		(295,069)		(280,999)		(261,568)
Other income (expense)		831		(2,533)		(1,332)
Interest expense, net		(84,484)		(82,296)		(80,359)
Earnings before members' income taxes	$	247,614	$	237,426	$	223,915
Balance sheet data as of December 31,		2013		2012		2011
Current assets	$	80,715	$	63,134	$	58,671
Noncurrent assets		3,509,517		3,274,704		3,053,742
Total assets	$	3,590,232	$	3,337,838	$	3,112,413
Current liabilities	$	381,467	$	251,541	$	298,473
Long-term debt		1,550,000		1,550,000		1,400,005
Other noncurrent liabilities		126,167		95,829		82,647
Members' equity		1,532,598		1,440,468		1,331,288
Total members' equity and liabilities	$	3,590,232	$	3,337,838	$	3,112,413

5.

Joint Plant Ownership - MGE Energy and MGE.

a.

Columbia.

MGE and two other utilities jointly own Columbia, a coal-fired generating facility located in Portage, Wisconsin, which accounts for 31% (245 MW) of MGE's net summer rated capacity. Power from this facility is shared in proportion to each company's ownership interest. MGE has a 22% ownership interest in Columbia. The other owners are WPL, which operates Columbia, and WPSC. MGE's share of fuel, operating, and maintenance expenses for Columbia were $37.5 million, $36.3 million, and $37.1 million for the years ended December 31, 2013, 2012, and 2011, respectively. See Footnote 18 for discussion of MGE's future capital commitments in respect to the environmental projects at Columbia as a result of this ownership interest.

Each owner provides its own financing and reflects its respective portion of facilities and operating costs in its financial statements. MGE's interest in Columbia, included in its gross utility plant in service, and the related accumulated depreciation reserves at December 31 were as follows:

(In thousands)		2013		2012
Utility plant	$	123,097	$	119,544
Accumulated depreciation		(78,880)		(78,016)
Property, plant, and equipment, net	$	44,217	$	41,528
Construction work in progress		120,858		59,917
Total property, plant, and equipment	$	165,075	$	101,445

b.

Elm Road.

MGE Power Elm Road owns an 8.33% ownership interest in each of two 615 MW coal-fired generating units in Oak Creek, Wisconsin, which accounts for 14% (106 MW) of MGE's net summer rated capacity. Unit 1 entered commercial operation on February 2, 2010. Unit 2 entered commercial operation on January 12, 2011. MGE Power Elm Road's sole principal asset is that ownership interest in those generating units. MGE Power Elm Road's interest in the Elm Road Units is leased to MGE pursuant to long-term leases.

The remainder of the ownership interest in the Elm Road Units is held by two other entities, one of which is also responsible for the Units' operation. Each owner provides its own financing and reflects its respective portion of the facility and costs in its financial statements. MGE's share of fuel, operating, and maintenance expenses for the Elm Road Units were $13.4 million, $13.2 million, and $18.0 million for the years ended December 31, 2013, 2012, and 2011, respectively.

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MGE Power Elm Road's interest in the portion of the Elm Road Units in-service and the related accumulated depreciation reserves at December 31 were as follows:

(In thousands)		2013		2012
Nonregulated plant	$	198,198	$	196,146
Accumulated depreciation		(15,541)		(11,126)
Property, plant, and equipment, net	$	182,657	$	185,020
Construction work in progress		1,115		1,440
Total property, plant, and equipment	$	183,772	$	186,460

c.

WCCF.

MGE Power West Campus and the UW jointly own the West Campus Cogeneration Facility located on the UW campus in Madison, Wisconsin. MGE Power West Campus owns 55% of the facility and the UW owns 45% of the facility. The UW owns a controlling interest in the chilled-water and steam plants, which are used to meet the growing needs for air-conditioning and steam-heat capacity for the UW campus. MGE Power West Campus owns a controlling interest in the electric generation plant, which is leased and operated by MGE.

Each owner provides its own financing and reflects its respective portion of the facility and operating costs in its financial statements. MGE Power West Campus' interest in WCCF and the related accumulated depreciation reserves at December 31 were as follows:

(In thousands)		2013		2012
Nonregulated plant	$	111,268	$	110,266
Accumulated depreciation		(21,704)		(19,927)
Property, plant, and equipment, net	$	89,564	$	90,339

Operating charges are allocated to the UW based on formulas contained in the operating agreement. Under the provisions of this arrangement, the UW is required to reimburse MGE for their allocated portion of fuel and operating expenses. For the years ended December 31, 2013 and 2012, the UW allocated share of fuel and operating costs was $4.9 million. For the year ended December 31, 2011, the UW allocated share of fuel and operating costs was $5.0 million.

6.

Regulatory Assets and Liabilities - MGE Energy and MGE.

The following regulatory assets and liabilities are reflected in MGE's consolidated balance sheet as of December 31:

(In thousands)		2013		2012
Regulatory Assets
Asset retirement obligation	$	4,863	$	4,608
Debt related costs		11,786		5,468
Derivatives		63,893		72,328
Elm Road		-		2,614
Environmental costs		920		1,154
Pension and OPRB costs		-		1,234
Tax recovery related to AFUDC equity		6,956		5,241
Unfunded pension and other postretirement liability		24,591		134,839
Other		534		1,694
Total regulatory assets	$	113,543	$	229,180
Regulatory Liabilities
Conservation costs	$	455	$	455
Deferred fuel savings		13,386		6,163
Elm Road		607		-
Income taxes		2,082		2,346
Non-ARO removal cost		15,182		13,957
Renewable energy credits		574		480
Other		1,044		1,137
Total regulatory liabilities	$	33,330	$	24,538

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MGE expects to recover its regulatory assets and return its regulatory liabilities through rates charged to customers based on PSCW decisions made during the ratemaking process or based on PSCW long-standing policies and guidelines. The adjustments to rates for these regulatory assets and liabilities will occur over the periods either specified by the PSCW or over the corresponding period related to the asset or liability. We believe it is probable that MGE will continue to recover from customers the regulatory assets described above based on prior and current ratemaking treatment for such costs. All regulatory assets for which a cash outflow had been made are earning a return, except for amounts expended for environmental costs.

Asset Retirement Obligation

See Footnote 19 for further discussion.

Debt Related Costs

This balance includes debt issuance costs of extinguished debt and other debt related expenses. The PSCW has allowed rate recovery on unamortized issuance costs for extinguished debt facilities. When the facility replacing the old facility is deemed by the PSCW to be more favorable for the ratepayers, the PSCW will allow rate recovery of any unamortized issuance costs related to the old facility. These amounts are recovered over the term of the new facility.

In 2013, MGE issued long-term debt and used the net proceeds to redeem Medium-Term Notes and partially redeem Senior Notes. Included in the redemption prices were make-whole premiums totalling $6.8 million. The make-whole premiums are treated as a regulatory asset and will be amortized over the life of the long-term debt issued.

Derivatives

MGE has physical and financial contracts that are defined as derivatives. The amounts recorded for the net mark-to-market value of the commodity based contracts is offset with a corresponding regulatory asset or liability because these transactions are part of the PGA or fuel rules clause authorized by the PSCW. A significant portion of the recorded amount is related 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. This agreement is accounted for as a derivative contract.

Elm Road

Costs associated with Elm Road are estimated in MGE's rates utilizing escrow accounting and include costs for lease payments, management fees, community impact mitigation, and operating costs. Also, MGE has deferred payments made to MGE Power Elm Road for carrying costs during construction of the facility. MGE is collecting carrying costs in rates over a six year period that began in 2010. All other costs are collected in rates over a one to two year period.

Environmental Costs

MGE has been allowed to defer actual costs on certain environmental matters, including clean up of two landfill sites and legal expenditures pertaining to the response to the EPA Clean Air Act enforcement matter at Columbia. For further discussion of the Columbia Clean Air Act litigation, see Footnote 18.d.

Pension and OPRB Costs

The PSCW has allowed MGE to defer the 2009 incremental pension and OPRB costs above the amounts recovered in rates. Recovery of the costs began in 2010. The costs are being recovered in rates over a four year period for electric portion and a two year period for gas portion.

Tax Recovery Related to AFUDC Equity

AFUDC equity represents the after-tax equity cost associated with utility plant construction and results in a temporary difference between the book and tax basis of such plant. It is probable under PSCW regulation that MGE will recover in future rates the future increase in taxes payable represented by the deferred income tax liability. The amounts will be recovered in rates over the depreciable life of the asset for which AFUDC was applied. Tax recovery related to AFUDC equity represents the revenue requirement related to recovery of these future taxes payable, calculated at current statutory tax rates.

Unfunded Pension and Other Postretirement Liability

MGE is required to recognize the unfunded status of defined benefit pension and other postretirement pension plans as a net liability or asset on the balance sheet with an offset to other comprehensive income. The amount normally charged to other comprehensive income for the unfunded status represents future expenses that are expected to be recovered in rates.

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Conservation Costs

MGE has received regulatory treatment for certain conservation expenditures. The expenditures are used for demand-side management programs to promote energy efficiency on the customer's premises. Costs for demand-side management programs are estimated in MGE's rates utilizing escrow accounting. The escrow accounting allows the utility to true-up its actual costs incurred and reflect the amount of the true-up in its next rate case filing and amortize the amount over the rate case period. The customer service - conservation escrow was discontinued as of January 1, 2013. These costs are expected to be trued up in MGE's next full base rate case.

Deferred Fuel Savings

The PSCW approved new fuel rules that became effective January 1, 2011. The new 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 fuel rules costs fall outside the lower end of the range and would defer costs, less any excess revenues, if the actual 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. See Footnote 17.b. for further discussion.

Income Taxes

Excess deferred income taxes result from past taxes provided at rates higher than current rates. The regulatory liability and deferred investment tax credit reflects the revenue requirement associated with the return of these tax benefits to customers.

Non-ARO Removal Costs

In connection with accounting for asset retirement obligations, companies are required to reclassify cumulative collections for non-ARO removal costs as a regulatory liability, with an offsetting entry to accumulated depreciation. Under the current rate structure, these removal costs are being recovered as a component of depreciation expense.

Renewable Energy Credits

MGE receives renewable energy credits from certain purchase power agreements. The value of the credits are recorded as inventory and expensed when the credit is redeemed or expired. A regulatory liability has been established for the value of the renewable energy credits included in inventory. In Wisconsin, renewable energy credits expire four years after the year of acquisition.

7.

Common Equity.

a.

Common Stock - MGE Energy and MGE.

On December 20, 2013, MGE Energy's Board of Directors declared a three-for-two stock split of MGE Energy's outstanding shares of common stock, effective in the form of a stock dividend. Shareholders of record at the close of business on January 24, 2014 received one additional share of MGE Energy common stock for every two shares of common stock owned on that date. The additional shares were distributed on February 7, 2014. Shareholders received cash in lieu of any fractional shares of common stock they otherwise would have received in connection with the dividend. All share and per share data provided in this report give effect to this stock split.

MGE Energy sells shares of its common stock through its Stock Plan. Those shares may be newly issued shares or shares that MGE Energy has purchased in the open market for resale to participants in the Stock Plan. All sales under the stock plan are covered by a shelf registration statement that MGE Energy filed with the SEC. For the years ended December 31, 2013 and 2012, MGE Energy did not issue any new shares of common stock under the Stock Plan.

MGE Energy purchases shares on the open market 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 specific maximum number of shares to be repurchased and no specified termination date for the repurchases.

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During the years ended December 31, 2013 and 2012, MGE Energy paid $37.1 million (or $1.07 per share) and $36.0 million (or $1.04 per share), respectively, in cash dividends on its common stock. Dividends on common stock at MGE are subject to restrictions imposed by the PSCW and the covenants of MGE's outstanding first mortgage bonds. See Footnote 9 for further discussion of these covenants. During the years ended December 31, 2013 and 2012, MGE paid $25.0 million and $20.4 million, respectively, in cash dividends to MGE Energy.

b.

Preferred Stock - MGE Energy and MGE.

MGE had 1,175,000 shares of $25 par value cumulative preferred stock authorized but unissued at December 31, 2011. In October 2012, MGE amended and restated its existing Restated Articles of Incorporation, which eliminated the previously authorized cumulative preferred stock. There were no shares of cumulative preferred stock authorized, issued, or outstanding at December 31, 2013 and 2012.

c.

Dilutive Shares Calculation - MGE Energy.

MGE Energy does not hold any dilutive securities.

8.

Noncontrolling Interest - MGE.

The noncontrolling interest on MGE's balance sheet at December 31 was as follows:

(In thousands)		2013		2012
MGE Power Elm Road (a)	$	69,876	$	69,803
MGE Power West Campus (a)		29,089		30,682
MGE Transco (b)		19,998		16,985
Total noncontrolling interest	$	118,963	$	117,470

The net income attributable to noncontrolling interest, net of tax, for the years ended December 31, 2013, 2012, and 2011 was as follows:

(In thousands)		2013		2012		2011
MGE Power Elm Road (a)	$	17,373	$	14,837	$	14,576
MGE Power West Campus (a)		7,657		7,506		7,501
MGE Transco (b)		2,408		2,146		1,893
Net income attributable to noncontrolling interest, net of tax	$	27,438	$	24,489	$	23,970

(a)

MGE Power Elm Road and MGE Power West Campus are not subsidiaries of MGE; however, they have been consolidated in the consolidated financial statements of MGE (see Footnote 2). MGE Power Elm Road and MGE Power West Campus are 100% owned by MGE Power, and MGE Power is 100% owned by MGE Energy. MGE Energy's proportionate share of the equity and net income (through its wholly owned subsidiary MGE Power) of MGE Power Elm Road and MGE Power West Campus is classified within the MGE financial statements as noncontrolling interest.

(b)

At December 31, 2013, MGE is the majority owner, and MGE Energy 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.

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9.

Long-Term Debt - MGE Energy and MGE.

a.

Long-Term Debt.

		2013				2012
(In thousands)		MGE Energy		MGE		MGE Energy		MGE
First Mortgage Bonds: (a)
7.70%, 2028 Series	$	1,200	$	1,200	$	1,200	$	1,200
Tax Exempt Debt:
3.45%, 2027 Series,
Industrial Development Revenue Bonds		19,300		19,300		19,300		19,300
Medium-Term Notes: (b)
5.26%, due 2017 (d)		-		-		20,000		20,000
5.25%, due 2017		30,000		30,000		30,000		30,000
6.12%, due 2028		20,000		20,000		20,000		20,000
7.12%, due 2032		25,000		25,000		25,000		25,000
6.247%, due 2037		25,000		25,000		25,000		25,000
Total Medium-Term Notes		100,000		100,000		120,000		120,000
Other Long-Term Debt: (c)
5.59%, due 2018 (d),(e)		20,000		20,000		40,000		40,000
3.38%, due 2020 (e)		15,000		15,000		15,000		15,000
3.09%, due 2023 (d),(e)		30,000		30,000		-		-
3.29%, due 2026 (d),(e)		15,000		15,000		-		-
5.68%, due 2033 (f)		29,797		29,797		30,000		30,000
5.19%, due 2033 (f)		19,857		19,857		20,000		20,000
5.26%, due 2040 (e)		15,000		15,000		15,000		15,000
5.04%, due 2040 (g)		43,472		43,472		45,138		45,138
4.74%, due 2041 (g)		27,167		27,167		28,167		28,167
4.38%, due 2042 (e)		28,000		28,000		28,000		28,000
4.42%, due 2043 (d),(e)		20,000		20,000		-		-
4.47%, due 2048 (d),(e)		20,000		20,000		-		-
Total Other Long-Term Debt		283,293		283,293		221,305		221,305
Long-term debt due within one year		(4,102)		(4,102)		(3,013)		(3,013)
Unamortized discount		(277)		(277)		(301)		(301)
Total Long-Term Debt	$	399,414	$	399,414	$	358,491	$	358,491

(a)

MGE's utility plant is subject to the lien of its Indenture of Mortgage and Deed of Trust, under which its first mortgage bonds are issued. The Mortgage Indenture provides that dividends or any other distribution or purchase of shares may not be made if the aggregate amount thereof since December 31, 1945 would exceed the earned surplus (retained earnings) accumulated subsequent to December 31, 1945. As of December 31, 2013, approximately $305.6 million was available for the payment of dividends under this covenant.

(b)

The indenture under which MGE's Medium-Term notes are issued provides that those notes will be entitled to be equally and ratably secured in the event that MGE issues any additional first mortgage bonds.

(c)

Unsecured notes issued pursuant to various Note Purchase Agreements with one or more purchasers. The notes are not issued under, or governed by, MGE's Indenture dated as of September 1, 1998, which governs MGE's Medium-Term Notes.

(d)

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. 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.

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The Note Purchase Agreement under which the Series A and Series B Notes were issued also included 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 were used and are expected to continue to be used to help finance the Columbia environmental project.

(e)

Issued by MGE. Under that Note Purchase Agreement: (i) note holders have the right to require MGE to repurchase their notes at par in the event of an acquisition of beneficial ownership of 30% or more of the outstanding voting stock of MGE Energy, (ii) MGE must maintain a ratio of its consolidated indebtedness to consolidated total capitalization not to exceed a maximum of 65%, and (iii) MGE cannot issue "Priority Debt" in an amount exceeding 20% of its consolidated assets. Priority Debt is defined as any indebtedness of MGE secured by liens other than specified liens permitted by the Note Purchase Agreement and certain unsecured indebtedness of certain subsidiaries. As of December 31, 2013, MGE is in compliance with the covenant requirements.

(f)

Issued by MGE Power West Campus. The Note Purchase Agreements require it to maintain a projected debt service coverage ratio of not less than 1.25 to 1.00, and debt to total capitalization ratio of not more than .65 to 1.00. The notes are secured by a collateral assignment of lease payments that MGE is making to MGE Power West Campus for use of its ownership interest in the West Campus Cogeneration Facility pursuant to a long-term lease. As of December 31, 2013, MGE Power West Campus is in compliance with the covenant requirements.

(g)

Issued by MGE Power Elm Road. The Note Purchase Agreement requires MGE Power Elm Road to maintain a projected and actual debt service coverage ratio at the end of any calendar quarter of not less than 1.25 to 1.00 for the trailing 12-month period. The notes are secured by a collateral assignment of lease payments that MGE is making to MGE Power Elm Road for use of its ownership interest in the Elm Road Units pursuant to long-term leases. As of December 31, 2013, MGE Power Elm Road is in compliance with the covenant requirements.

b.

Long-Term Debt Maturities.

Below is MGE Energy's and MGE's aggregate maturities for all long-term debt for years following the December 31, 2013, consolidated balance sheets.

(In thousands)		MGE Energy		MGE *
2014	$	4,102	$	4,102
2015		4,182		4,182
2016		4,268		4,268
2017		34,358		34,358
2018		24,452		24,452
Future years		332,431		332,431
Total	$	403,793	$	403,793

*

Includes $29.8 million and $19.9 million for MGE Power West Campus, and $43.5 million and $27.2 million for MGE Power Elm Road, all of which are consolidated with MGE's debt (see Footnote 2 for further information).

10.

Notes Payable to Banks, Commercial Paper, and Lines of Credit.

a.

MGE Energy.

At December 31, 2013, MGE Energy had an unsecured, committed revolving line of credit of $50 million expiring July 31, 2017. At December 31, 2013, no borrowings were outstanding under this facility.

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The agreement requires MGE Energy to maintain a ratio of its consolidated indebtedness to consolidated total capitalization not to exceed a maximum of 65%. A change in control constitutes a default under the agreement. Change in control events are defined as (i) a failure by MGE Energy to hold 100% of the outstanding voting equity interest in MGE or (ii) the acquisition of beneficial ownership of 30% or more of the outstanding voting stock of MGE Energy by one person or two or more persons acting in concert. As of December 31, 2013, MGE Energy is in compliance with the covenant requirements.

b.

MGE.

For short-term borrowings, MGE generally issues commercial paper (issued at the prevailing discount rate at the time of issuance), which is supported by unused committed bank lines of credit. At December 31, 2013, MGE had an unsecured, committed revolving line of credit for $100 million expiring July 31, 2017. The agreement requires MGE to have a period of at least one day, during any 365-day period, on which the principal amount of all outstanding loans thereunder shall be zero. At December 31, 2013, no borrowings were outstanding under this facility.

The agreement requires MGE to maintain a ratio of consolidated debt to consolidated total capitalization not to exceed a maximum of 65%. The ratio calculation excludes assets, liabilities, revenues, and expenses included in MGE's financial statements as the result of the consolidation of VIEs, such as MGE Power West Campus and MGE Power Elm Road. A change in control constitutes a default under the agreement. Change in control events are defined as (i) a failure by MGE Energy to hold 100% of the outstanding voting equity interest in MGE or (ii) the acquisition of beneficial ownership of 30% or more of the outstanding voting stock of MGE Energy by one person or two or more persons acting in concert. As of December 31, 2013, MGE is in compliance with the covenant requirements.

c.

MGE Energy and MGE.

Information concerning short-term borrowings for the past three years is shown below:

		As of December 31,
(In thousands)		2013		2012		2011
MGE Energy(a)
Available lines of credit	$	150,000	$	115,000	$	115,000
During the year:
Maximum short-term borrowings	$	32,000	$	16,000	$	28,500
Average short-term borrowings	$	6,992	$	1,154	$	3,410
Weighted-average interest rate		0.18 %		0.17 %		1.43 %
MGE
Available lines of credit	$	100,000	$	75,000	$	75,000
During the year:
Maximum short-term borrowings	$	32,000	$	16,000	$	9,500
Average short-term borrowings	$	6,992	$	1,154	$	349
Weighted-average interest rate		0.18 %		0.17 %		0.25 %

(a)

MGE Energy short-term borrowings include MGE Energy and MGE lines of credit and MGE commercial paper.

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.

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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 December 31, 2013 and 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 long-term debt is based on quoted market prices for similar financial instruments at December 31. Since long-term debt is not traded in an active market, it is classified as Level 2. The estimated fair market value of MGE Energy's and MGE's financial instruments are as follows:

		2013				2012
		Carrying Amount		Fair Value		Carrying Amount		Fair Value
(In thousands)
MGE Energy
Assets:
Cash and cash equivalents	$	68,813	$	68,813	$	46,357	$	46,357
Liabilities:
Long-term debt*		403,793		432,010		361,805		427,456
MGE
Assets:
Cash and cash equivalents	$	14,808	$	14,808	$	6,350	$	6,350
Liabilities:
Long-term debt*		403,793		432,010		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 December 31, 2013
(In thousands)		Total		Level 1		Level 2		Level 3
MGE Energy
Assets:
Exchange-traded investments	$	792	$	792	$	-	$	-
Total Assets	$	792	$	792	$	-	$	-
Liabilities:
Derivatives, net(a)	$	63,893	$	(735)	$	-	$	64,628
Deferred compensation		2,364		-		2,364		-
Total Liabilities	$	66,257	$	(735)	$	2,364	$	64,628
MGE
Assets:
Exchange-traded investments	$	431	$	431	$	-	$	-
Total Assets	$	431	$	431	$	-	$	-
Liabilities:
Derivatives, net(a)	$	63,893	$	(735)	$	-	$	64,628
Deferred compensation		2,364		-		2,364		-
Total Liabilities	$	66,257	$	(735)	$	2,364	$	64,628
(a) These amounts are shown gross and exclude $0.2 million of collateral that was posted against derivative positions with counterparties.

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	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 year ended December 31, 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 considered unobservable and classified as Level 3. Transactions done with an over-the-counter party are on inactive markets and are therefore classified as Level 3. These transactions are valued based on quoted prices from markets with similar exchange traded transactions. FTRs are priced based upon monthly auction results for identical or similar instruments in a closed market with limited data available and are therefore classified as Level 3.

The ten-year purchased power agreement (see Footnote 16) 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.

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

Significant Unobservable Inputs	Model Input
Basis adjustment:
On peak	94.2%
Off peak	92.6%
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.

(In thousands)		2013		2012		2011
Balance as of January 1,	$	(72,346)	$	(40,661)	$	(19,216)
Realized and unrealized gains (losses):
Included in regulatory liabilities (assets)		7,718		(31,685)		(21,445)
Included in other comprehensive income		-		-		-
Included in earnings		(2,618)		(5,005)		868
Included in current assets		(108)		-		-
Purchases		23,726		13,370		341
Sales		(2)		92		144
Issuances		-		-		-
Settlements		(20,998)		(8,457)		(1,353)
Transfers in and/or out of Level 3		-		-		-
Balance as of December 31,	$	(64,628)	$	(72,346)	$	(40,661)
Total gains (losses) included in earnings attributed to the
change in unrealized gains (losses) related to assets and
liabilities held at December 31,(b)	$	-	$	-	$	-

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

(In thousands)
Year Ended December 31,		2013		2012		2011
Purchased Power Expense	$	(2,618)	$	(5,005)	$	868

(b)

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.

12.

Income Taxes.

a.

MGE Energy and MGE Income Taxes.

MGE Energy files a consolidated federal income tax return that includes the operations of all subsidiary companies. The subsidiaries calculate their respective federal income tax provisions as if they were separate taxable entities.

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On a consolidated and separate company basis, MGE Energy's and MGE's income tax provision consists of the following provision (benefit) components for the years ended December 31:

		MGE Energy						MGE
(In thousands)		2013		2012		2011		2013		2012		2011
Current payable:
Federal	$	(1,508)	$	(6,053)	$	(1,504)	$	(448)	$	(5,030)	$	(607)
State		8,213		436		4,580		8,322		613		4,658
Net-deferred:
Federal		37,203		37,178		30,115		36,937		36,589		29,255
State		1,163		7,618		3,102		1,223		7,523		3,034
Amortized investment tax credits		(212)		(260)		(301)		(212)		(260)		(301)
Total income tax provision	$	44,859	$	38,919	$	35,992	$	45,822	$	39,435	$	36,039

MGE Energy's and MGE's consolidated income tax provision differs from the amount computed by applying the statutory federal income tax rate to income before income taxes, as follows:

	MGE Energy			MGE
	2013	2012	2011	2013	2012	2011
Statutory federal income tax rate	35.0 %	35.0 %	35.0 %	35.0 %	35.0 %	35.0 %
State income taxes, net of federal benefit	5.1 %	5.0 %	5.1 %	5.1 %	5.0 %	5.1 %
Amortized investment tax credits	(0.2)%	(0.3)%	(0.3)%	(0.2)%	(0.2)%	(0.3)%
Credit for electricity from wind energy	(1.5)%	(1.6)%	(1.8)%	(1.5)%	(1.5)%	(1.8)%
Domestic manufacturing deduction	(0.2)%	0.3 %	(0.7)%	(0.2)%	0.3 %	(0.7)%
AFUDC Equity, net	(0.7)%	(0.4)%	- %	(0.7)%	(0.4)%	- %
Other, net, individually insignificant	(0.0)%	(0.3)%	(0.2)%	(0.0)%	(0.5)%	(0.3)%
Effective income tax rate	37.5 %	37.7 %	37.1 %	37.5 %	37.7 %	37.0 %

The significant components of deferred tax liabilities (assets) that appear on MGE Energy's and MGE's consolidated balance sheets as of December 31 as follows:

		MGE Energy				MGE
(In thousands)		2013		2012		2013		2012
Property-related	$	263,881	$	248,545	$	263,881	$	248,545
Investment in ATC		32,696		29,147		27,073		24,993
Bond transactions		1,553		1,643		1,553		1,643
Pension and other postretirement benefits		34,478		82,072		34,478		82,072
Derivatives		26,361		29,134		26,361		29,134
Tax deductible prepayments		7,508		7,233		7,508		7,233
Other		1,995		10,662		1,911		10,634
Gross deferred income tax liabilities		368,472		408,436		362,765		404,254
Future federal tax benefit		-		(25,626)		-		(25,899)
Accrued expenses		(17,195)		(30,277)		(17,195)		(30,228)
Pension and other postretirement benefits		(26,838)		(69,941)		(26,838)		(69,941)
Deferred tax regulatory account		(1,402)		(1,551)		(1,402)		(1,551)
Derivatives		(26,361)		(29,134)		(26,361)		(29,134)
Other		(10,369)		(5,345)		(9,356)		(4,940)
Gross deferred income tax assets		(82,165)		(161,874)		(81,152)		(161,693)
Less valuation allowance		195		365		195		365
Net deferred income tax assets		(81,970)		(161,509)		(80,957)		(161,328)
Deferred income taxes	$	286,502	$	246,927	$	281,808	$	242,926

As of December 31, 2013, MGE Energy did not have a federal net operating loss or tax credit carryforwards. As of December 31, 2012, MGE Energy had approximately $63.4 million and $3.4 million of net operating loss and tax credit carryforwards, respectively. The net operating loss and tax credit carryforwards resulted in deferred tax assets of $22.2 million and $3.4 million, respectively, as of December 31, 2012.

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As of December 31, 2013, MGE did not have a federal net operating loss or tax credit carryforwards. As of December 31, 2012, MGE had approximately $64.2 million and $3.4 million of net operating loss and tax credit carryforwards, respectively. The net operating loss and tax credit carryforwards resulted in deferred tax assets of $22.5 million and $3.4 million, respectively, as of December 31, 2012.

The valuation allowance reduces MGE Energy's and MGE's deferred tax assets for state carryforward losses to estimated realizable value due to the uncertainty of future income estimates in various state tax jurisdictions.

For tax purposes, as of December 31, 2013, both MGE Energy and MGE had approximately $4.0 million of Illinois state tax net operating loss deductions that expire between 2014 and 2024 if unused.

b.

Accounting for Uncertainty in Income Taxes - MGE Energy and MGE.

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.

A tabular reconciliation of unrecognized tax benefits and interest from January 1, 2011, to December 31, 2013, is as follows:

(In thousands)
Unrecognized tax benefits:		2013		2012		2011
Unrecognized tax benefits, January 1,	$	3,204	$	2,364	$	4,377
Additions based on tax positions related to the current year		377		401		128
Additions based on tax positions related to the prior years		424		580		427
Reductions based on tax positions related to the current year		(40)		-		-
Reductions based on tax positions related to the prior years		(1,602)		(141)		(2,568)
Unrecognized tax benefits, December 31,	$	2,363	$	3,204	$	2,364
(In thousands)
Interest on unrecognized tax benefits:		2013		2012		2011
Accrued interest on unrecognized tax benefits, January 1,	$	314	$	216	$	214
Reduction in interest expense on uncertain tax positions		(275)		-		-
Interest expense on uncertain tax positions		62		98		2
Accrued interest on unrecognized tax benefits, December 31,	$	101	$	314	$	216

Unrecognized tax benefits are liabilities shown with Other Deferred Liabilities on the December 31, 2013, and December 31, 2012, consolidated balance sheets. The interest component is offset by a regulatory asset.

MGE Energy filed an application with its 2009 tax returns to change its income tax methods of accounting for electric generation, transmission and distribution repairs and its 2010 tax returns for gas distribution repairs. These method changes accelerated tax deductions for repairs in accordance with Treasury Regulations and case law, as compared to the prior method of claiming tax depreciation on project costs. During 2011, the IRS issued guidance on the treatment of electric transmission and distribution repairs. This guidance has prompted the reversal of a majority of the unrecognized tax benefits for these repairs. During 2013, the IRS issued guidance on the treatment of electric generation repairs. This guidance prompted the reversal of the unrecognized tax benefits for these repairs. At December 31, 2013, MGE Energy and MGE have an unrecognized tax benefit in the amount of $2.4 million related to temporary tax differences associated with the change in income tax method of accounting for electric transmission and distribution repairs and gas distribution repairs. At December 31, 2012, MGE Energy and MGE had an unrecognized tax benefit in the amount of $3.2 million primarily related to temporary tax differences associated with the change in income tax method of accounting for electric generation, transmission, and distribution repairs and gas distribution repairs. At December 31, 2011, MGE Energy and MGE had an unrecognized tax benefit in the amount of $2.4 million primarily related to temporary tax differences associated with the change in income tax method of accounting for electric generation repairs and gas distribution repairs. There were no unrecognized tax benefits at December 31, 2013, or December 31, 2012, related to federal permanent differences and tax credits. Unrecognized tax benefits at December 31, 2011, related to federal permanent differences and tax credits were $0.2 million.

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The unrecognized tax benefits at December 31, 2013, are not expected to significantly increase or decrease within the next twelve months. However, the IRS may issue guidance on the treatment of gas distribution repairs. In addition, statutes of limitations will expire for MGE Energy and MGE tax returns. The impact of the statutes of limitations expiring is not anticipated to be material. The following table shows tax years that remain subject to examination by major jurisdiction:

Taxpayer	Open Years
MGE Energy and consolidated subsidiaries in federal return	2010 through 2013
MGE Energy Wisconsin combined reporting corporation return	2009 through 2013

c.

Medicare Part D Subsidy - MGE Energy and MGE.

In March 2010, the Patient Protection and Affordable Care Act (the PPACA) was enacted. The PPACA effectively changes the tax treatment of federal subsidies paid to sponsors of retiree health benefit plans that provide a benefit that is at least actuarially equivalent to the benefits under Medicare Part D. As a result of the PPACA, these subsidy payments became taxable in tax years beginning after December 31, 2012. In 2012, MGE was able to specifically identify assets within the retiree health benefit plans to be used for payment of future health insurance premiums and prescription drug coverage. This process will allow certain Medicare Part D subsidy receipts to be non-taxable.

d.

Final Tangible Property Regulations.

In September 2013, the IRS and Treasury Department released final regulations under Section 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.

13.

Pension Plans and Other Postretirement Benefits - MGE Energy and MGE.

MGE maintains qualified and nonqualified pension plans, health care, and life insurance benefits, and two defined contribution 401(k) benefit plans for its employees and retirees. MGE's costs for the 401(k) plans were $2.3 million, $2.1 million, and $1.8 million in 2013, 2012, and 2011, respectively. A measurement date of December 31 is utilized for all pension and postretirement benefit plans.

All employees hired after December 31, 2006, have been enrolled in the defined contribution pension plan, rather than the defined benefit pension plan previously in place.

a.

Benefit Obligations.

(In thousands)		Pension Benefits				Other Postretirement Benefits
Change in benefit obligations:		2013		2012		2013		2012
Net benefit obligation at beginning of year	$	315,505	$	283,668	$	92,605	$	97,644
Service cost		7,705		7,139		2,380		2,528
Interest cost		12,656		12,704		3,871		4,431
Plan participants' contributions		-		-		665		718
Plan amendments(a)		-		(912)		(20,915)		-
Actuarial (gain) loss		(40,335)		22,266		(9,687)		(9,748)
Gross benefits paid		(11,573)		(9,360)		(2,998)		(3,155)
Less: federal subsidy on benefits paid		-		-		179		187
Benefit obligation at end of year	$	283,958	$	315,505	$	66,100	$	92,605

(a)

In 2013, MGE capped the amount it pays each year toward retiree medical premiums at 175% of the 2013 employer contribution for qualified employees.

78

The accumulated benefit obligation for the defined benefit pension plans at the end of 2013 and 2012 was $254.5 million and $272.5 million, respectively.

	Pension Benefits		Other Postretirement Benefits
Weighted-average assumptions used to
determine end of year benefit obligations:	2013	2012	2013	2012
Discount rate	4.88 %	4.09 %	4.69 %	4.14 %
Rate of compensation increase	3.90 %	4.60 %	N/A	N/A

The following table shows assumed health care cost trend rates at December 31:

	2013	2012
Health care cost trend rate assumed for next year	7.0 %	7.5 %
Rate to which the cost trend rate is assumed to
decline (the ultimate trend rate)	5.0 %	5.0 %
Year that the rate reaches the ultimate trend rate	2018	2018

The assumed health care cost trend rates have a significant effect on the amounts reported for the health care plans.

The following table shows how an assumed 1% increase or 1% decrease in health care cost trends could impact postretirement benefits in 2013 dollars:

(In thousands)		1% Increase		1% Decrease
Effect on other postretirement benefit obligation	$	1,286	$	(1,840)

In 2003, the Medicare Prescription Drug, Improvement and Modernization Act of 2003 was signed into law authorizing Medicare to provide prescription drug benefits to retirees. For the year ended December 31, 2013, the subsidy due to MGE was $0.2 million.

b.

Plan Assets.

(In thousands)		Pension Benefits				Other Postretirement Benefits
Change in plan assets:		2013		2012		2013		2012
Fair value of plan assets at beginning of year	$	212,277	$	173,311	$	32,124	$	23,456
Actual return on plan assets		45,816		27,511		5,000		3,046
Employer contributions		30,878		20,815		2,811		8,059
Plan participants' contributions		-		-		665		718
Gross benefits paid		(11,573)		(9,360)		(2,998)		(3,155)
Fair value of plan assets at end of year	$	277,398	$	212,277	$	37,602	$	32,124

The expected long-term rate of return on the pension plan assets is 8.10% for both 2013 and 2012.

c.

Explanation of Long-Term Rate of Return.

MGE employs a building-block approach in determining the expected long-term rate of return for asset classes. Historical markets are studied and long-term historical relationships among asset classes are analyzed, consistent with the widely accepted capital market principle that assets with higher volatility generate a greater return over the long run. Current market factors, such as interest rates and dividend yields, are evaluated before long-term capital market assumptions are determined.

The expected long-term nominal rate of return for plan assets is primarily a function of expected long-term real rates of return for component asset classes and the plan's target asset allocation in conjunction with an inflation assumption. Peer data and historical returns are reviewed to check for appropriateness.

79

The asset allocation for MGE's pension plans at the end of 2013 and 2012, and the target allocation for 2014, by asset category, follows:

	Target Allocation	Percentage of Plan Assets at Year End
		2013	2012
Equity securities	63.0 %	66.0 %	64.0 %
Debt securities	30.0 %	28.0 %	29.0 %
Real estate	7.0 %	6.0 %	7.0 %
Total	100.0 %	100.0 %	100.0 %

d.

Investment Strategy.

MGE employs a total return investment approach whereby a mix of equities, fixed income, and real estate investments are used to maximize the expected long-term return of plan assets for a prudent level of risk. Risk tolerance is established through careful consideration of plan liabilities, plan-funded status, and corporate financial condition. The investment portfolio contains a diversified blend of equity, fixed income, and real estate investments. Target asset allocations are as follows: 45.5% United States equity, 17.5% non-United States equity, 30.0% fixed income, and 7.0% real estate. Investment risk is measured and monitored on an ongoing basis through periodic investment portfolio reviews and liability measurements.

e.

Concentrations of Credit Risk.

MGE evaluated its pension and other postretirement benefit plans' asset portfolios for the existence of significant concentrations of credit risk as of December 31, 2013. Types of concentrations that were evaluated include, but are not limited to, investment concentrations in a single entity, type of industry, and foreign country. As of December 31, 2013, there were no significant concentrations (defined as greater than 10 percent of plan assets) of risk in MGE pension and postretirement benefit plan assets.

f.

Fair Value Measurements of Plan Assets.

Fair value is defined as the price that would be received to sell an asset or 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.

The following is a description of the valuation methodologies used for assets measured at fair value as of December 31, 2013:

Cash and Cash Equivalents – This category includes highly liquid investments with maturities of less than three months which are traded in active markets.

Equity Securities – These securities consist of U.S. and international stock funds. The U.S. stock funds are primarily invested in domestic equities. Securities in these funds are typically priced using the closing price from the applicable exchange, NYSE, NASDAQ, etc. The international funds are composed of international equities. Securities are priced using the closing price from the appropriate local stock exchange.

Fixed Income Securities – These securities consist of U.S. bond funds and short-term funds. U.S. bond funds are priced by a pricing agent using inputs such as benchmark yields, reported trades, broker/dealer quotes, and issuer spreads. The short-term funds are valued initially at cost and adjusted for amortization of any discount or premium.

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Real Estate – The fair value of real estate properties is determined through an external appraisal process.

Insurance Continuance Fund (ICF) – The fair value of the ICF is based on largely unobservable inputs, which are based on a commingled interest.

The fair value of MGE's plan assets, by asset category are as follows:

	Fair Value as of December 31, 2013
(In thousands)		Total		Level 1		Level 2		Level 3
Cash and Cash Equivalents	$	5,109	$	5,109	$	-	$	-
Equity Securities:
U.S. Large Cap		96,258		-		96,258		-
U.S. Mid Cap		22,741		-		22,741		-
U.S. Small Cap		28,854		-		28,854		-
International Blend		54,873		-		54,873		-
Fixed Income Securities:
Short-Term Fund		4,789		-		4,789		-
High Yield Bond		15,127		-		15,127		-
Long Duration Bond		66,193		-		66,193		-
Real Estate		19,628		-		-		19,628
Insurance Continuance Fund		1,428		-		-		1,428
Total	$	315,000	$	5,109	$	288,835	$	21,056
	Fair Value as of December 31, 2012
(In thousands)		Total		Level 1		Level 2		Level 3
Cash and Cash Equivalents	$	5,627	$	5,627	$	-	$	-
Equity Securities:
U.S. Large Cap		68,671		-		68,671		-
U.S. Mid Cap		16,741		-		16,741		-
U.S. Small Cap		21,222		-		21,222		-
International Blend		44,200		-		44,200		-
Fixed Income Securities:
Short-Term Fund		4,231		-		4,231		-
High Yield Bond		11,587		-		11,587		-
Long Duration Bond		53,515		-		53,515		-
Real Estate		17,141		-		-		17,141
Insurance Continuance Fund		1,466		-		-		1,466
Total	$	244,401	$	5,627	$	220,167	$	18,607

No transfers were made in or out of Level 1 or Level 2 for the year ended December 31, 2013.

The following table summarizes the changes in the fair value of the Level 3 plan assets.

		Level 3 Assets
(In thousands)		Real Estate		Insurance Continuance Fund
Balance as of January 1, 2012	$	15,565	$	906
Actual return on plan assets:
Relating to assets still held at the reporting date		682		33
Purchases, sales, and settlements		894		527
Transfers in and/or out of Level 3		-		-
Balance as of December 31, 2012	$	17,141	$	1,466
Actual return on plan assets:
Relating to assets still held at the reporting date		1,565		42
Purchases, sales, and settlements		922		(80)
Transfers in and/or out of Level 3		-		-
Balance as of December 31, 2013	$	19,628	$	1,428

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g.

Other Postretirement Benefits.

The fair value of plan assets for the postretirement benefit plans is $37.6 million and $32.1 million at the end of 2013 and 2012, respectively. The expected long-term rate of return on these plan assets is 6.79% and 7.26% for 2013 and 2012, respectively.

Of the above amounts, $31.1 million and $25.0 million at the end of 2013 and 2012, respectively, were held in the master pension trust and are allocable to postretirement health expenses. The target asset allocation and investment strategy for the portion of assets held in the master pension trust are the same as that explained for MGE's pension plans.

The remainder of postretirement benefit assets are held either in an insurance continuance fund for the payment of retiree life benefits or a health benefit trust for payment of retiree health claims. There is no formal target asset allocation for these assets, but the intent is to seek interest income and maintain stability of principal.

h.

Funded Status.

The funded status at the end of the year, and the related amounts recognized on the consolidated balance sheet are as follows:

(In thousands)		Pension Benefits				Other Postretirement Benefits
Funded status, end of year		2013		2012		2013		2012
Fair value of plan assets	$	277,398	$	212,277	$	37,602	$	32,124
Benefit obligations		283,958		315,505		66,100		92,605
Funded status	$	(6,560)	$	(103,228)	$	(28,498)	$	(60,481)

At December 31, 2013, MGE Energy and MGE included a $15.1 million long-term asset, a $1.0 million current liability, a $49.2 million long-term liability, and a $24.6 million regulatory asset in the consolidated balance sheets to reflect the unfunded status of the plans.

At December 31, 2012, MGE Energy and MGE included a $0.9 million current liability, a $162.8 million long-term liability, and a $134.8 million regulatory asset in the consolidated balance sheets to reflect the unfunded status of the plans.

(In thousands)		Pension Benefits				Other Postretirement Benefits
Amounts recognized as regulatory asset		2013		2012		2013		2012
Net actuarial loss	$	37,499	$	112,637	$	7,761	$	21,529
Prior service cost		(209)		105		(20,495)		530
Transition obligation		-		-		35		38
Total	$	37,290	$	112,742	$	(12,699)	$	22,097

The projected benefit obligation and fair value of plan assets for pension plans with a projected benefit obligation in excess of plan assets were as follows:

(In thousands)		Pension Benefits
Projected benefit obligation in excess of plan assets		2013		2012
Projected benefit obligation, end of year	$	21,631	$	315,505
Fair value of plan assets, end of year		-		212,277

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The projected benefit obligation, accumulated benefit obligation, and fair value of plan assets for pension plans with a projected benefit obligation in excess of plan assets and an accumulated benefit obligation in excess of plan assets were as follows:

(In thousands)		Pension Benefits
Accumulated benefit obligation in excess of plan assets		2013		2012
Projected benefit obligation, end of year	$	21,631	$	315,505
Accumulated benefit obligation, end of year		19,795		272,462
Fair value of plan assets, end of year		-		212,277

i.

Expected Cash Flows.

MGE does not expect to make contributions to the plans for 2014 or 2015. The contributions for years after 2015 are not yet currently estimated. MGE has adopted the asset smoothing as permitted in accordance with the Pension Protection Act of 2006, including modifications made by WRERA.

Due to uncertainties in the future economic performance of plan assets, discount rates, and other key assumptions, estimated contributions are subject to change. MGE may also elect to make additional discretionary contributions.

In 2013, MGE made $34.8 million in employer contributions to its pension and postretirement plans.

j.

Benefit Payments.

The following benefit payments, which reflect expected future service, as appropriate, are expected to be paid as follows:

		Pension	Other Postretirement
(In thousands)		Pension Benefits	Gross Postretirement Benefits	Expected Medicare Part D Subsidy		Net Postretirement Benefits
2014	$	11,474	2,924	(191)	$	2,733
2015		12,223	3,056	(219)		2,837
2016		12,844	3,308	(246)		3,062
2017		13,633	3,740	(266)		3,474
2018		14,755	4,198	(289)		3,909
2019 - 2023		87,676	27,110	(1,866)		25,244

k.

Net Periodic Cost.

MGE has elected to recognize the cost of its transition obligation (the accumulated postretirement benefit obligation as of January 1, 1993) by amortizing it on a straight-line basis over 20 years.

(In thousands)		Pension Benefits						Other Postretirement Benefits
Components of net periodic benefit cost		2013		2012		2011		2013		2012		2011
Service cost	$	7,705	$	7,139	$	6,013	$	2,380	$	2,528	$	1,920
Interest cost		12,656		12,704		12,281		3,871		4,431		3,980
Expected return on assets		(19,027)		(15,182)		(14,034)		(2,176)		(1,741)		(1,584)
Special termination benefits		-		-		13		-		-		-
Amortization of:
Transition obligation		-		-		-		3		425		427
Prior service cost		314		430		433		110		110		110
Actuarial loss		8,014		8,288		3,771		1,236		2,346		566
Net periodic benefit cost	$	9,662	$	13,379	$	8,477	$	5,424	$	8,099	$	5,419
Weighted-average assumptions used to
determine net periodic cost:
Discount rate		4.09%		4.50%		5.36%		4.14%		4.55%		5.42%
Expected return on plan assets		8.10%		8.10%		8.25%		6.79%		7.26%		7.39%
Rate of compensation increase		4.60%		4.59%		4.59%		N/A		N/A		N/A

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Assumed health care cost trend rates have a significant effect on the amounts reported for the health care plans. A 1% change in the assumed health care cost trend rates would have had the following effect:

(In thousands)		1% Increase		1% Decrease
Effect on total service and interest cost components	$	1,104	$	(879)

The PSCW has allowed MGE to defer the 2009 incremental pension and OPRB costs above the amounts recovered in rates. During both the years ended December 31, 2013 and 2012, $1.2 million has been recovered in rates.

14.

Share-Based Compensation - MGE Energy and MGE.

Under MGE Energy's Performance Unit Plan, eligible employees may receive performance units that entitle the holder to receive a cash payment equal to the value of a designated number of shares of MGE Energy's common stock, plus dividend equivalent payments thereon, at the end of the set performance period. In accordance with the plan's provisions, these awards are subject to a prescribed vesting schedule and must be settled in cash. Accordingly, no shares of common stock will be issued in connection with the plan.

On the grant date, MGE Energy and MGE measure the cost of the employee services received in exchange for a performance unit award based on the current market value of MGE Energy common stock. The fair value of the awards is re-measured quarterly, including at December 31, 2013, as required by applicable accounting standards. Changes in fair value as well as the original grant are recognized as compensation cost. Since this amount is re-measured throughout the vesting period, the compensation cost is subject to variability. These units are subject to a five year graded vesting schedule. Units have been adjusted to reflect the three-for-two stock split declared December 20, 2013.

Grant Date	MGE Energy Units Granted
January 15, 2010	25,965
January 21, 2011	23,483
February 17, 2012	25,040
February 15, 2013	22,884
February 21, 2014	21,991

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.

During the year ended December 31, 2013, MGE recorded $1.5 million in compensation expense as a result of awards under the Performance Unit Plan. Compensation expense during both the years ended December 31, 2012 and 2011 was $1.4 million. 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 years ended December 31, 2013, 2012, and 2011. At December 31, 2013, $4.5 million of outstanding awards are vested, and of this amount no cash settlements have occurred.

In December 2013, a Director Incentive Plan was approved for the non-employee members of the Board of Directors. This plan is similar to MGE Energy's Performance Unit Plan for eligible employees described above. Under the plan, a non-employee director can receive performance units that entitle the holder to receive a cash payment equal to the value of a designated number of shares of MGE Energy's common stock, plus dividend payments, at the end of the set performance period. The units are subject to a three year graded vesting schedule. In January 2014, unit awards of 4,683 (post-split) were granted to the non-employee Directors. For accounting purposes, the awards will be measured similarly to the employee unit awards.

15.

Regional Transmission Organizations - MGE Energy and MGE.

MGE reports on a net basis transactions on the MISO and PJM markets in which it buys and sells power within the same hour to meet electric energy delivery requirements. This treatment resulted in a $78.0 million reduction to sales to the market and purchase power expense for MISO markets for the year ended December 31, 2013, and a $75.9 million and $102.1 million reduction to sales to the market and purchased power expense for MISO and PJM markets for the years ended December 31, 2012 and 2011, respectively.

84

MISO

MGE is a nontransmission owning member of the MISO. MISO, a FERC approved RTO, is responsible for monitoring the electric transmission system that delivers power from generating plants to wholesale power transmitters. MISO's role is to ensure equal access to the transmission system and to maintain or improve electric system reliability in the Midwest.

MISO maintains a bid-based energy market. MGE offers substantially all of its generation on the MISO market and purchases much of its load requirement from the MISO market in accordance with the MISO Tariff. MGE participates in the ancillary services market operated by MISO. That market is an extension of the existing energy market in which MISO assumes the responsibility of maintaining sufficient generation reserves. In the ancillary services market, MISO provides the reserves for MGE's load, and MGE may offer to sell reserves from its generating units.

MGE participates in the voluntary capacity auction, which provides an optional monthly forum for buyers and sellers of aggregate planning resource credits to interact. Load serving entities, such as MGE, may participate in the voluntary capacity auction potentially to obtain the necessary aggregate planning resource credits needed to meet their planning reserve margin requirement established by the PSCW. Generator owners, such as MGE, may participate to sell any excess aggregate planning resource credits that are not needed by them.

PJM

MGE is a member of PJM. PJM, an RTO, is a neutral and independent party that coordinates and directs the operation of the transmission grid within its area of coverage, administers a competitive wholesale electricity market, and plans regional transmission expansion improvements to maintain grid reliability and relieve congestion.

16.

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:

	December 31, 2013	December 31, 2012
Commodity derivative contracts	458,660 MWh	444,650 MWh
Commodity derivative contracts	3,750,000 Dth	1,980,000 Dth
FTRs	1,984 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.

85

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 December 31, 2013 and 2012 the fair value of exchange traded derivatives and FTRs exceeded their cost basis by $1.8 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 December 31, 2013 and 2012, reflects a loss position of $65.7 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
December 31, 2013
Commodity derivative contracts	Other current assets	$	1,356	Derivative liability (current)	$	51
Commodity derivative contracts	Other deferred charges		167	Derivative liability (long-term)		48
FTRs	Other current assets		363	Derivative liability (current)		-
Ten-year PPA	N/A		N/A	Derivative liability (current)		7,750
Ten-year PPA	N/A		N/A	Derivative liability (long-term)		57,930
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

86

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
(In thousands)		Gross amounts		Gross amounts offset in balance sheet		Collateral posted against derivative positions		Net amount presented in balance sheet
December 31, 2013
Commodity derivative contracts	$	1,523	$	(99)	$	(175)	$	1,249
FTRs		363		-		-		363
December 31, 2012
Commodity derivative contracts	$	460	$	(405)	$	-	$	55
FTRs		206		-		-		206

Offsetting of Derivative Liabilities
(In thousands)		Gross amounts		Gross amounts offset in balance sheet		Collateral posted against derivative positions		Net amount presented in balance sheet
December 31, 2013
Commodity derivative contracts	$	99	$	(99)	$	-	$	-
Ten-year PPA		65,680		-		-		65,680
December 31, 2012
Commodity derivative contracts	$	405	$	(405)	$	-	$	-
Ten-year PPA		72,590		-		-		72,590

The following tables summarize the unrealized and realized gains (losses) related to the derivative instruments on the consolidated balance sheet at December 31, 2013 and 2012, and the consolidated income statement for the year ended December 31, 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
Year Ended December 31:
Balance at January 1,	$	72,329	$	574	$	42,356	$	1,604
Change in unrealized loss		(5,069)		-		37,822		-
Realized loss reclassified to a deferred account		(823)		823		(2,857)		2,857
Realized loss reclassified to income statement		(2,544)		(986)		(4,992)		(3,887)
Balance at December 31,	$	63,893	$	411	$	72,329	$	574

		Realized losses (gains)
(In thousands)		Fuel for Electric Generation/ Purchased Power		Cost of Gas Sold
Year Ended December 31, 2013:
Commodity derivative contracts	$	(564)	$	868
FTRs		(983)		-
Ten-year PPA		4,209		-
Year Ended December 31, 2012:
Commodity derivative contracts	$	2,620	$	3,072
FTRs		(45)		-
Ten-year PPA		3,232		-

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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 December 31, 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 December 31, 2013 and 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 December 31, 2013, no counterparties have defaulted.

17.

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.

On January 12, 2011, the PSCW authorized MGE to increase 2011 rates for retail electric customers by 2.3% or $8.0 million and to increase gas rates by 1.0% or $1.9 million. The increase in retail electric rates was driven by costs for MGE's share of the Elm Road Units. Pursuant to the provisions of this rate order, the fuel rules bandwidth effective January 1, 2011, will be plus or minus 2%. Authorized return on common stock equity was set at 10.3% based on a 58.1% utility common equity.

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 exceed 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 are less than 98% of the electric fuel costs allowed in that order.

As of December 31, 2013, MGE has deferred $6.7 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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18.

Commitments and Contingencies.

a.

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 December 31, 2013, the future minimum commitments related to these purchase contracts were as follows:

(In thousands)		2014		2015		2016		2017		2018
Coal(a)	$	22,109	$	14,633	$	10,938	$	5,073	$	2,710
Natural Gas
Transportation and storage(b)		17,211		16,857		9,288		272		191
Supply(c)		19,511		-		-		-		-
Purchase Power(d)		47,241		45,711		46,467		46,928		47,911
Other		2,314		498		498		498		124
	$	108,386	$	77,699	$	67,191	$	52,771	$	50,936

(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)

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

(c)

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

(d)

MGE has several purchase power agreements to help meet future electric supply requirements. Management expects to recover these costs in future customer rates. In October 2008, MGE entered into a ten-year purchase power agreement to help meet future electric supply requirements. Under this agreement, MGE has agreed to purchase 50 MW of wind power from Osceola Windpower II, LLC, which is located in Iowa. This facility became operational in October 2008. MGE does not have any capacity payment commitments under this agreement. However, MGE is obligated to purchase its ratable share of the energy produced by the project. MGE's commitment related to its ratable share of energy produced by the project has been estimated and is included in the above numbers.

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 December 31, 2013, 2012, and 2011, respectively, MGE had sold a $5.4 million, $4.5 million, and $4.3 million interest in these receivables. MGE retains the servicing responsibility for these receivables.

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 maintains responsibility for collecting and remitting loan payments from customers to the financial institution and does not retain any interest in the assets sold to the financial institution. At December 31, 2013, MGE had recorded a servicing asset of $0.3 million. At both December 31, 2012 and 2011, MGE had recorded a servicing asset of $0.2 million. MGE recognized a gain of $0.2 million for the year ended December 31, 2013, in connection with the sale of loan assets. MGE recognized gains of $0.1 million for each of the years ended December 31, 2012 and 2011, in connection with the sale of loan assets. The servicing asset amount amortized in 2013 was less than $0.1 million. The loan assets are sold to the financial institution at cost, which approximates fair value in view of their market rates of interest. During 2013, 2012,

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and 2011, MGE received approximately $1.6 million, $1.2 million, and $1.5 million, respectively, from the financial institution for the sale of loan assets. During those same years, payments of $0.8 million, $1.2 million, and $0.8 million, respectively, were made by MGE to the financial institution.

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 December 31, 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 next five years on the loans are:

(In thousands)		2014		2015		2016		2017		2018
Principal payments	$	714	$	1,007	$	910	$	506	$	449

c.

Leases - MGE Energy and MGE.

MGE has noncancelable operating leases, primarily for combustion turbines, railcars, and computer equipment. The operating leases generally do not contain renewal options, with the exception of certain railcar operating leases. These leases have a renewal option of one year or less. MGE is required to pay all executory costs such as maintenance and insurance for its leases.

Future minimum rental payments at December 31, 2013, under agreements classified as operating leases with noncancelable terms in excess of one year are as follows:

(In thousands)		2014		2015		2016		2017		2018		Thereafter
Minimum lease payments	$	1,668	$	1,478	$	983	$	718	$	418	$	8,179

Rental expense under operating leases totaled $2.7 million for 2013, $2.6 million for 2012, and $3.2 million for 2011.

d.

Environmental - MGE Energy and MGE.

Water Quality

Water quality regulations promulgated by the EPA and WDNR in accordance with the Federal Water Pollution Control Act, or more commonly known as the Clean Water Act (CWA), impose restrictions on discharges of various pollutants into surface waters. The CWA also regulates surface water quality issues that affect aquatic life, such as water temperatures, intake structures, and wetlands filling. The CWA also includes discharge standards, which require the use of effluent-treatment processes equivalent to categorical "best practicable" or "best available" technologies. The CWA regulates discharges from "point sources," such as power plants, through establishing discharge limits in water discharge permits. MGE's power plants operate under Wisconsin Pollution Discharge Elimination System (WPDES) permits to ensure compliance with these discharge limits.

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

Section 316(b) of the CWA requires that the cooling water intake structures at electric power plants meet best available technology standards so that mortality from entrainment (drawing aquatic life into a plant's cooling system) and impingement (trapping aquatic life on screens) are reduced. Section 316(b) is implemented in Wisconsin through modifications to plants' WPDES permits in a timeframe determined by the rule. Although new facilities have been required to meet 316(b) standards for some time, regulations for existing facilities have not yet been finalized but are expected to be issued by EPA in 2014.

The currently proposed rule for existing plants allows for a state permitting agency's discretion in determining best technology available at plants and does not require cooling towers in all instances. Blount and Columbia generating plants are subject to both the impingement and entrainment aspects of the current proposed rule. WCCF is subject to the impingement aspect only. The Elm Road Units met the new facility requirements when it was built. We anticipate that under the current proposed rule, equipment would need to be installed at Blount, WCCF and Columbia to meet the new standards. However it is not presently possible to estimate the potential costs associated with this rule because the rule has not been finalized.

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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 electric generation plants with a focus on coal-burning plants. The proposed rule regulates wastewater from seven specific wastewater types. The proposed rule is technology-driven in that specific technologies may need to be installed to meet the rule's requirements. Sites that already have these technologies will be deemed to meet the requirements of the rule. The proposed rule as written will likely affect wastewater systems at Columbia and the Elm Road Units.

The EPA has signed a consent decree to finalize the rule by May 2014 and have the rule apply to power plants as they renew their water discharge permits beginning in July 2017. Based on our current evaluation of the proposed rule and its alternatives we may need to add treatments systems or additional equipment at our Elm Road and Columbia facilities. We will have a better understanding of potential costs to MGE once the rule is finalized.

Energy Efficiency and Renewables

The Wisconsin Energy Efficiency and Renewables Act requires that, by 2015, 10% of the state's electricity be generated from renewable resources. MGE is in compliance with the 2015 requirement. The costs to comply with the Act and its accompanying regulations are being recovered in rates.

Air Quality

Federal and state air quality regulations impose restrictions on emission of particulates (PM), sulfur dioxide (SO₂), nitrogen oxides (NO_x) and other pollutants and require permits for operation of emission sources. These permits have been obtained by MGE and must be renewed periodically. Various initiatives, including interstate pollution transport rules, maximum achievable control technology (MACT) standards, such as the Reciprocating Internal Combustion Engine (RICE) MACT, new source performance standards (NSPS), the Clean Air Visibility Rule (also known as the Regional Haze Rule), and mercury emissions limits are expected to result in additional operating and capital expenditure costs for electric generating units.

Interstate Transport Rules for NO_x and SO₂

EPA has promulgated three interstate air pollution rules consisting of the NO_x SIP Call, the Clean Air Interstate Rule (CAIR) and the Cross-State Air Pollution Rule (CSAPR). These rules were each designed to reduce nitrogen oxide (NO_x) and/or sulfur dioxide (SO₂) air emissions from EGUs, including EGUs located in Wisconsin and other states. NO_x and SO₂ interact in the atmosphere to form ambient ozone and fine particulate matter pollution. As explained below, only the CAIR currently affects MGE's generation assets.

In 2000, the U.S. Court of Appeals for the D.C. Circuit held that Wisconsin had been illegally included in a portion of the NO_x SIP Call, but stayed the remaining legal challenges to the rule pending EPA's development of additional interstate pollution transport rules. The EPA developed the CAIR to replace the NO_x SIP Call, but in 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. In 2011, the EPA developed CSAPR which the U.S. Court of Appeals for the D.C. Circuit vacated in 2012 with directions that the EPA temporarily reinstate CAIR. That decision was argued before the U.S. Supreme Court in December 2013, and a decision is pending. The CAIR remains effective.

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. Phase I is currently in place. Phase II begins in 2015 and will require regional NO_x and SO₂ emissions reductions from 2003 levels by 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.

Based on our evaluation of Phase II of CAIR, we will be able to meet NO_x emissions reductions through using our NO_x allowances provided through the rule, and we will meet SO₂ emissions reductions through installation of pollution controls. New SO₂ controls that will meet or exceed CAIR allowances at Columbia are underway and are planned to be completed by mid-2014 (see the discussion regarding the Columbia environmental project below). MGE expects that any costs incurred to meet Phase II of the CAIR will be fully recoverable through rates. We will continue to monitor the Supreme Court's response to the CSAPR appeals and any actions by the EPA on any new or revised interstate transport rule.

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Clean Air Visibility Rule (CAVR)

Air modeling indicates that SO₂ and NO_x emissions (and to a lesser extent particulate matter) from Columbia may impair visibility at certain Class I Scenic Areas. Columbia may therefore be subject to the best available retrofit technology (BART) regulations, a subsection of the EPA's Clean Air Visibility Rule (CAVR), which may require pollution retrofits. The EPA had proposed that Columbia's compliance with emissions limitations in the CAIR and the CSAPR could also serve as compliance with the BART for SO₂ and NO_x emissions. However, this proposal is now uncertain because of the D.C. Circuit remanding the CAIR to the EPA and vacating the CSAPR. The Sierra Club has sought federal appellate court review of Wisconsin's implementation plan for the BART portion of CAVR and that appeal has been stayed pending the U.S. Supreme Court's decision on CSAPR. At this time, the BART regulatory obligations, compliance strategies and costs remain uncertain.

Reciprocating Internal Combustion Engines Maximum Achievable Control Technology (RICE MACT)

In January 2013, the EPA finalized amendments to its RICE MACT standard. RICE MACT applies to industrial or electrical engines that are classified as reciprocating internal combustion engines. Engines owned by MGE that would fall under the RICE MACT rule include backup generators and small engines at various locations, including our fleet of distributed generators that serve as electric system backup and emergency dispatch. Our units that currently serve as system or emergency backup will be restricted to emergency operation and limited (50 hours) non-emergency operation annually or will require additional pollution control equipment to run more often. The EPA issued a notice of reconsideration in August 2013 on the 50 hour non-emergency operating limit. MGE is currently installing pollution control equipment on a number of units. MGE will continue to monitor developments regarding potential changes to the number of hours allowed for non-emergency operation.

Mercury and Air Toxics Standards (MATs) for Utility Boilers (Also Referred to as the Maximum Achievable Control Technology or MACT)

In December 2011, the EPA finalized its Mercury and Air Toxics Standards for coal and oil-burning EGU boilers. MATs will require emissions standards for mercury, non-mercury HAPs metals, and acid gases. MGE's Columbia and Elm Road Units are subject to MATs. Wisconsin has a separate mercury rule that will be phased out as MATs is implemented. The Elm Road Unit's current pollution controls and Columbia's planned mercury pollution controls (baghouse and scrubbers) are expected to allow both facilities to comply with the MATs rule (see the discussion regarding Columbia environmental project below).

GHG New Source Performance Standards (NSPS) for New and Existing Electric Generating Units

In a June 2013 directive, President Obama instructed the EPA to re-propose greenhouse gas standards for new power plants, based on comments received on their original rule proposal issued in March 2012, and to finalize those standards in a timely manner. The EPA developed proposed standards for new power plants in September 2013, which 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. 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 this rule in 2014.

National Ambient Air Quality Standards (NAAQS)

The EPA has announced that they will be reviewing all of their NAAQS in 2014. Changes in NAAQS can affect the determination as to whether an area is designated as nonattainment, which can affect permitting, capital expenditures and operating costs for emission sources in those nonattainment areas. MGE will be monitoring the outcome of this planned review to evaluate whether changes affect our operations. MGE continues to monitor NAAQS closely because our generation facilities in areas designated as nonattainment for a NAAQS may have additional permitting requirements, including compliance demonstrations and/or equipment installations.

In addition the EPA has developed draft SO₂ NAAQS technical documents as guidance to states for classifying areas as attainment or nonattainment. The documents provide guidance for monitoring and/or modeling to determine SO₂ levels. We are currently unable to assess operational or capital costs associated with adoption of the final guidance as it has not been adopted by the State of Wisconsin. We will be monitoring State of Wisconsin actions to better evaluate the effect it may have on our Columbia and the Elm Road Units.

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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

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. WPL, the plant operator, currently estimates that MGE's share of the capital expenditures required for this project is approximately $135 million. The project is underway and estimated to be completed in mid-2014.

MGE's share of various contractual commitments entered for the project as of December 31, 2013, is $14.7 million. These costs are expected to be capitalized and included in the consolidated balance sheets of MGE Energy and MGE. See Footnote 20 for further information regarding the Columbia environmental construction project.

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, 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 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.

e.

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.

f.

Elm Road - MGE Energy and MGE.

The warranty periods for both of the Elm Road Units have expired. During 2013, WEPCO and Bechtel (the construction contractor for the Elm Road Units) were working through the outstanding warranty claims. The warranty claim for the costs incurred to repair steam turbine corrosion damage identified on both units was resolved through a binding arbitration in June 2013. Final acceptance of the Elm Road Units occurred in June 2013 after all requirements stated in the contract with Bechtel were satisfied.

g.

Other Commitments.

MGE Energy holds investments in nonpublic entities. From time to time, these entities require additional capital infusions from their investors. MGE Energy has committed to contribute $1.7 million in capital for such infusions. The timing of these infusions is dependent on the needs of the investee and is therefore uncertain at this time.

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In addition, MGE Energy has a three year agreement with a venture debt fund expiring in December 2016. MGE Energy has committed to invest up to a total of $1.0 million into this fund. As of December 31, 2013, MGE Energy has $0.5 million remaining in commitments. The timing of infusions is dependent on the needs of the fund and is therefore uncertain at this time.

MGE has several other commitments related to various projects. Payments for these commitments are expected to be as follows:

(In thousands)		2014		2015		2016		2017		2018		Thereafter
Other Commitments	$	1,473	$	474	$	475	$	433	$	435	$	6,961

19.

Asset Retirement Obligations - MGE Energy and MGE.

MGE recorded an obligation for the fair value of its legal liability for asset retirement obligations (AROs) associated with removal of the West Campus Cogeneration Facility and the Elm Road generating units, electric substations, combustion turbine generating units, wind generating facilities, and photovoltaic generating facilities, all of which are located on property not owned by MGE Energy and MGE and would need to be removed upon the ultimate end of the associated leases. The significant conditional AROs identified by MGE included the costs of abandoning in place gas services and mains, the abatement and disposal of equipment and buildings contaminated with asbestos and PCBs, and the proper disposal and removal of tanks, batteries, and underground cable. Changes in management's assumptions regarding settlement dates, settlement methods, or assigned probabilities could have a material effect on the liabilities recorded by MGE at December 31, 2013, as well as the regulatory asset recorded.

MGE also may have AROs relating to the removal of various assets, such as certain electric and gas distribution facilities. These facilities are generally located on property owned by third parties, on which MGE is permitted to operate by lease, permit, easement, license, or service agreement. The asset retirement obligations associated with these facilities cannot be reasonably determined due to the indeterminate life of the related agreements.

The following table shows a rollforward of the AROs from January 1, 2012, to December 31, 2013. Amounts include conditional AROs.

(In thousands)		2013		2012
Balance at January 1,	$	18,768	$	19,173
Liabilities incurred		296		49
Accretion expense		1,015		1,021
Liabilities settled		(744)		(221)
Revisions in estimated cash flows(a)		24		(1,254)
Balance at December 31,	$	19,359	$	18,768

(a)

In 2012, MGE recorded a decrease in revisions in estimated cash flows of $1.3 million based on revised asbestos abatement estimates.

20.

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, 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 $135 million. As of December 31, 2013, MGE had accumulated $120.9 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 expects to incur capital expenditures of $14 million in 2014. This amount may change as a result of modifications to the project estimate or timing differences. MGE has recognized $2.7 million and $1.4 million (after tax) in AFUDC equity related to this project for the years ended December 31, 2013 and 2012, respectively.

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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. For 2014, the PSCW authorized MGE 100% AFUDC on this project during construction.

21.

Adoption of Accounting Principles and Recently Issued 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 16 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 became 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 became 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.

22.

Segment Information - MGE Energy and MGE.

The electric utility business purchases, generates and distributes electricity, and contracts for transmission service. The gas utility business purchases and distributes natural gas and contracts for the transportation of natural gas. Both the electric and gas segments operate through MGE Energy's principal subsidiary, MGE.

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The nonregulated energy operations are conducted through MGE Energy's subsidiaries: MGE Power, MGE Power Elm Road, and MGE Power West Campus. These subsidiaries own and lease electric generating capacity to assist MGE. MGE Power Elm Road has an ownership interest in two coal-fired generating units in Oak Creek, Wisconsin, which are leased to MGE, and MGE Power West Campus owns a controlling interest in the electric

generation plant of a natural gas-fired cogeneration facility on the UW campus. MGE Power West Campus's portion is also leased to MGE.

The transmission investment segment invests, through MGE Transco, in ATC, a company that provides electric transmission services primarily in Wisconsin. See Footnote 4 for further discussion of MGE Transco and the investment in ATC.

The "All Others" segment includes: corporate, CWDC, MAGAEL, MGE Construct, NGV Fueling Services, and North Mendota. These entities' operations consist of investing in companies and property which relate to the regulated operations, financing the regulated operations, or owning and operating natural gas compression equipment.

General corporate expenses include the cost of executive management, corporate accounting and finance, information technology, risk management, human resources and legal functions, and employee benefits that are allocated to electric and gas segments based on formulas prescribed by the PSCW. Identifiable assets are those used in MGE's operations in each segment. Assets not allocated consist primarily of cash and cash equivalents, restricted cash, investments, other accounts receivable, and prepaid assets.

Sales between our electric and gas segments are based on PSCW approved tariffed rates. Additionally, intersegment operations related to the leasing arrangement between our electric segment and MGE Power Elm Road/MGE Power West Campus are based on terms previously approved by the PSCW. Consistent with internal reporting, management has presented the direct financing capital leases between MGE and MGE Power Elm Road/MGE Power West Campus based on actual lease payments included in rates. Lease payments made by MGE to MGE Power Elm Road and MGE Power West Campus are shown as operating expenses. The lease payments received by MGE Power Elm Road and MGE Power West Campus from MGE are shown as lease income in interdepartmental revenues. The depreciation expense associated with the Elm Road Units and WCCF is reflected in the nonregulated energy segment.

96

The following table shows segment information for MGE Energy's and MGE's operations:

(In thousands)		Electric		Gas		Non- Regulated Energy		Transmission Investment		All Others		Consolidation/ Elimination Entries		Consolidated Total
MGE Energy
Year Ended December 31, 2013
Operating revenues	$	403,957	$	181,462	$	5,468	$	-	$	-	$	-	$	590,887
Interdepartmental revenues		537		12,629		42,591		-		-		(55,757)		-
Total operating revenues		404,494		194,091		48,059		-		-		(55,757)		590,887
Depreciation and amortization		(25,780)		(5,898)		(7,156)		-		(4)		-		(38,838)
Other operating expenses		(316,277)		(162,661)		(128)		(1)		(752)		55,757		(424,062)
Operating income (loss)		62,437		25,532		40,775		(1)		(756)		-		127,987
Other (deductions) income, net		3,062		59		-		9,434		(1,854)		-		10,701
Interest (expense) income, net		(9,645)		(2,986)		(6,400)		-		107		-		(18,924)
Income (loss) before taxes		55,854		22,605		34,375		9,433		(2,503)		-		119,764
Income tax (provision) benefit		(19,176)		(9,168)		(13,682)		(3,796)		963		-		(44,859)
Net income (loss)	$	36,678	$	13,437	$	20,693	$	5,637	$	(1,540)	$	-	$	74,905
Year Ended December 31, 2012
Operating revenues	$	392,365	$	139,727	$	9,231	$	-	$	-	$	-	$	541,323
Interdepartmental revenues		487		12,814		34,714		-		-		(48,015)		-
Total operating revenues		392,852		152,541		43,945		-		-		(48,015)		541,323
Depreciation and amortization		(26,031)		(5,569)		(7,107)		-		-		-		(38,707)
Other operating expenses		(300,149)		(136,567)		(121)		-		(1,031)		48,015		(389,853)
Operating income (loss)		66,672		10,405		36,717		-		(1,031)		-		112,763
Other (deductions) income, net		1,145		323		-		9,080		(479)		-		10,069
Interest (expense) income, net		(10,189)		(2,874)		(6,537)		-		133		-		(19,467)
Income (loss) before taxes		57,628		7,854		30,180		9,080		(1,377)		-		103,365
Income tax (provision) benefit		(20,906)		(2,769)		(12,113)		(3,648)		517		-		(38,919)
Net income (loss)	$	36,722	$	5,085	$	18,067	$	5,432	$	(860)	$	-	$	64,446
Year Ended December 31, 2011
Operating revenues	$	375,858	$	165,271	$	5,253	$	-	$	-	$	-	$	546,382
Interdepartmental revenues		495		12,440		38,148		-		-		(51,083)		-
Total operating revenues		376,353		177,711		43,401		-		-		(51,083)		546,382
Depreciation and amortization		(28,323)		(5,593)		(7,026)		-		-		-		(40,942)
Other operating expenses		(292,080)		(155,444)		(174)		-		(957)		51,083		(397,572)
Operating income (loss)		55,950		16,674		36,201		-		(957)		-		107,868
Other income, net		71		20		-		8,614		509		-		9,214
Interest (expense) income, net		(10,849)		(3,060)		(6,331)		-		78		-		(20,162)
Income (loss) before taxes		45,172		13,634		29,870		8,614		(370)		-		96,920
Income tax (provision) benefit		(15,334)		(5,249)		(11,988)		(3,467)		46		-		(35,992)
Net income (loss)	$	29,838	$	8,385	$	17,882	$	5,147	$	(324)	$	-	$	60,928

97

(In thousands)		Electric		Gas		Non- Regulated Energy		Transmission Investment		Consolidation/ Elimination Entries		Consolidated Total
MGE
Year Ended December 31, 2013
Operating revenues	$	403,980	$	181,477	$	5,468	$	-	$	-	$	590,925
Interdepartmental revenues		514		12,614		42,591		-		(55,719)		-
Total operating revenues		404,494		194,091		48,059		-		(55,719)		590,925
Depreciation and amortization		(25,780)		(5,898)		(7,156)		-		-		(38,834)
Other operating expenses*		(335,059)		(171,717)		(13,810)		(1)		55,719		(464,868)
Operating income (loss)*		43,655		16,476		27,093		(1)		-		87,223
Other (deductions) income, net*		2,668		(53)		-		5,638		-		8,253
Interest expense, net		(9,645)		(2,986)		(6,400)		-		-		(19,031)
Net income		36,678		13,437		20,693		5,637		-		76,445
Less: Net income attributable to
noncontrolling interest, net of tax		-		-		-		-		(27,438)		(27,438)
Net income attributable to MGE	$	36,678	$	13,437	$	20,693	$	5,637	$	(27,438)	$	49,007
Year Ended December 31, 2012
Operating revenues	$	392,365	$	139,727	$	9,231	$	-	$	-	$	541,323
Interdepartmental revenues		487		12,814		34,714		-		(48,015)		-
Total operating revenues		392,852		152,541		43,945		-		(48,015)		541,323
Depreciation and amortization		(26,031)		(5,569)		(7,107)		-		-		(38,707)
Other operating expenses*		(320,701)		(139,236)		(12,234)		-		48,015		(424,156)
Operating income*		46,120		7,736		24,604		-		-		78,460
Other income, net*		791		223		-		5,432		-		6,446
Interest expense, net		(10,189)		(2,874)		(6,537)		-		-		(19,600)
Net income		36,722		5,085		18,067		5,432		-		65,306
Less: net income attributable to
noncontrolling interest, net of tax		-		-		-		-		(24,489)		(24,489)
Net income attributable to MGE	$	36,722	$	5,085	$	18,067	$	5,432	$	(24,489)	$	40,817
Year Ended December 31, 2011
Operating revenues	$	375,858	$	165,271	$	5,253	$	-	$	-	$	546,382
Interdepartmental revenues		495		12,440		38,148		-		(51,083)		-
Total operating revenues		376,353		177,711		43,401		-		(51,083)		546,382
Depreciation and amortization		(28,323)		(5,593)		(7,026)		-		-		(40,942)
Other operating expenses*		(307,193)		(160,631)		(12,162)		-		51,083		(428,903)
Operating income*		40,837		11,487		24,213		-		-		76,537
Other (deductions) income, net*		(150)		(42)		-		5,147		-		4,955
Interest expense, net		(10,849)		(3,060)		(6,331)		-		-		(20,240)
Net income		29,838		8,385		17,882		5,147		-		61,252
Less: Net income attributable to
noncontrolling interest, net of tax		-		-		-		-		(23,970)		(23,970)
Net income attributable to MGE	$	29,838	$	8,385	$	17,882	$	5,147	$	(23,970)	$	37,282
*Amounts are shown net of the related tax expense, consistent with the presentation on the consolidated MGE Income Statement.

98

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

		Utility							Consolidated
(In thousands)		Electric		Gas		Assets not Allocated		Nonregulated Energy			Transmission Investment		All Others	Consolidation/ Elimination Entries			Total
MGE Energy
Assets:
December 31, 2013	$	899,257	$	265,694	$	19,853	$	288,116		$	64,504	$	431,436	$	(389,800)	$	1,579,060
December 31, 2012		888,444		285,468		18,559		323,216			61,064		413,291		(403,118)		1,586,924
December 31, 2011		794,738		285,702		32,882		299,421			57,006		401,862		(412,729)		1,458,882
Capital Expenditures:
Year ended Dec. 31, 2013	$	100,146	$	15,554	$	-	$	3,347		$	-	$	-	$	-	$	119,047
Year ended Dec. 31, 2012		81,965		13,812		-		2,658			-		-		-		98,435
Year ended Dec. 31, 2011		47,206		15,830		-		2,140			-		-		-		65,176

		Utility						Consolidated
(In thousands)		Electric		Gas		Assets not Allocated		Nonregulated Energy		Transmission Investment	Consolidation/ Elimination Entries			Total
MGE
Assets:
December 31, 2013	$	899,257	$	265,694	$	19,853	$	288,066	$	64,504	$	(6,731)	$	1,530,643
December 31, 2012		888,444		285,468		18,559		323,166		61,064		(23,050)		1,553,651
December 31, 2011		794,738		285,702		32,882		299,171		57,006		(35,706)		1,433,793
Capital Expenditures:
Year ended Dec. 31, 2013	$	100,146	$	15,554	$	-	$	3,347	$	-	$	-	$	119,047
Year ended Dec. 31, 2012		81,965		13,812		-		2,658		-		-		98,435
Year ended Dec. 31, 2011		47,206		15,830		-		2,140		-		-		65,176

23.

Quarterly Summary of Operations - MGE Energy (unaudited).

(In thousands, except per share amounts)		Quarters Ended
2013		March 31		June 30		September 30		December 31
Operating revenues:
Regulated electric revenues	$	93,494	$	96,846	$	119,836	$	93,781
Regulated gas revenues		72,467		30,042		18,864		60,089
Nonregulated revenues		1,276		1,400		1,399		1,393
Total Operating Revenues		167,237		128,288		140,099		155,263
Operating expenses		129,609		103,791		100,199		129,301
Operating income		37,628		24,497		39,900		25,962
Interest and other income, net		(1,366)		(1,946)		(855)		(4,056)
Income tax provision		(13,678)		(8,660)		(14,692)		(7,829)
Earnings on common stock	$	22,584	$	13,891	$	24,353	$	14,077
Earnings per common share	$	0.65	$	0.40	$	0.70	$	0.41
Dividends per share	$	0.263	$	0.263	$	0.272	$	0.272
2012
Operating revenues:
Regulated electric revenues	$	89,936	$	96,339	$	118,914	$	87,176
Regulated gas revenues		57,019		18,629		16,587		47,492
Nonregulated revenues		2,304		2,253		2,337		2,337
Total Operating Revenues		149,259		117,221		137,838		137,005
Operating expenses		120,815		92,140		97,950		117,655
Operating income		28,444		25,081		39,888		19,350
Interest and other income, net		(2,534)		(2,215)		(1,993)		(2,656)
Income tax provision		(9,862)		(8,596)		(14,253)		(6,208)
Earnings on common stock	$	16,048	$	14,270	$	23,642	$	10,486
Earnings per common share	$	0.47	$	0.41	$	0.68	$	0.30
Dividends per share	$	0.255	$	0.255	$	0.263	$	0.263

99

Notes:

·

The quarterly results of operations within a year may not be comparable because of seasonal and other factors.

·

The sum of earnings per share of common stock for any four quarters may vary slightly from the earnings per share of common stock for the equivalent twelve-month period due to rounding.

·

MGE Energy's operations are based primarily on its utility subsidiary MGE.

·

Per share amounts for all periods presented reflect the three-for-two stock split declared on December 20, 2013, effective in the form of a stock dividend distributed on February 7, 2014.

24.

Related Party Transactions - MGE Energy and MGE.

ATC

During 2013, 2012, and 2011, MGE recorded $27.7 million, $25.3 million, and $25.0 million, respectively, for transmission services received from ATC. MGE also provides a variety of operational, maintenance, and project management work for ATC, which is reimbursed by ATC. For the years ended December 31, 2013, 2012, and 2011, MGE had a receivable due from ATC of $0.2 million.

For additional discussion on MGE's relationship with ATC, see Footnote 4.

100

Item 9. Changes in and Disagreements with Accountants on Accounting and Financial Disclosure.

MGE Energy and MGE

None.

Item 9A. Controls and Procedures.

MGE Energy and MGE

Conclusion Regarding the Effectiveness of Disclosure Controls and Procedures

During the fourth 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 its principal executive officer and its principal financial officer, 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 December 31, 2013, the principal executive officer and principal financial officer of each registrant concluded that such registrant's disclosure controls and procedures (as defined in Rules 13a-15(e) and 15d-15(e) under the Securities Exchange Act of 1934) were effective to accomplish their objectives. 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 December 31, 2013, there were no changes in MGE Energy or MGE's internal controls over financial reporting that materially affected, or are reasonably likely to affect materially, MGE Energy or MGE's internal control over financial reporting.

MGE Energy and MGE

Management of MGE Energy and MGE are required to assess and report on the effectiveness of its internal control over financial reporting as of December 31, 2013. As a result of that assessment, management determined that there were no material weaknesses as of December 31, 2013 and, therefore, concluded that MGE Energy and MGE's internal control over financial reporting was effective. Management's Report on Internal Control Over Financial Reporting is included in Item 8. - Financial Statements and Supplementary Data.

Item 9B. Other Information.

MGE Energy

None.

101

PART III.

Item 10. Directors, Executive Officers, and Corporate Governance.

MGE Energy

The information required by Item 10 relating to directors and nominees for election as directors at MGE Energy's annual meeting of shareholders is incorporated herein by reference to the information under the heading "ELECTION OF DIRECTORS" in MGE Energy's definitive proxy statement (2014 Proxy Statement) to be filed with the SEC on or before March 28, 2014. Information relating to compliance with Section 16(a) of the Securities Exchange Act of 1934 is incorporated herein by reference to the information under the heading "BENEFICIAL OWNERSHIP - Section 16(a) Beneficial Ownership Reporting Compliance" in the 2014 Proxy Statement.

The information required by Item 10 relating to executive officers is set forth above in Item 1. Business - Executive Officers of the Registrants.

Code of Ethics

MGE Energy has adopted a Code of Ethics applicable to its directors and all of its employees, including its chief executive officer, chief financial officer, and principal accounting officer. The Code of Ethics is available on MGE Energy's website at www.mgeenergy.com.

Item 11. Executive Compensation.

See Item 12.

Item 12. Security Ownership of Certain Beneficial Owners and Management and Related Stockholder Matters.

MGE Energy

The required information for Items 11 and 12 is included in the 2014 Proxy Statement, which will be filed with the SEC on or before March 28, 2014, under the section "EXECUTIVE COMPENSATION," not including "Compensation Committee Report," and "Company Performance," and under the section "BENEFICIAL OWNERSHIP," which is incorporated herein by reference.

MGE Energy does not have or maintain any equity compensation plans.

Item 13. Certain Relationships and Related Transactions, and Director Independence.

MGE Energy

The information required by Item 13 is incorporated by reference herein from the "BOARD OF DIRECTORS INFORMATION" section in the 2014 Proxy Statement, which will be filed with the SEC on or before March 28, 2014.

102

Item 14. Principal Accounting Fees and Services.

MGE Energy

The information required by Item 14 is incorporated herein by reference to the information under the heading "RATIFICATION OF PRICEWATERHOUSECOOPERS LLP AS OUR INDEPENDENT REGISTERED PUBLIC ACCOUNTING FIRM" in the 2014 Proxy Statement, which will be filed with the SEC on or before March 28, 2014.

MGE

Independent Registered Public Accounting Firm Fees Disclosure

		2013		2012
Audit Fees:
Audit of financial statements and internal controls	$	735,399	$	650,661
Review of SEC filings, comfort letters and comment letters		-		7,034
Total Audit Fees	$	735,399	$	657,695
Audit-Related Fees:
Services rendered for Department of Energy grant compliance audit	$	50,000	$	45,901
Services rendered for utility commission-mandated obligations		50,000		36,000
Total Audit-Related Fees	$	100,000	$	81,901
Tax Fees:
Services rendered on prefunding postretirement prescription drug benefit	$	2,300	$	77,700
Services rendered to change tax method of accounting for repairs		-		74,938
Review of federal and state income tax returns		43,113		37,893
Services rendered on bonus depreciation		-		34,450
Total Tax Fees	$	45,413	$	224,981
All Other Fees:
Power Plant system implementation assurance review	$	106,687	$	80,139
Generation projects advisory services		83,885		1,750
Fee to access online accounting standards library		3,600		3,600
Total All Other Fees	$	194,172	$	85,489

MGE is a wholly owned subsidiary of MGE Energy and does not have a separate audit committee. Instead, that function is fulfilled for MGE by the MGE Energy Audit Committee. The Audit Committee approves each engagement of the independent registered public accounting firm to render any audit or nonaudit services before the firm is engaged to render those services. The Chair of the Audit Committee or other designated Audit Committee member may represent the entire Audit Committee for purposes of this approval. Any services approved by the Chair or other designated Audit Committee member are reported to the full Audit Committee at the next scheduled Audit Committee meeting. No de minimis exceptions to this approval process are allowed under the Audit Committee Charter; and thus, none of the services described in the preceding table were approved pursuant to Rule 2-01(c)(7)(i)(C) of Regulation S-X.

103

PART IV.

Item 15. Exhibits and Financial Statement Schedules.

(a) 1. Financial Statements.

MGE Energy
Report of Independent Registered Public Accounting Firm	47
Consolidated Statements of Income for the years ended December 31, 2013, 2012, and 2011	49
Consolidated Statements of Comprehensive Income for the years ended December 31, 2013, 2012, and 2011	49
Consolidated Statements of Cash Flows for the years ended December 31, 2013, 2012, and 2011	50
Consolidated Balance Sheets as of December 31, 2013 and 2012	51
Consolidated Statements of Common Equity as of December 31, 2013, 2012, and 2011	52
Notes to Consolidated Financial Statements	57
MGE
Report of Independent Registered Public Accounting Firm	48
Consolidated Statements of Income for the years ended December 31, 2013, 2012, and 2011	53
Consolidated Statements of Comprehensive Income for the years ended December 31, 2013, 2012, and 2011	53
Consolidated Statements of Cash Flows for the years ended December 31, 2013, 2012, and 2011	54
Consolidated Balance Sheets as of December 31, 2013 and 2012	55
Consolidated Statements of Common Equity as of December 31, 2013, 2012, and 2011	56
Notes to Consolidated Financial Statements	57

2.

Financial Statement Schedule.

Schedule I – Condensed Parent Company Financial Statements.

Schedule II – Valuation and Qualifying Accounts for MGE Energy, Inc. and Madison Gas and Electric Company.

All other schedules have been omitted because they are not applicable or not required, or because the required information is shown in the consolidated financial statements or notes thereto.

3.

All Exhibits Including Those Incorporated by Reference.

Exhibits. Several of the following exhibits are incorporated herein by reference under Rule 12b-32 of the Securities Exchange Act of 1934, as amended, as indicated by the parenthetical reference. Several other instruments, which would otherwise be required to be listed below, have not been so listed because those instruments do not authorize securities in an amount that exceeds 10% of the total assets of the applicable registrant and its subsidiaries on a consolidated basis. The relevant registrant agrees to furnish a copy of any instrument that was so omitted on that basis to the Commission upon request.

3.1

Amended and Restated Articles of Incorporation of MGE Energy, Inc. (Exhibit 3.1 to MGE Energy's Registration Statement on Form S-4, Registration No. 333-72694.)

3.2

Amended and Restated Bylaws of MGE Energy, Inc. (Exhibit 3.2 to MGE Energy's Registration Statement on Form S-4, Registration No. 333-72694.)

3.3

Restated Articles of Incorporation of Madison Gas and Electric Company as in effect at October 25, 2012. (Exhibit 3.1 to Form 8-K dated October 25, 2012, File No. 0-1125.)

3.4

Amended Bylaws of Madison Gas and Electric Company as in effect at August 16, 2002. (Exhibit 3.4 to Form 10-K for year ended December 31, 2002, File No. 0-1125.)

4.1

Indenture of Mortgage and Deed of Trust between Madison Gas and Electric Company and U.S. Bank, N.A. (successor to First Wisconsin Trust Company), as Trustee, dated as of January 1, 1946. (Exhibit 7-D to Registration Statement, Registration No. 2-6059.)

4.2

Supplemental Indenture dated as of February 1, 1993 to aforementioned Indenture of Mortgage and Deed of Trust. (Exhibit 4F to Form 10-K for year ended December 31, 1992, File No. 0-1125.)

104

4.3

Indenture between Madison Gas and Electric Company and The Bank of New York Mellon Trust Company, N.A. (as successor to Bank One, N.A.), as Trustee, dated as of September 1, 1998. (Exhibit 4B to Form 10-K for year ended December 31, 1999, File No. 0-1125.)

10.1

Credit Agreement dated as of July 30, 2010, among MGE Energy, Inc., the Lenders party thereto and JPMorgan Chase Bank, N.A., as Administrative Agent. (Exhibit 10.1 to Form 10-Q for the quarter ended June 30, 2010, File No. 0-49965.)

10.2

Third Amendment dated as of June 19, 2013, to Credit Agreement dated as of July 30, 2010, among MGE Energy, Inc., various financial institutions, and JPMorgan Chase Bank, N.A., as Administrative Agent. (Exhibit 10.1 to Form 8-K dated June 27, 2013, File No. 0-49965.)

10.3

Credit Agreement dated as of July 30, 2010, among Madison Gas and Electric Company, the Lenders party thereto and JPMorgan Chase Bank, N.A., as Administrative Agent. (Exhibit 10.2 to Form 10-Q for the quarter ended June 30, 2010, File No. 0-1125.)

10.4

Third Amendment dated as of June 19, 2013, to Credit Agreement dated as of July 30, 2010, among Madison Gas and Electric Company, various financial institutions, and JPMorgan Chase Bank, N.A., as Administrative Agent. (Exhibit 10.2 to Form 8-K dated June 27, 2013, File No. 0-1125.)

10.5

Copy of Joint Power Supply Agreement with Wisconsin Power and Light Company and Wisconsin Public Service Corporation dated February 2, 1967. (Exhibit 4.09 to Registration Statement, Registration No. 2-27308.)

10.6

Copy of Joint Power Supply Agreement (Exclusive of Exhibits) with Wisconsin Power and Light Company and Wisconsin Public Service Corporation dated July 26, 1973. (Exhibit 5.04A to Registration Statement, Registration No. 2-48781.)

10.7

Copy of Amended and Restated Agreement for Construction and Operation of Columbia Generating Plant dated January 17, 2007. (Exhibit 10.9 to Form 10-K for the year ended December 31, 2006, File No. 0-1125.)

10.8

West Campus Cogeneration Facility Joint Ownership Agreement, dated as of October 13, 2003, among MGE Power West Campus, LLC, The Board of Regents of the University of Wisconsin System, and the State of Wisconsin, as Joint Owners. (Exhibit 10.19 to Form 10-Q for the quarter ended September 30, 2005, File No. 0-1125.)

10.9

West Campus Cogeneration Facility Operation and Maintenance Agreement, dated as of October 13, 2003, among Madison Gas and Electric Company, as Operator, and the Board of Regents of the University of Wisconsin System, as Joint Owner. (Exhibit 10.20 to Form 10-Q for the quarter ended September 30, 2005, File No. 0-1125.)

10.10

West Campus Cogeneration Facility Lease Agreement, dated as of March 18, 2004, among MGE Power West Campus, LLC, as Lessor, and Madison Gas and Electric Company, as Lessee. (Exhibit 10.21 to Form 10-Q for the quarter ended September 30, 2005, File No. 0-1125.)

10.11

West Campus Cogeneration Facility Ground Lease, dated as of July 15, 2002, among MGE Power LLC, as Lessee, and the Board of Regents of the University of Wisconsin System, as Lessor. (Exhibit 10.22 to Form 10-Q for the quarter ended September 30, 2005, File No. 0-1125.)

10.12

West Campus Cogeneration Facility Amendment of Ground Lease, dated as of March 18, 2004, among MGE Power West Campus, LLC, as Lessee, and the Board of Regents of the University of Wisconsin System, as Lessor. (Exhibit 10.23 to Form 10-Q for the quarter ended September 30, 2005, File No. 0-1125.)

10.13

West Campus Cogeneration Facility MGE Ground Sublease, dated as of March 18, 2004, among MGE Power West Campus, LLC, as Lessee, and Madison Gas and Electric Company, as Lessor. (Exhibit 10.24 to Form 10-Q for the quarter ended September 30, 2005, File No. 0-1125.)

105

10.14

Elm Road Generating Station Common Facilities Operating and Maintenance Agreement, dated as of December 17, 2004, among Madison Gas and Electric Company, Wisconsin Electric Power Company, and Wisconsin Public Power Inc., as Lessee/Owner Parties, and Wisconsin Electric Power Company, as Operating Agent. (Exhibit 10.7 to Form 10-Q for the quarter ended September 30, 2005, File No. 0-1125.)

10.15

Elm Road Generating Station New Common Facilities Ownership Agreement, dated as of December 17, 2004, among MGE Power Elm Road, LLC, Elm Road Generating Station Supercritical, LLC, and Wisconsin Public Power Inc., as Joint Owners. (Exhibit 10.8 to Form 10-Q for the quarter ended September 30, 2005, File No. 0-1125.)

10.16

Elm Road Generating Station I Ownership Agreement, dated as of December 17, 2004, among MGE Power Elm Road, LLC, Elm Road Generating Station Supercritical, LLC, and Wisconsin Public Power Inc., as Joint Owners, Elm Road Services, LLC, as Project Manager, and W.E. Power LLC. (Exhibit 10.9 to Form 10-Q for the quarter ended September 30, 2005, File No. 0-1125.)

10.17

Elm Road Generating Station I Facility Lease Agreement, dated as of November 4, 2005, among MGE Power Elm Road, LLC, as Lessor, and Madison Gas and Electric Company, as Lessee. (Exhibit 10.10 to Form 10-Q for the quarter ended September 30, 2005, File No. 0-1125.)

10.18

Elm Road Generating Station I Operating and Maintenance Agreement, dated as of December 17, 2004, among Madison Gas and Electric Company, Wisconsin Electric Power Company, and Wisconsin Public Power Inc., as Lessee/ Owners, and Wisconsin Electric Power Company, as Operating Agent. (Exhibit 10.11 to Form 10-Q for the quarter ended September 30, 2005, File No. 0-1125.)

10.19

Elm Road Generating Station I Easement and Indemnification Agreement, dated as of December 17, 2004, among MGE Power Elm Road, LLC and Wisconsin Public Power Inc., as Grantees, and Wisconsin Electric Power Company, as Grantor. (Exhibit 10.12 to Form 10-Q for the quarter ended September 30, 2005, File No. 0-1125.)

10.20

Assignment and Assumption Agreement, dated as of November 4, 2005 between MGE Power Elm Road, LLC and Madison Gas and Electric Company relating to Elm Road Generating Station I Easement and Indemnification Agreement, dated as of December 17, 2004, among MGE Power Elm Road, LLC and Wisconsin Public Power Inc., as Grantees, and Wisconsin Electric Power Company, as Grantor. (Exhibit 10.16 to Form 10-K for the year ended December 31, 2005, File No. 0-1125.)

10.21

Elm Road Generating Station II Ownership Agreement, dated as of December 17, 2004, among MGE Power Elm Road, LLC, Elm Road Generating Station Supercritical, LLC, and Wisconsin Public Power Inc., as Joint Owners, Elm Road Services, LLC, as Project Manager, and W.E. Power LLC. (Exhibit 10.13 to Form 10-Q for the quarter ended September 30, 2005, File No. 0-1125.)

10.22

Elm Road Generating Station II Facility Lease Agreement, dated as of November 4, 2005, among MGE Power Elm Road, LLC, as Lessor, and Madison Gas and Electric Company, as Lessee. (Exhibit 10.14 to Form 10-Q for the quarter ended September 30, 2005, File No. 0-1125.)

10.23

Elm Road Generating Station II Operating and Maintenance Agreement, dated as of December 17, 2004, among Madison Gas and Electric Company, Wisconsin Electric Power Company, and Wisconsin Public Power Inc., as Lessee/ Owners, and Wisconsin Electric Power Company, as Operating Agent. (Exhibit 10.15 to Form 10-Q for the quarter ended September 30, 2005, File No. 0-1125.)

10.24

Elm Road Generating Station II Easement and Indemnification Agreement, dated as of December 17, 2004, among MGE Power Elm Road, LLC and Wisconsin Public Power Inc., as Grantees, and Wisconsin Electric Power Company, as Grantor. (Exhibit 10.16 to Form 10-Q for the quarter ended September 30, 2005, File No. 0-1125.)

10.25

Operating Agreement, dated as of October 28, 2005, among MGE Energy, Inc., Madison Gas and Electric Company, and MGE Transco Investment LLC. (Exhibit 10.17 to Form 10-Q for the quarter ended September 30, 2005, File No. 0-1125.)

106

10.26

Substation and Transformer Shared Use Agreement and Easement Agreement, dated as of September 29, 2006, among Madison Gas and Electric Company and Northern Iowa Windpower II LLC as Joint Owners. (Exhibit 10.6 to Form 10-Q for the quarter ended September 30, 2006, File No. 0-1125.)

10.27

Management and Administration Agreement, dated as of October 13, 2006, among Madison Gas and Electric Company as Owner and Midwest Renewable Energy Resources, LLC as Manager. (Exhibit 10.7 to Form 10-Q for the quarter ended September 30, 2006, File No. 0-1125.)

10.28*

Form of Severance Agreement. (Exhibit 10.37 to Form 10-K for the year ended December 31, 2008, File No. 0-49965.)

10.29*

Form of Amendment to Severance Agreement. (Exhibit 10.29 to Form 10-K for the year ended December 31, 2010, File No. 0-49965.)

10.30*

Form of Deferred Compensation Agreement. (Exhibit 10.38 to Form 10-K for the year ended December 31, 2008, File No. 0-49965.)

10.31*

Form of Amended and Restated Deferred Compensation Agreement. (Exhibit 10.39 to Form 10-K for the year ended December 31, 2008, File No. 0-49965.)

10.32*

Form of Income Continuation Agreement. (Exhibit 10.40 to Form 10-K for the year ended December 31, 2008, File No. 0-49965.)

10.33*

MGE Energy, Inc., 2006 Performance Unit Plan. (Exhibit 10.41 to Form 10-K for the year ended December 31, 2008, File No. 0-49965.)

10.34*

Amendment Number One to MGE Energy, Inc., 2006 Performance Unit Plan, dated March 18, 2011. (Exhibit 10.2 to Form 8-K dated March 24, 2011, File No. 0-49965.)

10.35*

Form of Performance Unit Award Agreement. (Exhibit 10.42 to Form 10-K for the year ended December 31, 2008, File No. 0-49965.)

10.36*

Form of Amendment to Performance Unit Award Agreement. (Exhibit 10.1 to Form 8-K dated April 15, 2011, File No. 0-49965.)

10.37*

MGE Energy, Inc., 2013 Director Incentive Plan.

10.38*

Form of 2013 Director Incentive Plan Award Agreement.

12

Statements regarding computation of ratio of earnings to fixed charges:

12.1

MGE Energy, Inc.

12.2

Madison Gas and Electric Company

21

Subsidiaries of MGE Energy, Inc.

23

Consent of Independent Registered Public Accounting Firm

23.1

MGE Energy, Inc.

23.2

Madison Gas and Electric Company

31

Certifications Pursuant to Rule 13a-14(a) and 15d-14(a) of the Securities Exchange Act of 1934 as to the Annual Report on Form 10-K for the year ended December 31, 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

107

32

Certifications Pursuant to Section 1350 of Chapter 63 of Title 18 United States Code (Sarbanes-Oxley Act of 2002) as to the Annual Report on Form 10-K for the year ended December 31, 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

*

Indicates a management contract or compensatory plan or arrangement.

108

Schedule I

Condensed Parent Company Financial Statements

MGE Energy, Inc.

Statements of Comprehensive Income

(Parent Company Only)

(In thousands)

		For the years ended December 31,
		2013		2012		2011
Operating Expenses:
Other operations and maintenance	$	613	$	649	$	718
Total Operating Expenses		613		649		718
Operating Loss		(613)		(649)		(718)
Equity in earnings of investments		76,362		65,132		61,075
Other income/(loss), net		(1,863)		(496)		505
Other interest		55		45		(22)
Income before income taxes		73,941		64,032		60,840
Income tax provision		964		414		88
Net Income		74,905		64,446		60,928
Other Comprehensive Income (Loss), Net of Tax:
Unrealized gain (loss) on available-for-sale securities, net of
tax ($189, $12, and $10)		283		(18)		(15)
Reclassification of realized gain on available-for-sale
securities, net of tax ($-, $-, and $10)		-		-		(15)
Comprehensive Income	$	75,188	$	64,428	$	60,898
The accompanying notes are an integral part of the above consolidated financial statements.

MGE Energy, Inc.

Statements of Cash Flows

(Parent Company Only)

(In thousands)

		For the years ended December 31,
		2013		2012		2011
Net Cash Flows Provided by Operating Activities	$	53,952	$	49,819	$	50,696
Investing Activities:
Return of investment - affiliates		-		-		30,000
Other investing		(2,425)		(1,558)		(3,022)
Cash Provided by (Used for) Investing Activities		(2,425)		(1,558)		26,978
Financing Activities:
Cash dividends paid on common stock		(37,107)		(35,951)		(35,026)
Change in short-term debt		-		-		(19,000)
Other financing		(97)		(49)		-
Cash Used for Financing Activities		(37,204)		(36,000)		(54,026)
Change in Cash and Cash Equivalents:		14,323		12,261		23,648
Cash and cash equivalents at beginning of period		36,881		24,620		972
Cash and cash equivalents at end of period	$	51,204	$	36,881	$	24,620
The accompanying notes are an integral part of the above consolidated financial statements.

109

Schedule I

Condensed Parent Company Financial Statements (continued)

MGE Energy, Inc.

Balance Sheets

(Parent Company Only)

(In thousands)

		At December 31,
ASSETS		2013		2012
Current Assets:
Cash and cash equivalents	$	51,204	$	36,881
Accounts receivable, net:
Accounts receivable from affiliates		125		795
Prepaid taxes and other		1,015		451
Total Current Assets		52,344		38,127
Other deferred assets and other		157		129
Investments:
Investments in affiliates		583,435		556,911
Other investments		948		787
Total Investments		584,383		557,698
Total Assets	$	636,884	$	595,954
LIABILITIES AND SHAREHOLDERS' EQUITY
Current Liabilities:
Accounts payable to affiliates	$	530	$	603
Accrued taxes		4,297		4,164
Other current liabilities		3,076		1,148
Total Current Liabilities		7,903		5,915
Other Credits:
Deferred income taxes		5,646		4,228
Accounts payable to affiliates		5,825		6,382
Total Other Credits		11,471		10,610
Shareholders' Equity:
Common shareholders' equity		350,936		350,936
Retained income		266,197		228,399
Other comprehensive income		377		94
Total Shareholders' Equity		617,510		579,429
Commitments and contingencies (see Footnote 18)		-		-
Total Liabilities and Shareholders' Equity	$	636,884	$	595,954
The accompanying notes are an integral part of the above consolidated financial statements.

110

Schedule I

Condensed Parent Company Financial Statements (continued)

Notes to Condensed Financial Statements

(Parent Company Only)

1.

Basis of Presentation.

MGE Energy is a holding company and conducts substantially all of its business operations through its subsidiaries. For Parent Company only presentation, investment in subsidiaries are accounted for using the equity method. These condensed Parent Company financial statements and related notes have been prepared in accordance with Rule 12-04, Schedule I of Regulation S-X. These statements should be read in conjunction with the financial statements and the notes in Item 8. Financial Statements and Supplementary Data of the Annual Report on Form 10-K for the year ended December 31, 2013.

2.

Credit Agreements.

As of December 31, 2013, MGE Energy had access to an unsecured, committed credit facility with aggregate bank commitments of $50.0 million. At December 31, 2013, no borrowings were outstanding under this facility.

See Footnote 10 of the Notes to Consolidated Financial Statements for further information regarding MGE Energy's credit agreements.

3.

Commitments and Contingencies.

See Footnote 18 of the Notes to Consolidated Financial Statements for commitments and contingencies.

4.

Dividends from Affiliates.

		Dividends from Affiliates
(In thousands)		2013		2012		2011
MGE	$	25,000	$	20,404	$	26,648
MGE Construct		-		239		-
MGE Power Elm Road		17,300		16,000		43,000
MGE Power		-		200		-
MGE Power West Campus		9,250		7,500		9,500
MGE Transco		816		-		-
Total	$	52,366	$	44,343	$	79,148

Dividend Restrictions

Dividend payments by MGE to MGE Energy are subject to restrictions arising under a PSCW rate order and, to a lesser degree, MGE's first mortgage bonds. The PSCW order restricts any dividends that MGE may pay MGE Energy if its common equity ratio, calculated in the manner used in the rate proceeding, is less than 55%. MGE's thirteen month rolling average common equity ratio at December 31, 2013, is 57.6% as determined under the calculation used in the rate proceeding. MGE paid cash dividends of $25.0 million to MGE Energy in 2013. The rate proceeding calculation includes as indebtedness imputed amounts for MGE's outstanding purchase power capacity payments and other PSCW adjustments, but does not include the indebtedness associated with MGE Power Elm Road or MGE Power West Campus, which are consolidated into MGE's financial statements but are not direct obligations of MGE.

MGE has covenanted with the holders of its first mortgage bonds not to declare or pay any dividend or make any other distribution on or purchase any shares of its common stock unless, after giving effect thereto, the aggregate amount of all such dividends and distributions and all amounts applied to such purchases, after December 31, 1945, shall not exceed the earned surplus (retained earnings) accumulated subsequent to December 31, 1945. As of December 31, 2013, approximately $305.6 million was available for the payment of dividends under this covenant.

See Footnotes 9 and 10 of the Notes to Consolidated Financial Statement for long-term debt and lines of credit dividend restrictions.

Stock Split

On December 20, 2013, MGE Energy's Board of Directors declared a three-for-two stock split of MGE Energy's common stock in the form of a stock dividend. The additional shares were distributed February 7, 2014 to all shareholders of record as of January 24, 2014. All share and per share data provided in this report give effect to this stock split.

111

Schedule II

MGE Energy, Inc. and Madison Gas and Electric Company

Valuation and Qualifying Accounts

			Additions
		Balance at beginning of period	(1) Charged to costs and expenses	(2) Charged to other accounts	Net Accounts written off		Balance at end of period
Fiscal Year 2011:
Accumulated provision for uncollectibles	$	4,588,675	2,174,729	49,500	(2,712,571)	$	4,100,333
Fiscal Year 2012:
Accumulated provision for uncollectibles	$	4,100,333	2,825,300	44,400	(2,153,915)	$	4,816,118
Fiscal Year 2013:
Accumulated provision for uncollectibles	$	4,816,118	2,373,342	37,200	(2,256,949)	$	4,969,711

112

Signatures - MGE Energy, Inc.

Pursuant to the requirements of Section 13 or 15(d) 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.
	(Registrant)
Date: February 27, 2014	/s/ Gary J. Wolter
	Chairman, President and Chief Executive Officer

Pursuant to the requirements of the Securities Exchange Act of 1934, this report has been signed below by the following persons on behalf of the registrant and in the capacities indicated on February 27, 2014.

/s/ Gary J. Wolter	Gary J. Wolter Chairman, President and Chief Executive Officer and Director (Principal Executive Officer)
/s/ Jeffrey C. Newman	Jeffrey C. Newman Vice President, Chief Financial Officer, Secretary and Treasurer (Principal Financial Officer and Principal Accounting Officer)
/s/ Mark D. Bugher	Mark D. Bugher, Director
/s/ Londa J. Dewey	Londa J. Dewey, Director
/s/ F. Curtis Hastings	F. Curtis Hastings, Director
/s/ Regina M. Millner	Regina M. Millner, Director
/s/ John R. Nevin	John R. Nevin, Director
/s/ James L. Possin	James L. Possin, Director
/s/ Thomas R. Stolper	Thomas R. Stolper, Director

113

Signatures - Madison Gas and Electric Company

Pursuant to the requirements of Section 13 or 15(d) 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
	(Registrant)
Date: February 27, 2014	/s/ Gary J. Wolter
	Chairman, President and Chief Executive Officer

Pursuant to the requirements of the Securities Exchange Act of 1934, this report has been signed below by the following persons on behalf of the registrant and in the capacities indicated on February 27, 2014.

/s/ Gary J. Wolter	Gary J. Wolter Chairman, President and Chief Executive Officer and Director (Principal Executive Officer)
/s/ Jeffrey C. Newman	Jeffrey C. Newman Vice President, Chief Financial Officer, Secretary and Treasurer (Principal Financial Officer and Principal Accounting Officer)
/s/ Mark D. Bugher	Mark D. Bugher, Director
/s/ Londa J. Dewey	Londa J. Dewey, Director
/s/ F. Curtis Hastings	F. Curtis Hastings, Director
/s/ Regina M. Millner	Regina M. Millner, Director
/s/ John R. Nevin	John R. Nevin, Director
/s/ James L. Possin	James L. Possin, Director
/s/ Thomas R. Stolper	Thomas R. Stolper, Director

114

EX-10

EXHIBIT 10.37

MGE ENERGY, INC.

2013 DIRECTOR INCENTIVE PLAN

MGE ENERGY, INC.

2013 DIRECTOR INCENTIVE PLAN

1.

Purpose; Effective Date

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

2.

Definitions

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

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

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

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

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

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

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

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

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

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

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

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

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

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

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

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

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

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

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

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

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

3.

Administration

3.1

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

3.2

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

3.3

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

4.

Participation

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

5.

Awards

5.1

General.  Awards may be granted on the terms and conditions set forth in this Section 5.  In addition, the Committee may impose on any Award or the exercise thereof, at the date of grant or thereafter, such additional terms and conditions, not inconsistent with the provisions of the Plan, as the Committee shall determine,

including terms requiring forfeiture of Awards in the event of a Participant’s Termination.  The Committee shall retain full power and discretion with respect to any term or condition of an Award that is not mandatory under the Plan.  

5.2

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

5.3

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

Year

Vesting

  1

33-1/3%   

  2

33-1/3%

  3

33-1/3%

5.4

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

6.

Termination Events

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

6.1

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

6.2

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

7.

Change in Control

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

8.

Claims; Arbitration

8.1

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

8.2

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

9.

Miscellaneous

9.1

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

9.2

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

9.3

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

9.4

Unfunded Plan.  The Plan is intended to constitute an “unfunded” plan for incentive and deferred compensation.  With respect to any amount payable to a

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

9.5

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

9.6

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

9.7

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

9.8

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

9.9

Notices.  All notices or other communications made or given pursuant to this Plan shall be in writing and shall be sufficiently made or given if hand-

delivered or mailed by certified mail addressed to any Participant at the address contained in the records of the Company or to the Company at its principal office.

9.10

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

9.11

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

9.12

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

9.13

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

9.14

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

IN WITNESS WHEREOF, and as evidence of the adoption of this Plan effective December 20, 2013, the Company has caused this instrument to be executed by its duly authorized officer this 20th day of December, 2013.

MGE ENERGY, INC.

By:

 /s/ Gary J. Wolter

Its:

Chairman, President and Chief Executive Officer

EX-10

EXHIBIT 10.38

MGE ENERGY, INC.

____________________________________________________________________________

2013 DIRECTOR INCENTIVE PLAN AWARD AGREEMENT

Name of Participant:   [●]

Number of Units:       [●]

Grant Date:  [●]

THIS DIRECTOR INCENTIVE AGREEMENT (the “Agreement”) is made by and between MGE ENERGY, INC., a corporation organized and existing under the laws of the State of Wisconsin (the “Company”), and the Director named above (the “Participant”), as of the date designated above (the “Grant Date”).  This Agreement provides notice of the terms and conditions applicable to a grant of Units made pursuant to the Company’s 2013 Director Incentive Plan (the “Plan”).  By execution below, the Participant agrees to be bound by the terms and conditions described herein and the provisions of the Plan.  Unless otherwise defined below or in Exhibit 1 attached hereto and made a part hereof, capitalized terms have the meanings ascribed to them in the Plan, a copy of which is being delivered with this Agreement.

1.

Grant of Units.  As of the Grant Date, the Board of Directors of the Company (the “Board”) grants to the Participant an aggregate of the Units indicated above, each of which gives the recipient the right to receive the Unit Value, equal to the Fair Market Value plus Dividend Equivalents declared during the relevant Vesting Period, subject to the restrictions described herein. Such Units do not represent real shares of stock, shall not be sold, assigned, transferred, pledged or hypothecated and have no value other than the cash settlement rights ascribed to them in the Plan (the “Units”).  

2.

 Vesting and Settlement.  

(a)

Vesting. Subject to Section 5 hereof, Units shall vest according to the following schedule:

Date

% Vest

December 31, 20[●]

33-1/3%

December 31, 20[●]

33-1/3%

December 31, 20[●]

33-1/3%

(b)

Settlement.

Units shall be valued and settled in cash on the Settlement Date, in accordance with the Plan.

3.

Dividend Equivalents.  Unit Value of the Units includes Dividend Equivalents for all dividends declared by the Company during the Vesting Period.  For purposes of computing Unit Value, such dividends shall be considered in aggregate but shall not be deemed to be reinvested in the Company’s Stock or to earn interest through the Settlement Date.

4.

Termination of Employment.  

(a)

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

(b)

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

5.

Change in Control.  Upon the occurrence of a Change in Control (as defined in Exhibit 1), all Units not previously forfeited shall become immediately vested and shall be settled in accordance with the Plan on the appropriate Settlement Date following the conclusion of the full Vesting Period.

6.

No Assignment of Units.  During the Vesting Period, Units granted hereunder shall not be subject in any manner to sale, transfer, pledge, assignment, encumbrance, division or other disposition, whether by operation of law or otherwise and whether voluntarily or involuntarily, including any division of property incident to a divorce or other allocation of marital property.  Notwithstanding the foregoing, Units shall be transferrable by will, the laws of descent and distribution or pursuant to beneficiary designation procedures established by the Company from time to time in its sole and absolute discretion.      

7.

Adjustment.  During the Vesting Period, the aggregate number of Units granted hereunder shall be subject to adjustment (as determined by the Compensation Committee in its sole discretion) due to any stock split, stock dividend or other form of recapitalization which affects the Company’s outstanding Stock.

8.

Service Rights.  Neither this Agreement nor the grant of Units hereunder shall be deemed to confer on the Participant any right to remain in the service of the Board.

9.

Amendment and Modification.  The terms and conditions of this Agreement may be amended only in writing signed by both the Participant and an authorized Company representative.

10.

Successors and Assigns.  This Agreement shall be binding upon and shall inure to the benefit of the Participant and the Company, including their respective heirs, executors, administrators, successors and assigns.

11.

Plan and Available Information.  Units granted hereunder shall be subject to such additional terms and conditions as may be imposed under the terms of the Plan, a copy of which has been furnished with this grant.  If any conflict exists between this Agreement and the Plan, the Plan shall prevail.

12.

Governing Law.  The validity, construction, and effect of all rules and regulations applicable to this Agreement shall be determined in accordance with the laws of the State of Wisconsin and applicable Federal law.

13.

Withholding Tax.  The Company may deduct from any payment to be made to the Participant any amount that federal, state, local or foreign tax law requires to be withheld with respect to the granting and settlement of Units hereunder.  

14.

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

PARTICIPANT

________________________________

MGE ENERGY, INC.

By:

      Its:   

Exhibit 1

Definitions

“Change in Control” means the occurrence of any of the following events:

(1) the acquisition by any individual, entity or group (a “Person”), including any “person” within the meaning of Section 13(d)(3) or 14(d)(2) of the Securities Exchange Act of 1934, as amended (the “Exchange Act”), of beneficial ownership within the meaning of Rule 13d-3 promulgated under the Exchange Act, of 35% or more of either (i) the then outstanding shares of common stock of the Company (the “Outstanding Company Common Stock”) or (ii) the combined voting power of the then outstanding securities of the Company entitled to vote generally in the election of directors (the “Outstanding Company Voting Securities”); provided, however, that the following acquisitions shall not constitute a Change in Control:

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

(B) any acquisition by the Company,

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

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

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

(2)

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

(3)

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

(4)

approval by the Company’s shareholders of (1) a plan of complete liquidation or dissolution of the Company, or (ii) the sale or other disposition of all or substantially all of the assets of the Company other than to a corporation with respect to which, immediately after such sale or other disposition each of, the Shareholder Continuity Condition, Beneficial Ownership Condition and Board of Directors Continuity Condition shall be satisfied.

For purposes of this definition:

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

“Beneficial Ownership Condition” shall be satisfied in connection with a transaction if no Person other than the Company, any employee benefit plan (or related trust) sponsored or maintained by the Company or the corporation resulting from such transaction (or any corporation controlled by the Company) and any Person who beneficially owned, immediately prior to such transaction, directly or indirectly, 35% or more of the Outstanding Company Common Stock or the Outstanding Company Voting Securities, as the case may be) beneficially owns, directly or indirectly, 35% or more of the then outstanding shares of common stock of such corporation or 35% or more of the combined voting power of the then outstanding securities of such corporation entitled to vote generally in the election of directors.

“Board of Directors Continuity Condition” shall be satisfied in connection with a transaction if at least a majority of the members of the board of directors of the corporation resulting from such transaction were members of the Incumbent Board at the time of the execution of the initial agreement or action of the Board providing for such transaction.

EX-12

EXHIBIT 12.1

MGE Energy, Inc.

Ratio of Earnings to Fixed Charges

Twelve Months Ended December 31, 2013

(In thousands)

Earnings
Net income	$74,905
Equity earnings	(9,434)
Income distribution from equity investees	7,404
Federal and state income taxes	44,859
Amortization of capitalized interest	527
Fixed charges	20,848
Total Earnings as Defined	$139,109
Fixed Charges
Interest expense on long-term debt and other	$18,248
Interest on rentals*	889
AFUDC - borrowed funds	1,035
Amortization of debt issuance costs	676
Total Fixed Charges	$20,848
Ratio of Earnings to Fixed Charges	6.67X

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

gives a reasonable approximation for actual interest on rentals.

EX-12

EXHIBIT 12.2

Madison Gas and Electric Company

Ratio of Earnings to Fixed Charges

Twelve Months Ended December 31, 2013

(In thousands)

Earnings
Net income before minority interest	$76,445
Equity earnings	(9,434)
Income distribution from equity investees	7,404
Minority interest in pretax income	(4,022)
Amortization of capitalized interest	527
Federal and state income taxes	45,822
Fixed charges	20,955
Total Earnings as Defined	$137,697
Fixed Charges
Interest expense on long-term debt and other	$18,355
Interest on rentals*	889
Amortization of debt issuance costs	676
AFUDC - borrowed funds	1,035
Total Fixed Charges	$20,955
Ratio of Earnings to Fixed Charges	6.57X

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

gives a reasonable approximation for actual interest on rentals.

EX-21

EXHIBIT 21

Subsidiaries of MGE Energy, Inc.

As of December 31, 2013, the company held the following subsidiaries (all of which are formed or organized as Wisconsin entities):

·

Madison Gas and Electric Company – a regulated utility that generates and distributes electricity to approximately 141,000 customers in Dane County, Wisconsin, and purchases and distributes natural gas to approximately 147,000 customers in seven Wisconsin counties.

·

MGE Power LLC – owns MGE Power West Campus, LLC, and MGE Power Elm Road, LLC.

·

MGE Power West Campus, LLC – owns a controlling interest in the electric generating assets related to the West Campus Cogeneration Facility. MGE Power West Campus has leased its share of these assets to Madison Gas and Electric Company through a long-term lease agreement.

·

MGE Power Elm Road, LLC – owns an 8.33% undivided ownership interest in two coal-fired generating units in Oak Creek, Wisconsin. MGE Power Elm Road has leased its share of the generating units to Madison Gas and Electric Company through separate long-term lease agreements.

·

MGE Transco Investment LLC – owns a minority equity interest in American Transmission Company LLC, which owns and operates electric transmission facilities in Wisconsin.

·

Central Wisconsin Development Corporation – assists new and expanding businesses throughout central Wisconsin by participating in planning, financing, property acquisition, joint ventures, and associated activities.

·

MAGAEL, LLC – holds title to property for future utility plant expansion and nonutility property.

·

MGE Construct LLC – provides construction services for building new generation to meet the needs of Madison Gas and Electric Company customers.

·

NGV Fueling Services, LLC – owns and maintains natural gas compression equipment to facilitate the use of compressed natural gas in natural gas vehicles.

·

North Mendota Energy & Technology Park, LLC – owns and serves as the development entity for property.

EX-23

EXHIBIT 23.1

CONSENT OF INDEPENDENT REGISTERED PUBLIC ACCOUNTING FIRM

We hereby consent to the incorporation by reference in the Registration Statement on Form S-3 (No. 333-176478) of MGE Energy, Inc. of our report dated February 27, 2014 relating to the financial statements, financial statement schedules and the effectiveness of internal control over financial reporting, which appears in this Form 10-K.

/s/ PricewaterhouseCoopers LLP

Boston, MA

February 27, 2014

EX-23

EXHIBIT 23.2

CONSENT OF INDEPENDENT REGISTERED PUBLIC ACCOUNTING FIRM

We hereby consent to the incorporation by reference in the Registration Statement on Form S-3 (No. 333-176478-01) of Madison Gas and Electric Company of our report dated February 27, 2014 relating to the financial statements and financial statement schedule, which appears in this Form 10-K.

/s/ PricewaterhouseCoopers LLP

Boston, MA

February 27, 2014

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 annual report on Form 10-K 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: February 27, 2014

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 annual report on Form 10-K 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: February 27, 2014

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 annual report on Form 10-K 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: February 27, 2014

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 annual report on Form 10-K 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: February 27, 2014

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 annual report on Form 10-K of MGE Energy, Inc. (the "Company"), for the period ended December 31, 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: February 27, 2014

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 annual report on Form 10-K of MGE Energy, Inc. (the "Company"), for the period ended December 31, 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: February 27, 2014

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 annual report on Form 10-K of Madison Gas and Electric Company (the "Company"), for the period ended December 31, 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: February 27, 2014

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 annual report on Form 10-K of Madison Gas and Electric Company (the "Company"), for the period ended December 31, 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: February 27, 2014

XML

Valuation and Qualifying Accounts

12 Months Ended

Dec. 31, 2013

Valuation and Qualifying Accounts [Abstract]

Valuation and Qualifying Accounts

Schedule II
MGE Energy, Inc. and Madison Gas and Electric Company
Valuation and Qualifying Accounts
			Additions
			(1)	(2)
		Balance at	Charged to	Charged	Net		Balance at
		beginning	costs and	to other	Accounts		end of
		of period	expenses	accounts	written off		period
Fiscal Year 2011:
Accumulated provision for uncollectibles	$	4,588,675	2,174,729	49,500	(2,712,571)	$	4,100,333
Fiscal Year 2012:
Accumulated provision for uncollectibles	$	4,100,333	2,825,300	44,400	(2,153,915)	$	4,816,118
Fiscal Year 2013:
Accumulated provision for uncollectibles	$	4,816,118	2,373,342	37,200	(2,256,949)	$	4,969,711

XML

Derivative and Hedging Instruments (Tables)

12 Months Ended

Dec. 31, 2013

Derivative Instruments and Hedging Activities Disclosure [Abstract]

Gross Notional Volume of Open Derivatives

The gross notional volume of open derivatives is as follows:

	December 31, 2013	December 31, 2012
Commodity derivative contracts	458,660MWh	444,650MWh
Commodity derivative contracts	3,750,000Dth	1,980,000Dth
FTRs	1,984MW	2,670MW

Fair Value of Derivative Instruments on the Balance Sheet

	Asset Derivatives			Liability Derivatives
(In thousands)	Balance Sheet Location		Fair Value	Balance Sheet Location		Fair Value
December 31, 2013
Commodity derivative contracts	Other current assets	$	1,356	Derivative liability (current)	$	51
Commodity derivative contracts	Other deferred charges		167	Derivative liability (long-term)		48
FTRs	Other current assets		363	Derivative liability (current)		0
Ten-year PPA	N/A		N/A	Derivative liability (current)		7,750
Ten-year PPA	N/A		N/A	Derivative liability (long-term)		57,930
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
December 31, 2013
Commodity derivative contracts	$	1,523	$	(99)	$	(175)	$	1,249
FTRs		363		-		-		363
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
December 31, 2013
Commodity derivative contracts	$	99	$	(99)	$	-	$	-
Ten-year PPA		65,680		-		-		65,680
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 (losses) related to the derivative instruments on the consolidated balance sheet at December 31, 2013 and 2012, and the consolidated income statement for the year ended December 31, 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
Year Ended December 31:
Balance at January 1,	$	72,329	$	574	$	42,356	$	1,604
Change in unrealized loss		(5,069)		0		37,822		0
Realized loss reclassified to a deferred account		(823)		823		(2,857)		2,857
Realized loss reclassified to income statement		(2,544)		(986)		(4,992)		(3,887)
Balance at December 31,	$	63,893	$	411	$	72,329	$	574

Derivative Gains and Losses in Income Statement

		Realized losses (gains)
		Fuel for Electric
		Generation/		Cost of
(In thousands)		Purchased Power		Gas Sold
Year Ended December 31, 2013:
Commodity derivative contracts	$	(564)	$	868
FTRs		(983)		0
Ten-year PPA		4,209		0
Year Ended December 31, 2012:
Commodity derivative contracts	$	2,620	$	3,072
FTRs		(45)		0
Ten-year PPA		3,232		0

XML

Long-Term Debt (Tables)

12 Months Ended

Dec. 31, 2013

Debt Disclosure [Abstract]

Schedule of Long-Term Debt

		2013				2012
(In thousands)		MGE Energy		MGE		MGE Energy		MGE
First Mortgage Bonds: (a)
7.70%, 2028 Series	$	1,200	$	1,200	$	1,200	$	1,200
Tax Exempt Debt:
3.45%, 2027 Series,
Industrial Development Revenue Bonds		19,300		19,300		19,300		19,300
Medium-Term Notes: (b)
5.26%, due 2017 (d)		0		0		20,000		20,000
5.25%, due 2017		30,000		30,000		30,000		30,000
6.12%, due 2028		20,000		20,000		20,000		20,000
7.12%, due 2032		25,000		25,000		25,000		25,000
6.247%, due 2037		25,000		25,000		25,000		25,000
Total Medium-Term Notes		100,000		100,000		120,000		120,000
Other Long-Term Debt: (c)
5.59%, due 2018 (d), (e)		20,000		20,000		40,000		40,000
3.38%, due 2020 (e)		15,000		15,000		15,000		15,000
3.09%, due 2023 (d), (e)		30,000		30,000		0		0
3.29%, due 2026 (d), (e)		15,000		15,000		0		0
5.68%, due 2033 (f)		29,797		29,797		30,000		30,000
5.19%, due 2033 (f)		19,857		19,857		20,000		20,000
5.26%, due 2040 (e)		15,000		15,000		15,000		15,000
5.04%, due 2040 (g)		43,472		43,472		45,138		45,138
4.74%, due 2041 (g)		27,167		27,167		28,167		28,167
4.38%, due 2042 (e)		28,000		28,000		28,000		28,000
4.42%, due 2043 (d), (e)		20,000		20,000		0		0
4.47%, due 2048 (d), (e)		20,000		20,000		0		0
Total Other Long-Term Debt		283,293		283,293		221,305		221,305
Long-term debt due within one year		(4,102)		(4,102)		(3,013)		(3,013)
Unamortized discount		(277)		(277)		(301)		(301)
Total Long-Term Debt	$	399,414	$	399,414	$	358,491	$	358,491

(a)MGE's utility plant is subject to the lien of its Indenture of Mortgage and Deed of Trust, under which its first mortgage bonds are issued. The Mortgage Indenture provides that dividends or any other distribution or purchase of shares may not be made if the aggregate amount thereof since December 31, 1945 would exceed the earned surplus (retained earnings) accumulated subsequent to December 31, 1945. As of December 31, 2013, approximately $305.6 million was available for the payment of dividends under this covenant.

(b)The indenture under which MGE's Medium-Term notes are issued provides that those notes will be entitled to be equally and ratably secured in the event that MGE issues any additional first mortgage bonds.

(c)Unsecured notes issued pursuant to various Note Purchase Agreements with one or more purchasers. The notes are not issued under, or governed by, MGE's Indenture dated as of September 1, 1998, which governs MGE's Medium-Term Notes.

(d)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. 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 included 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 were used and are expected to continue to be used to help finance the Columbia environmental project.

(e)Issued by MGE. Under that Note Purchase Agreement: (i) note holders have the right to require MGE to repurchase their notes at par in the event of an acquisition of beneficial ownership of 30% or more of the outstanding voting stock of MGE Energy, (ii) MGE must maintain a ratio of its consolidated indebtedness to consolidated total capitalization not to exceed a maximum of 65%, and (iii) MGE cannot issue "Priority Debt" in an amount exceeding 20% of its consolidated assets. Priority Debt is defined as any indebtedness of MGE secured by liens other than specified liens permitted by the Note Purchase Agreement and certain unsecured indebtedness of certain subsidiaries. As of December 31, 2013, MGE is in compliance with the covenant requirements.

(f)Issued by MGE Power West Campus. The Note Purchase Agreements require it to maintain a projected debt service coverage ratio of not less than 1.25 to 1.00, and debt to total capitalization ratio of not more than .65 to 1.00. The notes are secured by a collateral assignment of lease payments that MGE is making to MGE Power West Campus for use of its ownership interest in the West Campus Cogeneration Facility pursuant to a long-term lease.As of December 31, 2013, MGE Power West Campus is in compliance with the covenant requirements.

(g)Issued by MGE Power Elm Road. The Note Purchase Agreement requires MGE Power Elm Road to maintain a projected and actual debt service coverage ratio at the end of any calendar quarter of not less than 1.25 to 1.00 for the trailing 12-month period. The notes are secured by a collateral assignment of lease payments that MGE is making to MGE Power Elm Road for use of its ownership interest in the Elm Road Units pursuant to long-term leases.As of December 31, 2013, MGE Power Elm Road is in compliance with the covenant requirements.

Schedule of Long-Term Debt Maturities

Below is MGE Energy's and MGE's aggregate maturities for all long-term debt for years following the December 31, 2013,consolidated balance sheets.

		MGE
(In thousands)		Energy		MGE *
2014	$	4,102	$	4,102
2015		4,182		4,182
2016		4,268		4,268
2017		34,358		34,358
2018		24,452		24,452
Future years		332,431		332,431
Total	$	403,793	$	403,793

*Includes $29.8 million and $19.9 million for MGE Power West Campus, and $43.5 million and $27.2 million for MGE Power Elm Road, all of which are consolidated with MGE's debt (see Footnote 2 for further information).

XML

Notes Payable to Banks, Commercial Paper, and Lines of Credit (Details) (USD $)	12 Months Ended
	Dec. 31, 2013		Dec. 31, 2012		Dec. 31, 2011
Short-term Debt [Line Items]
Maximum short-term borrowings	$ 32,000,000	[1]	$ 16,000,000	[1]	$ 28,500,000	[1]
Average short-term borrowings	6,992,000	[1]	1,154,000	[1]	3,410,000	[1]
Weighted-average interest rate during the year	0.18%	[1]	0.17%	[1]	1.43%	[1]
Line of Credit [Member]
Short-term Debt [Line Items]
Available lines of credit	150,000,000	[1]	115,000,000	[1]	115,000,000	[1]
MGE [Member]
Short-term Debt [Line Items]
Maximum short-term borrowings	32,000,000		16,000,000		9,500,000
Average short-term borrowings	6,992,000		1,154,000		349,000
Weighted-average interest rate during the year	0.18%		0.17%		0.25%
MGE [Member] | Line of Credit [Member]
Short-term Debt [Line Items]
Available lines of credit	100,000,000		75,000,000		75,000,000
MGE [Member] | Line of Credit [Member] | MGE $100 million unsecured committed revolving line of credit
Short-term Debt [Line Items]
Available lines of credit	100,000,000
Line of credit, borrowings outstanding	0
Debt covenant, required parent company ownership of MGE	100.00%
MGE [Member] | Line of Credit [Member] | MGE $100 million unsecured committed revolving line of credit | Minimum [Member]
Short-term Debt [Line Items]
Debt covenant, ownership interest by outside party resulting in repurchase of notes at par value	30.00%
MGE [Member] | Line of Credit [Member] | MGE $100 million unsecured committed revolving line of credit | Maximum [Member]
Short-term Debt [Line Items]
Debt to total capitalization ratio	0.65
MGE Energy [Member] | Line of Credit [Member] | MGE Energy $50 million unsecured commiteed revolving line of credit
Short-term Debt [Line Items]
Available lines of credit	50,000,000
Line of credit, borrowings outstanding	$ 0
Debt covenant, required parent company ownership of MGE	100.00%
MGE Energy [Member] | Line of Credit [Member] | MGE Energy $50 million unsecured commiteed revolving line of credit | Minimum [Member]
Short-term Debt [Line Items]
Debt covenant, ownership interest by outside party resulting in repurchase of notes at par value	30.00%
MGE Energy [Member] | Line of Credit [Member] | MGE Energy $50 million unsecured commiteed revolving line of credit | Maximum [Member]
Short-term Debt [Line Items]
Debt to total capitalization ratio	0.65

[1] MGE Energy short-term borrowings include MGE Energy and MGE lines of credit and MGE commercial paper.

XML

Commitments and Contingencies (Tables)

12 Months Ended

Dec. 31, 2013

Commitments and Contingencies Disclosure [Abstract]

Contractual Obligation, Fiscal Year Maturity Schedule

As of December 31, 2013, the future minimum commitments related to these purchase contracts were as follows:

(In thousands)		2014		2015		2016		2017		2018
Coal(a)	$	22,109	$	14,633	$	10,938	$	5,073	$	2,710
Natural Gas
Transportation and storage(b)		17,211		16,857		9,288		272		191
Supply(c)		19,511		0		0		0		0
Purchase Power(d)		47,241		45,711		46,467		46,928		47,911
Other		2,314		498		498		498		124
	$	108,386	$	77,699	$	67,191	$	52,771	$	50,936

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

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

(d)MGE has several purchase power agreements to help meet future electric supply requirements. Management expects to recover these costs in future customer rates. In October 2008, MGE entered into a ten-year purchase power agreement to help meet future electric supply requirements. Under this agreement, MGE has agreed to purchase 50 MW of wind power from Osceola Windpower II, LLC, which is located in Iowa. This facility became operational in October 2008. MGE does not have any capacity payment commitments under this agreement. However, MGE is obligated to purchase its ratable share of the energy produced by the project. MGE's commitment related to its ratable share of energy produced by the project has been estimated and is included in the above numbers.

Guarantor Obligations, Fiscal Year Maturity Schedule

Principal payments for the next five years on the loans are:

(In thousands)		2014		2015		2016		2017		2018
Principal payments	$	714	$	1,007	$	910	$	506	$	449

Operating Leases, Future Minimum Rental Payments

Future minimum rental payments at December 31, 2013, under agreements classified as operating leases with noncancelable terms in excess of one year are as follows:

(In thousands)		2014		2015		2016		2017		2018		Thereafter
Minimum lease payments	$	1,668	$	1,478	$	983	$	718	$	418	$	8,179

Other Commitments

MGE has several other commitments related to various projects. Payments for these commitments are expected to be as follows:

(In thousands)		2014		2015		2016		2017		2018		Thereafter
Other Commitments	$	1,473	$	474	$	475	$	433	$	435	$	6,961

XML

Pension Plans and Other Postretirement Benefits (Details-3) (USD $) In Thousands, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	$ 315,000	$ 244,401
Cash and Cash Equivalents [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	5,109	5,627
Equity Securities [Member] | U.S. Large Cap [Memeber]
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	96,258	68,671
Equity Securities [Member] | U.S. Mid Cap [Memeber]
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	22,741	16,741
Equity Securities [Member] | U.S. Small Cap [Memeber]
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	28,854	21,222
Equity Securities [Member] | International Blend [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	54,873	44,200
Fixed Income Securities [Member] | Short-Term Fund [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	4,789	4,231
Fixed Income Securities [Member] | High Yield Bond [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	15,127	11,587
Fixed Income Securities [Member] | Long Duration Bond [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	66,193	53,515
Real Estate [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	19,628	17,141
Insurance Continuance Fund [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	1,428	1,466
Level 1 [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	5,109	5,627
Level 1 [Member] | Cash and Cash Equivalents [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	5,109	5,627
Level 1 [Member] | Equity Securities [Member] | U.S. Large Cap [Memeber]
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	0	0
Level 1 [Member] | Equity Securities [Member] | U.S. Mid Cap [Memeber]
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	0	0
Level 1 [Member] | Equity Securities [Member] | U.S. Small Cap [Memeber]
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	0	0
Level 1 [Member] | Equity Securities [Member] | International Blend [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	0	0
Level 1 [Member] | Fixed Income Securities [Member] | Short-Term Fund [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	0	0
Level 1 [Member] | Fixed Income Securities [Member] | High Yield Bond [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	0	0
Level 1 [Member] | Fixed Income Securities [Member] | Long Duration Bond [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	0	0
Level 1 [Member] | Real Estate [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	0	0
Level 1 [Member] | Insurance Continuance Fund [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	0	0
Level 2 [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	288,835	220,167
Level 2 [Member] | Cash and Cash Equivalents [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	0	0
Level 2 [Member] | Equity Securities [Member] | U.S. Large Cap [Memeber]
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	96,258	68,671
Level 2 [Member] | Equity Securities [Member] | U.S. Mid Cap [Memeber]
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	22,741	16,741
Level 2 [Member] | Equity Securities [Member] | U.S. Small Cap [Memeber]
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	28,854	21,222
Level 2 [Member] | Equity Securities [Member] | International Blend [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	54,873	44,200
Level 2 [Member] | Fixed Income Securities [Member] | Short-Term Fund [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	4,789	4,231
Level 2 [Member] | Fixed Income Securities [Member] | High Yield Bond [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	15,127	11,587
Level 2 [Member] | Fixed Income Securities [Member] | Long Duration Bond [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	66,193	53,515
Level 2 [Member] | Real Estate [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	0	0
Level 2 [Member] | Insurance Continuance Fund [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	0	0
Level 3 [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	21,056	18,607
Level 3 [Member] | Cash and Cash Equivalents [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	0	0
Level 3 [Member] | Equity Securities [Member] | U.S. Large Cap [Memeber]
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	0	0
Level 3 [Member] | Equity Securities [Member] | U.S. Mid Cap [Memeber]
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	0	0
Level 3 [Member] | Equity Securities [Member] | U.S. Small Cap [Memeber]
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	0	0
Level 3 [Member] | Equity Securities [Member] | International Blend [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	0	0
Level 3 [Member] | Fixed Income Securities [Member] | Short-Term Fund [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	0	0
Level 3 [Member] | Fixed Income Securities [Member] | High Yield Bond [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	0	0
Level 3 [Member] | Fixed Income Securities [Member] | Long Duration Bond [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	0	0
Level 3 [Member] | Real Estate [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	19,628	17,141	15,565
Level 3 [Member] | Insurance Continuance Fund [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	$ 1,428	$ 1,466	$ 906

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Schedule I - Condensed Parent Company Finanical Statements (Details-Notes 1) (Line of Credit [Member], USD $)	Dec. 31, 2013		Dec. 31, 2012		Dec. 31, 2011
Credit facilities [Line Items]
Available lines of credit	$ 150,000,000	[1]	$ 115,000,000	[1]	$ 115,000,000	[1]
MGE Energy [Member] | MGE Energy $50 million unsecured commiteed revolving line of credit
Credit facilities [Line Items]
Available lines of credit	50,000,000
Line of credit, borrowings outstanding	$ 0

[1] MGE Energy short-term borrowings include MGE Energy and MGE lines of credit and MGE commercial paper.

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Regulatory Assets and Liabilities (Tables)

12 Months Ended

Dec. 31, 2013

Regulatory Assets and Liabilities Disclosure [Abstract]

Regulatory Assets and Liabilities

The following regulatory assets and liabilities are reflected in MGE's consolidated balance sheet as of December 31:

(In thousands)		2013		2012
Regulatory Assets
Asset retirement obligation	$	4,863	$	4,608
Debt related costs		11,786		5,468
Derivatives		63,893		72,328
Elm Road		0		2,614
Environmental costs		920		1,154
Pension and OPRB costs		0		1,234
Tax recovery related to AFUDC equity		6,956		5,241
Unfunded pension and other postretirement liability		24,591		134,839
Other		534		1,694
Total regulatory assets	$	113,543	$	229,180
Regulatory Liabilities
Conservation costs	$	455	$	455
Deferred fuel savings		13,386		6,163
Elm Road		607		0
Income taxes		2,082		2,346
Non-ARO removal cost		15,182		13,957
Renewable energy credits		574		480
Other		1,044		1,137
Total regulatory liabilities	$	33,330	$	24,538

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Columbia Environmental Project Construction

12 Months Ended

Dec. 31, 2013

Jointly Owned Utility Plant Interests [Line Items]

Columbia Environmental Project Construction

Joint Plant Ownership - MGE Energy and MGE.

a.       Columbia.

MGE and two other utilities jointly own Columbia, a coal-fired generating facility located in Portage,Wisconsin, which accounts for 31% (245 MW) of MGE's net summer rated capacity. Power from this facility is shared in proportion to each company's ownership interest. MGE has a 22% ownership interest in Columbia. The other owners are WPL, which operates Columbia, and WPSC. MGE's share of fuel, operating, and maintenance expenses for Columbia were $37.5 million, $36.3 million, and $37.1 million for the years ended December 31,2013, 2012, and 2011, respectively. See Footnote 18 for discussion of MGE's future capital commitments in respect to the environmental projects at Columbia as a result of this ownership interest.

Each owner provides its own financing and reflects its respective portion of facilities and operating costs in its financial statements. MGE's interest in Columbia, included in its gross utility plant in service, and the related accumulated depreciation reserves at December 31 were as follows:

(In thousands)		2013		2012
Utility plant	$	123,097	$	119,544
Accumulated depreciation		(78,880)		(78,016)
Property, plant, and equipment, net	$	44,217	$	41,528
Construction work in progress		120,858		59,917
Total property, plant, and equipment	$	165,075	$	101,445

b.       Elm Road.

MGE Power Elm Road owns an 8.33% ownership interest in each of two 615 MW coal-fired generating units in Oak Creek, Wisconsin, which accounts for 14% (106 MW) of MGE's net summer rated capacity. Unit 1 entered commercial operation on February 2, 2010. Unit 2 entered commercial operation on January 12, 2011. MGE Power Elm Road's sole principal asset is that ownership interest in those generating units. MGE Power Elm Road's interest in the Elm Road Units is leased to MGE pursuant to long-term leases.

The remainder of the ownership interest in the Elm Road Units is held by two other entities, one of which is also responsible for the Units' operation. Each owner provides its own financing and reflects its respective portion of the facility and costs in its financial statements. MGE's share of fuel, operating, and maintenance expenses for the Elm Road Units were $13.4 million, $13.2 million, and $18.0 million for the years ended December 31, 2013,2012, and 2011, respectively.MGE Power Elm Road's interest in the portion of the Elm Road Units in-service and the related accumulated depreciation reserves at December 31 were as follows:

(In thousands)		2013		2012
Nonregulated plant	$	198,198	$	196,146
Accumulated depreciation		(15,541)		(11,126)
Property, plant, and equipment, net	$	182,657	$	185,020
Construction work in progress		1,115		1,440
Total property, plant, and equipment	$	183,772	$	186,460

c.       WCCF.

MGE Power West Campus and the UW jointly own the West Campus Cogeneration Facility located on the UW campus in Madison, Wisconsin. MGE Power West Campus owns 55% of the facility and the UW owns 45% of the facility. The UW owns a controlling interest in the chilled-water and steam plants, which are used to meet the growing needs for air-conditioning and steam-heat capacity for the UW campus. MGE Power West Campus owns a controlling interest in the electric generation plant, which is leased and operated by MGE.

Each owner provides its own financing and reflects its respective portion of the facility and operating costs in its financial statements. MGE Power West Campus' interest in WCCF and the related accumulated depreciation reserves at December 31 were as follows:

(In thousands)		2013		2012
Nonregulated plant	$	111,268	$	110,266
Accumulated depreciation		(21,704)		(19,927)
Property, plant, and equipment, net	$	89,564	$	90,339

Operating charges are allocated to the UW based on formulas contained in the operating agreement. Under the provisions of this arrangement, the UW is required to reimburse MGE for their allocated portion of fuel and operating expenses. For the years ended December 31, 2013 and 2012, the UW allocated share of fuel and operating costs was $4.9 million. For the year ended December 31, 2011, the UW allocated share of fuel and operating costs was$5.0 million.

Columbia Environmental Project [Member]

Jointly Owned Utility Plant Interests [Line Items]

Columbia Environmental Project Construction

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,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 $135 million. As of December 31,2013, MGE had accumulated $120.9 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 expects to incur capital expenditures of $14 million in 2014. This amount may change as a result of modifications to the project estimate or timing differences. MGE has recognized $2.7 million and $1.4 million (after tax) in AFUDC equity related to this project for the years ended December 31, 2013 and 2012, respectively.

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 a50% current return (included in customer rates) and the remaining 50% as AFUDC. For 2014, the PSCW authorized MGE 100% AFUDC on this project during construction.

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Pension Plans and Other Postretirement Benefits (Details-4) (USD $) In Thousands, unless otherwise specified	12 Months Ended
	Dec. 31, 2013	Dec. 31, 2012
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Fair value of plan assets at end of year	$ 315,000	$ 244,401
Real Estate [Member]
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Fair value of plan assets at end of year	19,628	17,141
Insurance Continuance Fund [Member]
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Fair value of plan assets at end of year	1,428	1,466
Level 3 [Member]
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Fair value of plan assets at end of year	21,056	18,607
Level 3 [Member] | Real Estate [Member]
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Fair value of plan assets at beginning of year	17,141	15,565
Actual return on plan assets still held	1,565	682
Purchases, sales, and settlements	922	894
Transfers in and/or out of Level 3	0	0
Fair value of plan assets at end of year	19,628	17,141
Level 3 [Member] | Insurance Continuance Fund [Member]
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Fair value of plan assets at beginning of year	1,466	906
Actual return on plan assets still held	42	33
Purchases, sales, and settlements	(80)	527
Transfers in and/or out of Level 3	0	0
Fair value of plan assets at end of year	$ 1,428	$ 1,466

XML

Fair Value of Financial Instruments (Details-3)	12 Months Ended
	Dec. 31, 2013
Basis adjustment:
Basis adjustment - on peak	94.20%
Basis adjustment - off peak	92.60%
US Treasury Bills [Member]
Deferred compensation plan
Investment interest calculation, investment maturity period (26 weeks)	182 days
Investment interest calculation, monthly compounding rate	1.00%
Investment interest calculation, minimum annual rate compounded monthly	7.00%
Minimum [Member]
Counterparty fuel mix:
Internal generation	50.00%
Purchased power	30.00%
Maximum [Member]
Counterparty fuel mix:
Internal generation	70.00%
Purchased power	50.00%

XML

Rate Matters (Details) (USD $) In Millions, unless otherwise specified	12 Months Ended
	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011	Dec. 31, 2013 PSCW [Member]	Dec. 31, 2011 PSCW [Member]	Dec. 31, 2014 PSCW [Member] Approved Future Rate Matters [Member]	Dec. 31, 2013 PSCW [Member] Columbia Environmental Project [Member]	Dec. 31, 2012 PSCW [Member] Columbia Environmental Project [Member]	Dec. 31, 2011 PSCW [Member] Columbia Environmental Project [Member]	Dec. 31, 2014 PSCW [Member] Columbia Environmental Project [Member] Approved Future Rate Matters [Member]	Dec. 31, 2013 Electric Rate Proceeding [Member] PSCW [Member]	Dec. 31, 2012 Electric Rate Proceeding [Member] PSCW [Member]	Dec. 31, 2011 Electric Rate Proceeding [Member] PSCW [Member]	Dec. 31, 2014 Electric Rate Proceeding [Member] PSCW [Member] Approved Future Rate Matters [Member]	Dec. 31, 2013 Gas Rate Proceeding [Member] PSCW [Member]	Dec. 31, 2012 Gas Rate Proceeding [Member] PSCW [Member]	Dec. 31, 2011 Gas Rate Proceeding [Member] PSCW [Member]	Dec. 31, 2014 Gas Rate Proceeding [Member] PSCW [Member] Approved Future Rate Matters [Member]
Public Utilities, Rate Matters [Abstract]
Authorized rate increase (decrease), percentage											3.80%	4.30%	2.30%	0.00%	1.00%	0.30%	1.00%	0.00%
Authorized rate increase (decrease), amount											$ 14.9	$ 15.7	$ 8.0	$ 0	$ 1.6	$ 0.6	$ 1.9	$ 0
Authorized AFUDC rate	50.00%	50.00%	50.00%				50.00%	100.00%	100.00%	100.00%
Return of fuel rule surplus credit, to be amortized						6.2
Authorized return on common stock				10.30%	10.30%	10.30%
Approved equity capital structure, percentage					58.10%
Fuel Rules [Abstract]
Fuel rules, bandwidth				2.00%	2.00%
Fuel rules, electric fuel costs, deferral, upper threshold	102.00%
Fuel rules, electric fuel costs, deferral, lower threshold	98.00%
Fuel rules, deferred electric cost	$ (6.7)

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Segment Information (Tables)

12 Months Ended

Dec. 31, 2013

Segment Reporting [Abstract]

Segment Information

The following table shows segment information for MGE Energy's and MGE's operations:

(In thousands)						Non-						Consolidation/
MGE Energy						Regulated		Transmission		All		Elimination		Consolidated
		Electric		Gas		Energy		Investment		Others		Entries		Total
Year Ended December 31, 2013
Operating revenues	$	403,957	$	181,462	$	5,468	$	0	$	0	$	0	$	590,887
Interdepartmental revenues		537		12,629		42,591		0		0		(55,757)		0
Total operating revenues		404,494		194,091		48,059		0		0		(55,757)		590,887
Depreciation and amortization		(25,780)		(5,898)		(7,156)		0		(4)		0		(38,838)
Other operating expenses		(316,277)		(162,661)		(128)		(1)		(752)		55,757		(424,062)
Operating income (loss)		62,437		25,532		40,775		(1)		(756)		0		127,987
Other (deductions) income, net		3,062		59		0		9,434		(1,854)		0		10,701
Interest (expense) income, net		(9,645)		(2,986)		(6,400)		0		107		0		(18,924)
Income (loss) before taxes		55,854		22,605		34,375		9,433		(2,503)		0		119,764
Income tax (provision) benefit		(19,176)		(9,168)		(13,682)		(3,796)		963		0		(44,859)
Net income (loss)	$	36,678	$	13,437	$	20,693	$	5,637	$	(1,540)	$	0	$	74,905
Year Ended December 31, 2012
Operating revenues	$	392,365	$	139,727	$	9,231	$	0	$	0	$	0	$	541,323
Interdepartmental revenues		487		12,814		34,714		0		0		(48,015)		0
Total operating revenues		392,852		152,541		43,945		0		0		(48,015)		541,323
Depreciation and amortization		(26,031)		(5,569)		(7,107)		0		0		0		(38,707)
Other operating expenses		(300,149)		(136,567)		(121)		0		(1,031)		48,015		(389,853)
Operating income (loss)		66,672		10,405		36,717		0		(1,031)		0		112,763
Other (deductions) income, net		1,145		323		0		9,080		(479)		0		10,069
Interest (expense) income, net		(10,189)		(2,874)		(6,537)		0		133		0		(19,467)
Income (loss) before taxes		57,628		7,854		30,180		9,080		(1,377)		0		103,365
Income tax (provision) benefit		(20,906)		(2,769)		(12,113)		(3,648)		517		0		(38,919)
Net income (loss)	$	36,722	$	5,085	$	18,067	$	5,432	$	(860)	$	0	$	64,446
Year Ended December 31, 2011
Operating revenues	$	375,858	$	165,271	$	5,253	$	0	$	0	$	0	$	546,382
Interdepartmental revenues		495		12,440		38,148		0		0		(51,083)		0
Total operating revenues		376,353		177,711		43,401		0		0		(51,083)		546,382
Depreciation and amortization		(28,323)		(5,593)		(7,026)		0		0		0		(40,942)
Other operating expenses		(292,080)		(155,444)		(174)		0		(957)		51,083		(397,572)
Operating income (loss)		55,950		16,674		36,201		0		(957)		0		107,868
Other income, net		71		20		0		8,614		509		0		9,214
Interest (expense) income, net		(10,849)		(3,060)		(6,331)		0		78		0		(20,162)
Income (loss) before taxes		45,172		13,634		29,870		8,614		(370)		0		96,920
Income tax (provision) benefit		(15,334)		(5,249)		(11,988)		(3,467)		46		0		(35,992)
Net income (loss)	$	29,838	$	8,385	$	17,882	$	5,147	$	(324)	$	0	$	60,928

(In thousands)						Non-				Consolidation/
MGE						Regulated		Transmission		Elimination		Consolidated
		Electric		Gas		Energy		Investment		Entries		Total
Year Ended December 31, 2013
Operating revenues	$	403,980	$	181,477	$	5,468	$	0	$	0	$	590,925
Interdepartmental revenues		514		12,614		42,591		0		(55,719)		0
Total operating revenues		404,494		194,091		48,059		0		(55,719)		590,925
Depreciation and amortization		(25,780)		(5,898)		(7,156)		0		0		(38,834)
Other operating expenses*		(335,059)		(171,717)		(13,810)		(1)		55,719		(464,868)
Operating income (loss)*		43,655		16,476		27,093		(1)		0		87,223
Other (deductions) income, net*		2,668		(53)		0		5,638		0		8,253
Interest expense, net		(9,645)		(2,986)		(6,400)		0		0		(19,031)
Net income		36,678		13,437		20,693		5,637		0		76,445
Less: Net income attributable to
noncontrolling interest, net of tax		0		0		0		0		(27,438)		(27,438)
Net income attributable to MGE	$	36,678	$	13,437	$	20,693	$	5,637	$	(27,438)	$	49,007
Year Ended December 31, 2012
Operating revenues	$	392,365	$	139,727	$	9,231	$	0	$	0	$	541,323
Interdepartmental revenues		487		12,814		34,714		0		(48,015)		0
Total operating revenues		392,852		152,541		43,945		0		(48,015)		541,323
Depreciation and amortization		(26,031)		(5,569)		(7,107)		0		0		(38,707)
Other operating expenses*		(320,701)		(139,236)		(12,234)		0		48,015		(424,156)
Operating income*		46,120		7,736		24,604		0		0		78,460
Other income, net*		791		223		0		5,432		0		6,446
Interest expense, net		(10,189)		(2,874)		(6,537)		0		0		(19,600)
Net income		36,722		5,085		18,067		5,432		0		65,306
Less: net income attributable to
noncontrolling interest, net of tax		0		0		0		0		(24,489)		(24,489)
Net income attributable to MGE	$	36,722	$	5,085	$	18,067	$	5,432	$	(24,489)	$	40,817
Year Ended December 31, 2011
Operating revenues	$	375,858	$	165,271	$	5,253	$	0	$	0	$	546,382
Interdepartmental revenues		495		12,440		38,148		0		(51,083)		0
Total operating revenues		376,353		177,711		43,401		0		(51,083)		546,382
Depreciation and amortization		(28,323)		(5,593)		(7,026)		0		0		(40,942)
Other operating expenses*		(307,193)		(160,631)		(12,162)		0		51,083		(428,903)
Operating income*		40,837		11,487		24,213		0		0		76,537
Other (deductions) income, net*		(150)		(42)		0		5,147		0		4,955
Interest expense, net		(10,849)		(3,060)		(6,331)		0		0		(20,240)
Net income		29,838		8,385		17,882		5,147		0		61,252
Less: Net income attributable to
noncontrolling interest, net of tax		0		0		0		0		(23,970)		(23,970)
Net income attributable to MGE	$	29,838	$	8,385	$	17,882	$	5,147	$	(23,970)	$	37,282
*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:
December 31, 2013	$	899,257	$	265,694	$	19,853	$	288,116	$	64,504	$	431,436	$	(389,800)	$	1,579,060
December 31, 2012		888,444		285,468		18,559		323,216		61,064		413,291		(403,118)		1,586,924
December 31, 2011		794,738		285,702		32,882		299,421		57,006		401,862		(412,729)		1,458,882
Capital Expenditures:
Year ended Dec. 31, 2013	$	100,146	$	15,554	$	0	$	3,347	$	0	$	0	$	0	$	119,047
Year ended Dec. 31, 2012		81,965		13,812		0		2,658		0		0		0		98,435
Year ended Dec. 31, 2011		47,206		15,830		0		2,140		0		0		0		65,176

		Utility						Consolidated
(In thousands)						Assets					Consolidation/
MGE						not	Nonregulated			Transmission		Elimination
		Electric		Gas		Allocated		Energy		Investment		Entries		Total
Assets:
December 31, 2013	$	899,257	$	265,694	$	19,853	$	288,066	$	64,504	$	(6,731)	$	1,530,643
December 31, 2012		888,444		285,468		18,559		323,166		61,064		(23,050)		1,553,651
December 31, 2011		794,738		285,702		32,882		299,171		57,006		(35,706)		1,433,793
Capital Expenditures:
Year ended Dec. 31, 2013	$	100,146	$	15,554	$	0	$	3,347	$	0	$	0	$	119,047
Year ended Dec. 31, 2012		81,965		13,812		0		2,658		0		0		98,435
Year ended Dec. 31, 2011		47,206		15,830		0		2,140		0		0		65,176

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Pension Plans and Other Postretirement Benefits (Details-1) (USD $)	12 Months Ended
	Dec. 31, 2013		Dec. 31, 2012	Dec. 31, 2011
Defined contribution plans [Abstract]
Defined contribution costs	$ 2,300,000		$ 2,100,000	$ 1,800,000
Health care cost trend rates [Abstract]
Health care cost trend rate assumed for next year	7.00%		7.50%
Ultimate trend rate	5.00%		5.00%
Year that the rate reaches the ultimate trend rate	2018		2018
How 1% increase or decrease in health care cost trends could impact postretirement benefits [Abstract]
1% increase	1,286,000
1% decrease	(1,840,000)
Postretirement Medical Plans with Prescription Drug Benefits [Abstract]
Medicare subsidy due to MGE	200,000
Pension Benefits [Member]
Change in benefit obligations [Roll Forward]
Net benefit obligation at beginning of year	315,505,000		283,668,000
Service cost	7,705,000		7,139,000	6,013,000
Interest cost	12,656,000		12,704,000	12,281,000
Plan participants' contributions	0		0
Plan amendments	0		(912,000)
Actuarial (gain) loss	(40,335,000)		22,266,000
Special termination benefits	0		0	13,000
Gross benefits paid	(11,573,000)		(9,360,000)
Less: federal subsidy on benefits paid	0		0
Benefit obligation at end of year	283,958,000		315,505,000	283,668,000
Accumulated benefit obligation	254,500,000		272,500,000
Weighted-average assumptions used to determine benefit obligations [Abstract]
Discount rate	4.88%		4.09%
Rate of compensation increase	3.90%		4.60%
Postretirement Benefits [Member]
Change in benefit obligations [Roll Forward]
Net benefit obligation at beginning of year	92,605,000		97,644,000
Service cost	2,380,000		2,528,000	1,920,000
Interest cost	3,871,000		4,431,000	3,980,000
Plan participants' contributions	665,000		718,000
Plan amendments	(20,915,000)	[1]	0
Actuarial (gain) loss	(9,687,000)		(9,748,000)
Special termination benefits	0		0	0
Gross benefits paid	(2,998,000)		(3,155,000)
Less: federal subsidy on benefits paid	179,000		187,000
Benefit obligation at end of year	$ 66,100,000		$ 92,605,000	$ 97,644,000
Plan amendment, maximum percentage of 2013 employer contributions to be paid toward retiree medical premiums	175.00%
Weighted-average assumptions used to determine benefit obligations [Abstract]
Discount rate	4.69%		4.14%

[1] In 2013, MGE capped the amount it pays each year toward retiree medical premiums at 175% of the 2013 employer contribution for qualified employees.

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Derivative and Hedging Instruments (Details-3) (USD $) In Thousands, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012
Commodity Derivative Contracts [Member]
Offsetting Liabilities [Line Items]
Gross liability	$ 99	$ 405
Gross amounts offset in balance sheet	(99)	(405)
Collateral posted against derivative positions	0	0
Net amount presented in the balance sheet	0	0
Ten-year PPA [Member]
Offsetting Liabilities [Line Items]
Gross liability	65,680	72,590
Gross amounts offset in balance sheet	0	0
Collateral posted against derivative positions	0	0
Net amount presented in the balance sheet	$ 65,680	$ 72,590

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Pension Plans and Other Postretirement Benefits (Details-6) (USD $)	12 Months Ended
	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Expected Cash Flows
Expected employer contributions for next fiscal year	$ 0
Cash contributions to pension and other postretirement plans	34,765,000	28,857,000	23,670,000
Components of Net Periodic Benefit Cost
Transition obligation straight-line amortization period	20 years
How 1% increase or decrease in health care cost trends could impact postretirement benefits [Abstract]
1% increase	1,104,000
1% decrease	(879,000)
Deferred Pension and OPRB Costs
Deferred pension and ORPB costs, recovered in rates	1,200,000	1,200,000
Pension Benefits [Member]
Expected Cash Flows
Employer contributions	30,878,000	20,815,000
Benefit Payments
Defined benefit plan expected future benefit payments, 2014	11,474,000
Defined benefit plan expected future benefit payments, 2015	12,223,000
Defined benefit plan expected future benefit payments, 2016	12,844,000
Defined benefit plan expected future benefit payments, 2017	13,633,000
Defined benefit plan expected future benefit payments, 2018	14,755,000
Defined benefit plan expected future benefit payments, 2019-2023	87,676,000
Components of Net Periodic Benefit Cost
Service cost	7,705,000	7,139,000	6,013,000
Interest cost	12,656,000	12,704,000	12,281,000
Expected return on assets	(19,027,000)	(15,182,000)	(14,034,000)
Special termination benefits	0	0	13,000
Amortization of:
Transition obligation	0	0	0
Prior service cost	314,000	430,000	433,000
Actuarial loss	8,014,000	8,288,000	3,771,000
Net periodic benefit cost	9,662,000	13,379,000	8,477,000
Weighted-average assumptions used to determine net periodic cost:
Discount rate	4.09%	4.50%	5.36%
Long-term rate of return	8.10%	8.10%	8.25%
Rate of compensation increase	4.60%	4.59%	4.59%
Postretirement Benefits [Member]
Expected Cash Flows
Employer contributions	2,811,000	8,059,000
Benefit Payments
Defined benefit plan expected future benefit payments, 2014	2,733,000
Defined benefit plan expected future benefit payments, 2015	2,837,000
Defined benefit plan expected future benefit payments, 2016	3,062,000
Defined benefit plan expected future benefit payments, 2017	3,474,000
Defined benefit plan expected future benefit payments, 2018	3,909,000
Defined benefit plan expected future benefit payments, 2019-2023	25,244,000
Components of Net Periodic Benefit Cost
Service cost	2,380,000	2,528,000	1,920,000
Interest cost	3,871,000	4,431,000	3,980,000
Expected return on assets	(2,176,000)	(1,741,000)	(1,584,000)
Special termination benefits	0	0	0
Amortization of:
Transition obligation	3,000	425,000	427,000
Prior service cost	110,000	110,000	110,000
Actuarial loss	1,236,000	2,346,000	566,000
Net periodic benefit cost	5,424,000	8,099,000	5,419,000
Weighted-average assumptions used to determine net periodic cost:
Discount rate	4.14%	4.55%	5.42%
Long-term rate of return	6.79%	7.26%	7.39%
Gross Postretirement Benefits [Member]
Benefit Payments
Defined benefit plan expected future benefit payments, 2014	2,924,000
Defined benefit plan expected future benefit payments, 2015	3,056,000
Defined benefit plan expected future benefit payments, 2016	3,308,000
Defined benefit plan expected future benefit payments, 2017	3,740,000
Defined benefit plan expected future benefit payments, 2018	4,198,000
Defined benefit plan expected future benefit payments, 2019-2023	27,110,000
Expected Medicare Part D Subsidy [Member]
Benefit Payments
Defined benefit plan expected future benefit payments, 2014	(191,000)
Defined benefit plan expected future benefit payments, 2015	(219,000)
Defined benefit plan expected future benefit payments, 2016	(246,000)
Defined benefit plan expected future benefit payments, 2017	(266,000)
Defined benefit plan expected future benefit payments, 2018	(289,000)
Defined benefit plan expected future benefit payments, 2019-2023	$ (1,866,000)

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Derivative and Hedging Instruments (Details-4) (USD $) In Thousands, unless otherwise specified	12 Months Ended
	Dec. 31, 2013	Dec. 31, 2012
Current and Long-Term Regulatory Asset [Member]
Change in Derivative Fair Value [Roll Forward]
Beginning balance	$ 72,329	$ 42,356
Change in unrealized loss	(5,069)	37,822
Realized loss reclassified to a deferred account	(823)	(2,857)
Realized gain (loss) reclassified to income statement	(2,544)	(4,992)
Ending balance	63,893	72,329
Other Current Assets [Member]
Change in Derivative Fair Value [Roll Forward]
Beginning balance	574	1,604
Change in unrealized loss	0	0
Realized loss reclassified to a deferred account	823	2,857
Realized gain (loss) reclassified to income statement	(986)	(3,887)
Ending balance	$ 411	$ 574

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Pension Plans and Other Postretirement Benefits (Details-2) (USD $) In Thousands, unless otherwise specified	12 Months Ended
	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Fair value of plan assets at beginning of year	$ 244,401
Fair value of plan assets at end of year	315,000
Defined Benefit Plan, Information about Plan Assets [Abstract]
Target Plan Asset Allocation	100.00%
Actual Plan Asset Allocation	100.00%	100.00%
Plan Assets [Member]
Concentration of Credit Risk [Abstract]
Concentration risk, percentage	10.00%
Concentration risk, number of significant concentrations	0
Equity Securities [Member]
Defined Benefit Plan, Information about Plan Assets [Abstract]
Target Plan Asset Allocation	63.00%
Actual Plan Asset Allocation	66.00%	64.00%
United States Equity Securities [Member]
Defined Benefit Plan, Information about Plan Assets [Abstract]
Target Plan Asset Allocation	45.50%
Non-United States Equity Securities [Member]
Defined Benefit Plan, Information about Plan Assets [Abstract]
Target Plan Asset Allocation	17.50%
Debt securities [Member]
Defined Benefit Plan, Information about Plan Assets [Abstract]
Target Plan Asset Allocation	30.00%
Actual Plan Asset Allocation	28.00%	29.00%
Real Estate [Member]
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Fair value of plan assets at beginning of year	17,141
Fair value of plan assets at end of year	19,628
Defined Benefit Plan, Information about Plan Assets [Abstract]
Target Plan Asset Allocation	7.00%
Actual Plan Asset Allocation	6.00%	7.00%
Pension Benefits [Member]
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Fair value of plan assets at beginning of year	212,277	173,311
Actual return on plan assets	45,816	27,511
Employer contributions	30,878	20,815
Plan participants' contributions	0	0
Gross benefits paid	(11,573)	(9,360)
Fair value of plan assets at end of year	277,398	212,277	173,311
Weighted-average assumptions used to determine net periodic cost:
Long-term rate of return	8.10%	8.10%	8.25%
Postretirement Benefits [Member]
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Fair value of plan assets at beginning of year	32,124	23,456
Actual return on plan assets	5,000	3,046
Employer contributions	2,811	8,059
Plan participants' contributions	665	718
Gross benefits paid	(2,998)	(3,155)
Fair value of plan assets at end of year	$ 37,602	$ 32,124	$ 23,456
Weighted-average assumptions used to determine net periodic cost:
Long-term rate of return	6.79%	7.26%	7.39%

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Fair Value of Financial Instruments (Details-1) (USD $) In Thousands, unless otherwise specified	Dec. 31, 2013		Dec. 31, 2012
Carrying Amount [Member]
Assets:
Cash and cash equivalents	$ 68,813		$ 46,357
Liabilities:
Long-Term debt	403,793	[1]	361,805	[1]
Fair Value [Member]
Assets:
Cash and cash equivalents	68,813		46,357
Liabilities:
Long-Term debt	432,010	[1]	427,456	[1]
MGE [Member] | Carrying Amount [Member]
Assets:
Cash and cash equivalents	14,808		6,350
Liabilities:
Long-Term debt	403,793	[1]	361,805	[1]
MGE [Member] | Fair Value [Member]
Assets:
Cash and cash equivalents	14,808		6,350
Liabilities:
Long-Term debt	$ 432,010	[1]	$ 427,456	[1]

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

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Income Taxes

12 Months Ended

Dec. 31, 2013

Income Tax Disclosure [Abstract]

Income Taxes

Income Taxes.

a.       MGE Energy and MGE Income Taxes.

MGE Energy files a consolidated federal income tax return that includes the operations of all subsidiary companies. The subsidiaries calculate their respective federal income tax provisions as if they were separate taxable entities.

On a consolidated and separate company basis, MGE Energy's and MGE's income tax provision consists of the following provision (benefit) components for the years ended December 31:

		MGE Energy						MGE
(In thousands)		2013		2012		2011		2013		2012		2011
Current payable:
Federal	$	(1,508)	$	(6,053)	$	(1,504)	$	(448)	$	(5,030)	$	(607)
State		8,213		436		4,580		8,322		613		4,658
Net-deferred:
Federal		37,203		37,178		30,115		36,937		36,589		29,255
State		1,163		7,618		3,102		1,223		7,523		3,034
Amortized investment tax credits		(212)		(260)		(301)		(212)		(260)		(301)
Total income tax provision	$	44,859	$	38,919	$	35,992	$	45,822	$	39,435	$	36,039

MGE Energy's and MGE's consolidated income tax provision differs from the amount computed by applying the statutory federal income tax rate to income before income taxes, as follows:

	MGE Energy			MGE
	2013	2012	2011	2013	2012	2011
Statutory federal income tax rate	35.0%	35.0%	35.0%	35.0%	35.0%	35.0%
State income taxes, net of federal benefit	5.1%	5.0%	5.1%	5.1%	5.0%	5.1%
Amortized investment tax credits	(0.2)%	(0.3)%	(0.3)%	(0.2)%	(0.2)%	(0.3)%
Credit for electricity from wind energy	(1.5)%	(1.6)%	(1.8)%	(1.5)%	(1.5)%	(1.8)%
Domestic manufacturing deduction	(0.2)%	0.3%	(0.7)%	(0.2)%	0.3%	(0.7)%
AFUDC Equity, net	(0.7)%	(0.4)%	0.0%	(0.7)%	(0.4)%	0.0%
Other, net, individually insignificant	(0.0)%	(0.3)%	(0.2)%	(0.0)%	(0.5)%	(0.3)%
Effective income tax rate	37.5%	37.7%	37.1%	37.5%	37.7%	37.0%

The significant components of deferred tax liabilities (assets) that appear on MGE Energy's and MGE's consolidated balance sheets as of December 31 as follows:

		MGE Energy				MGE
(In thousands)		2013		2012		2013		2012
Property-related	$	263,881	$	248,545	$	263,881	$	248,545
Investment in ATC		32,696		29,147		27,073		24,993
Bond transactions		1,553		1,643		1,553		1,643
Pension and other postretirement benefits		34,478		82,072		34,478		82,072
Derivatives		26,361		29,134		26,361		29,134
Tax deductible prepayments		7,508		7,233		7,508		7,233
Other		1,995		10,662		1,911		10,634
Gross deferred income tax liabilities		368,472		408,436		362,765		404,254
Future federal tax benefit		0		(25,626)		0		(25,899)
Accrued expenses		(17,195)		(30,277)		(17,195)		(30,228)
Pension and other postretirement benefits		(26,838)		(69,941)		(26,838)		(69,941)
Deferred tax regulatory account		(1,402)		(1,551)		(1,402)		(1,551)
Derivatives		(26,361)		(29,134)		(26,361)		(29,134)
Other		(10,369)		(5,345)		(9,356)		(4,940)
Gross deferred income tax assets		(82,165)		(161,874)		(81,152)		(161,693)
Less valuation allowance		195		365		195		365
Net deferred income tax assets		(81,970)		(161,509)		(80,957)		(161,328)
Deferred income taxes	$	286,502	$	246,927	$	281,808	$	242,926

As of December 31, 2013, MGE Energy did not have a federal net operating loss or tax credit carryforwards. As of December 31, 2012, MGE Energy had approximately $63.4 million and $3.4 million of net operating loss and tax credit carryforwards, respectively. The net operating loss and tax credit carryforwards resulted in deferred tax assets of $22.2 million and $3.4 million, respectively, as of December 31, 2012.

As of December 31, 2013, MGE did not have a federal net operating loss or tax credit carryforwards. As of December 31, 2012, MGE had approximately $64.2 million and $3.4 million of net operating loss and tax credit carryforwards, respectively. The net operating loss and tax credit carryforwards resulted in deferred tax assets of $22.5 million and $3.4 million, respectively, as of December 31, 2012.

The valuation allowance reduces MGE Energy's and MGE's deferred tax assets for state carryforward losses to estimated realizable value due to the uncertainty of future income estimates in various state tax jurisdictions.

For tax purposes, as of December 31, 2013, both MGE Energy and MGE had approximately $4.0million of Illinois state tax net operating loss deductions that expire between 2014 and 2024 if unused.

b.       Accounting for Uncertainty in Income Taxes - MGE Energy and MGE.

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.

A tabular reconciliation of unrecognized tax benefits and interest from January 1, 2011 to December 31, 2013, is as follows:

(In thousands)
Unrecognized tax benefits:		2013		2012		2011
Unrecognized tax benefits, January 1,	$	3,204	$	2,364	$	4,377
Additions based on tax positions related to the current year		377		401		128
Additions based on tax positions related to the prior years		424		580		427
Reductions based on tax positions related to the current year		(40)		0		0
Reductions based on tax positions related to the prior years		(1,602)		(141)		(2,568)
Unrecognized tax benefits, December 31,	$	2,363	$	3,204	$	2,364
(In thousands)
Interest on unrecognized tax benefits:		2013		2012		2011
Accrued interest on unrecognized tax benefits, January 1,	$	314	$	216	$	214
Reduction in interest expense on uncertain tax positions		(275)		0		0
Interest expense on uncertain tax positions		62		98		2
Accrued interest on unrecognized tax benefits, December 31,	$	101	$	314	$	216

Unrecognized tax benefits are liabilities shown with Other Deferred Liabilities on the December 31, 2013 and December 31, 2012, consolidated balance sheets. The interest component is offset by a regulatory asset.

MGE Energy filed an application with its 2009 tax returns to change its income tax methods of accounting for electric generation, transmission and distribution repairs and its 2010 tax returns for gas distribution repairs. These method changes accelerated tax deductions for repairs in accordance with Treasury Regulations and case law, as compared to the prior method of claiming tax depreciation on project costs. During 2011, the IRS issued guidance on the treatment of electric transmission and distribution repairs. This guidance has prompted the reversal of a majority of the unrecognized tax benefits for these repairs. During 2013, the IRS issued guidance on the treatment of electric generation repairs. This guidance prompted the reversal of the unrecognized tax benefits for these repairs. At December 31, 2013, MGE Energy and MGE have an unrecognized tax benefit in the amount of $2.4 million related to temporary tax differences associated with the change in income tax method of accounting for electric transmission and distribution repairs and gas distribution repairs. At December 31, 2012, MGE Energy and MGE had an unrecognized tax benefit in the amount of $3.2 million primarily related to temporary tax differences associated with the change in income tax method of accounting for electric generation, transmission, and distribution repairs and gas distribution repairs. At December 31, 2011, MGE Energy and MGE had an unrecognized tax benefit in the amount of $2.4 million primarily related to temporary tax differences associated with the change in income tax method of accounting for electric generation repairs and gas distribution repairs. There were no unrecognized tax benefits at December 31, 2013or December 31, 2012related to federal permanent differences and tax credits. Unrecognized tax benefits at December 31, 2011 related to federal permanent differences and tax credits were$0.2million.

The unrecognized tax benefits at December 31, 2013, are not expected to significantly increase or decrease within the next twelve months. However, the IRS may issue guidance on the treatment of gas distribution repairs. In addition, statutes of limitations will expire for MGE Energy and MGE tax returns. The impact of the statutes of limitations expiring is not anticipated to be material. The following table shows tax years that remain subject to examination by major jurisdiction:

Taxpayer	Open Years
MGE Energy and consolidated subsidiaries in federal return	2010 through 2013
MGE Energy Wisconsin combined reporting corporation return	2009 through 2013

c.       Medicare Part D Subsidy- MGE Energy and MGE.

In March 2010, the Patient Protection and Affordable Care Act (the PPACA) was enacted. The PPACA effectively changes the tax treatment of federal subsidies paid to sponsors of retiree health benefit plans that provide a benefit that is at least actuarially equivalent to the benefits under Medicare Part D. As a result of the PPACA, these subsidy payments became taxable in tax years beginning after December 31, 2012. In 2012, MGE was able to specifically identifyassets within the retiree health benefit plans to be used for payment of future health insurance premiums and prescription drug coverage. This process will allow certain Medicare Part D subsidy receipts to be non-taxable.

d.Final Tangible Property Regulations.

In September 2013, the IRS and Treasury Department released final regulations under Section 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 (Tables)

12 Months Ended

Dec. 31, 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:

		2013				2012
		Carrying		Fair		Carrying		Fair
(In thousands)		Amount		Value		Amount		Value
MGE Energy
Assets:
Cash and cash equivalents	$	68,813	$	68,813	$	46,357	$	46,357
Liabilities:
Long-term debt*		403,793		432,010		361,805		427,456
MGE
Assets:
Cash and cash equivalents	$	14,808	$	14,808	$	6,350	$	6,350
Liabilities:
Long-term debt*		403,793		432,010		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 December 31, 2013
(In thousands)		Total		Level 1		Level 2		Level 3
MGE Energy
Assets:
Exchange-traded investments	$	792	$	792	$	0	$	0
Total Assets	$	792	$	792	$	0	$	0
Liabilities:
Derivatives, net(a)	$	63,893	$	(735)	$	0	$	64,628
Deferred compensation		2,364		0		2,364		0
Total Liabilities	$	66,257	$	(735)	$	2,364	$	64,628
MGE
Assets:
Exchange-traded investments	$	431	$	431	$	0	$	0
Total Assets	$	431	$	431	$	0	$	0
Liabilities:
Derivatives, net(a)	$	63,893	$	(735)	$	0	$	64,628
Deferred compensation		2,364		0		2,364		0
Total Liabilities	$	66,257	$	(735)	$	2,364	$	64,628
(a)     These amounts are shown gross and exclude $0.2 million of collateral that was posted
against derivative positions with counterparties.
	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	94.2%
Off peak	92.6%
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.

(In thousands)		2013		2012		2011
Balance as of January 1,	$	(72,346)	$	(40,661)	$	(19,216)
Realized and unrealized gains (losses):
Included in regulatory liabilities (assets)		7,718		(31,685)		(21,445)
Included in other comprehensive income		0		0		0
Included in earnings		(2,618)		(5,005)		868
Included in current assets		(108)		0		0
Purchases		23,726		13,370		341
Sales		(2)		92		144
Issuances		0		0		0
Settlements		(20,998)		(8,457)		(1,353)
Transfers in and/or out of Level 3		0		0		0
Balance as of December 31,	$	(64,628)	$	(72,346)	$	(40,661)
Total gains (losses) included in earnings attributed to the
change in unrealized gains (losses) related to assets and
liabilities held at December 31,(b)	$	0	$	0	$	0

(b)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(b).

(In thousands)
Year Ended December 31,		2013		2012		2011
Purchased Power Expense	$	(2,618)	$	(5,005)	$	868

(b)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.

XML

Variable Interest Entities (Tables)

12 Months Ended

Dec. 31, 2013

MGE Power Elm Road [Member]

Variable Interest Entity [Line Items]

Variable interest entities significant balance sheet accounts

At December 31, MGE has included the following significant accounts on its consolidated balance sheet related to its interest in this VIE:

(In thousands)		2013		2012
Property, plant, and equipment, net	$	182,657	$	185,020
Construction work in progress		1,115		1,440
Deferred income tax asset - current		219		30,842
Deferred income tax liability		34,141		56,434
Long-term debt		70,639		73,306
Noncontrolling interest		69,876		69,803

MGE Power West Campus [Member]

Variable Interest Entity [Line Items]

Variable interest entities significant balance sheet accounts

At December 31, MGE has included the following significant accounts on its consolidated balance sheet related to its interest in this VIE:

(In thousands)		2013		2012
Property, plant, and equipment, net	$	89,564	$	90,339
Affiliate receivables		6,767		6,912
Accrued interest and taxes		4,888		3,327
Deferred income taxes		23,154		21,410
Long-term debt		49,653		50,000
Noncontrolling interest		29,089		30,682

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Income Taxes (Details) (USD $)	3 Months Ended								12 Months Ended
	Dec. 31, 2013	Sep. 30, 2013	Jun. 30, 2013	Mar. 31, 2013	Dec. 31, 2012	Sep. 30, 2012	Jun. 30, 2012	Mar. 31, 2012	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Income tax provision components [Abstract]
Current payable: Federal									$ (1,508,000)	$ (6,053,000)	$ (1,504,000)
Current payable: State									8,213,000	436,000	4,580,000
Net-deferred: Federal									37,203,000	37,178,000	30,115,000
Net-deferred: State									1,163,000	7,618,000	3,102,000
Amortized investment tax credits									(212,000)	(260,000)	(301,000)
Total income tax provision	7,829,000	14,692,000	8,660,000	13,678,000	6,208,000	14,253,000	8,596,000	9,862,000	44,859,000	38,919,000	35,992,000
Reconciliation of tax provision to statutory federal income tax rate [Abstract]
Statutory federal income tax rate									35.00%	35.00%	35.00%
State income taxes, net of federal benefit									5.10%	5.00%	5.10%
Amortized investment tax credits									(0.20%)	(0.30%)	(0.30%)
Credit for electricity from wind energy									(1.50%)	(1.60%)	(1.80%)
Domestic manufacturing deduction									(0.20%)	0.30%	(0.70%)
AFUDC Equity, net									(0.70%)	(0.40%)	0.00%
Other, net, individually significant									0.00%	(0.30%)	(0.20%)
Effective income tax rate									37.50%	37.70%	37.10%
Deferred tax liabilities (assets) on balance sheet [Abstract]
Property-related	263,881,000				248,545,000				263,881,000	248,545,000
Investment in ATC	32,696,000				29,147,000				32,696,000	29,147,000
Bond transactions	1,553,000				1,643,000				1,553,000	1,643,000
Pension and other postretirement benefits	34,478,000				82,072,000				34,478,000	82,072,000
Derivatives	26,361,000				29,134,000				26,361,000	29,134,000
Tax deductible prepayments	7,508,000				7,233,000				7,508,000	7,233,000
Other deferred tax liabilities	1,995,000				10,662,000				1,995,000	10,662,000
Gross deferred income tax liabilities	368,472,000				408,436,000				368,472,000	408,436,000
Future federal tax benefit	0				(25,626,000)				0	(25,626,000)
Accrued expenses	(17,195,000)				(30,277,000)				(17,195,000)	(30,277,000)
Pension and other postretirement benefits	(26,838,000)				(69,941,000)				(26,838,000)	(69,941,000)
Deferred tax regulatory account	(1,402,000)				(1,551,000)				(1,402,000)	(1,551,000)
Derivatives	(26,361,000)				(29,134,000)				(26,361,000)	(29,134,000)
Other deferred tax assets	(10,369,000)				(5,345,000)				(10,369,000)	(5,345,000)
Gross deferred income tax assets	(82,165,000)				(161,874,000)				(82,165,000)	(161,874,000)
Less valuation allowance	195,000				365,000				195,000	365,000
Net deferred income tax assets	(81,970,000)				(161,509,000)				(81,970,000)	(161,509,000)
Deferred income taxes	286,502,000				246,927,000				286,502,000	246,927,000
Operating loss deductions and tax credit carryforwards [Abstract]
Operating loss carryforward	0				63,400,000				0	63,400,000
Operating loss carryforward, deferred tax asset					22,200,000					22,200,000
Tax credit carryforward, amount	0				3,400,000				0	3,400,000
Tax credit carryforward, deferred tax asset					3,400,000					3,400,000
State net tax operating loss deductions	4,000,000								4,000,000
Unrecognized tax benefits [Roll Forward]
Unrecognized tax benefits, beginning balance				3,204,000				2,364,000	3,204,000	2,364,000	4,377,000
Additions based on tax positions related to current year									377,000	401,000	128,000
Additions based on tax positions related to prior year									424,000	580,000	427,000
Reductions based on tax positions related to the current year									(40,000)	0	0
Reductions based on tax positions related to prior years									(1,602,000)	(141,000)	(2,568,000)
Unrecognized tax benefits, ending balance	2,363,000				3,204,000				2,363,000	3,204,000	2,364,000
Interest on unrecognized tax benefits [Roll Forward]
Accrued interest on unrecognized tax benefits, beginning balance				314,000				216,000	314,000	216,000	214,000
Reduction in interest expense on uncertain tax positions									(275,000)	0	0
Interest expense on uncertain tax positions									62,000	98,000	2,000
Accrued interest on unrecognized tax benefits, ending balance	101,000				314,000				101,000	314,000	216,000
Unrecognized Tax Benefits
Unrecognized tax benefits permanent differences	0				0				0	0	200,000
MGE [Member]
Income tax provision components [Abstract]
Current payable: Federal									(448,000)	(5,030,000)	(607,000)
Current payable: State									8,322,000	613,000	4,658,000
Net-deferred: Federal									36,937,000	36,589,000	29,255,000
Net-deferred: State									1,223,000	7,523,000	3,034,000
Amortized investment tax credits									(212,000)	(260,000)	(301,000)
Total income tax provision									45,822,000	39,435,000	36,039,000
Reconciliation of tax provision to statutory federal income tax rate [Abstract]
Statutory federal income tax rate									35.00%	35.00%	35.00%
State income taxes, net of federal benefit									5.10%	5.00%	5.10%
Amortized investment tax credits									(0.20%)	(0.20%)	(0.30%)
Credit for electricity from wind energy									(1.50%)	(1.50%)	(1.80%)
Domestic manufacturing deduction									(0.20%)	0.30%	(0.70%)
AFUDC Equity, net									(0.70%)	(0.40%)	0.00%
Other, net, individually significant									0.00%	(0.50%)	(0.30%)
Effective income tax rate									37.50%	37.70%	37.00%
Deferred tax liabilities (assets) on balance sheet [Abstract]
Property-related	263,881,000				248,545,000				263,881,000	248,545,000
Investment in ATC	27,073,000				24,993,000				27,073,000	24,993,000
Bond transactions	1,553,000				1,643,000				1,553,000	1,643,000
Pension and other postretirement benefits	34,478,000				82,072,000				34,478,000	82,072,000
Derivatives	26,361,000				29,134,000				26,361,000	29,134,000
Tax deductible prepayments	7,508,000				7,233,000				7,508,000	7,233,000
Other deferred tax liabilities	1,911,000				10,634,000				1,911,000	10,634,000
Gross deferred income tax liabilities	362,765,000				404,254,000				362,765,000	404,254,000
Future federal tax benefit	0				(25,899,000)				0	(25,899,000)
Accrued expenses	(17,195,000)				(30,228,000)				(17,195,000)	(30,228,000)
Pension and other postretirement benefits	(26,838,000)				(69,941,000)				(26,838,000)	(69,941,000)
Deferred tax regulatory account	(1,402,000)				(1,551,000)				(1,402,000)	(1,551,000)
Derivatives	(26,361,000)				(29,134,000)				(26,361,000)	(29,134,000)
Other deferred tax assets	(9,356,000)				(4,940,000)				(9,356,000)	(4,940,000)
Gross deferred income tax assets	(81,152,000)				(161,693,000)				(81,152,000)	(161,693,000)
Less valuation allowance	195,000				365,000				195,000	365,000
Net deferred income tax assets	(80,957,000)				(161,328,000)				(80,957,000)	(161,328,000)
Deferred income taxes	281,808,000				242,926,000				281,808,000	242,926,000
Operating loss deductions and tax credit carryforwards [Abstract]
Operating loss carryforward	0				64,200,000				0	64,200,000
Operating loss carryforward, deferred tax asset					22,500,000					22,500,000
Tax credit carryforward, amount	0				3,400,000				0	3,400,000
Tax credit carryforward, deferred tax asset					3,400,000					3,400,000
State net tax operating loss deductions	$ 4,000,000								$ 4,000,000

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Segment Information (Details) (USD $) In Thousands, unless otherwise specified	3 Months Ended								12 Months Ended
	Dec. 31, 2013	Sep. 30, 2013	Jun. 30, 2013	Mar. 31, 2013	Dec. 31, 2012	Sep. 30, 2012	Jun. 30, 2012	Mar. 31, 2012	Dec. 31, 2013		Dec. 31, 2012		Dec. 31, 2011
Segment Reporting Information [Line Items]
Operating revenues	$ 155,263	$ 140,099	$ 128,288	$ 167,237	$ 137,005	$ 137,838	$ 117,221	$ 149,259	$ 590,887		$ 541,323		$ 546,382
Depreciation and amortization									(38,838)		(38,707)		(40,942)
Other operating expenses									(424,062)		(389,853)		(397,572)
Operating Income	25,962	39,900	24,497	37,628	19,350	39,888	25,081	28,444	127,987		112,763		107,868
Other (deductions) income, net									10,701		10,069		9,214
Interest (expense) income, net									(18,924)		(19,467)		(20,162)
Income before income taxes									119,764		103,365		96,920
Income tax (provision) benefit	(7,829)	(14,692)	(8,660)	(13,678)	(6,208)	(14,253)	(8,596)	(9,862)	(44,859)		(38,919)		(35,992)
Net Income	14,077	24,353	13,891	22,584	10,486	23,642	14,270	16,048	74,905		64,446		60,928
Segment Reporting Information Assets And Capital Expenditures [Abstract]
Assets	1,579,060				1,586,924				1,579,060		1,586,924		1,458,882
Capital expenditures									119,047		98,435		65,176
Electric [Member]
Segment Reporting Information [Line Items]
Operating revenues									404,494		392,852		376,353
Gas [Member]
Segment Reporting Information [Line Items]
Operating revenues									194,091		152,541		177,711
Non Regulated Energy [Member]
Segment Reporting Information [Line Items]
Operating revenues									48,059		43,945		43,401
Transmission Investment [Member]
Segment Reporting Information [Line Items]
Operating revenues									0		0		0
All Others [Member]
Segment Reporting Information [Line Items]
Operating revenues									0		0		0
Operating Segments [Member] | Electric [Member]
Segment Reporting Information [Line Items]
Operating revenues									403,957		392,365		375,858
Depreciation and amortization									(25,780)		(26,031)		(28,323)
Other operating expenses									(316,277)		(300,149)		(292,080)
Operating Income									62,437		66,672		55,950
Other (deductions) income, net									3,062		1,145		71
Interest (expense) income, net									(9,645)		(10,189)		(10,849)
Income before income taxes									55,854		57,628		45,172
Income tax (provision) benefit									(19,176)		(20,906)		(15,334)
Net Income									36,678		36,722		29,838
Segment Reporting Information Assets And Capital Expenditures [Abstract]
Assets	899,257				888,444				899,257		888,444		794,738
Capital expenditures									100,146		81,965		47,206
Operating Segments [Member] | Gas [Member]
Segment Reporting Information [Line Items]
Operating revenues									181,462		139,727		165,271
Depreciation and amortization									(5,898)		(5,569)		(5,593)
Other operating expenses									(162,661)		(136,567)		(155,444)
Operating Income									25,532		10,405		16,674
Other (deductions) income, net									59		323		20
Interest (expense) income, net									(2,986)		(2,874)		(3,060)
Income before income taxes									22,605		7,854		13,634
Income tax (provision) benefit									(9,168)		(2,769)		(5,249)
Net Income									13,437		5,085		8,385
Segment Reporting Information Assets And Capital Expenditures [Abstract]
Assets	265,694				285,468				265,694		285,468		285,702
Capital expenditures									15,554		13,812		15,830
Operating Segments [Member] | Non Regulated Energy [Member]
Segment Reporting Information [Line Items]
Operating revenues									5,468		9,231		5,253
Depreciation and amortization									(7,156)		(7,107)		(7,026)
Other operating expenses									(128)		(121)		(174)
Operating Income									40,775		36,717		36,201
Other (deductions) income, net									0		0		0
Interest (expense) income, net									(6,400)		(6,537)		(6,331)
Income before income taxes									34,375		30,180		29,870
Income tax (provision) benefit									(13,682)		(12,113)		(11,988)
Net Income									20,693		18,067		17,882
Segment Reporting Information Assets And Capital Expenditures [Abstract]
Assets	288,116				323,216				288,116		323,216		299,421
Capital expenditures									3,347		2,658		2,140
Operating Segments [Member] | Transmission Investment [Member]
Segment Reporting Information [Line Items]
Operating revenues									0		0		0
Depreciation and amortization									0		0		0
Other operating expenses									(1)		0		0
Operating Income									(1)		0		0
Other (deductions) income, net									9,434		9,080		8,614
Interest (expense) income, net									0		0		0
Income before income taxes									9,433		9,080		8,614
Income tax (provision) benefit									(3,796)		(3,648)		(3,467)
Net Income									5,637		5,432		5,147
Segment Reporting Information Assets And Capital Expenditures [Abstract]
Assets	64,504				61,064				64,504		61,064		57,006
Capital expenditures									0		0		0
Operating Segments [Member] | All Others [Member]
Segment Reporting Information [Line Items]
Operating revenues									0		0		0
Depreciation and amortization									(4)		0		0
Other operating expenses									(752)		(1,031)		(957)
Operating Income									(756)		(1,031)		(957)
Other (deductions) income, net									(1,854)		(479)		509
Interest (expense) income, net									107		133		78
Income before income taxes									(2,503)		(1,377)		(370)
Income tax (provision) benefit									963		517		46
Net Income									(1,540)		(860)		(324)
Segment Reporting Information Assets And Capital Expenditures [Abstract]
Assets	431,436				413,291				431,436		413,291		401,862
Capital expenditures									0		0		0
Operating Segments [Member] | Assets Not Allocated [Member]
Segment Reporting Information Assets And Capital Expenditures [Abstract]
Assets	19,853				18,559				19,853		18,559		32,882
Capital expenditures									0		0		0
Consolidation/Elimination Entries [Member]
Segment Reporting Information [Line Items]
Operating revenues									(55,757)		(48,015)		(51,083)
Depreciation and amortization									0		0		0
Other operating expenses									55,757		48,015		51,083
Operating Income									0		0		0
Other (deductions) income, net									0		0		0
Interest (expense) income, net									0		0		0
Income before income taxes									0		0		0
Income tax (provision) benefit									0		0		0
Net Income									0		0		0
Segment Reporting Information Assets And Capital Expenditures [Abstract]
Assets	(389,800)				(403,118)				(389,800)		(403,118)		(412,729)
Capital expenditures									0		0		0
Consolidation/Elimination Entries [Member] | Electric [Member]
Segment Reporting Information [Line Items]
Operating revenues									537		487		495
Consolidation/Elimination Entries [Member] | Gas [Member]
Segment Reporting Information [Line Items]
Operating revenues									12,629		12,814		12,440
Consolidation/Elimination Entries [Member] | Non Regulated Energy [Member]
Segment Reporting Information [Line Items]
Operating revenues									42,591		34,714		38,148
Consolidation/Elimination Entries [Member] | Transmission Investment [Member]
Segment Reporting Information [Line Items]
Operating revenues									0		0		0
Consolidation/Elimination Entries [Member] | All Others [Member]
Segment Reporting Information [Line Items]
Operating revenues									0		0		0
MGE [Member]
Segment Reporting Information [Line Items]
Operating revenues									590,925		541,323		546,382
Depreciation and amortization									(38,834)		(38,707)		(40,942)
Other operating expenses									(464,868)	[1]	(424,156)	[1]	(428,903)	[1]
Operating Income									87,223	[1]	78,460	[1]	76,537	[1]
Other (deductions) income, net									8,253	[1]	6,446	[1]	4,955	[1]
Interest (expense) income, net									(19,031)		(19,600)		(20,240)
Income tax (provision) benefit									(45,822)		(39,435)		(36,039)
Net Income Including Noncontrolling Interest									76,445		65,306		61,252
Less Net Income Attributable to Noncontrolling Interest, net of tax									(27,438)		(24,489)		(23,970)
Net Income									49,007		40,817		37,282
Segment Reporting Information Assets And Capital Expenditures [Abstract]
Assets	1,530,643				1,553,651				1,530,643		1,553,651		1,433,793
Capital expenditures									119,047		98,435		65,176
MGE [Member] | Electric [Member]
Segment Reporting Information [Line Items]
Operating revenues									404,494		392,852		376,353
MGE [Member] | Gas [Member]
Segment Reporting Information [Line Items]
Operating revenues									194,091		152,541		177,711
MGE [Member] | Non Regulated Energy [Member]
Segment Reporting Information [Line Items]
Operating revenues									48,059		43,945		43,401
MGE [Member] | Transmission Investment [Member]
Segment Reporting Information [Line Items]
Operating revenues									0		0		0
MGE [Member] | Operating Segments [Member] | Electric [Member]
Segment Reporting Information [Line Items]
Operating revenues									403,980		392,365		375,858
Depreciation and amortization									(25,780)		(26,031)		(28,323)
Other operating expenses									(335,059)	[1]	(320,701)	[1]	(307,193)	[1]
Operating Income									43,655	[1]	46,120	[1]	40,837	[1]
Other (deductions) income, net									2,668	[1]	791	[1]	(150)	[1]
Interest (expense) income, net									(9,645)		(10,189)		(10,849)
Net Income Including Noncontrolling Interest									36,678		36,722		29,838
Less Net Income Attributable to Noncontrolling Interest, net of tax									0		0		0
Net Income									36,678		36,722		29,838
Segment Reporting Information Assets And Capital Expenditures [Abstract]
Assets	899,257				888,444				899,257		888,444		794,738
Capital expenditures									100,146		81,965		47,206
MGE [Member] | Operating Segments [Member] | Gas [Member]
Segment Reporting Information [Line Items]
Operating revenues									181,477		139,727		165,271
Depreciation and amortization									(5,898)		(5,569)		(5,593)
Other operating expenses									(171,717)	[1]	(139,236)	[1]	(160,631)	[1]
Operating Income									16,476	[1]	7,736	[1]	11,487	[1]
Other (deductions) income, net									(53)	[1]	223	[1]	(42)	[1]
Interest (expense) income, net									(2,986)		(2,874)		(3,060)
Net Income Including Noncontrolling Interest									13,437		5,085		8,385
Less Net Income Attributable to Noncontrolling Interest, net of tax									0		0		0
Net Income									13,437		5,085		8,385
Segment Reporting Information Assets And Capital Expenditures [Abstract]
Assets	265,694				285,468				265,694		285,468		285,702
Capital expenditures									15,554		13,812		15,830
MGE [Member] | Operating Segments [Member] | Non Regulated Energy [Member]
Segment Reporting Information [Line Items]
Operating revenues									5,468		9,231		5,253
Depreciation and amortization									(7,156)		(7,107)		(7,026)
Other operating expenses									(13,810)	[1]	(12,234)	[1]	(12,162)	[1]
Operating Income									27,093	[1]	24,604	[1]	24,213	[1]
Other (deductions) income, net									0	[1]	0	[1]	0	[1]
Interest (expense) income, net									(6,400)		(6,537)		(6,331)
Net Income Including Noncontrolling Interest									20,693		18,067		17,882
Less Net Income Attributable to Noncontrolling Interest, net of tax									0		0		0
Net Income									20,693		18,067		17,882
Segment Reporting Information Assets And Capital Expenditures [Abstract]
Assets	288,066				323,166				288,066		323,166		299,171
Capital expenditures									3,347		2,658		2,140
MGE [Member] | Operating Segments [Member] | Transmission Investment [Member]
Segment Reporting Information [Line Items]
Operating revenues									0		0		0
Depreciation and amortization									0		0		0
Other operating expenses									(1)	[1]	0	[1]	0	[1]
Operating Income									(1)	[1]	0	[1]	0	[1]
Other (deductions) income, net									5,638	[1]	5,432	[1]	5,147	[1]
Interest (expense) income, net									0		0		0
Net Income Including Noncontrolling Interest									5,637		5,432		5,147
Less Net Income Attributable to Noncontrolling Interest, net of tax									0		0		0
Net Income									5,637		5,432		5,147
Segment Reporting Information Assets And Capital Expenditures [Abstract]
Assets	64,504				61,064				64,504		61,064		57,006
Capital expenditures									0		0		0
MGE [Member] | Operating Segments [Member] | Assets Not Allocated [Member]
Segment Reporting Information Assets And Capital Expenditures [Abstract]
Assets	19,853				18,559				19,853		18,559		32,882
Capital expenditures									0		0		0
MGE [Member] | Consolidation/Elimination Entries [Member]
Segment Reporting Information [Line Items]
Operating revenues									(55,719)		(48,015)		(51,083)
Depreciation and amortization									0		0		0
Other operating expenses									55,719	[1]	48,015	[1]	51,083	[1]
Operating Income									0	[1]	0	[1]	0	[1]
Other (deductions) income, net									0	[1]	0	[1]	0	[1]
Interest (expense) income, net									0		0		0
Net Income Including Noncontrolling Interest									0		0		0
Less Net Income Attributable to Noncontrolling Interest, net of tax									(27,438)		(24,489)		(23,970)
Net Income									(27,438)		(24,489)		(23,970)
Segment Reporting Information Assets And Capital Expenditures [Abstract]
Assets	(6,731)				(23,050)				(6,731)		(23,050)		(35,706)
Capital expenditures									0		0		0
MGE [Member] | Consolidation/Elimination Entries [Member] | Electric [Member]
Segment Reporting Information [Line Items]
Operating revenues									514		487		495
MGE [Member] | Consolidation/Elimination Entries [Member] | Gas [Member]
Segment Reporting Information [Line Items]
Operating revenues									12,614		12,814		12,440
MGE [Member] | Consolidation/Elimination Entries [Member] | Non Regulated Energy [Member]
Segment Reporting Information [Line Items]
Operating revenues									42,591		34,714		38,148
MGE [Member] | Consolidation/Elimination Entries [Member] | Transmission Investment [Member]
Segment Reporting Information [Line Items]
Operating revenues									$ 0		$ 0		$ 0

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

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Related Party Transactions

12 Months Ended

Dec. 31, 2013

Related Party Transactions [Abstract]

Related Party Transactions

Related Party Transactions - MGE Energy and MGE.

ATC

During 2013, 2012, and 2011, MGE recorded $27.7 million, $25.3 million, and $25.0 million, respectively, for transmission services received from ATC. MGE also provides a variety of operational, maintenance, and project management work for ATC, which is reimbursed by ATC. For the years endedDecember 31,2013, 2012, and 2011, MGE had a receivable due from ATC of $0.2 million.

For additional discussion on MGE's relationship with ATC, see Footnote 4.

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Pension Plans and Other Postretirement Benefits (Tables)

12 Months Ended

Dec. 31, 2013

Compensation and Retirement Disclosure [Abstract]

Change in Benefit Obligations

						Other Postretirement
(In thousands)		Pension Benefits				Benefits
Change in benefit obligations:		2013		2012		2013		2012
Net benefit obligation at beginning of year	$	315,505	$	283,668	$	92,605	$	97,644
Service cost		7,705		7,139		2,380		2,528
Interest cost		12,656		12,704		3,871		4,431
Plan participants' contributions		0		0		665		718
Plan amendments(a)		0		(912)		(20,915)		0
Actuarial (gain) loss		(40,335)		22,266		(9,687)		(9,748)
Gross benefits paid		(11,573)		(9,360)		(2,998)		(3,155)
Less: federal subsidy on benefits paid		0		0		179		187
Benefit obligation at end of year	$	283,958	$	315,505	$	66,100	$	92,605

• In 2013, MGE capped the amount it pays each year toward retiree medical premiums at 175%of the 2013 employer contribution for qualified employees.

Assumptions to Determine Benefit Obligations

			Other Postretirement
	Pension Benefits		Benefits
Weighted-average assumptions used to
determine end of year benefit obligations:	2013	2012	2013	2012
Discount rate	4.88%	4.09%	4.69%	4.14%
Rate of compensation increase	3.90%	4.60%	N/A	N/A

Health Care Cost Trends

The following table shows assumed health care cost trend rates at December 31:

	2013	2012
Health care cost trend rate assumed for next year	7.0%	7.5%
Rate to which the cost trend rate is assumed to
decline (the ultimate trend rate)	5.0%	5.0%
Year that the rate reaches the ultimate trend rate	2018	2018

Effect of 1% Increase or Decrease in Health Care Costs

The following table shows how an assumed 1% increase or 1% decrease in health care cost trends could impact postretirement benefits in 2013 dollars:

(In thousands)		1% Increase		1% Decrease
Effect on other postretirement benefit obligation	$	1,286	$	(1,840)

A 1% change in the assumed health care cost trend rates would have had the following effect:

(In thousands)		1% Increase		1% Decrease
Effect on total service and interest cost components	$	1,104	$	(879)

Change in Plan Assets

						Other Postretirement
(In thousands)		Pension Benefits				Benefits
Change in plan assets:		2013		2012		2013		2012
Fair value of plan assets at beginning of year	$	212,277	$	173,311	$	32,124	$	23,456
Actual return on plan assets		45,816		27,511		5,000		3,046
Employer contributions		30,878		20,815		2,811		8,059
Plan participants' contributions		0		0		665		718
Gross benefits paid		(11,573)		(9,360)		(2,998)		(3,155)
Fair value of plan assets at end of year	$	277,398	$	212,277	$	37,602	$	32,124

Fair Value of Plan Assets by Asset Category

The asset allocation for MGE's pension plans at the end of 2013 and 2012, and the target allocation for 2014, by asset category, follows:

		Percentage of Plan
	Target	Assets at Year End
	Allocation	2013	2012
Equity securities	63.0%	66.0%	64.0%
Debt securities	30.0%	28.0%	29.0%
Real estate	7.0%	6.0%	7.0%
Total	100.0%	100.0%	100.0%

The fair value of MGE's plan assets, by asset category are as follows:

	Fair Value as of December 31, 2013
(In thousands)		Total		Level 1		Level 2		Level 3
Cash and Cash Equivalents	$	5,109	$	5,109	$	0	$	0
Equity Securities:
U.S. Large Cap		96,258		0		96,258		0
U.S. Mid Cap		22,741		0		22,741		0
U.S. Small Cap		28,854		0		28,854		0
International Blend		54,873		0		54,873		0
Fixed Income Securities:
Short-Term Fund		4,789		0		4,789		0
High Yield Bond		15,127		0		15,127		0
Long Duration Bond		66,193		0		66,193		0
Real Estate		19,628		0		0		19,628
Insurance Continuance Fund		1,428		0		0		1,428
Total	$	315,000	$	5,109	$	288,835	$	21,056
	Fair Value as of December 31, 2012
(In thousands)		Total		Level 1		Level 2		Level 3
Cash and Cash Equivalents	$	5,627	$	5,627	$	0	$	0
Equity Securities:
U.S. Large Cap		68,671		0		68,671		0
U.S. Mid Cap		16,741		0		16,741		0
U.S. Small Cap		21,222		0		21,222		0
International Blend		44,200		0		44,200		0
Fixed Income Securities:
Short-Term Fund		4,231		0		4,231		0
High Yield Bond		11,587		0		11,587		0
Long Duration Bond		53,515		0		53,515		0
Real Estate		17,141		0		0		17,141
Insurance Continuance Fund		1,466		0		0		1,466
Total	$	244,401	$	5,627	$	220,167	$	18,607

Change in Fair Value of Level 3 Plan Assets

The following table summarizes the changes in the fair value of the Level 3 plan assets.

		Level 3 Assets
				Insurance
				Continuance
(In thousands)		Real Estate		Fund
Balance as of January 1, 2012	$	15,565	$	906
Actual return on plan assets:
Relating to assets still held at the reporting date		682		33
Purchases, sales, and settlements		894		527
Transfers in and/or out of Level 3		0		0
Balance as of December 31, 2012	$	17,141	$	1,466
Actual return on plan assets:
Relating to assets still held at the reporting date		1,565		42
Purchases, sales, and settlements		922		(80)
Transfers in and/or out of Level 3		0		0
Balance as of December 31, 2013	$	19,628	$	1,428

Funded Status

The funded status at the end of the year, and the related amounts recognized on the consolidated balance sheet are as follows:

						Other Postretirement
(In thousands)		Pension Benefits				Benefits
Funded status, end of year		2013		2012		2013		2012
Fair value of plan assets	$	277,398	$	212,277	$	37,602	$	32,124
Benefit obligations		283,958		315,505		66,100		92,605
Funded status	$	(6,560)	$	(103,228)	$	(28,498)	$	(60,481)

Amounts Recognized in Regulatory Asset

						Other Postretirement
(In thousands)		Pension Benefits				Benefits
Amounts recognized as regulatory asset		2013		2012		2013		2012
Net actuarial loss	$	37,499	$	112,637	$	7,761	$	21,529
Prior service cost		(209)		105		(20,495)		530
Transition obligation		0		0		35		38
Total	$	37,290	$	112,742	$	(12,699)	$	22,097

Scehdule of Projected Benefit Obligations in Excess of Plan Assets

The projected benefit obligation and fair value of plan assets for pension plans with a projected benefit obligation in excess of plan assets were as follows:

(In thousands)		Pension Benefits
Projected benefit obligation in excess of plan assets		2013		2012
Projected benefit obligation, end of year	$	21,631	$	315,505
Fair value of plan assets, end of year		0		212,277

Schedule of Projected Benefit and Accumulated Benefit Obligations in Excess of Plan Assets

The projected benefit obligation, accumulated benefit obligation, and fair value of plan assets for pension plans with a projected benefit obligation in excess of plan assets and an accumulated benefit obligation in excess of plan assets were as follows:

(In thousands)		Pension Benefits
Accumulated benefit obligation in excess of plan assets		2013		2012
Projected benefit obligation, end of year	$	21,631	$	315,505
Accumulated benefit obligation, end of year		19,795		272,462
Fair value of plan assets, end of year		0		212,277

Benefit Payments, Fiscal Year Maturity

The following benefit payments, which reflect expected future service, as appropriate, are expected to be paid as follows:

		Pension	Other Postretirement
			Gross	Expected		Net
		Pension	Postretirement	Medicare Part D		Postretirement
(In thousands)		Benefits	Benefits	Subsidy		Benefits
2014	$	11,474	2,924	(191)	$	2,733
2015		12,223	3,056	(219)		2,837
2016		12,844	3,308	(246)		3,062
2017		13,633	3,740	(266)		3,474
2018		14,755	4,198	(289)		3,909
2019 - 2023		87,676	27,110	(1,866)		25,244

Net Periodic Benefit Costs

(In thousands)		Pension Benefits						Other Postretirement Benefits
Components of net periodic benefit cost		2013		2012		2011		2013		2012		2011
Service cost	$	7,705	$	7,139	$	6,013	$	2,380	$	2,528	$	1,920
Interest cost		12,656		12,704		12,281		3,871		4,431		3,980
Expected return on assets		(19,027)		(15,182)		(14,034)		(2,176)		(1,741)		(1,584)
Special termination benefits		0		0		13		0		0		0
Amortization of:
Transition obligation		0		0		0		3		425		427
Prior service cost		314		430		433		110		110		110
Actuarial loss		8,014		8,288		3,771		1,236		2,346		566
Net periodic benefit cost	$	9,662	$	13,379	$	8,477	$	5,424	$	8,099	$	5,419
Weighted-average assumptions used to
determine net periodic cost:
Discount rate		4.09%		4.50%		5.36%		4.14%		4.55%		5.42%
Expected return on plan assets		8.10%		8.10%		8.25%		6.79%		7.26%		7.39%
Rate of compensation increase		4.60%		4.59%		4.59%		N/A		N/A		N/A

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Common Equity (Details) (USD $) In Thousands, except Share data, unless otherwise specified	0 Months Ended	3 Months Ended								12 Months Ended
	Dec. 20, 2013	Dec. 31, 2013	Sep. 30, 2013	Jun. 30, 2013	Mar. 31, 2013	Dec. 31, 2012	Sep. 30, 2012	Jun. 30, 2012	Mar. 31, 2012	Dec. 31, 2013		Dec. 31, 2012		Dec. 31, 2011
Class of Stock [Line Items]
Stock split declared December 20, 2013, ratio (3:2)	1.5
Common stock dividends declared										$ 37,107	[1]	$ 35,951	[2]	$ 35,026	[3]
Common stock dividends declared (in dollars per share)		$ 0.272	$ 0.272	$ 0.263	$ 0.263	$ 0.263	$ 0.263	$ 0.255	$ 0.255	$ 1.07		$ 1.04		$ 1.01
Shares of preferred stock		0				0				0		0		1,175,000
Par value of preferred stock (in dollars per share)														$ 25
Preferred stock, shares issued		0				0				0		0		0
Preferred stock, shares outstanding		0				0				0		0		0
MGE [Member]
Class of Stock [Line Items]
Cash dividends paid to parent by MGE										$ 25,000		$ 20,404		$ 26,648

[1] $1.07 per share

[2] $1.04 per share

[3] $1.01 per share

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Property, Plant, and Equipment (Details) (USD $) In Thousands, unless otherwise specified	Dec. 31, 2013		Dec. 31, 2012
Property, Plant and Equipment [Line Items]
In-service utility plant, net	$ 1,018,809		$ 975,053
Construction work in progress	141,415		98,411
Total property, plant, and equipment	1,160,224		1,073,464
First Mortgage Bonds [Member] | 7.70%, 2028 Series
Plant related debt items
Long-term debt, gross	1,200	[1]	1,200	[1]
Regulated [Member]
Property, Plant and Equipment [Line Items]
In-service utility plant, gross	1,304,984		1,245,040
Less: Accumulated depreciation and amortization	560,066		546,483
In-service utility plant, net	744,918		698,557
Construction work in progress	140,301		96,863
Electric [Member] | Regulated [Member]
Property, Plant and Equipment [Line Items]
In-service utility plant, gross	953,290		912,273
Gas [Member] | Regulated [Member]
Property, Plant and Equipment [Line Items]
In-service utility plant, gross	351,694		332,767
Non Regulated Energy [Member] | Non-regulated [Member]
Property, Plant and Equipment [Line Items]
In-service utility plant, gross	311,742		308,043
Less: Accumulated depreciation and amortization	37,851		31,547
In-service utility plant, net	273,891		276,496
Construction work in progress	1,114		1,548
MGE [Member]
Property, Plant and Equipment [Line Items]
In-service utility plant, net	1,017,877		974,549
Construction work in progress	141,415		98,411
Total property, plant, and equipment	1,159,292		1,072,960
MGE [Member] | First Mortgage Bonds [Member] | 7.70%, 2028 Series
Plant related debt items
Long-term debt, gross	1,200	[1]	1,200	[1]
MGE [Member] | Regulated [Member]
Property, Plant and Equipment [Line Items]
In-service utility plant, gross	1,305,012		1,245,068
Less: Accumulated depreciation and amortization	560,066		546,483
In-service utility plant, net	744,946		698,585
Construction work in progress	140,301		96,863
MGE [Member] | Electric [Member] | Regulated [Member]
Property, Plant and Equipment [Line Items]
In-service utility plant, gross	953,307		912,289
MGE [Member] | Gas [Member] | Regulated [Member]
Property, Plant and Equipment [Line Items]
In-service utility plant, gross	351,705		332,779
MGE [Member] | Non Regulated Energy [Member] | Non-regulated [Member]
Property, Plant and Equipment [Line Items]
In-service utility plant, gross	310,745		307,511
Less: Accumulated depreciation and amortization	37,814		31,547
In-service utility plant, net	272,931		275,964
Construction work in progress	$ 1,114		$ 1,548

[1] MGE's utility plant is subject to the lien of its Indenture of Mortgage and Deed of Trust, under which its first mortgage bonds are issued. The Mortgage Indenture provides that dividends or any other distribution or purchase of shares may not be made if the aggregate amount thereof since December 31, 1945 would exceed the earned surplus (retained earnings) accumulated subsequent to December 31, 1945. As of December 31, 2013, approximately $305.6 million was available for the payment of dividends under this covenant.

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Noncontrolling Interest (Tables) (MGE [Member])

12 Months Ended

Dec. 31, 2013

MGE [Member]

Noncontrolling Interest [Line Items]

Noncontrolling Interest in Balance Sheet

The noncontrolling interest on MGE's balance sheet at December 31 was as follows:

(In thousands)		2013		2012
MGE Power Elm Road (a)	$	69,876	$	69,803
MGE Power West Campus (a)		29,089		30,682
MGE Transco (b)		19,998		16,985
Total noncontrolling interest	$	118,963	$	117,470

(a)MGE Power Elm Road and MGE Power West Campus are not subsidiaries of MGE; however, they have been consolidated in the consolidated financial statements of MGE (see Footnote 2). MGE Power Elm Road and MGE Power West Campus are100% owned by MGE Power, and MGE Power is 100% owned by MGE Energy. MGE Energy's proportionate share of the equity and net income (through its wholly owned subsidiary MGE Power) of MGE Power Elm Road and MGE Power West Campus is classified within the MGE financial statements as noncontrolling interest.

(b)At December 31, 2013, MGE is the majority owner, and MGE Energy 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.

Net Income Attributable to Noncontrolling Interest, Net of Tax

The net income attributable to noncontrolling interest, net of tax, for the years ended December 31,2013, 2012, and 2011was as follows:

(In thousands)		2013		2012		2011
MGE Power Elm Road (a)	$	17,373	$	14,837	$	14,576
MGE Power West Campus (a)		7,657		7,506		7,501
MGE Transco (b)		2,408		2,146		1,893
Net income attributable to noncontrolling interest, net of tax	$	27,438	$	24,489	$	23,970

(a)MGE Power Elm Road and MGE Power West Campus are not subsidiaries of MGE; however, they have been consolidated in the consolidated financial statements of MGE (see Footnote 2). MGE Power Elm Road and MGE Power West Campus are100% owned by MGE Power, and MGE Power is 100% owned by MGE Energy. MGE Energy's proportionate share of the equity and net income (through its wholly owned subsidiary MGE Power) of MGE Power Elm Road and MGE Power West Campus is classified within the MGE financial statements as noncontrolling interest.

(b)At December 31, 2013, MGE is the majority owner, and MGE Energy 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.

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Consolidated Balance Sheets (USD $) In Thousands, unless otherwise specified	Dec. 31, 2013		Dec. 31, 2012
Current Assets:
Cash and cash equivalents	$ 68,813		$ 46,357
Accounts receivable, less reserves	44,890	[1]	41,386	[2]
Other accounts receivables, less reserves	5,352	[3]	6,746	[4]
Unbilled revenues	31,982		28,262
Materials and supplies, at average cost	16,662		16,997
Fossil fuel	5,206		6,367
Stored natural gas, at average cost	13,988		14,980
Prepaid taxes	19,106		19,520
Regulatory assets - current	6,377		10,327
Deferred income taxes	0		23,483
Other current assets	8,225		8,512
Total Current Assets	220,601		222,937
Other long-term receivables	2,193		1,102
Regulatory assets	107,166		218,853
Pension and other postretirement benefits	15,071		0
Other deferred assets and other	5,853		5,973
Property, Plant, and Equipment:
Property, plant, and equipment, net	1,018,809		975,053
Construction work in progress	141,415		98,411
Total Property, Plant, and Equipment	1,160,224		1,073,464
Investments	67,952		64,595
Total Assets	1,579,060		1,586,924
Current Liabilities:
Long-term debt due within one year	4,102		3,013
Accounts payable	43,684		43,518
Accrued interest and taxes	5,661		4,296
Accrued payroll related items	10,731		10,063
Deferred income taxes	1,711		0
Regulatory liabilities - current	13,538		0
Derivative liabilities	7,750		9,270
Other current liabilities	9,489		5,637
Total Current Liabilities	96,666		75,797
Other Credits:
Deferred income taxes	284,791		270,410
Investment tax credit - deferred	1,413		1,520
Regulatory liabilities	19,792		24,538
Accrued pension and other postretirement benefits	49,184		162,835
Derivative liabilities	57,930		63,320
Other deferred liabilities and other	52,360		50,584
Total Other Credits	465,470		573,207
Common shareholders' equity:
Common stock	34,668	[5]	34,668	[5]
Additional paid-in capital	316,268		316,268
Retained earnings	266,197		228,399
Accumulated other comprehensive income, net of tax	377		94
Total Common Shareholders' Equity	617,510		579,429
Long-term debt	399,414		358,491
Total Capitalization	1,016,924		937,920
Commitments and contingencies (see Footnote 18)	0		0
Total Liabilities and Capitalization	1,579,060		1,586,924
MGE [Member]
Current Assets:
Cash and cash equivalents	14,808		6,350
Accounts receivable, less reserves	44,890	[1]	41,386	[2]
Affiliate receivables	534		634
Other accounts receivables, less reserves	5,274	[3]	6,732	[4]
Unbilled revenues	31,982		28,262
Materials and supplies, at average cost	16,662		16,997
Fossil fuel	5,206		6,367
Stored natural gas, at average cost	13,988		14,980
Prepaid taxes	23,934		23,561
Regulatory assets - current	6,377		10,327
Deferred income taxes	0		23,305
Other current assets	8,197		8,488
Total Current Assets	171,852		187,389
Affiliate receivable long-term	5,825		6,354
Regulatory assets	107,166		218,853
Pension and other postretirement benefits	15,071		0
Other deferred assets and other	6,138		6,540
Property, Plant, and Equipment:
Property, plant, and equipment, net	1,017,877		974,549
Construction work in progress	141,415		98,411
Total Property, Plant, and Equipment	1,159,292		1,072,960
Investments	65,299		61,555
Total Assets	1,530,643		1,553,651
Current Liabilities:
Long-term debt due within one year	4,102		3,013
Accounts payable	43,684		43,517
Affiliate payables	34		767
Accrued interest and taxes	6,040		4,248
Accrued payroll related items	10,731		10,063
Deferred income taxes	2,723		0
Regulatory liabilities - current	13,538		0
Derivative liabilities	7,750		9,270
Other current liabilities	6,412		4,491
Total Current Liabilities	95,014		75,369
Other Credits:
Deferred income taxes	279,085		266,231
Investment tax credit - deferred	1,413		1,520
Regulatory liabilities	19,792		24,538
Accrued pension and other postretirement benefits	49,184		162,835
Derivative liabilities	57,930		63,320
Other deferred liabilities and other	52,357		50,581
Total Other Credits	459,761		569,025
Common shareholders' equity:
Common stock	17,348	[6]	17,348	[6]
Additional paid-in capital	192,417		192,417
Retained earnings	247,534		223,527
Accumulated other comprehensive income, net of tax	192		4
Total Common Shareholders' Equity	457,491		433,296
Noncontrolling interest	118,963		117,470
Total Equity	576,454		550,766
Long-term debt	399,414		358,491
Total Capitalization	975,868		909,257
Commitments and contingencies (see Footnote 18)	0		0
Total Liabilities and Capitalization	$ 1,530,643		$ 1,553,651

[1] less reserves of $4,219

[2] less reserves of $3,885

[3] less reserves of $750

[4] less reserves of $931

[5] $1 par value - 50,000 shares authorized; 34,668 shares issued and outstanding

[6] $1 par value - 50,000 shares authorized; 17,348 shares outstanding

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Investments (Details-1) (USD $) In Thousands, unless otherwise specified	12 Months Ended
	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Available-for-sale securities:
Cost basis	$ 1,736	$ 1,575
Gross unrealized gains	629	161
Gross unrealized losses	0	(3)
Fair Value	2,365	1,733
Equity method investments:
Equity method investments	65,587	61,058
Other Investments	0	1,804
Total investments	67,952	64,595
Results of Investment Liquidation [Abstract]
Proceeds from sale of investments	39	0	260
Gain (loss) on sale of investments	2	0	198
ATC [Member]
Equity method investments:
Equity method investments	64,488	61,038
Other Equity Method Investments [Member]
Equity method investments:
Equity method investments	1,099	20
MGE [Member]
Available-for-sale securities:
Cost basis	490	490
Gross unrealized gains	321	10
Gross unrealized losses	0	(3)
Fair Value	811	497
Equity method investments:
Equity method investments	64,488	61,058
Other Investments	0	0
Total investments	65,299	61,555
Results of Investment Liquidation [Abstract]
Proceeds from sale of investments	16	0	223
Gain (loss) on sale of investments	(3)	0	171
MGE [Member] | ATC [Member]
Equity method investments:
Equity method investments	64,488	61,038
MGE [Member] | Other Equity Method Investments [Member]
Equity method investments:
Equity method investments	$ 0	$ 20

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Property, Plant, and Equipment (Tables)

12 Months Ended

Dec. 31, 2013

Property, Plant and Equipment [Abstract]

Schedule of Property, Plant, and Equipment

Property, plant, and equipment consisted of the following at December 31:

		MGE Energy				MGE
(In thousands)		2013		2012		2013		2012
Utility:
Electric	$	953,290	$	912,273	$	953,307	$	912,289
Gas		351,694		332,767		351,705		332,779
Total utility plant		1,304,984		1,245,040		1,305,012		1,245,068
Less: Accumulated depreciation and amortization		560,066		546,483		560,066		546,483
In-service utility plant, net		744,918		698,557		744,946		698,585
Nonregulated:
Nonregulated		311,742		308,043		310,745		307,511
Less: Accumulated depreciation and amortization		37,851		31,547		37,814		31,547
In-service nonregulated plant, net		273,891		276,496		272,931		275,964
Construction work in progress:
Utility construction work in progress		140,301		96,863		140,301		96,863
Nonregulated construction work in progress		1,114		1,548		1,114		1,548
Total property, plant, and equipment	$	1,160,224	$	1,073,464	$	1,159,292	$	1,072,960

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Derivative and Hedging Instruments

12 Months Ended

Dec. 31, 2013

Derivative Instruments and Hedging Activities Disclosure [Abstract]

Derivative and Hedging Instruments

Derivative and Hedging Instruments - MGE Energy and MGE.

a.       Purpose.

As part of its regular operations, MGE enters into contracts, including options, swaps, futures, forwards, and other contractual commitments, to manage its exposure to commodity prices 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:

	December 31, 2013	December 31, 2012
Commodity derivative contracts	458,660MWh	444,650MWh
Commodity derivative contracts	3,750,000Dth	1,980,000Dth
FTRs	1,984MW	2,670MW

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 December 31, 2013 and 2012the fair value of exchange traded derivatives and FTRs exceeded their cost basis by $1.8 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 December 31, 2013 and 2012, reflects a loss position of $65.7 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
December 31, 2013
Commodity derivative contracts	Other current assets	$	1,356	Derivative liability (current)	$	51
Commodity derivative contracts	Other deferred charges		167	Derivative liability (long-term)		48
FTRs	Other current assets		363	Derivative liability (current)		0
Ten-year PPA	N/A		N/A	Derivative liability (current)		7,750
Ten-year PPA	N/A		N/A	Derivative liability (long-term)		57,930
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
December 31, 2013
Commodity derivative contracts	$	1,523	$	(99)	$	(175)	$	1,249
FTRs		363		-		-		363
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
December 31, 2013
Commodity derivative contracts	$	99	$	(99)	$	-	$	-
Ten-year PPA		65,680		-		-		65,680
December 31, 2012
Commodity derivative contracts	$	405	$	(405)	$	-	$	-
Ten-year PPA		72,590		-		-		72,590

The following tables summarize the unrealized and realized gains (losses) related to the derivative instruments on the consolidated balance sheet at December 31, 2013 and 2012, and the consolidated income statement for the year ended December 31, 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
Year Ended December 31:
Balance at January 1,	$	72,329	$	574	$	42,356	$	1,604
Change in unrealized loss		(5,069)		0		37,822		0
Realized loss reclassified to a deferred account		(823)		823		(2,857)		2,857
Realized loss reclassified to income statement		(2,544)		(986)		(4,992)		(3,887)
Balance at December 31,	$	63,893	$	411	$	72,329	$	574

		Realized losses (gains)
		Fuel for Electric
		Generation/		Cost of
(In thousands)		Purchased Power		Gas Sold
Year Ended December 31, 2013:
Commodity derivative contracts	$	(564)	$	868
FTRs		(983)		0
Ten-year PPA		4,209		0
Year Ended December 31, 2012:
Commodity derivative contracts	$	2,620	$	3,072
FTRs		(45)		0
Ten-year PPA		3,232		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 December 31, 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 December 31, 2013 and 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 December 31, 2013, no counterparties have defaulted.

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Regional Transmission Organizations

12 Months Ended

Dec. 31, 2013

Regional Transmission Organizations Disclosure [Abstract]

Regional Transmission Organizations

Regional Transmission Organizations - MGE Energy and MGE.

MGE reports on a net basis transactions on the MISO and PJM markets in which it buys and sells power within the same hour to meet electric energy delivery requirements. This treatment resulted in a $78.0 million reduction to sales to the market and purchase power expense for MISO markets for the year ended December 31, 2013, and a $75.9 million and $102.1 million reduction to sales to the market and purchased power expense for MISO and PJM markets for the years ended December 31,2012 and 2011, respectively.

MISO

MGE is a nontransmission owning member of the MISO. MISO, a FERC approved RTO, is responsible for monitoring the electric transmission system that delivers power from generating plants to wholesale power transmitters. MISO's role is to ensure equal access to the transmission system and to maintain or improve electric system reliability in the Midwest.

MISO maintains a bid-based energy market. MGE offers substantially all of its generation on the MISO market and purchases much of its load requirement from the MISO market in accordance with the MISO Tariff. MGE participates in the ancillary services market operated by MISO. That market is an extension of the existing energy market in which MISO assumes the responsibility of maintaining sufficient generation reserves. In the ancillary services market, MISO provides the reserves for MGE's load, and MGE may offer to sell reserves from its generating units.

MGE participates in the voluntary capacity auction, which provides an optional monthly forum for buyers and sellers of aggregate planning resource credits to interact. Load serving entities, such as MGE, may participate in the voluntary capacity auction potentially to obtain the necessary aggregate planning resource credits needed to meet their planning reserve margin requirement established by the PSCW. Generator owners, such as MGE, may participate to sell any excess aggregate planning resource credits that are not needed by them.

PJM

MGE is a member of PJM. PJM, an RTO, is a neutral and independent party that coordinates and directs the operation of the transmission grid within its area of coverage, administers a competitive wholesale electricity market, and plans regional transmission expansion improvements to maintain grid reliability and relieve congestion.

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Schedule I - Condensed Parent Company Finanical Statements (Details-Comprehensive Income Statement) (USD $) In Thousands, unless otherwise specified	3 Months Ended								12 Months Ended
	Dec. 31, 2013	Sep. 30, 2013	Jun. 30, 2013	Mar. 31, 2013	Dec. 31, 2012	Sep. 30, 2012	Jun. 30, 2012	Mar. 31, 2012	Dec. 31, 2013		Dec. 31, 2012		Dec. 31, 2011
Operating Expenses:
Other operations and maintenance									$ 171,248		$ 172,996		$ 165,859
Total Operating Expenses	129,301	100,199	103,791	129,609	117,655	97,950	92,140	120,815	462,900		428,560		438,514
Operating Income	25,962	39,900	24,497	37,628	19,350	39,888	25,081	28,444	127,987		112,763		107,868
Equity in earnings of investments									9,434		9,079		8,615
Income before income taxes									119,764		103,365		96,920
Income tax provision	(7,829)	(14,692)	(8,660)	(13,678)	(6,208)	(14,253)	(8,596)	(9,862)	(44,859)		(38,919)		(35,992)
Net Income	14,077	24,353	13,891	22,584	10,486	23,642	14,270	16,048	74,905		64,446		60,928
Other comprehensive income/(loss), net of tax:
Unrealized gain (loss) on available for sale securities, net of tax									283	[1]	(18)	[2]	(15)	[3]
Reclassification of realized gain on available-for-sale securities, net of tax									0	[4]	0	[4]	(15)	[3]
Comprehensive Income									75,188		64,428		60,898
MGE Energy [Member]
Operating Expenses:
Other operations and maintenance									613		649		718
Total Operating Expenses									613		649		718
Operating Income									(613)		(649)		(718)
Equity in earnings of investments									76,362		65,132		61,075
Other income/(loss), net									(1,863)		(496)		505
Other interest									55		45		(22)
Income before income taxes									73,941		64,032		60,840
Income tax provision									964		414		88
Net Income									74,905		64,446		60,928
Other comprehensive income/(loss), net of tax:
Unrealized gain (loss) on available for sale securities, net of tax									283	[1]	(18)	[2]	(15)	[3]
Reclassification of realized gain on available-for-sale securities, net of tax									0	[4]	0	[4]	(15)	[3]
Comprehensive Income									$ 75,188		$ 64,428		$ 60,898

[1] Net of $189 tax

[2] Net of $12 tax

[3] Net of $10 tax

[4] Net of $0 tax

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Asset Retirement Obligations (Tables)

12 Months Ended

Dec. 31, 2013

Asset Retirement Obligation Disclosure [Abstract]

Change in Asset Retirement Obligations

The following table shows a rollforward of the AROs from January 1, 2012 toDecember 31, 2013. Amounts include conditional AROs.

(In thousands)		2013		2012
Balance at January 1,	$	18,768	$	19,173
Liabilities incurred		296		49
Accretion expense		1,015		1,021
Liabilities settled		(744)		(221)
Revisions in estimated cash flows(a)		24		(1,254)
Balance at December 31,	$	19,359	$	18,768

(a) In2012, MGE recorded a decrease in revisions in estimated cash flows of $1.3 million based on revised asbestos abatement estimates.

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Investments (Tables)

12 Months Ended

Dec. 31, 2013

Investments Disclosure [Abstract]

Equity Method, Available for Sale Securities, and Other Investments

		MGE Energy				MGE
(In thousands)		2013		2012		2013		2012
Available for sale securities:
Cost basis	$	1,736	$	1,575	$	490	$	490
Gross unrealized gains		629		161		321		10
Gross unrealized losses		0		(3)		0		(3)
Fair value	$	2,365	$	1,733	$	811	$	497
Equity method investments:
ATC	$	64,488	$	61,038	$	64,488	$	61,038
Other		1,099		20		0		20
Total equity method investments	$	65,587	$	61,058	$	64,488	$	61,058
Other investments		0		1,804		0		0
Total	$	67,952	$	64,595	$	65,299	$	61,555

During the year ended December 31, certain investments were liquidated. As a result of these liquidations, MGE Energy and MGE received the following:

		MGE Energy						MGE
(In thousands)		2013		2012		2011		2013		2012		2011
Cash proceeds	$	39	$	0	$	260	$	16	$	0	$	223
Gain (loss) on sale		2		0		198		(3)		0		171

ATC's Summarized Financial Data

ATC's summarized financial data for the years endedDecember 31, 2013, 2012, and 2011 is as follows:

(In thousands)
Income statement data for the year ended December 31,		2013		2012		2011
Operating revenues	$	626,336	$	603,254	$	567,174
Operating expenses		(295,069)		(280,999)		(261,568)
Other income (expense)		831		(2,533)		(1,332)
Interest expense, net		(84,484)		(82,296)		(80,359)
Earnings before members' income taxes	$	247,614	$	237,426	$	223,915
Balance sheet data as of December 31,		2013		2012		2011
Current assets	$	80,715	$	63,134	$	58,671
Noncurrent assets		3,509,517		3,274,704		3,053,742
Total assets	$	3,590,232	$	3,337,838	$	3,112,413
Current liabilities	$	381,467	$	251,541	$	298,473
Long-term debt		1,550,000		1,550,000		1,400,005
Other noncurrent liabilities		126,167		95,829		82,647
Members' equity		1,532,598		1,440,468		1,331,288
Total members' equity and liabilities	$	3,590,232	$	3,337,838	$	3,112,413

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Rate Matters

12 Months Ended

Dec. 31, 2013

Regulated Operations [Abstract]

Rate Matters

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.Theauthorized return on common stock equity remains unchanged at10.3%.

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 ofCSAPR costs.

On January 12, 2011, the PSCW authorized MGE to increase 2011 rates for retail electric customers by 2.3% or $8.0 million and to increase gas rates by 1.0% or $1.9 million. The increase in retail electric rates was driven by costs for MGE's share of the Elm Road Units. Pursuant to the provisions of this rate order, the fuel rules bandwidth effective January 1, 2011, will be plus or minus 2%. Authorized return on common stock equity was set at 10.3% based on a 58.1% utility common equity.

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 exceed 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 are less than 98% of the electric fuel costs allowed in that order.

As of December 31, 2013, MGE has deferred $6.7 million (to be returned to customers in a future period) of 2013electric fuel-related savings that are outside the range authorized by the PSCW.

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Commitments and Contingencies

12 Months Ended

Dec. 31, 2013

Commitments and Contingencies Disclosure [Abstract]

Commitments and Contingencies

Commitments and Contingencies.

a.       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 December 31, 2013, the future minimum commitments related to these purchase contracts were as follows:

(In thousands)		2014		2015		2016		2017		2018
Coal(a)	$	22,109	$	14,633	$	10,938	$	5,073	$	2,710
Natural Gas
Transportation and storage(b)		17,211		16,857		9,288		272		191
Supply(c)		19,511		0		0		0		0
Purchase Power(d)		47,241		45,711		46,467		46,928		47,911
Other		2,314		498		498		498		124
	$	108,386	$	77,699	$	67,191	$	52,771	$	50,936

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

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

(d)MGE has several purchase power agreements to help meet future electric supply requirements. Management expects to recover these costs in future customer rates. In October 2008, MGE entered into a ten-year purchase power agreement to help meet future electric supply requirements. Under this agreement, MGE has agreed to purchase 50 MW of wind power from Osceola Windpower II, LLC, which is located in Iowa. This facility became operational in October 2008. MGE does not have any capacity payment commitments under this agreement. However, MGE is obligated to purchase its ratable share of the energy produced by the project. MGE's commitment related to its ratable share of energy produced by the project has been estimated and is included in the above numbers.

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 December 31, 2013, 2012, and 2011, respectively, MGE had sold a $5.4 million, $4.5 million, and $4.3 million interest in these receivables. MGE retains the servicing responsibility for these receivables.

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 maintains responsibility for collecting and remitting loan payments from customers to the financial institution and does not retain any interest in the assets sold to the financial institution. At December 31,2013, MGE had recorded a servicing asset of $0.3 million. At both December 31,2012 and 2011, MGE had recorded a servicing asset of $0.2 million. MGE recognizeda gain of $0.2 million for the year endedDecember 31,2013 in connection with the sale of loan assets.MGE recognized gains of$0.1 million for each of the years endedDecember 31,2012and 2011, in connection with the sale of loan assets. The servicing asset amount amortized in 2013 was less than $0.1 million. The loan assets are sold to the financial institution at cost, which approximates fair value in view of their market rates of interest. During 2013, 2012, and 2011, MGE received approximately $1.6 million, $1.2 million, and $1.5 million, respectively, from the financial institution for the sale of loan assets. During those same years, payments of $0.8 million, $1.2 million, and $0.8 million, respectively, were made by MGE to the financial institution.

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 December 31, 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 next five years on the loans are:

(In thousands)		2014		2015		2016		2017		2018
Principal payments	$	714	$	1,007	$	910	$	506	$	449

c.       Leases - MGE Energy and MGE.

MGE has noncancelable operating leases, primarily for combustion turbines, railcars, and computer equipment. The operating leases generally do not contain renewal options, with the exception of certain railcar operating leases. These leases have a renewal option of one year or less. MGE is required to pay all executory costs such as maintenance and insurance for its leases.

Future minimum rental payments at December 31, 2013, under agreements classified as operating leases with noncancelable terms in excess of one year are as follows:

(In thousands)		2014		2015		2016		2017		2018		Thereafter
Minimum lease payments	$	1,668	$	1,478	$	983	$	718	$	418	$	8,179

Rental expense under operating leases totaled $2.7 million for 2013, $2.6 million for 2012, and $3.2 million for 2011.

d.       Environmental - MGE Energy and MGE.

Water Quality

Water quality regulations promulgated by the EPA and WDNR in accordance with the Federal Water Pollution Control Act, or more commonly known as the Clean Water Act (CWA), impose restrictions on discharges of various pollutants into surface waters. The CWA also regulates surface water quality issues that affect aquatic life, such as water temperatures, intake structures, and wetlands filling. The CWA also includes discharge standards, which require the use of effluent-treatment processes equivalent to categorical "best practicable" or "best available" technologies. The CWA regulates discharges from "point sources," such as power plants, through establishing discharge limits in water discharge permits. MGE's power plants operate under Wisconsin Pollution Discharge Elimination System (WPDES) permits to ensure compliance with these discharge limits.

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

Section 316(b) of the CWA requires that the cooling water intake structures at electric power plants meet best available technology standards so that mortality from entrainment (drawing aquatic life into a plant's cooling system) and impingement (trapping aquatic life on screens) are reduced. Section 316(b) is implemented in Wisconsin through modifications to plants' WPDES permits in a timeframe determined by the rule. Although new facilities have been required to meet 316(b) standards for some time, regulations for existing facilities have not yet been finalized but are expected to be issued by EPA in 2014.

The currently proposed rule for existing plants allows for a state permitting agency's discretion in determining best technology available at plants and does not require cooling towers in all instances. Blount and Columbia generating plants are subject to both the impingement and entrainment aspects of the current proposed rule. WCCF is subject to the impingement aspect only.The Elm Road Units met the new facility requirements when it was built. We anticipate that under the current proposed rule, equipment would need to be installed at Blount, WCCF and Columbia to meet the new standards. However it is not presently possible to estimate the potential costs associated with this rule because the rule has not been finalized.

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 electric generation plants with a focus on coal-burning plants. The proposed rule regulates wastewater from seven specific wastewater types. The proposed rule is technology-driven in that specific technologies may need to be installed to meet the rule's requirements. Sites that already have these technologies will be deemed to meet the requirements of the rule. The proposed rule as written will likely affect wastewater systems at Columbia and the Elm Road Units.

The EPA has signed a consent decree to finalize the rule by May 2014 and have the rule apply to power plants as they renew their water discharge permits beginning in July 2017. Based on our current evaluation of the proposed rule and its alternatives we may need to add treatments systems or additional equipment at our Elm Road and Columbia facilities. We will have a better understanding of potential costs to MGE once the rule is finalized.

Energy Efficiency and Renewables

The Wisconsin Energy Efficiency and Renewables Act requires that, by 2015, 10% of the state's electricity be generated from renewable resources. MGE is in compliance with the 2015 requirement. The costs to comply with the Act and its accompanying regulations are being recovered in rates.

Air Quality

Federal and state air quality regulations impose restrictions on emission of particulates (PM), sulfur dioxide (SO2), nitrogen oxides (NOx) and other pollutants and require permits for operation of emission sources. These permits have been obtained by MGE and must be renewed periodically. Various initiatives, including interstate pollution transport rules, maximum achievable control technology (MACT) standards, such as the Reciprocating Internal Combustion Engine (RICE) MACT, new source performance standards (NSPS), the Clean Air Visibility Rule (also known as the Regional Haze Rule), and mercury emissions limits are expected to result in additional operating and capital expenditure costs for electric generating units.

Interstate Transport Rules for NOx and SO2

EPA has promulgated three interstate air pollution rules consisting of the NOx SIP Call, the Clean Air Interstate Rule (CAIR) and the Cross-State Air Pollution Rule (CSAPR). These rules were each designed to reduce nitrogen oxide (NOx) and/or sulfur dioxide (SO2) air emissions from EGUs, including EGUs located in Wisconsin and other states. NOx and SO2 interact in the atmosphere to form ambient ozone and fine particulate matter pollution. As explained below, only the CAIR currently affects MGE's generation assets.

In 2000, the U.S. Court of Appeals for the D.C. Circuit held that Wisconsin had been illegally included in a portion of the NOx SIP Call, but stayed the remaining legal challenges to the rule pending EPA's development of additional interstate pollution transport rules. The EPA developed the CAIR to replace the NOx SIP Call, but in 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. In 2011, the EPA developed CSAPR which the U.S. Court of Appeals for the D.C. Circuit vacated in 2012 with directions that the EPA temporarily reinstate CAIR. That decision was argued before the U.S. Supreme Court in December 2013, and a decision is pending. The CAIR remains effective.

The CAIR generally requires NOx 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. Phase I is currently in place. Phase II begins in 2015 and will require regional NOx and SO2 emissions reductions from 2003 levels by 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.

Based on our evaluation of Phase II of CAIR, we will be able to meet NOx emissions reductions through using our NOx allowances provided through the rule, and we will meet SO2 emissions reductions through installation of pollution controls. New SO2 controls that will meet or exceed CAIR allowances at Columbia are underway and are planned to be completed by mid-2014 (see the discussion regarding the Columbia environmental project below). MGE expects that any costs incurred to meet Phase II of the CAIR will be fully recoverable through rates. We will continue to monitor the Supreme Court's response to the CSAPR appeals and any actions by the EPA on any new or revised interstate transport rule.

Clean Air Visibility Rule (CAVR)

Air modeling indicates that SO2 and NOx emissions (and to a lesser extent particulate matter) from Columbia may impair visibility at certain Class I Scenic Areas. Columbia may therefore be subject to the best available retrofit technology (BART) regulations, a subsection of the EPA's Clean Air Visibility Rule (CAVR), which may require pollution retrofits. The EPA had proposed that Columbia's compliance with emissions limitations in the CAIR and the CSAPR could also serve as compliance with the BART for SO2 and NOx emissions. However, this proposal is now uncertain because of the D.C. Circuit remanding the CAIR to the EPA and vacating the CSAPR. The Sierra Club has sought federal appellate court review of Wisconsin's implementation plan for the BART portion of CAVR and that appeal has been stayed pending the U.S. Supreme Court's decision on CSAPR. At this time, the BART regulatory obligations, compliance strategies and costs remain uncertain.

Reciprocating Internal Combustion Engines Maximum Achievable Control Technology (RICE MACT)

In January 2013, the EPA finalized amendments to its RICE MACT standard. RICE MACT applies to industrial or electrical engines that are classified as reciprocating internal combustion engines. Engines owned by MGE that would fall under the RICE MACT rule include backup generators and small engines at various locations, including our fleet of distributed generators that serve as electric system backup and emergency dispatch. Our units that currently serve as system or emergency backup will be restricted to emergency operation and limited (50 hours) non-emergency operation annually or will require additional pollution control equipment to run more often. The EPA issued a notice of reconsideration in August, 2013 on the 50 hour non-emergency operating limit. MGE is currently installing pollution control equipment on a number of units. MGE will continue to monitor developments regarding potential changes to the number of hours allowed for non-emergency operation.

Mercury and Air Toxics Standards (MATs) for Utility Boilers (Also Referred to as the Maximum Achievable Control Technology or MACT)

In December 2011, the EPA finalized its Mercury and Air Toxics Standards for coal and oil-burning EGU boilers. MATs will require emissions standards for mercury, non-mercury HAPs metals, and acid gases. MGE's Columbia and Elm Road Units are subject to MATs. Wisconsin has a separate mercury rule that will be phased out as MATs is implemented. The Elm Road Unit's current pollution controls and Columbia's planned mercury pollution controls (baghouse and scrubbers) are expected to allow both facilities to comply with the MATs rule (see the discussion regarding Columbia environmental project below).

GHG New Source Performance Standards (NSPS) for New and Existing Electric Generating Units

In a June 2013 directive, President Obama instructed the EPA to re-propose greenhouse gas standards for new power plants, based on comments received on their original rule proposal issued in March 2012, and to finalize those standards in a timely manner. The EPA developed proposed standards for new power plants in September 2013, which 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. 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 this rule in 2014.

National Ambient Air Quality Standards (NAAQS)

The EPA has announced that they will be reviewing all of their NAAQS in 2014. Changes in NAAQS can affect the determination as to whether an area is designated as nonattainment, which can affect permitting, capital expenditures and operating costs for emission sources in those nonattainment areas. MGE will be monitoring the outcome of this planned review to evaluate whether changes affect our operations. MGE continues to monitor NAAQS closely because our generation facilities in areas designated as nonattainment for a NAAQS may have additional permitting requirements, including compliance demonstrations and/or equipment installations.

In addition the EPA has developed draft SO2 NAAQS technical documents as guidance to states for classifying areas as attainment or nonattainment. The documents provide guidance for monitoring and/or modeling to determine SO2 levels. We are currently unable to assess operational or capital costs associated with adoption of the final guidance as it has not been adopted by the State of Wisconsin. We will be monitoring State of Wisconsin actions to better evaluate the effect it may have on our Columbia and the Elm Road Units.

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

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. WPL, the plant operator, currently estimates that MGE's share of the capital expenditures required for this project is approximately $135 million. The project is underway and estimated to be completed in mid-2014.

MGE's share of various contractual commitments entered for the project as of December 31, 2013 is $14.7 million. These costs are expected to be capitalized and included in the consolidated balance sheets of MGE Energy and MGE. See Footnote 20 for further information regarding the Columbia environmental construction project.

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, 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.

e.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.

f.Elm Road - MGE Energy and MGE.

The warranty periods for both of the Elm Road Units have expired. During 2013, WEPCO and Bechtel (the construction contractor for the Elm Road Units) were working through theoutstanding warranty claims. The warranty claim for the costs incurred to repair steam turbine corrosion damage identified on both units was resolved through a binding arbitration in June 2013. Final acceptance of the Elm Road Units occurred in June 2013 after all requirements stated in the contract with Bechtel were satisfied.

g.       Other Commitments.

MGE Energy holds investments in nonpublic entities. From time to time, these entities require additional capital infusions from their investors. MGE Energy has committed to contribute $1.7 million in capital for such infusions. The timing of these infusions is dependent on the needs of the investee and is therefore uncertain at this time.

In addition, MGE Energy has a three year agreement with a venture debt fund expiring in December 2016. MGE Energy has committed to invest up to a total of $1.0 million into this fund. As of December 31,2013, MGE Energy has $0.5 million remaining in commitments. The timing of infusions is dependent on the needs of the fund and is therefore uncertain at this time.

MGE has several other commitments related to various projects. Payments for these commitments are expected to be as follows:

(In thousands)		2014		2015		2016		2017		2018		Thereafter
Other Commitments	$	1,473	$	474	$	475	$	433	$	435	$	6,961

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Madison Gas and Electric Company Consolidated Statements of Cash Flows (USD $) In Thousands, unless otherwise specified	12 Months Ended
	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Items not affecting cash:
Depreciation and amortization	$ 38,838	$ 38,707	$ 40,942
Deferred income taxes	38,365	44,797	33,698
Provision for doubtful receivables	2,448	2,498	2,312
Employee benefit plan expenses	13,303	18,353	13,703
Equity earnings in ATC	(9,434)	(9,079)	(8,615)
Other items	117	1,283	1,616
Changes in working capital items:
Receivable - margin account (change)	1,444	3,726	(2,609)
Trade and other receivables (change)	(3,827)	(6,208)	173
Inventories (change)	2,488	1,457	7,438
Unbilled revenues (change)	(3,720)	(2,508)	3,466
Prepaid taxes (change)	414	2,731	245
Other current assets (change)	1,070	367	538
Accounts payable (change)	858	(272)	2,055
Other current liabilities (change)	6,271	425	(4,300)
Dividend income from ATC	7,404	7,146	6,728
Cash contributions to pension and other postretirement plans	(34,765)	(28,857)	(23,670)
Debt make-whole premium	(6,757)	0	0
Other noncurrent items, net	10,845	6,992	(3,876)
Cash Provided by (Used for) Operating Activities	140,267	146,004	130,772
Investing Activities:
Capital expenditures	(119,047)	(98,435)	(65,176)
Capital contributions to investments	(1,660)	(2,419)	(1,008)
Other investing	(1,205)	(496)	1,985
Cash Provided by (Used for) Investing Activities	(121,922)	(101,353)	(66,351)
Financing Activities:
Repayment of long-term debt	(43,012)	(30,668)	(2,500)
Issuance of long-term debt	85,000	28,000	30,000
Decrease in short-term debt	0	0	(22,500)
Other financing	(770)	(844)	(336)
Cash Provided by (Used for) Financing Activities	4,111	(39,463)	(30,362)
Change in Cash and Cash Equivalents:	22,456	5,188	34,059
Cash and cash equivalents at beginning of period	46,357	41,169	7,110
Cash and cash equivalents at end of period	68,813	46,357	41,169
Supplemental disclosures of cash flow information:
Interest paid	17,991	19,499	19,788
Income taxes paid	8,046	3,544	5,537
Income taxes received	(1,339)	(12,536)	(4,370)
Significant noncash investing activities:
Accrued capital expenditures	9,892	10,317	684
MGE [Member]
Operating Activities:
Net Income	76,445	65,306	61,252
Items not affecting cash:
Depreciation and amortization	38,834	38,707	40,942
Deferred income taxes	37,462	44,112	32,773
Provision for doubtful receivables	2,448	2,498	2,312
Employee benefit plan expenses	13,303	18,353	13,703
Equity earnings in ATC	(9,434)	(9,079)	(8,615)
Other items	651	1,813	2,172
Changes in working capital items:
Receivable - margin account (change)	1,444	3,726	(2,609)
Trade and other receivables (change)	(3,699)	(7,219)	1,183
Inventories (change)	2,488	1,457	7,438
Unbilled revenues (change)	(3,720)	(2,508)	3,466
Prepaid taxes (change)	(373)	(1,584)	(477)
Other current assets (change)	1,074	366	536
Accounts payable (change)	126	(1,658)	4,214
Accrued interest and taxes (change)	2,065	211	(3,741)
Other current liabilities (change)	2,975	(714)	(4,027)
Dividend income from ATC	7,404	7,146	6,728
Cash contributions to pension and other postretirement plans	(34,765)	(28,857)	(23,670)
Debt make-whole premium	(6,757)	0	0
Other noncurrent items, net	10,713	6,696	(3,897)
Cash Provided by (Used for) Operating Activities	138,684	138,772	129,683
Investing Activities:
Capital expenditures	(119,047)	(98,435)	(65,176)
Capital contributions to investments	(1,420)	(2,140)	(888)
Other investing	(130)	(508)	342
Cash Provided by (Used for) Investing Activities	(120,597)	(101,083)	(65,722)
Financing Activities:
Cash dividends paid to parent by MGE	(25,000)	(20,404)	(26,648)
Distributions to parent from noncontrolling interest	(27,365)	(23,500)	(52,500)
Equity contribution received by noncontrolling interest	1,420	2,130	888
Repayment of long-term debt	(43,012)	(30,668)	(2,500)
Issuance of long-term debt	85,000	28,000	30,000
Decrease in short-term debt	0	0	(3,500)
Other financing	(672)	(795)	(297)
Cash Provided by (Used for) Financing Activities	(9,629)	(45,237)	(54,557)
Change in Cash and Cash Equivalents:	8,458	(7,548)	9,404
Cash and cash equivalents at beginning of period	6,350	13,898	4,494
Cash and cash equivalents at end of period	14,808	6,350	13,898
Supplemental disclosures of cash flow information:
Interest paid	17,991	19,499	19,731
Income taxes paid	144	44	28
Income taxes received	0	(448)	(10)
Significant noncash investing activities:
Accrued capital expenditures	$ 9,892	$ 10,317	$ 684

XML

Asset Retirement Obligations

12 Months Ended

Dec. 31, 2013

Asset Retirement Obligation Disclosure [Abstract]

Asset Retirement Obligations

Asset Retirement Obligations - MGE Energy and MGE.

MGE recorded an obligation for the fair value of its legal liability for asset retirement obligations (AROs) associated with removal of the West Campus Cogeneration Facility and the Elm Road generating units, electric substations, combustion turbine generating units, wind generating facilities, and photovoltaic generating facilities, all of which are located on property not owned by MGE Energy and MGE and would need to be removed upon the ultimate end of the associated leases. The significant conditional AROs identified by MGE included the costs of abandoning in place gas services and mains, the abatement and disposal of equipment and buildings contaminated with asbestos and PCBs, and the proper disposal and removal of tanks, batteries, and underground cable. Changes in management's assumptions regarding settlement dates, settlement methods, or assigned probabilities could have a material effect on the liabilities recorded by MGE at December 31, 2013, as well as the regulatory asset recorded.

MGE also may have AROs relating to the removal of various assets, such as certain electric and gas distribution facilities. These facilities are generally located on property owned by third parties, on which MGE is permitted to operate by lease, permit, easement, license, or service agreement. The asset retirement obligations associated with these facilities cannot be reasonably determined due to the indeterminate life of the related agreements.

The following table shows a rollforward of the AROs from January 1, 2012 toDecember 31, 2013. Amounts include conditional AROs.

(In thousands)		2013		2012
Balance at January 1,	$	18,768	$	19,173
Liabilities incurred		296		49
Accretion expense		1,015		1,021
Liabilities settled		(744)		(221)
Revisions in estimated cash flows(a)		24		(1,254)
Balance at December 31,	$	19,359	$	18,768

(a) In2012, MGE recorded a decrease in revisions in estimated cash flows of $1.3 million based on revised asbestos abatement estimates.

XML

Regional Transmission Organizations (Details) (USD $) In Millions, unless otherwise specified	12 Months Ended
	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Regional Transmission Organizations Disclosure [Abstract]
Reduction to sales and purchased power expense from reporting RTO transactions from net basis reporting	$ 78.0	$ 75.9	$ 102.1

XML

Significant Accounting Policies (Policies)

12 Months Ended

Dec. 31, 2013

Accounting Policies [Abstract]

Basis of Presentation

Basis of Presentation - MGE Energy and MGE.

The consolidated financial statements are prepared in conformity with accounting principles generally accepted in the United States of America (GAAP), which give recognition to the rate makingaccounting policies for regulated operationsprescribed by the regulatory authorities having jurisdiction, principally the PSCW and FERC. MGE's accounting records conform to the FERC uniform system of accounts.

On December 20, 2013, MGE Energy's Board of Directors declared a three-for-two stock split of MGE Energy's common stock in the form of a stock dividend. The additional shares were distributed February 7, 2014 to all shareholders of record as of January 24, 2014. All shares and per sharedata provided in this reportgive effect to this stock split.

Principles of Consolidation

Principles of Consolidation - MGE Energy and MGE.

MGE, a wholly owned subsidiary of MGE Energy, is a regulated electric and gas utility headquartered in Madison, Wisconsin. MGE Energy and MGE consolidate all majority owned subsidiaries in which it has controlling influence. MGE is the majority owner of MGE Transco. MGE Transco is a nonregulated entity formed to manage the investment in ATC.

Wholly owned subsidiaries of MGE Energy include CWDC, MAGAEL, MGE Construct, MGE Power, NGV Fueling Services, and North Mendota. MGE Power owns 100% of MGE Power Elm Road and MGE PowerWest Campus. MGE Power and its subsidiaries are part of MGE Energy's nonregulated energy operations, which were formed to own and lease electric generation projects to assist MGE.

MGE Energy and MGE consolidate variable interest entities (VIEs) for which it is the primary beneficiary. Variable interest entities are legal entities that possess any of the following characteristics: equity investors who have an insufficient amount of equity at risk to finance their activities, equity owners who do not have the power to direct the significant activities of the entity (or have voting rights that are disproportionate to their ownership interest), or equity holders who do not receive expected losses or returns significant to the VIE. If MGE Energy or MGE is not the primary beneficiary and an ownership interest is held, the VIE is accounted for under the equity method of accounting. When assessing the determination of the primary beneficiary, all relevant facts and circumstances are considered, including: the power, through voting or similar rights, to direct the activities of the VIE that most significantly impact the VIE's economic performance and the obligation to absorb the expected losses and/or the right to receive the expected returns of the VIE. Ongoing reassessments of all VIEs are performed to determine if the primary beneficiary status has changed. MGE has consolidated MGE Power Elm Road and MGE PowerWest Campus. Both entities are VIEs. MGE is considered the primary beneficiary of these entities as a result of contractual agreements. See Footnote 2 for more discussion of these entities.

The consolidated financial statements reflect the application of certain accounting policies described in this note. All significant intercompany accounts and transactions have been eliminated in consolidation.

Use of Estimates

Use of Estimates - MGE Energy and MGE.

In order to prepare consolidated financial statements in conformity with GAAP, management must make estimates and assumptions. These estimates could affect reported amounts of assets, liabilities, and disclosures at the date of the financial statements, as well as the reported amounts of revenues and expenses during the reporting periods. Actual results could differ from management's estimates.

Cash Equivalents and Restricted Cash

Cash Equivalents and Restricted Cash - MGE Energy and MGE.

MGE Energy and MGE consider all highly liquid investments purchased with an original maturity of three months or less to be cash equivalents.

MGE has certain cash accounts that are restricted to uses other than current operations and designated for a specific purpose. MGE's restricted cash accounts include cash held by trustees for certain employee benefits. These are included in other current assets.

Receivable Margin Account

Receivable – Margin Account - MGE Energy and MGE.

Cash amounts held by counterparties as margin for certain financial transactions are recorded as receivable – margin account. The balance is shown net of any collateral posted against derivative positions.

Changes in this cash account are considered cash flows from operating activities to match with the costs being hedged. The costs being hedged are fuel for electric generation, purchased power, and cost of gas sold.

Trade Receivables, Allowance for Doubtful Accounts, and Concentration Risk

Trade Receivables, Allowance for Doubtful Accounts, and Concentration Risk - MGE Energy and MGE.

Trade accounts receivable are recorded at the invoiced amount and do not bear interest. However, a 1% late payment charge is recorded on all receivables unpaid after the due date. The allowance for doubtful accounts associated with these receivables represents our best estimate of the amount of probable credit losses in our existing accounts receivable. We determine our allowance for doubtful accounts based on historical write-off experience, regional economic data, and review of the accounts receivable aging.

MGE is obligated to provide service to all electric and gas customers within its franchised territories. MGE's franchised electric territory includes a 316 square-mile area in Dane County, Wisconsin, and MGE's franchised gas territory includes a service area covering 1,649 square-miles in Wisconsin. MGE manages this concentration and the related credit risk through its credit and collection policies, which are consistent with state regulatory requirements.

Inventories

Inventories - MGE Energy and MGE.

Inventories consist of natural gas in storage, fossil fuels, materials and supplies, SO2 allowances, and renewable energy credits (RECs). MGE values natural gas in storage, fossil fuels, and materials and supplies using average cost.

SO2 emission allowances are included in inventory and are recorded at weighted average cost. These allowances are charged to fuel expense as they are used in operations.

REC allowances are included in inventory and are recorded based on specific identification. These allowances are charged to purchase power expense as they are used in operations.

Regulatory Assets and Liabilities

Regulatory Assets and Liabilities - MGE Energy and MGE.

Regulatory assets and regulatory liabilities are recorded consistent with regulatory treatment. Regulatory assets represent costs which are deferred due to the probable future recovery from customers through regulated rates. Regulatory liabilities represent the excess recovery of costs or accrued credits which were deferred because MGE believes it is probable such amounts will be returned to customers through future regulated rates. Regulatory assets and liabilities are amortized in the consolidated statements of income consistent with the recovery or refund included in customer rates. MGE believes that it is probable that its recorded regulatory assets and liabilities will be recovered and refunded, respectively, in future rates. See Footnote 6 for further information.

Debt Issuance Costs

Debt Issuance Costs - MGE Energy and MGE.

Premiums, discounts, and expenses incurred with the issuance of outstanding long-term debt are amortized over the life of the debt issue. Any call premiums or unamortized expenses associated with refinancing higher-cost debt obligations used to finance utility-regulated assets and operations are amortized consistent with regulatory treatment of those items.

Property, Plant, and Equipment

Property, Plant, and Equipment - MGE Energy and MGE.

Property, plant, and equipment is recorded at original cost. Cost includes indirect costs consisting of payroll taxes, pensions, postretirement benefits, other fringe benefits, and administrative and general costs. Also, included in the cost is AFUDC for utility property and capitalized interest for nonregulated property. Additions for significant replacements of property are charged to property, plant, and equipment at cost; and minor items are charged to maintenance expense. Depreciation rates on utility property are approved by the PSCW, based on the estimated economic lives of property, and include estimates for salvage value and removal costs. Removal costs of utility property, less any salvage value, are adjusted through regulatory liabilities. Depreciation rates on nonregulated property are based on the estimated economic lives of the property.

	2013	2012	2011
Electric	2.7%	2.9%	3.2%
Gas	1.7%	1.7%	1.6%
Nonregulated	2.3%	2.3%	2.3%

Asset Retirement Obligations Policy

Asset Retirement Obligations - MGE Energy and MGE.

MGE Energy and MGE are required to record a liability for the fair value of an ARO to be recognized in the period in which it is incurred if it can be reasonably estimated. The offsetting associated asset retirement costs are capitalized as a long-lived asset and depreciated over the asset's useful life. The expected present value technique used to calculate the fair value of ARO liabilities includes assumptions about costs, probabilities, settlement dates, interest accretion, and inflation. Revisions to the assumptions, including the timing or amount of expected asset retirement costs, could result in increases or decreases to the AROs. All asset retirement obligations are recorded as other long-term liabilities on our balance sheets. MGE has regulatory treatment and recognizes regulatory assets or liabilities for the timing differences between when we recover legal AROs in rates and when we would recognize these costs.

Repairs and Maintenance Expense

Repairs and Maintenance Expense - MGE Energy and MGE.

MGE utilizes the direct expensing method for planned major maintenance projects. Under this method, MGE expenses all costs associated with major planned maintenance activities as incurred.

Purchased Gas Adjustment Clause

Purchased Gas Adjustment Clause - MGE Energy and MGE.

MGE's natural gas rates are subject to a fuel adjustment clause designed to recover or refund the difference between the actual cost of purchased gas and the amount included in rates. Differences between the amounts billed to customers and the actual costs recoverable are deferred and recovered or refunded in future periods by means of prospective monthly adjustments to rates.

These amounts are netted in other current liabilities on the consolidated balance sheet.

Revenue Recognition

Revenue Recognition - MGE Energy and MGE.

Operating revenues are recorded as service is rendered or energy is delivered to customers. Meters are read on a systematic basis throughout the month based on established meter-reading schedules. At the end of the month, MGE accrues an estimate for the unbilled amount of energy delivered to customers. The unbilled revenue estimate is based on daily system demand volumes, weather factors, estimated line losses, estimated customer usage by class, and applicable customer rates.

Utility Cost Recovery

Utility Cost Recovery - MGE Energy and MGE.

MGE's rates include a provision for fuel costs. The PSCW allows Wisconsin utilities to defer electric fuel-related costs, less excess revenues, 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. Such deferred amounts will be recognized in “Purchased Power Expense” in MGE Energy's and MGE's income statement each period. The cumulative effects of these deferred amounts will be recorded in “Regulatory assets” or “Regulatory liabilities” on MGE Energy's and MGE's consolidated balance sheets until they are reflected in future billings to customers. See Footnote 17.b. for further information regarding the regulatory rules applicable to the recovery of electric fuel costs.

Allowance for Funds Used During Construction Policy

Allowance for Funds Used During Construction - MGE Energy and MGE.

Allowance for funds used during construction is included in utility plant accounts and represents the cost of borrowed funds used during plant construction and a return on shareholders' capital used for construction purposes. In the consolidated income statements, the cost of borrowed funds (AFUDC-debt) is presented as an offset to interest expense and the return on shareholders' capital (AFUDC-equity funds) is shown as an item within other income. For both 2012 and 2011, as approved by the PSCW, MGE capitalized AFUDC-debt and equity on 50% of applicable average construction work in progress at 8.36%.For 2013, MGE capitalized AFUDC-debt and equity on 50% of applicable average construction work in progress at8.21%.For both 2012 and 2011, MGE received specific approval to recover 100% AFUDC on certain environmental costs for Columbia and 50% in 2013. Although the allowance does not represent current cash income, it is recovered under the ratemaking process over the service lives of the related properties. See Footnote 20 for further information regarding Columbia AFUDC.

Investments

Investments - MGE Energy and MGE.

Investments in limited liability companies that have specific ownership accounts in which MGE Energy or MGE's ownership interest is more than minor are accounted for using the equity method. All other investments are carried at fair value or at cost, as appropriate. See Footnote 4 for further information.

Capitalized Software Costs

Capitalized Software Costs - MGE Energy and MGE.

Property, plant, and equipment includes the capitalized costs of internal use software totaling $20.9 million and $14.5 million at December 31, 2013 and 2012, respectively. During 2013 and 2012, MGE recorded $1.5 million and $1.3 million, respectively, of amortization expense related to these costs. These costs are amortized on a straight-line basis over the estimated useful lives of the assets. For internal use software, the useful lives range from five to ten years.

Impairment of Long-Lived Assets Policy

Impairment of Long-Lived Assets - MGE Energy and MGE.

MGE reviews plant and equipment and other property for impairment when events or changes in circumstances indicate that the carrying amount of the assets may not be recoverable. MGE's policy for determining when long-lived assets are impaired is to recognize an impairment loss if the sum of the expected future cash flows (undiscounted and without interest charges) from an asset are less than the carrying amount of that asset. If an impairment loss is recognized, the amount that will be recorded will be measured as the amount by which the carrying amount of the asset exceeds the fair value of the asset.

Income Taxes and Excise Taxes

Income Taxes and Excise Taxes - MGE Energy and MGE.

Income taxes

Under the liability method, income taxes are deferred for all temporary differences between pretax financial and taxable income and between the book and tax basis of assets and liabilities using the tax rates scheduled by law to be in effect when the temporary differences reverse. Future tax benefits are recognized to the extent that realization of such benefits is more likely than not. A valuation allowance is recorded for those benefits that do not meet this criterion.

Accounting for uncertainty in income taxes applies to all tax positions and requires a recognition threshold and measurement standard for the financial statement recognition and measurement of a tax position taken, or expected to be taken, in an income tax return. The threshold is defined for recognizing tax return positions in the financial statements as "more likely than not" that the position is sustainable, based on its merits. Subsequent recognition, derecognition, and measurement is based on management's best judgment given the facts, circumstances, and information available at the reporting date.

Regulatory and accounting principles have resulted in a regulatory liability related to income taxes. Excess deferred income taxes result from past taxes provided at rates higher than current rates. The income tax regulatory liability and deferred investment tax credit reflect the revenue requirement associated with the return of these tax benefits to customers.

Investment tax credits from regulated operations are amortized over related property service lives.

Excise taxes

MGE Energy, through its utility operations, pays a state license fee tax in lieu of property taxes on property used in utility operations. License fee tax is calculated as a percentage of adjusted operating revenues of the prior year. The electric tax rate is 3.19% for retail sales and 1.59% for sales of electricity for resale by the purchaser. The tax rate on sales of natural gas is 0.97%. The tax is required to be estimated and prepaid in the year prior to its computation and expensing. License fee tax expense, included in other general taxes, was $13.8 million, $13.5 million, and $12.9 million for the years ended December 31,2013, 2012, and 2011, respectively.

Operating income taxes, including tax credits and license fee tax are included in rates for utility related items.

Share-based Compensation

Share-Based Compensation - MGE Energy and MGE.

Under two separate incentive plans, eligible participants, including employees and non-employee directors, 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. Under the plans, these awards are subject to a prescribed vesting schedule and must be settled in cash. Accordingly, no new shares of common stock are issued in connection with the plans.

MGE Energy and MGE initially measure the cost of the employee or director 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 award is subsequently re-measured at each reporting date through the settlement date. Changes in fair value during the requisite period are recognized as compensation cost over that period.

See Footnote 14 for additional information regarding the plans.

Treasury Stock

Treasury Stock - MGE Energy.

Treasury shares are recorded at cost. Any shares of common stock repurchased are held as treasury shares unless cancelled or reissued.

Comprehensive Income (Loss)

Comprehensive Income - MGE Energy and MGE.

Total comprehensive income includes all changes in equity during a period except those resulting from investments by and distributions to shareholders. Comprehensive income is reflected in the consolidated statements of comprehensive income.

Derivative and Hedging Instruments

Derivative and Hedging Instruments - MGE Energy and MGE.

As part of regular operations, MGE enters into contracts, including options, swaps, futures, forwards, and other contractual commitments, to manage its exposure to interest rates, commodity prices, and gas revenues. MGE recognizes all derivatives in the consolidated balance sheets at fair value, with changes in the fair value of derivative instruments to be recorded in current earnings or deferred in accumulated other comprehensive income (loss), depending on whether a derivative is designated as, and is effective as, a hedge and on the type of hedge transaction. Derivative activities are in accordance with the company's risk management policy.

If the derivative qualifies for regulatory deferral, the derivatives are marked to fair value and any resulting loss or gain is offset with a corresponding regulatory asset or liability. Cash flows from such derivative instruments are classified on a basis consistent with the nature of the underlying hedged item.

Common Equity

Common Stock

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

MGE Energy purchases shares on the open market 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 specific maximum number of shares to be repurchased and no specified termination date for the repurchases.

Fair Value of Financial Instruments

Recurring Fair Value Measurements

At December 31,2013 and 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 long-term debt is based on quoted market prices for similar financial instruments at December 31. Since long-term debt is not traded in an active market, it is classified as Level 2.

No transfers were made in or out of Level 1 or Level 2 for the year ended December 31, 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 considered unobservable and classified as Level 3. Transactions done with an over-the-counter party are on inactive markets and are therefore classified as Level 3. These transactions are valued based on quoted prices from markets with similar exchange traded transactions. FTRs are priced based upon monthly auction results for identical or similar instruments in a closed market with limited data available and are therefore classified as Level 3.

The ten-year purchased power agreement (see Footnote 16) 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	94.2%
Off peak	92.6%
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 26week 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.

Income Taxes

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.

Unrecognized tax benefits are liabilities shown with Other Deferred Liabilities on the December 31, 2013 and December 31, 2012, consolidated balance sheets. The interest component is offset by a regulatory asset.

MGE Energy filed an application with its 2009 tax returns to change its income tax methods of accounting for electric generation, transmission and distribution repairs and its 2010 tax returns for gas distribution repairs. These method changes accelerated tax deductions for repairs in accordance with Treasury Regulations and case law, as compared to the prior method of claiming tax depreciation on project costs. During 2011, the IRS issued guidance on the treatment of electric transmission and distribution repairs. This guidance has prompted the reversal of a majority of the unrecognized tax benefits for these repairs. During 2013, the IRS issued guidance on the treatment of electric generation repairs. This guidance prompted the reversal of the unrecognized tax benefits for these repairs. At December 31, 2013, MGE Energy and MGE have an unrecognized tax benefit in the amount of $2.4 million related to temporary tax differences associated with the change in income tax method of accounting for electric transmission and distribution repairs and gas distribution repairs. At December 31, 2012, MGE Energy and MGE had an unrecognized tax benefit in the amount of $3.2 million primarily related to temporary tax differences associated with the change in income tax method of accounting for electric generation, transmission, and distribution repairs and gas distribution repairs. At December 31, 2011, MGE Energy and MGE had an unrecognized tax benefit in the amount of $2.4 million primarily related to temporary tax differences associated with the change in income tax method of accounting for electric generation repairs and gas distribution repairs. There were no unrecognized tax benefits at December 31, 2013or December 31, 2012related to federal permanent differences and tax credits. Unrecognized tax benefits at December 31, 2011 related to federal permanent differences and tax credits were$0.2million.

The unrecognized tax benefits at December 31, 2013, are not expected to significantly increase or decrease within the next twelve months. However, the IRS may issue guidance on the treatment of gas distribution repairs. In addition, statutes of limitations will expire for MGE Energy and MGE tax returns. The impact of the statutes of limitations expiring is not anticipated to be material.

Pension Plans and Other Postretirement Benefits

Fair Value of Pension and Other Postretirement Benefit Plan Assets

Fair value is defined as the price that would be received to sell an asset or 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.

The following is a description of the valuation methodologies used for assets measured at fair value as of December 31, 2013:

Cash and Cash Equivalents – This category includes highly liquid investments with maturities of less than three months which are traded in active markets.

Equity Securities – These securities consist of U.S. and international stock funds. The U.S. stock funds are primarily invested in domestic equities. Securities in these funds are typically priced using the closing price from the applicable exchange, NYSE, NASDAQ, etc. The international funds are composed of international equities. Securities are priced using the closing price from the appropriate local stock exchange.

Fixed Income Securities – These securities consist of U.S. bond funds and short-term funds. U.S. bond funds are priced by a pricing agent using inputs such as benchmark yields, reported trades, broker/dealer quotes, and issuer spreads. The short-term funds are valued initially at cost and adjusted for amortization of any discount or premium.

Real Estate – The fair value of real estate properties is determined through an external appraisal process.

Insurance Continuance Fund (ICF) – The fair value of the ICF is based on largely unobservable inputs, which are based on a commingled interest.

Derivative and Hedging Instruments

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.

Regional Transmission Organizations

Regional Transmission Organizations

MGE reports on a net basis transactions on the MISO and PJM markets in which it buys and sells power within the same hour to meet electric energy delivery requirements.

Commitments and Contingencies

Chattel PaperAgreement

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.

MGE retains the servicing responsibility for these receivables.

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 maintains responsibility for collecting and remitting loan payments from customers to the financial institution and does not retain any interest in the assets sold to the financial institution.

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 December 31, 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.

Adoption of Accounting Principles and Recently Issued Accounting Pronouncements

New Accounting Pronouncements

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 16 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 became 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 became 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.

Segment Information

Segment Information

Segment Information - MGE Energy and MGE.

The electric utility business purchases, generates and distributes electricity, and contracts for transmission service. The gas utility business purchases and distributes natural gas and contracts for the transportation of natural gas. Both the electric and gas segments operate through MGE Energy's principal subsidiary, MGE.

The nonregulated energy operations are conducted through MGE Energy's subsidiaries: MGE Power, MGE Power Elm Road, and MGE Power West Campus. These subsidiaries own and lease electric generating capacity to assist MGE. MGE Power Elm Road has an ownership interest in two coal-fired generating units in Oak Creek, Wisconsin, which are leased to MGE, and MGE Power West Campus owns a controlling interest in the electric generation plant of a natural gas-fired cogeneration facility on the UW campus. MGE Power West Campus's portion is also leased to MGE.

The transmission investment segment invests, through MGE Transco, in ATC, a company that provides electric transmission services primarily in Wisconsin. See Footnote 4 for further discussion of MGE Transco and the investment in ATC.

The "All Others" segment includes: corporate, CWDC, MAGAEL, MGE Construct, NGV Fueling Services, and North Mendota. These entities' operations consist of investing in companies and property which relate to the regulated operations, financing the regulated operations, or owning and operating natural gas compression equipment.

General corporate expenses include the cost of executive management, corporate accounting and finance, information technology, risk management, human resources and legal functions, and employee benefits that are allocated to electric and gas segments based on formulas prescribed by the PSCW. Identifiable assets are those used in MGE's operations in each segment. Assets not allocated consist primarily of cash and cash equivalents, restricted cash, investments, other accounts receivable, and prepaid assets.

Sales between our electric and gas segments are based on PSCW approved tariffed rates. Additionally, intersegment operations related to the leasing arrangement between our electric segment and MGE Power Elm Road/MGE Power West Campus are based on terms previously approved by the PSCW. Consistent with internal reporting, management has presented the direct financing capital leases between MGE and MGE Power Elm Road/MGE Power West Campus based on actual lease payments included in rates.Lease payments made by MGE to MGE PowerElm Roadand MGE Power West Campusare shown as operating expenses. The lease payments received by MGE PowerElm Roadand MGE Power West Campusfrom MGE are shown as lease income in interdepartmental revenues. The depreciation expense associated with the Elm Road Unitsand WCCF is reflected in the nonregulated energy segment.

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Share-Based Compensation (Tables)

12 Months Ended

Dec. 31, 2013

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

Performance Unit Graded Vesting Schedule

	MGE Energy
Grant Date	Units Granted
January 15, 2010	25,965
January 21, 2011	23,483
February 17, 2012	25,040
February 15, 2013	22,884
February 21, 2014	21,991

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Fair Value of Financial Instruments (Details-2) (USD $) In Thousands, unless otherwise specified	Dec. 31, 2013		Dec. 31, 2012
Assets:
Available-for-sale securities	$ 2,365		$ 1,733
Liabilities:
Derivative asset, collateral offset	200		0
Recurring [Member]
Assets:
Total Assets	792		320
Liabilities:
Derivatives, net	63,893	[1]	72,329
Deferred compensation	2,364		2,010
Total Liabilities	66,257		74,339
Recurring [Member] | Exchange-traded investments
Assets:
Available-for-sale securities	792		320
Recurring [Member] | Level 1 [Member]
Assets:
Total Assets	792		320
Liabilities:
Derivatives, net	(735)	[1]	(17)
Deferred compensation	0		0
Total Liabilities	(735)		(17)
Recurring [Member] | Level 1 [Member] | Exchange-traded investments
Assets:
Available-for-sale securities	792		320
Recurring [Member] | Level 2 [Member]
Assets:
Total Assets	0		0
Liabilities:
Derivatives, net	0	[1]	0
Deferred compensation	2,364		2,010
Total Liabilities	2,364		2,010
Recurring [Member] | Level 2 [Member] | Exchange-traded investments
Assets:
Available-for-sale securities	0		0
Recurring [Member] | Level 3 [Member]
Assets:
Total Assets	0		0
Liabilities:
Derivatives, net	64,628	[1]	72,346
Deferred compensation	0		0
Total Liabilities	64,628		72,346
Recurring [Member] | Level 3 [Member] | Exchange-traded investments
Assets:
Available-for-sale securities	0		0
MGE [Member]
Assets:
Available-for-sale securities	811		497
Liabilities:
Derivative asset, collateral offset	200
MGE [Member] | Recurring [Member]
Assets:
Total Assets	431		117
Liabilities:
Derivatives, net	63,893	[1]	72,329
Deferred compensation	2,364		2,010
Total Liabilities	66,257		74,339
MGE [Member] | Recurring [Member] | Exchange-traded investments
Assets:
Available-for-sale securities	431		117
MGE [Member] | Recurring [Member] | Level 1 [Member]
Assets:
Total Assets	431		117
Liabilities:
Derivatives, net	(735)	[1]	(17)
Deferred compensation	0		0
Total Liabilities	(735)		(17)
MGE [Member] | Recurring [Member] | Level 1 [Member] | Exchange-traded investments
Assets:
Available-for-sale securities	431		117
MGE [Member] | Recurring [Member] | Level 2 [Member]
Assets:
Total Assets	0		0
Liabilities:
Derivatives, net	0	[1]	0
Deferred compensation	2,364		2,010
Total Liabilities	2,364		2,010
MGE [Member] | Recurring [Member] | Level 2 [Member] | Exchange-traded investments
Assets:
Available-for-sale securities	0		0
MGE [Member] | Recurring [Member] | Level 3 [Member]
Assets:
Total Assets	0		0
Liabilities:
Derivatives, net	64,628	[1]	72,346
Deferred compensation	0		0
Total Liabilities	64,628		72,346
MGE [Member] | Recurring [Member] | Level 3 [Member] | Exchange-traded investments
Assets:
Available-for-sale securities	$ 0		$ 0

[1] These amounts are shown gross and exclude $0.2 million of collateral that was posted against derivative positions with counterparties.

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MGE Energy Inc Consolidated Statements of Income (USD $) In Thousands, except Per Share data, unless otherwise specified	12 Months Ended
	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Operating Revenues:
Regulated electric revenues	$ 403,957	$ 392,365	$ 375,858
Regulated gas revenues	181,462	139,727	165,271
Nonregulated revenues	5,468	9,231	5,253
Total Operating Revenues	590,887	541,323	546,382
Operating Expenses:
Fuel for electric generation	46,062	46,499	50,819
Purchased power	80,830	73,842	64,085
Cost of gas sold	107,315	78,156	99,465
Other operations and maintenance	171,248	172,996	165,859
Depreciation and amortization	38,838	38,707	40,942
Other general taxes	18,607	18,360	17,344
Total Operating Expenses	462,900	428,560	438,514
Operating Income	127,987	112,763	107,868
Other income, net	10,701	10,069	9,214
Interest expense, net	(18,924)	(19,467)	(20,162)
Income before income taxes	119,764	103,365	96,920
Income tax provision	(44,859)	(38,919)	(35,992)
Net Income	$ 74,905	$ 64,446	$ 60,928
Earnings Per Share of Common Stock (basic and diluted)	$ 2.16	$ 1.86	$ 1.76
Dividends per share of common stock	$ 1.07	$ 1.04	$ 1.01
Weighted Average Shares Outstanding (basic and diluted)	34,668	34,668	34,668

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Joint Plant Ownership (Tables)

12 Months Ended

Dec. 31, 2013

Columbia Units [Member]

Jointly Owned Utility Plant Interests [Line Items]

Joint Plant Ownership

MGE's interest in Columbia, included in its gross utility plant in service, and the related accumulated depreciation reserves at December 31 were as follows:

(In thousands)		2013		2012
Utility plant	$	123,097	$	119,544
Accumulated depreciation		(78,880)		(78,016)
Property, plant, and equipment, net	$	44,217	$	41,528
Construction work in progress		120,858		59,917
Total property, plant, and equipment	$	165,075	$	101,445

Elm Road Units [Member]

Jointly Owned Utility Plant Interests [Line Items]

Joint Plant Ownership

MGE Power Elm Road's interest in the portion of the Elm Road Units in-service and the related accumulated depreciation reserves at December 31 were as follows:

(In thousands)		2013		2012
Nonregulated plant	$	198,198	$	196,146
Accumulated depreciation		(15,541)		(11,126)
Property, plant, and equipment, net	$	182,657	$	185,020
Construction work in progress		1,115		1,440
Total property, plant, and equipment	$	183,772	$	186,460

West Campus [Member]

Jointly Owned Utility Plant Interests [Line Items]

Joint Plant Ownership

MGE Power West Campus' interest in WCCF and the related accumulated depreciation reserves at December 31 were as follows:

(In thousands)		2013		2012
Nonregulated plant	$	111,268	$	110,266
Accumulated depreciation		(21,704)		(19,927)
Property, plant, and equipment, net	$	89,564	$	90,339

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Columbia Environmental Project Construction (Details) (USD $)	12 Months Ended									12 Months Ended
	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011	Dec. 31, 2013 Columbia Environmental Project [Member] PSCW [Member]	Dec. 31, 2012 Columbia Environmental Project [Member] PSCW [Member]	Dec. 31, 2011 Columbia Environmental Project [Member] PSCW [Member]	Dec. 31, 2014 Columbia Environmental Project [Member] PSCW [Member] Approved Future Rate Matters [Member]	Dec. 31, 2013 Columbia Units [Member] WPL [Member]	Dec. 31, 2013 Columbia Units [Member] WPSC [Member]	Dec. 31, 2013 MGE [Member]	Dec. 31, 2012 MGE [Member]	Dec. 31, 2011 MGE [Member]	Dec. 31, 2013 MGE [Member] Columbia Environmental Project [Member]	Dec. 31, 2012 MGE [Member] Columbia Environmental Project [Member]	Dec. 31, 2013 MGE [Member] Columbia Units [Member]
Jointly Owned Utility Plant Interests [Line Items]
Jointly owned utility plant, ownership interest								46.20%	31.80%						22.00%
Jointly owned utility plant, total expected capital expenditures													$ 135,000,000
Total incurred costs to date	141,415,000	98,411,000								141,415,000	98,411,000		120,900,000
Expected capital expenditures in next fiscal year													14,000,000
AFUDC equity recognized										$ 3,140,000	$ 1,731,000	$ 413,000	$ 2,700,000	$ 1,400,000
Authorized AFUDC rate	50.00%	50.00%	50.00%	50.00%	100.00%	100.00%	100.00%
Authorized rate of return				50.00%

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Consolidated Statements of Comprehensive Income (Parentheticals) (USD $) In Thousands, unless otherwise specified	12 Months Ended
	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Unrealized gain (loss) on available-for-sale securities, taxes	$ 189	$ (12)	$ (10)
Reclassification of realized gain on available-for-sale securities, taxes	0	0	(10)
MGE [Member]
Unrealized gain (loss) on available-for-sale securities, taxes	126	(29)	(7)
Reclassification of realized gain on available-for-sale securities, taxes	$ 0	$ 0	$ (10)

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Commitments and Contingencies (Details-5) (USD $)	Dec. 31, 2013
MGE [Member]
Other Commitments [Line Items]
Other commitments, due in 2014	$ 1,473,000
Other commitments, due in 2015	474,000
Other commitments, due in 2016	475,000
Other commitments, due in 2017	433,000
Other commitments, due in 2018	435,000
Other commitment, due thereafter	6,961,000
MGE Energy [Member] | Investments in Non Public Entities, Capital Infusions [Member]
Other Commitments [Line Items]
Other commitment, initial agreed upon commitment total	1,700,000
MGE Energy [Member] | Venture Debt Fund [Member]
Other Commitments [Line Items]
Other commitment, initial agreed upon commitment total	1,000,000
Other commitments, total as of balance sheet date	$ 500,000

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Summary of Significant Accounting Policies (Details) (USD $)	0 Months Ended	12 Months Ended
	Dec. 20, 2013	Dec. 31, 2013 sqmi	Dec. 31, 2012	Dec. 31, 2011
Basis of Presentation
Stock split declared December 20, 2013, ratio (3:2)	1.5
Receivable - Margin Account [Abstract]
Derivative asset, collateral offset		$ 200,000	$ 0
Trade Receivables, Allowance for Doubtful Accounts, and Concentration Risk
Late payment charge on upaid receivables		1.00%
Electric territory (in square miles)		316
Gas territory (in square miles)		1,649
Inventories
Emissions allowance included in inventory		100,000	100,000
Renewable energy credit allowance included in inventory		600,000	500,000
Purchased Gas Adjustment Clause
Purchased gas adjustment, over (under) collected		1,700,000	(100,000)
Allowance for Funds Used During Construction
Authorized AFUDC rate		50.00%	50.00%	50.00%
Rate at which AFUDC was capitalized		8.21%	8.36%	8.36%
Capitalized Software Costs
Capitalized software		20,900,000	14,500,000
Capitalized software amortization		1,500,000	1,300,000
Impairment of Long-Lived Assets
Impairment of long-lived assets		0	0	0
Excise taxes
License fee tax rate, electric, retail sales		3.19%
License fee tax rate, electric, resale by purchaser		1.59%
License fee tax rate, natural gas		0.97%
License fee tax expense		$ 13,800,000	$ 13,500,000	$ 12,900,000
Treasury Stock
Treasury stock outstanding (in shares)		0
Minimum [Member] | Capitalized Software [Member]
Capitalized Software Costs
Property, plant, and equipment, useful life		5 years
Maximum [Member] | Capitalized Software [Member]
Capitalized Software Costs
Property, plant, and equipment, useful life		10 years
Columbia Environmental Project [Member] | PSCW [Member]
Allowance for Funds Used During Construction
Authorized AFUDC rate		50.00%	100.00%	100.00%
Electric [Member]
Property, Plant, and Equiptment
Composite straight-line depreciation rates		2.70%	2.90%	3.20%
Gas [Member]
Property, Plant, and Equiptment
Composite straight-line depreciation rates		1.70%	1.70%	1.60%
Non Regulated Energy [Member]
Property, Plant, and Equiptment
Composite straight-line depreciation rates		2.30%	2.30%	2.30%
MGE Power Elm Road [Member]
Principles of Consolidation
Ownership percentage by parent		100.00%
MGE Power West Campus [Member]
Principles of Consolidation
Ownership percentage by parent		100.00%

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Related Party Transactions (Details) (ATC [Member], USD $) In Millions, unless otherwise specified	12 Months Ended
	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
ATC [Member]
Related party transaction [Line Items]
Related party expenses	$ 27.7	$ 25.3	$ 25.0
Due from Related Parties	$ 0.2	$ 0.2	$ 0.2

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Segment Information

12 Months Ended

Dec. 31, 2013

Segment Reporting [Abstract]

Segment Information

Segment Information - MGE Energy and MGE.

The electric utility business purchases, generates and distributes electricity, and contracts for transmission service. The gas utility business purchases and distributes natural gas and contracts for the transportation of natural gas. Both the electric and gas segments operate through MGE Energy's principal subsidiary, MGE.

The nonregulated energy operations are conducted through MGE Energy's subsidiaries: MGE Power, MGE Power Elm Road, and MGE Power West Campus. These subsidiaries own and lease electric generating capacity to assist MGE. MGE Power Elm Road has an ownership interest in two coal-fired generating units in Oak Creek, Wisconsin, which are leased to MGE, and MGE Power West Campus owns a controlling interest in the electric generation plant of a natural gas-fired cogeneration facility on the UW campus. MGE Power West Campus's portion is also leased to MGE.

The transmission investment segment invests, through MGE Transco, in ATC, a company that provides electric transmission services primarily in Wisconsin. See Footnote 4 for further discussion of MGE Transco and the investment in ATC.

The "All Others" segment includes: corporate, CWDC, MAGAEL, MGE Construct, NGV Fueling Services, and North Mendota. These entities' operations consist of investing in companies and property which relate to the regulated operations, financing the regulated operations, or owning and operating natural gas compression equipment.

General corporate expenses include the cost of executive management, corporate accounting and finance, information technology, risk management, human resources and legal functions, and employee benefits that are allocated to electric and gas segments based on formulas prescribed by the PSCW. Identifiable assets are those used in MGE's operations in each segment. Assets not allocated consist primarily of cash and cash equivalents, restricted cash, investments, other accounts receivable, and prepaid assets.

Sales between our electric and gas segments are based on PSCW approved tariffed rates. Additionally, intersegment operations related to the leasing arrangement between our electric segment and MGE Power Elm Road/MGE Power West Campus are based on terms previously approved by the PSCW. Consistent with internal reporting, management has presented the direct financing capital leases between MGE and MGE Power Elm Road/MGE Power West Campus based on actual lease payments included in rates.Lease payments made by MGE to MGE PowerElm Roadand MGE Power West Campusare shown as operating expenses. The lease payments received by MGE PowerElm Roadand MGE Power West Campusfrom MGE are shown as lease income in interdepartmental revenues. The depreciation expense associated with the Elm Road Unitsand WCCF is reflected in the nonregulated energy segment.

The following table shows segment information for MGE Energy's and MGE's operations:

(In thousands)						Non-						Consolidation/
MGE Energy						Regulated		Transmission		All		Elimination		Consolidated
		Electric		Gas		Energy		Investment		Others		Entries		Total
Year Ended December 31, 2013
Operating revenues	$	403,957	$	181,462	$	5,468	$	0	$	0	$	0	$	590,887
Interdepartmental revenues		537		12,629		42,591		0		0		(55,757)		0
Total operating revenues		404,494		194,091		48,059		0		0		(55,757)		590,887
Depreciation and amortization		(25,780)		(5,898)		(7,156)		0		(4)		0		(38,838)
Other operating expenses		(316,277)		(162,661)		(128)		(1)		(752)		55,757		(424,062)
Operating income (loss)		62,437		25,532		40,775		(1)		(756)		0		127,987
Other (deductions) income, net		3,062		59		0		9,434		(1,854)		0		10,701
Interest (expense) income, net		(9,645)		(2,986)		(6,400)		0		107		0		(18,924)
Income (loss) before taxes		55,854		22,605		34,375		9,433		(2,503)		0		119,764
Income tax (provision) benefit		(19,176)		(9,168)		(13,682)		(3,796)		963		0		(44,859)
Net income (loss)	$	36,678	$	13,437	$	20,693	$	5,637	$	(1,540)	$	0	$	74,905
Year Ended December 31, 2012
Operating revenues	$	392,365	$	139,727	$	9,231	$	0	$	0	$	0	$	541,323
Interdepartmental revenues		487		12,814		34,714		0		0		(48,015)		0
Total operating revenues		392,852		152,541		43,945		0		0		(48,015)		541,323
Depreciation and amortization		(26,031)		(5,569)		(7,107)		0		0		0		(38,707)
Other operating expenses		(300,149)		(136,567)		(121)		0		(1,031)		48,015		(389,853)
Operating income (loss)		66,672		10,405		36,717		0		(1,031)		0		112,763
Other (deductions) income, net		1,145		323		0		9,080		(479)		0		10,069
Interest (expense) income, net		(10,189)		(2,874)		(6,537)		0		133		0		(19,467)
Income (loss) before taxes		57,628		7,854		30,180		9,080		(1,377)		0		103,365
Income tax (provision) benefit		(20,906)		(2,769)		(12,113)		(3,648)		517		0		(38,919)
Net income (loss)	$	36,722	$	5,085	$	18,067	$	5,432	$	(860)	$	0	$	64,446
Year Ended December 31, 2011
Operating revenues	$	375,858	$	165,271	$	5,253	$	0	$	0	$	0	$	546,382
Interdepartmental revenues		495		12,440		38,148		0		0		(51,083)		0
Total operating revenues		376,353		177,711		43,401		0		0		(51,083)		546,382
Depreciation and amortization		(28,323)		(5,593)		(7,026)		0		0		0		(40,942)
Other operating expenses		(292,080)		(155,444)		(174)		0		(957)		51,083		(397,572)
Operating income (loss)		55,950		16,674		36,201		0		(957)		0		107,868
Other income, net		71		20		0		8,614		509		0		9,214
Interest (expense) income, net		(10,849)		(3,060)		(6,331)		0		78		0		(20,162)
Income (loss) before taxes		45,172		13,634		29,870		8,614		(370)		0		96,920
Income tax (provision) benefit		(15,334)		(5,249)		(11,988)		(3,467)		46		0		(35,992)
Net income (loss)	$	29,838	$	8,385	$	17,882	$	5,147	$	(324)	$	0	$	60,928

(In thousands)						Non-				Consolidation/
MGE						Regulated		Transmission		Elimination		Consolidated
		Electric		Gas		Energy		Investment		Entries		Total
Year Ended December 31, 2013
Operating revenues	$	403,980	$	181,477	$	5,468	$	0	$	0	$	590,925
Interdepartmental revenues		514		12,614		42,591		0		(55,719)		0
Total operating revenues		404,494		194,091		48,059		0		(55,719)		590,925
Depreciation and amortization		(25,780)		(5,898)		(7,156)		0		0		(38,834)
Other operating expenses*		(335,059)		(171,717)		(13,810)		(1)		55,719		(464,868)
Operating income (loss)*		43,655		16,476		27,093		(1)		0		87,223
Other (deductions) income, net*		2,668		(53)		0		5,638		0		8,253
Interest expense, net		(9,645)		(2,986)		(6,400)		0		0		(19,031)
Net income		36,678		13,437		20,693		5,637		0		76,445
Less: Net income attributable to
noncontrolling interest, net of tax		0		0		0		0		(27,438)		(27,438)
Net income attributable to MGE	$	36,678	$	13,437	$	20,693	$	5,637	$	(27,438)	$	49,007
Year Ended December 31, 2012
Operating revenues	$	392,365	$	139,727	$	9,231	$	0	$	0	$	541,323
Interdepartmental revenues		487		12,814		34,714		0		(48,015)		0
Total operating revenues		392,852		152,541		43,945		0		(48,015)		541,323
Depreciation and amortization		(26,031)		(5,569)		(7,107)		0		0		(38,707)
Other operating expenses*		(320,701)		(139,236)		(12,234)		0		48,015		(424,156)
Operating income*		46,120		7,736		24,604		0		0		78,460
Other income, net*		791		223		0		5,432		0		6,446
Interest expense, net		(10,189)		(2,874)		(6,537)		0		0		(19,600)
Net income		36,722		5,085		18,067		5,432		0		65,306
Less: net income attributable to
noncontrolling interest, net of tax		0		0		0		0		(24,489)		(24,489)
Net income attributable to MGE	$	36,722	$	5,085	$	18,067	$	5,432	$	(24,489)	$	40,817
Year Ended December 31, 2011
Operating revenues	$	375,858	$	165,271	$	5,253	$	0	$	0	$	546,382
Interdepartmental revenues		495		12,440		38,148		0		(51,083)		0
Total operating revenues		376,353		177,711		43,401		0		(51,083)		546,382
Depreciation and amortization		(28,323)		(5,593)		(7,026)		0		0		(40,942)
Other operating expenses*		(307,193)		(160,631)		(12,162)		0		51,083		(428,903)
Operating income*		40,837		11,487		24,213		0		0		76,537
Other (deductions) income, net*		(150)		(42)		0		5,147		0		4,955
Interest expense, net		(10,849)		(3,060)		(6,331)		0		0		(20,240)
Net income		29,838		8,385		17,882		5,147		0		61,252
Less: Net income attributable to
noncontrolling interest, net of tax		0		0		0		0		(23,970)		(23,970)
Net income attributable to MGE	$	29,838	$	8,385	$	17,882	$	5,147	$	(23,970)	$	37,282
*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:
December 31, 2013	$	899,257	$	265,694	$	19,853	$	288,116	$	64,504	$	431,436	$	(389,800)	$	1,579,060
December 31, 2012		888,444		285,468		18,559		323,216		61,064		413,291		(403,118)		1,586,924
December 31, 2011		794,738		285,702		32,882		299,421		57,006		401,862		(412,729)		1,458,882
Capital Expenditures:
Year ended Dec. 31, 2013	$	100,146	$	15,554	$	0	$	3,347	$	0	$	0	$	0	$	119,047
Year ended Dec. 31, 2012		81,965		13,812		0		2,658		0		0		0		98,435
Year ended Dec. 31, 2011		47,206		15,830		0		2,140		0		0		0		65,176

		Utility						Consolidated
(In thousands)						Assets					Consolidation/
MGE						not	Nonregulated			Transmission		Elimination
		Electric		Gas		Allocated		Energy		Investment		Entries		Total
Assets:
December 31, 2013	$	899,257	$	265,694	$	19,853	$	288,066	$	64,504	$	(6,731)	$	1,530,643
December 31, 2012		888,444		285,468		18,559		323,166		61,064		(23,050)		1,553,651
December 31, 2011		794,738		285,702		32,882		299,171		57,006		(35,706)		1,433,793
Capital Expenditures:
Year ended Dec. 31, 2013	$	100,146	$	15,554	$	0	$	3,347	$	0	$	0	$	119,047
Year ended Dec. 31, 2012		81,965		13,812		0		2,658		0		0		98,435
Year ended Dec. 31, 2011		47,206		15,830		0		2,140		0		0		65,176

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Joint Plant Ownership (Details) (USD $)	12 Months Ended
	Dec. 31, 2013 MW	Dec. 31, 2012	Dec. 31, 2011
Columbia Units [Member]
Jointly Owned Plants, Net Plant Ownership [Abstract]
Plant	$ 123,097,000	$ 119,544,000
Accumulated depreciation	(78,880,000)	(78,016,000)
Property, plant, and equipment, net	44,217,000	41,528,000
Construction work in progress	120,858,000	59,917,000
Total property, plant, and equipment	165,075,000	101,445,000
Columbia Units [Member] | MGE [Member]
Jointly Owned Utility Plant Interests [Line Items]
Jointly owned utility plant, proportion of total net summer generating capability	31.00%
Jointly owned utility plant, plant capacity (in MW)	245
Jointly owned utility plant, ownership interest	22.00%
Jointly owned utility plant, fuel, operating, and maintenance expense	37,500,000	36,300,000	37,100,000
Elm Road Units [Member] | MGE [Member]
Jointly Owned Utility Plant Interests [Line Items]
Jointly owned utility plant, fuel, operating, and maintenance expense	13,400,000	13,200,000	18,000,000
Elm Road Units [Member] | MGE Power Elm Road [Member]
Jointly Owned Utility Plant Interests [Line Items]
Jointly owned utility plant, proportion of total net summer generating capability	14.00%
Jointly owned utility plant, plant capacity (in MW)	106
Jointly owned utility plant, number of operating units	2
Jointly Owned Plants, Net Plant Ownership [Abstract]
Plant	198,198,000	196,146,000
Accumulated depreciation	(15,541,000)	(11,126,000)
Property, plant, and equipment, net	182,657,000	185,020,000
Construction work in progress	1,115,000	1,440,000
Total property, plant, and equipment	183,772,000	186,460,000
Elm Road Unit 1 [Member] | MGE Power Elm Road [Member]
Jointly Owned Utility Plant Interests [Line Items]
Jointly owned utility plant, plant capacity (in MW)	615
Jointly owned utility plant, ownership interest	8.33%
Elm Road Unit 2 [Member] | MGE Power Elm Road [Member]
Jointly Owned Utility Plant Interests [Line Items]
Jointly owned utility plant, plant capacity (in MW)	615
Jointly owned utility plant, ownership interest	8.33%
West Campus [Member] | UW [Member]
Jointly Owned Utility Plant Interests [Line Items]
Jointly owned utility plant, ownership interest	45.00%
Jointly owned utility plant, fuel, operating, and maintenance expense	4,900,000	4,900,000	5,000,000
West Campus [Member] | MGE Power West Campus [Member]
Jointly Owned Utility Plant Interests [Line Items]
Jointly owned utility plant, ownership interest	55.00%
Jointly Owned Plants, Net Plant Ownership [Abstract]
Plant	111,268,000	110,266,000
Accumulated depreciation	(21,704,000)	(19,927,000)
Property, plant, and equipment, net	$ 89,564,000	$ 90,339,000

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Long-Term Debt

12 Months Ended

Dec. 31, 2013

Debt Disclosure [Abstract]

Long-Term Debt

Long-Term Debt- MGE Energy and MGE.

a.Long-Term Debt.

		2013				2012
(In thousands)		MGE Energy		MGE		MGE Energy		MGE
First Mortgage Bonds: (a)
7.70%, 2028 Series	$	1,200	$	1,200	$	1,200	$	1,200
Tax Exempt Debt:
3.45%, 2027 Series,
Industrial Development Revenue Bonds		19,300		19,300		19,300		19,300
Medium-Term Notes: (b)
5.26%, due 2017 (d)		0		0		20,000		20,000
5.25%, due 2017		30,000		30,000		30,000		30,000
6.12%, due 2028		20,000		20,000		20,000		20,000
7.12%, due 2032		25,000		25,000		25,000		25,000
6.247%, due 2037		25,000		25,000		25,000		25,000
Total Medium-Term Notes		100,000		100,000		120,000		120,000
Other Long-Term Debt: (c)
5.59%, due 2018 (d), (e)		20,000		20,000		40,000		40,000
3.38%, due 2020 (e)		15,000		15,000		15,000		15,000
3.09%, due 2023 (d), (e)		30,000		30,000		0		0
3.29%, due 2026 (d), (e)		15,000		15,000		0		0
5.68%, due 2033 (f)		29,797		29,797		30,000		30,000
5.19%, due 2033 (f)		19,857		19,857		20,000		20,000
5.26%, due 2040 (e)		15,000		15,000		15,000		15,000
5.04%, due 2040 (g)		43,472		43,472		45,138		45,138
4.74%, due 2041 (g)		27,167		27,167		28,167		28,167
4.38%, due 2042 (e)		28,000		28,000		28,000		28,000
4.42%, due 2043 (d), (e)		20,000		20,000		0		0
4.47%, due 2048 (d), (e)		20,000		20,000		0		0
Total Other Long-Term Debt		283,293		283,293		221,305		221,305
Long-term debt due within one year		(4,102)		(4,102)		(3,013)		(3,013)
Unamortized discount		(277)		(277)		(301)		(301)
Total Long-Term Debt	$	399,414	$	399,414	$	358,491	$	358,491

(a)MGE's utility plant is subject to the lien of its Indenture of Mortgage and Deed of Trust, under which its first mortgage bonds are issued. The Mortgage Indenture provides that dividends or any other distribution or purchase of shares may not be made if the aggregate amount thereof since December 31, 1945 would exceed the earned surplus (retained earnings) accumulated subsequent to December 31, 1945. As of December 31, 2013, approximately $305.6 million was available for the payment of dividends under this covenant.

(b)The indenture under which MGE's Medium-Term notes are issued provides that those notes will be entitled to be equally and ratably secured in the event that MGE issues any additional first mortgage bonds.

(c)Unsecured notes issued pursuant to various Note Purchase Agreements with one or more purchasers. The notes are not issued under, or governed by, MGE's Indenture dated as of September 1, 1998, which governs MGE's Medium-Term Notes.

(d)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. 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 included 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 were used and are expected to continue to be used to help finance the Columbia environmental project.

(e)Issued by MGE. Under that Note Purchase Agreement: (i) note holders have the right to require MGE to repurchase their notes at par in the event of an acquisition of beneficial ownership of 30% or more of the outstanding voting stock of MGE Energy, (ii) MGE must maintain a ratio of its consolidated indebtedness to consolidated total capitalization not to exceed a maximum of 65%, and (iii) MGE cannot issue "Priority Debt" in an amount exceeding 20% of its consolidated assets. Priority Debt is defined as any indebtedness of MGE secured by liens other than specified liens permitted by the Note Purchase Agreement and certain unsecured indebtedness of certain subsidiaries. As of December 31, 2013, MGE is in compliance with the covenant requirements.

(f)Issued by MGE Power West Campus. The Note Purchase Agreements require it to maintain a projected debt service coverage ratio of not less than 1.25 to 1.00, and debt to total capitalization ratio of not more than .65 to 1.00. The notes are secured by a collateral assignment of lease payments that MGE is making to MGE Power West Campus for use of its ownership interest in the West Campus Cogeneration Facility pursuant to a long-term lease.As of December 31, 2013, MGE Power West Campus is in compliance with the covenant requirements.

(g)Issued by MGE Power Elm Road. The Note Purchase Agreement requires MGE Power Elm Road to maintain a projected and actual debt service coverage ratio at the end of any calendar quarter of not less than 1.25 to 1.00 for the trailing 12-month period. The notes are secured by a collateral assignment of lease payments that MGE is making to MGE Power Elm Road for use of its ownership interest in the Elm Road Units pursuant to long-term leases.As of December 31, 2013, MGE Power Elm Road is in compliance with the covenant requirements.

b.       Long-Term Debt Maturities.

Below is MGE Energy's and MGE's aggregate maturities for all long-term debt for years following the December 31, 2013,consolidated balance sheets.

		MGE
(In thousands)		Energy		MGE *
2014	$	4,102	$	4,102
2015		4,182		4,182
2016		4,268		4,268
2017		34,358		34,358
2018		24,452		24,452
Future years		332,431		332,431
Total	$	403,793	$	403,793

*Includes $29.8 million and $19.9 million for MGE Power West Campus, and $43.5 million and $27.2 million for MGE Power Elm Road, all of which are consolidated with MGE's debt (see Footnote 2 for further information).

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Quarterly Summary of Operations

12 Months Ended

Dec. 31, 2013

Quarterly Financial Information Disclosure [Abstract]

Quarterly Summary of Operations

Quarterly Summary of Operations - MGE Energy (unaudited).

(In thousands, except per share amounts)		Quarters Ended
2013		March 31		June 30		September 30		December 31
Operating revenues:
Regulated electric revenues	$	93,494	$	96,846	$	119,836	$	93,781
Regulated gas revenues		72,467		30,042		18,864		60,089
Nonregulated revenues		1,276		1,400		1,399		1,393
Total Operating Revenues		167,237		128,288		140,099		155,263
Operating expenses		129,609		103,791		100,199		129,301
Operating income		37,628		24,497		39,900		25,962
Interest and other income, net		(1,366)		(1,946)		(855)		(4,056)
Income tax provision		(13,678)		(8,660)		(14,692)		(7,829)
Earnings on common stock	$	22,584	$	13,891	$	24,353	$	14,077
Earnings per common share	$	0.65	$	0.40	$	0.70	$	0.41
Dividends per share	$	0.263	$	0.263	$	0.272	$	0.272
2012
Operating revenues:
Regulated electric revenues	$	89,936	$	96,339	$	118,914	$	87,176
Regulated gas revenues		57,019		18,629		16,587		47,492
Nonregulated revenues		2,304		2,253		2,337		2,337
Total Operating Revenues		149,259		117,221		137,838		137,005
Operating expenses		120,815		92,140		97,950		117,655
Operating income		28,444		25,081		39,888		19,350
Interest and other income, net		(2,534)		(2,215)		(1,993)		(2,656)
Income tax provision		(9,862)		(8,596)		(14,253)		(6,208)
Earnings on common stock	$	16,048	$	14,270	$	23,642	$	10,486
Earnings per common share	$	0.47	$	0.41	$	0.68	$	0.30
Dividends per share	$	0.255	$	0.255	$	0.263	$	0.263

Notes:

•The quarterly results of operations within a year may not be comparable because of seasonal and other factors.

•The sum of earnings per share of common stock for any four quarters may vary slightly from the earnings per share of common stock for the equivalent twelve-month period due to rounding.

•MGE Energy's operations are based primarily on its utility subsidiary MGE

•Per share amounts for all periods presented reflect the three-for-two stock split declared on December 20, 2013 effective in the form of a stock dividend distributed onFebruary 7, 2014.

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Quarterly Summary of Operations (Details) (USD $) In Thousands, except Per Share data, unless otherwise specified	0 Months Ended	3 Months Ended								12 Months Ended
	Dec. 20, 2013	Dec. 31, 2013	Sep. 30, 2013	Jun. 30, 2013	Mar. 31, 2013	Dec. 31, 2012	Sep. 30, 2012	Jun. 30, 2012	Mar. 31, 2012	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Operating Revenues:
Regulated electric revenues		$ 93,781	$ 119,836	$ 96,846	$ 93,494	$ 87,176	$ 118,914	$ 96,339	$ 89,936	$ 403,957	$ 392,365	$ 375,858
Regulated gas revenues		60,089	18,864	30,042	72,467	47,492	16,587	18,629	57,019	181,462	139,727	165,271
Nonregulated revenues		1,393	1,399	1,400	1,276	2,337	2,337	2,253	2,304	5,468	9,231	5,253
Total Operating Revenues		155,263	140,099	128,288	167,237	137,005	137,838	117,221	149,259	590,887	541,323	546,382
Operating expenses		129,301	100,199	103,791	129,609	117,655	97,950	92,140	120,815	462,900	428,560	438,514
Operating Income		25,962	39,900	24,497	37,628	19,350	39,888	25,081	28,444	127,987	112,763	107,868
Interest and other income, net		(4,056)	(855)	(1,946)	(1,366)	(2,656)	(1,993)	(2,215)	(2,534)
Income tax provision		(7,829)	(14,692)	(8,660)	(13,678)	(6,208)	(14,253)	(8,596)	(9,862)	(44,859)	(38,919)	(35,992)
Net Income		$ 14,077	$ 24,353	$ 13,891	$ 22,584	$ 10,486	$ 23,642	$ 14,270	$ 16,048	$ 74,905	$ 64,446	$ 60,928
Earnings per common share		$ 0.41	$ 0.70	$ 0.40	$ 0.65	$ 0.30	$ 0.68	$ 0.41	$ 0.47	$ 2.16	$ 1.86	$ 1.76
Dividends per share		$ 0.272	$ 0.272	$ 0.263	$ 0.263	$ 0.263	$ 0.263	$ 0.255	$ 0.255	$ 1.07	$ 1.04	$ 1.01
Stock split declared December 20, 2013, ratio (3:2)	1.5

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Fair Value of Financial Instruments

12 Months Ended

Dec. 31, 2013

Fair Value Disclosures [Abstract]

Fair Value of Financial Instruments

Fair Value of Financial Instruments - MGE Energy and MGE.

Fair value is defined as the price that would be received to sell an asset or would be paid to transfer a liability (an exit price) in the principal or most advantageous market for the asset or liability in an orderly transaction between market participants at the measurement date. The 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 December 31,2013 and 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 long-term debt is based on quoted market prices for similar financial instruments at December 31. Since long-term debt is not traded in an active market, it is classified as Level 2.The estimated fair market value of MGE Energy's and MGE's financial instruments are as follows:

		2013				2012
		Carrying		Fair		Carrying		Fair
(In thousands)		Amount		Value		Amount		Value
MGE Energy
Assets:
Cash and cash equivalents	$	68,813	$	68,813	$	46,357	$	46,357
Liabilities:
Long-term debt*		403,793		432,010		361,805		427,456
MGE
Assets:
Cash and cash equivalents	$	14,808	$	14,808	$	6,350	$	6,350
Liabilities:
Long-term debt*		403,793		432,010		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 December 31, 2013
(In thousands)		Total		Level 1		Level 2		Level 3
MGE Energy
Assets:
Exchange-traded investments	$	792	$	792	$	0	$	0
Total Assets	$	792	$	792	$	0	$	0
Liabilities:
Derivatives, net(a)	$	63,893	$	(735)	$	0	$	64,628
Deferred compensation		2,364		0		2,364		0
Total Liabilities	$	66,257	$	(735)	$	2,364	$	64,628
MGE
Assets:
Exchange-traded investments	$	431	$	431	$	0	$	0
Total Assets	$	431	$	431	$	0	$	0
Liabilities:
Derivatives, net(a)	$	63,893	$	(735)	$	0	$	64,628
Deferred compensation		2,364		0		2,364		0
Total Liabilities	$	66,257	$	(735)	$	2,364	$	64,628
(a)     These amounts are shown gross and exclude $0.2 million of collateral that was posted
against derivative positions with counterparties.
	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 year ended December 31, 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 considered unobservable and classified as Level 3. Transactions done with an over-the-counter party are on inactive markets and are therefore classified as Level 3. These transactions are valued based on quoted prices from markets with similar exchange traded transactions. FTRs are priced based upon monthly auction results for identical or similar instruments in a closed market with limited data available and are therefore classified as Level 3.

The ten-year purchased power agreement (see Footnote 16) 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	94.2%
Off peak	92.6%
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 26week 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.

(In thousands)		2013		2012		2011
Balance as of January 1,	$	(72,346)	$	(40,661)	$	(19,216)
Realized and unrealized gains (losses):
Included in regulatory liabilities (assets)		7,718		(31,685)		(21,445)
Included in other comprehensive income		0		0		0
Included in earnings		(2,618)		(5,005)		868
Included in current assets		(108)		0		0
Purchases		23,726		13,370		341
Sales		(2)		92		144
Issuances		0		0		0
Settlements		(20,998)		(8,457)		(1,353)
Transfers in and/or out of Level 3		0		0		0
Balance as of December 31,	$	(64,628)	$	(72,346)	$	(40,661)
Total gains (losses) included in earnings attributed to the
change in unrealized gains (losses) related to assets and
liabilities held at December 31,(b)	$	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(b).

(In thousands)
Year Ended December 31,		2013		2012		2011
Purchased Power Expense	$	(2,618)	$	(5,005)	$	868

(b)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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Noncontrolling Interest (Details) (USD $) In Thousands, unless otherwise specified	12 Months Ended
	Dec. 31, 2013		Dec. 31, 2012		Dec. 31, 2011
MGE [Member]
Noncontrolling Interest [Line Items]
Noncontrolling interest on balance sheet	$ 118,963		$ 117,470
Net income attributable to noncontrolling interest, net of tax	27,438		24,489		23,970
MGE Transco [Member]
Noncontrolling Interest [Line Items]
Noncontrolling interest on balance sheet	19,998	[1]	16,985	[1]
Net income attributable to noncontrolling interest, net of tax	2,408	[1]	2,146	[1]	1,893	[1]
MGE Power [Member]
Noncontrolling Interest [Line Items]
Ownership percentage by parent	100.00%
MGE Power West Campus [Member]
Noncontrolling Interest [Line Items]
Ownership percentage by parent	100.00%
Noncontrolling interest on balance sheet	29,089	[2]	30,682	[2]
Net income attributable to noncontrolling interest, net of tax	7,657	[2]	7,506	[2]	7,501	[2]
MGE Power Elm Road [Member]
Noncontrolling Interest [Line Items]
Ownership percentage by parent	100.00%
Noncontrolling interest on balance sheet	69,876	[2]	69,803	[2]
Net income attributable to noncontrolling interest, net of tax	$ 17,373	[2]	$ 14,837	[2]	$ 14,576	[2]

[1] At December 31, 2013, MGE is the majority owner, and MGE Energy 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.

[2] MGE Power Elm Road and MGE Power West Campus are not subsidiaries of MGE; however, they have been consolidated in the consolidated financial statements of MGE (see Footnote 2). MGE Power Elm Road and MGE Power West Campus are 100% owned by MGE Power, and MGE Power is 100% owned by MGE Energy. MGE Energy's proportionate share of the equity and net income (through its wholly owned subsidiary MGE Power) of MGE Power Elm Road and MGE Power West Campus is classified within the MGE financial statements as noncontrolling interest.

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MGE Energy Inc Consolidated Statements of Cash Flows (USD $) In Thousands, unless otherwise specified	12 Months Ended
	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Operating Activities:
Net Income	$ 74,905	$ 64,446	$ 60,928
Items not affecting cash:
Depreciation and amortization	38,838	38,707	40,942
Deferred income taxes	38,365	44,797	33,698
Provision for doubtful receivables	2,448	2,498	2,312
Employee benefit plan expenses	13,303	18,353	13,703
Equity earnings in ATC	(9,434)	(9,079)	(8,615)
Other items	117	1,283	1,616
Changes in working capital items:
Receivable - margin account (change)	1,444	3,726	(2,609)
Trade and other receivables (change)	(3,827)	(6,208)	173
Inventories (change)	2,488	1,457	7,438
Unbilled revenues (change)	(3,720)	(2,508)	3,466
Prepaid taxes (change)	414	2,731	245
Other current assets (change)	1,070	367	538
Accounts payable (change)	858	(272)	2,055
Other current liabilities (change)	6,271	425	(4,300)
Dividend income from ATC	7,404	7,146	6,728
Cash contributions to pension and other postretirement plans	(34,765)	(28,857)	(23,670)
Debt make-whole premium	(6,757)	0	0
Other noncurrent items, net	10,845	6,992	(3,876)
Cash Provided by (Used for) Operating Activities	140,267	146,004	130,772
Investing Activities:
Capital expenditures	(119,047)	(98,435)	(65,176)
Capital contributions to investments	(1,660)	(2,419)	(1,008)
Purchase of investment - land	(10)	(3)	(2,152)
Other investing	(1,205)	(496)	1,985
Cash Provided by (Used for) Investing Activities	(121,922)	(101,353)	(66,351)
Financing Activities:
Cash dividends paid on common stock	(37,107)	(35,951)	(35,026)
Repayment of long-term debt	(43,012)	(30,668)	(2,500)
Issuance of long-term debt	85,000	28,000	30,000
Decrease in short-term debt	0	0	(22,500)
Other financing	(770)	(844)	(336)
Cash Provided by (Used for) Financing Activities	4,111	(39,463)	(30,362)
Change in Cash and Cash Equivalents:	22,456	5,188	34,059
Cash and cash equivalents at beginning of period	46,357	41,169	7,110
Cash and cash equivalents at end of period	68,813	46,357	41,169
Supplemental disclosures of cash flow information:
Interest paid	17,991	19,499	19,788
Income taxes paid	8,046	3,544	5,537
Income taxes received	(1,339)	(12,536)	(4,370)
Significant noncash investing activities:
Accrued capital expenditures	$ 9,892	$ 10,317	$ 684

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Madison Gas and Electric Company Consolidated Statements of Income (USD $) In Thousands, unless otherwise specified	12 Months Ended
	Dec. 31, 2013		Dec. 31, 2012		Dec. 31, 2011
Operating Revenues:
Regulated electric revenues	$ 403,957		$ 392,365		$ 375,858
Regulated gas revenues	181,462		139,727		165,271
Nonregulated revenues	5,468		9,231		5,253
Total Operating Revenues	590,887		541,323		546,382
Operating Expenses:
Fuel for electric generation	46,062		46,499		50,819
Purchased power	80,830		73,842		64,085
Cost of gas sold	107,315		78,156		99,465
Other operations and maintenance	171,248		172,996		165,859
Depreciation and amortization	38,838		38,707		40,942
Other general taxes	18,607		18,360		17,344
Total Operating Expenses	462,900		428,560		438,514
Operating Income	127,987		112,763		107,868
Other Income and Deductions:
Equity in earnings in ATC	9,434		9,079		8,615
Total Other Income and Deductions	10,701		10,069		9,214
Interest Expense:
Net Interest Expense	18,924		19,467		20,162
Net Income	74,905		64,446		60,928
MGE [Member]
Operating Revenues:
Regulated electric revenues	403,980		392,365		375,858
Regulated gas revenues	181,477		139,727		165,271
Nonregulated revenues	5,468		9,231		5,253
Total Operating Revenues	590,925		541,323		546,382
Operating Expenses:
Fuel for electric generation	46,070		46,499		50,819
Purchased power	80,844		73,842		64,085
Cost of gas sold	107,330		78,156		99,465
Other operations and maintenance	170,498		171,965		164,903
Depreciation and amortization	38,834		38,707		40,942
Other general taxes	18,607		18,360		17,344
Income tax provision	41,519		35,334		32,287
Total Operating Expenses	503,702		462,863		469,845
Operating Income	87,223	[1]	78,460	[1]	76,537	[1]
Other Income and Deductions:
AFUDC - equity funds	3,140		1,731		413
Equity in earnings in ATC	9,434		9,079		8,615
Income tax provision	(4,303)		(4,101)		(3,752)
Other deductions, net	(18)		(263)		(321)
Total Other Income and Deductions	8,253	[1]	6,446	[1]	4,955	[1]
Income before interest expense	95,476		84,906		81,492
Interest Expense:
Interest on long-term debt	20,087		20,386		20,634
Other interest, net	(21)		(82)		(226)
AFUDC - borrowed funds	(1,035)		(704)		(168)
Net Interest Expense	19,031		19,600		20,240
Net Income Including Noncontrolling Interest	76,445		65,306		61,252
Less Net Income Attributable to Noncontrolling Interest, net of tax	(27,438)		(24,489)		(23,970)
Net Income	$ 49,007		$ 40,817		$ 37,282

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

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Investments

12 Months Ended

Dec. 31, 2013

Investments Disclosure [Abstract]

Investments

Investments - MGE Energy and MGE.

a.       Equity Method Investments, Available for Sale Securities, and Other Investments.

		MGE Energy				MGE
(In thousands)		2013		2012		2013		2012
Available for sale securities:
Cost basis	$	1,736	$	1,575	$	490	$	490
Gross unrealized gains		629		161		321		10
Gross unrealized losses		0		(3)		0		(3)
Fair value	$	2,365	$	1,733	$	811	$	497
Equity method investments:
ATC	$	64,488	$	61,038	$	64,488	$	61,038
Other		1,099		20		0		20
Total equity method investments	$	65,587	$	61,058	$	64,488	$	61,058
Other investments		0		1,804		0		0
Total	$	67,952	$	64,595	$	65,299	$	61,555

MGE Energy's and MGE's available for sale securities represent publicly traded securities and private equity investments in common stock of companies in various industries.

During the year ended December 31, certain investments were liquidated. As a result of these liquidations, MGE Energy and MGE received the following:

		MGE Energy						MGE
(In thousands)		2013		2012		2011		2013		2012		2011
Cash proceeds	$	39	$	0	$	260	$	16	$	0	$	223
Gain (loss) on sale		2		0		198		(3)		0		171

b.       ATC.

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

MGE Transco has accounted for its investment in ATC under the equity method of accounting. For the years endedDecember 31, 2013, 2012, and 2011, MGE Transco recorded equity earnings from the investment in ATC of $9.4 million, $9.1 million, and $8.6million, respectively. Dividends received from ATC were $7.4 million, $7.1 million, and $6.7 million for the years endedDecember 31, 2013, 2012, and 2011, respectively. During the years endedDecember 31, 2013, 2012, and 2011, MGE Transco made $1.4 million, $2.1 million, and $0.9 million, respectively, in capital contributions to ATC.On January 31, 2014, MGE Transco made a $0.5million capital contribution to ATC.

At December 31, 2013 and 2012, MGE Transco held a 3.6% ownership interest in ATC. MGE Transco's investment balance is different from the amount of the underlying equity in the net assets of ATC. This difference is attributable to the allocation of certain tax impacts related to the initial asset transfer.

At December 31, 2013 and 2012, 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 years endedDecember 31, 2013, 2012, and 2011 is as follows:

(In thousands)
Income statement data for the year ended December 31,		2013		2012		2011
Operating revenues	$	626,336	$	603,254	$	567,174
Operating expenses		(295,069)		(280,999)		(261,568)
Other income (expense)		831		(2,533)		(1,332)
Interest expense, net		(84,484)		(82,296)		(80,359)
Earnings before members' income taxes	$	247,614	$	237,426	$	223,915
Balance sheet data as of December 31,		2013		2012		2011
Current assets	$	80,715	$	63,134	$	58,671
Noncurrent assets		3,509,517		3,274,704		3,053,742
Total assets	$	3,590,232	$	3,337,838	$	3,112,413
Current liabilities	$	381,467	$	251,541	$	298,473
Long-term debt		1,550,000		1,550,000		1,400,005
Other noncurrent liabilities		126,167		95,829		82,647
Members' equity		1,532,598		1,440,468		1,331,288
Total members' equity and liabilities	$	3,590,232	$	3,337,838	$	3,112,413

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Schedule I - Condensed Parent Company Finanical Statements (Details-Balance Sheet) (USD $) In Thousands, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011	Dec. 31, 2010
Current Assets:
Cash and cash equivalents	$ 68,813	$ 46,357	$ 41,169	$ 7,110
Accounts receivable, net:
Prepaid taxes and other	19,106	19,520
Total Current Assets	220,601	222,937
Other deferred assets and other	5,853	5,973
Investments:
Other investments	0	1,804
Total investments	67,952	64,595
Total Assets	1,579,060	1,586,924	1,458,882
Current Liabilities:
Accrued interest and taxes	5,661	4,296
Other current liabilities	9,489	5,637
Total Current Liabilities	96,666	75,797
Other Credits:
Deferred income taxes	284,791	270,410
Total Other Credits	465,470	573,207
Shareholders' Equity:
Retained income	266,197	228,399
Other comprehensive income (loss)	377	94
Total Common Shareholders' Equity	617,510	579,429	550,952	525,080
Commitments and contingencies (see Footnote 18)	0	0
Total Liabilities and Capitalization	1,579,060	1,586,924
MGE Energy [Member]
Current Assets:
Cash and cash equivalents	51,204	36,881	24,620	972
Accounts receivable, net:
Accounts receivable from affiliates	125	795
Prepaid taxes and other	1,015	451
Total Current Assets	52,344	38,127
Other deferred assets and other	157	129
Investments:
Investments in affiliates	583,435	556,911
Other investments	948	787
Total investments	584,383	557,698
Total Assets	636,884	595,954
Current Liabilities:
Accounts payable to affiliates	530	603
Accrued interest and taxes	4,297	4,164
Other current liabilities	3,076	1,148
Total Current Liabilities	7,903	5,915
Other Credits:
Deferred income taxes	5,646	4,228
Accounts payable to affiliates	5,825	6,382
Total Other Credits	11,471	10,610
Shareholders' Equity:
Common shareholders' equity	350,936	350,936
Retained income	266,197	228,399
Other comprehensive income (loss)	377	94
Total Common Shareholders' Equity	617,510	579,429
Commitments and contingencies (see Footnote 18)	0	0
Total Liabilities and Capitalization	$ 636,884	$ 595,954

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Commitments and Contingencies (Details-4) (USD $) In Millions, unless otherwise specified	12 Months Ended
	Dec. 31, 2013
Columbia Environmental Project [Member] | MGE [Member]
Columbia
Jointly owned utility plant, total expected capital expenditures	$ 135.0
Columbia Units [Member]
Columbia
Contractual commitments	14.7
Envrionmental civil penalty expense	0.2
Accrual for future environmental mitigation projects	$ 0.6
Wisconsin Energy Efficiency and Renewables Act [Member]
Energy Efficiency and Renewables
Minimum electricity generated from renewable resources by 2015	10.00%
Clean Air Interstate Rule [Member]
Air Quality
Minimum capacity of fossil-fuel fired electric generating units required to meet certain air quality regulations (in MW)	25
Fossil-fuel EGU emission reduction levels as compared to 2003, phase two (beginning in 2015), NOx	65.00%
Fossil-fuel EGU emission reduction levels as compared to 2003, phase two (beginning in 2015), SO2	70.00%

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Commitments and Contingencies (Details-2) (Chattel Paper Agreement [Member], USD $)	12 Months Ended
	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Guarantor Obligations [Line Items]
Guarantor obligation, maximum financing receivable	$ 10,000,000
Guarantor obligation, current carrying value	5,400,000	4,500,000	4,300,000
Servicing asset, amount recognized at period end	300,000	200,000	200,000
Servicing asset, gain recognized during the year in connection with sale of new loan assets	200,000	100,000	100,000
Servicing asset, amortization	100,000
Guarantor obligation, proceeds received from financial institution for sale of loan assets	1,600,000	1,200,000	1,500,000
Guarantor obligation, payments to financial institution for loan assets	800,000	1,200,000	800,000
Guarantor Obligation, Fiscal Year Maturity [Abstract]
Guarantor obligation, 2014	714,000
Guarantor obligation, 2015	1,007,000
Guarantor obligation, 2016	910,000
Guarantor obligation, 2017	506,000
Guarantor obligation, 2018	$ 449,000
Minimum [Member]
Guarantor Obligations [Line Items]
Guarantor obligation, term	1 year
Maximum [Member]
Guarantor Obligations [Line Items]
Guarantor obligation, term	10 years

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Document and Entity Information (USD $)	12 Months Ended
	Dec. 31, 2013
Document and Entity Information [Line Items]
Entity Registrant Name	MGE Energy Inc
Entity Central Index Key	0001161728
Document Type	10-K
Document Period End Date	Dec. 31, 2013
Amendment Flag	false
Document Fiscal Year Focus	2013
Document Fiscal Period Focus	FY
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 Public Float	$ 1,262,041,684
Entity Common Stock Shares Outstanding	34,668,370
MGE [Member]
Document and Entity Information [Line Items]
Entity Registrant Name	Madison Gas and Electric Company
Entity Central Index Key	0000061339
Entity Well known Seasoned Issuer	No
Entity Voluntary Filers	No
Entity Current Reporting Status	Yes
Entity Filer Category	Non-accelerated Filer
Entity Common Stock Shares Outstanding	17,347,894

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Joint Plant Ownership

12 Months Ended

Dec. 31, 2013

Regulated Operations [Abstract]

Joint Plant Ownership

Joint Plant Ownership - MGE Energy and MGE.

a.       Columbia.

MGE and two other utilities jointly own Columbia, a coal-fired generating facility located in Portage,Wisconsin, which accounts for 31% (245 MW) of MGE's net summer rated capacity. Power from this facility is shared in proportion to each company's ownership interest. MGE has a 22% ownership interest in Columbia. The other owners are WPL, which operates Columbia, and WPSC. MGE's share of fuel, operating, and maintenance expenses for Columbia were $37.5 million, $36.3 million, and $37.1 million for the years ended December 31,2013, 2012, and 2011, respectively. See Footnote 18 for discussion of MGE's future capital commitments in respect to the environmental projects at Columbia as a result of this ownership interest.

Each owner provides its own financing and reflects its respective portion of facilities and operating costs in its financial statements. MGE's interest in Columbia, included in its gross utility plant in service, and the related accumulated depreciation reserves at December 31 were as follows:

(In thousands)		2013		2012
Utility plant	$	123,097	$	119,544
Accumulated depreciation		(78,880)		(78,016)
Property, plant, and equipment, net	$	44,217	$	41,528
Construction work in progress		120,858		59,917
Total property, plant, and equipment	$	165,075	$	101,445

b.       Elm Road.

MGE Power Elm Road owns an 8.33% ownership interest in each of two 615 MW coal-fired generating units in Oak Creek, Wisconsin, which accounts for 14% (106 MW) of MGE's net summer rated capacity. Unit 1 entered commercial operation on February 2, 2010. Unit 2 entered commercial operation on January 12, 2011. MGE Power Elm Road's sole principal asset is that ownership interest in those generating units. MGE Power Elm Road's interest in the Elm Road Units is leased to MGE pursuant to long-term leases.

The remainder of the ownership interest in the Elm Road Units is held by two other entities, one of which is also responsible for the Units' operation. Each owner provides its own financing and reflects its respective portion of the facility and costs in its financial statements. MGE's share of fuel, operating, and maintenance expenses for the Elm Road Units were $13.4 million, $13.2 million, and $18.0 million for the years ended December 31, 2013,2012, and 2011, respectively.MGE Power Elm Road's interest in the portion of the Elm Road Units in-service and the related accumulated depreciation reserves at December 31 were as follows:

(In thousands)		2013		2012
Nonregulated plant	$	198,198	$	196,146
Accumulated depreciation		(15,541)		(11,126)
Property, plant, and equipment, net	$	182,657	$	185,020
Construction work in progress		1,115		1,440
Total property, plant, and equipment	$	183,772	$	186,460

c.       WCCF.

MGE Power West Campus and the UW jointly own the West Campus Cogeneration Facility located on the UW campus in Madison, Wisconsin. MGE Power West Campus owns 55% of the facility and the UW owns 45% of the facility. The UW owns a controlling interest in the chilled-water and steam plants, which are used to meet the growing needs for air-conditioning and steam-heat capacity for the UW campus. MGE Power West Campus owns a controlling interest in the electric generation plant, which is leased and operated by MGE.

Each owner provides its own financing and reflects its respective portion of the facility and operating costs in its financial statements. MGE Power West Campus' interest in WCCF and the related accumulated depreciation reserves at December 31 were as follows:

(In thousands)		2013		2012
Nonregulated plant	$	111,268	$	110,266
Accumulated depreciation		(21,704)		(19,927)
Property, plant, and equipment, net	$	89,564	$	90,339

Operating charges are allocated to the UW based on formulas contained in the operating agreement. Under the provisions of this arrangement, the UW is required to reimburse MGE for their allocated portion of fuel and operating expenses. For the years ended December 31, 2013 and 2012, the UW allocated share of fuel and operating costs was $4.9 million. For the year ended December 31, 2011, the UW allocated share of fuel and operating costs was$5.0 million.

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Pension Plans and Other Postretirement Benefits (Details-5) (USD $)	12 Months Ended
	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Other postretirement benefits [Abstract]
Fair value of plan assets	$ 315,000,000	$ 244,401,000
Funded status [Abstract]
Fair value of plan assets	315,000,000	244,401,000
Unfunded status of the plans in balance sheet [Abstract]
Long-term asset	15,071,000	0
Current liability	1,000,000	900,000
Long-term liability	49,184,000	162,835,000
Regulatory asset	24,600,000	134,800,000
Pension Benefits [Member]
Other postretirement benefits [Abstract]
Fair value of plan assets	277,398,000	212,277,000	173,311,000
Long-term rate of return	8.10%	8.10%	8.25%
Funded status [Abstract]
Fair value of plan assets	277,398,000	212,277,000	173,311,000
Benefit obligations	283,958,000	315,505,000	283,668,000
Funded status	(6,560,000)	(103,228,000)
Amounts recognized as regulatory asset [Abstract]
Net actuarial loss	37,499,000	112,637,000
Prior service (credit) cost	(209,000)	105,000
Transition obligation	0	0
Total	37,290,000	112,742,000
Projected benefit obligation in excess of plan assets [Abstract]
Projected benefit obligation with projected benefit obligation in excess of plan assets, end of year	21,631,000	315,505,000
Fair value of plan assets with projected benefit obligation in excess of plan assets, end of year	0	212,277,000
Accumulated benefit obligation in excess of plan assets [Abstract]
Projected benefit obligation with accumulated benefit obligation in excess of plan assets, end of year	21,631,000	315,505,000
Accumulated benefit obligation with accumulated benefit obligation in excess of plan assets, end of year	19,795,000	272,462,000
Fair value of plan assets with accumulated benefit obligation in excess of plan assets, end of year	0	212,277,000
Postretirement Benefits [Member]
Other postretirement benefits [Abstract]
Fair value of plan assets	37,602,000	32,124,000	23,456,000
Long-term rate of return	6.79%	7.26%	7.39%
Funded status [Abstract]
Fair value of plan assets	37,602,000	32,124,000	23,456,000
Benefit obligations	66,100,000	92,605,000	97,644,000
Funded status	(28,498,000)	(60,481,000)
Amounts recognized as regulatory asset [Abstract]
Net actuarial loss	7,761,000	21,529,000
Prior service (credit) cost	(20,495,000)	530,000
Transition obligation	35,000	38,000
Total	(12,699,000)	22,097,000
Master Pension Trust [Member]
Other postretirement benefits [Abstract]
Fair value of plan assets	31,100,000	25,000,000
Funded status [Abstract]
Fair value of plan assets	$ 31,100,000	$ 25,000,000

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Commitments and Contingencies (Details-1) (USD $) In Thousands, unless otherwise specified	12 Months Ended
	Dec. 31, 2013 MW
Purchase Obligation, Fiscal Year Maturity [Abstract]
Purchase obligation due in next twelve months	$ 108,386
Purchase obligation due in second year	77,699
Purchase obligation due in third year	67,191
Purchase obligation due in fourth year	52,771
Purchase obligation due in fifth year	50,936
Coal [Member]
Purchase Obligation, Fiscal Year Maturity [Abstract]
Purchase obligation due in next twelve months	22,109	[1]
Purchase obligation due in second year	14,633	[1]
Purchase obligation due in third year	10,938	[1]
Purchase obligation due in fourth year	5,073	[1]
Purchase obligation due in fifth year	2,710	[1]
Natural Gas, Transportation and Storage [Member]
Purchase Obligation, Fiscal Year Maturity [Abstract]
Purchase obligation due in next twelve months	17,211	[2]
Purchase obligation due in second year	16,857	[2]
Purchase obligation due in third year	9,288	[2]
Purchase obligation due in fourth year	272	[2]
Purchase obligation due in fifth year	191	[2]
Natural Gas, Supply [Member]
Purchase Obligation, Fiscal Year Maturity [Abstract]
Purchase obligation due in next twelve months	19,511	[3]
Purchase obligation due in second year	0	[3]
Purchase obligation due in third year	0	[3]
Purchase obligation due in fourth year	0	[3]
Purchase obligation due in fifth year	0	[3]
Purchase Power [Member]
Purchase Obligation, Fiscal Year Maturity [Abstract]
Purchase obligation due in next twelve months	47,241	[4]
Purchase obligation due in second year	45,711	[4]
Purchase obligation due in third year	46,467	[4]
Purchase obligation due in fourth year	46,928	[4]
Purchase obligation due in fifth year	47,911	[4]
Ten-year Purchase Power Agreement, Osceola Windpower II, LLC [Member]
Purchase Power Agreement [Abstract]
Long-term purchase commitment, term	10 years
Long-term purchase commitment, minimum power required (in MW)	50
Other [Member]
Purchase Obligation, Fiscal Year Maturity [Abstract]
Purchase obligation due in next twelve months	2,314
Purchase obligation due in second year	498
Purchase obligation due in third year	498
Purchase obligation due in fourth year	498
Purchase obligation due in fifth year	$ 124

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

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

[4] MGE has several purchase power agreements to help meet future electric supply requirements. Management expects to recover these costs in future customer rates. In October 2008, MGE entered into a ten-year purchase power agreement to help meet future electric supply requirements. Under this agreement, MGE has agreed to purchase 50 MW of wind power from Osceola Windpower II, LLC, which is located in Iowa. This facility became operational in October 2008. MGE does not have any capacity payment commitments under this agreement. However, MGE is obligated to purchase its ratable share of the energy produced by the project. MGE's commitment related to its ratable share of energy produced by the project has been estimated and is included in the above numbers.

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MGE Energy Inc Consolidated Statements of Comprehensive Income (USD $) In Thousands, unless otherwise specified	3 Months Ended								12 Months Ended
	Dec. 31, 2013	Sep. 30, 2013	Jun. 30, 2013	Mar. 31, 2013	Dec. 31, 2012	Sep. 30, 2012	Jun. 30, 2012	Mar. 31, 2012	Dec. 31, 2013		Dec. 31, 2012		Dec. 31, 2011
Statement of Other Comprehensive Income [Abstract]
Net Income	$ 14,077	$ 24,353	$ 13,891	$ 22,584	$ 10,486	$ 23,642	$ 14,270	$ 16,048	$ 74,905		$ 64,446		$ 60,928
Other comprehensive income/(loss), net of tax:
Unrealized gain (loss) on available for sale securities, net of tax									283	[1]	(18)	[2]	(15)	[3]
Reclassification of realized gain on available-for-sale securities, net of tax									0	[4]	0	[4]	(15)	[3]
Comprehensive Income									$ 75,188		$ 64,428		$ 60,898

[1] Net of $189 tax

[2] Net of $12 tax

[3] Net of $10 tax

[4] Net of $0 tax

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Madison Gas and Electric Company Consolidated Statements of Common Equity (USD $) In Thousands, unless otherwise specified	Total USD ($)	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, 2010		$ 544,309		$ 17,348	$ 192,417	$ 192,480		$ 71	$ 141,993
Beginning balance, shares at Dec. 31, 2010			34,668	17,348
Increase (Decrease) in Common Equity [Roll Forward]
Net Income		61,252				37,282			23,970
Other comprehensive income/(loss)	(30)	(24)					(30)	(24)
Cash dividends paid to parent by MGE	(79,148)	(26,648)				(26,648)
Equity contribution received by noncontrolling interest		888							888
Distributions to parent from noncontrolling interest		(52,500)							(52,500)
Ending balance, value at Dec. 31, 2011		527,277		17,348	192,417	203,114		47	114,351
Ending balance, shares at Dec. 31, 2011			34,668	17,348
Increase (Decrease) in Common Equity [Roll Forward]
Net Income		65,306				40,817			24,489
Other comprehensive income/(loss)	(18)	(43)					(18)	(43)
Cash dividends paid to parent by MGE	(44,343)	(20,404)				(20,404)
Equity contribution received by noncontrolling interest		2,130							2,130
Distributions to parent from noncontrolling interest		(23,500)							(23,500)
Ending balance, value at Dec. 31, 2012		550,766		17,348	192,417	223,527		4	117,470
Ending balance, shares at Dec. 31, 2012			34,668	17,348
Increase (Decrease) in Common Equity [Roll Forward]
Net Income		76,445				49,007			27,438
Other comprehensive income/(loss)	283	188					283	188
Cash dividends paid to parent by MGE	(52,366)	(25,000)				(25,000)
Equity contribution received by noncontrolling interest		1,420							1,420
Distributions to parent from noncontrolling interest		(27,365)							(27,365)
Ending balance, value at Dec. 31, 2013		$ 576,454		$ 17,348	$ 192,417	$ 247,534		$ 192	$ 118,963
Ending balance, shares at Dec. 31, 2013			34,668	17,348

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MGE Energy Inc Consolidated Statements of Common Equity (USD $) In Thousands, unless otherwise specified		Total	Common Stock [Member]	Additional Paid-In Capital [Member]	Retained Earnings [Member]	Accumulated Other Comprehensive (Loss)/ Income [Member]
Beginning balance, value at Dec. 31, 2010		$ 525,080	$ 34,668	$ 316,268	$ 174,002	$ 142
Beginning balance, shares at Dec. 31, 2010			34,668
Increase (Decrease) in Common Equity [Roll Forward]
Net Income		60,928			60,928
Other comprehensive income/(loss)		(30)				(30)
Common stock dividends declared	[1]	(35,026)			(35,026)
Ending balance, value at Dec. 31, 2011		550,952	34,668	316,268	199,904	112
Ending balance, shares at Dec. 31, 2011			34,668
Increase (Decrease) in Common Equity [Roll Forward]
Net Income		64,446			64,446
Other comprehensive income/(loss)		(18)				(18)
Common stock dividends declared	[2]	(35,951)			(35,951)
Ending balance, value at Dec. 31, 2012		579,429	34,668	316,268	228,399	94
Ending balance, shares at Dec. 31, 2012			34,668
Increase (Decrease) in Common Equity [Roll Forward]
Net Income		74,905			74,905
Other comprehensive income/(loss)		283				283
Common stock dividends declared	[3]	(37,107)			(37,107)
Ending balance, value at Dec. 31, 2013		$ 617,510	$ 34,668	$ 316,268	$ 266,197	$ 377
Ending balance, shares at Dec. 31, 2013			34,668

[1] $1.01 per share

[2] $1.04 per share

[3] $1.07 per share

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Notes Payable to Banks, Commercial Paper, and Lines of Credit

12 Months Ended

Dec. 31, 2013

Debt Disclosure [Abstract]

Notes Payable to Banks, Commercial Paper, and Lines of Credit

Notes Payable to Banks, Commercial Paper, and Lines of Credit.

a.       MGE Energy.

At December 31, 2013, MGE Energy had an unsecured, committed revolving line of credit of $50 million expiring July 31, 2017. At December 31, 2013, no borrowings were outstanding under this facility.

The agreement requires MGE Energy to maintain a ratio of its consolidated indebtedness to consolidated total capitalization not to exceed a maximum of 65%. A change in control constitutes a default under the agreement. Change in control events are defined as (i) a failure by MGE Energy to hold 100% of the outstanding voting equity interest in MGE or (ii) the acquisition of beneficial ownership of 30% or more of the outstanding voting stock of MGE Energy by one person or two or more persons acting in concert.As of December 31, 2013, MGE Energy is in compliance with the covenant requirements.

b.       MGE.

For short-term borrowings, MGE generally issues commercial paper (issued at the prevailing discount rate at the time of issuance), which is supported by unused committed bank lines of credit. At December 31, 2013, MGE had an unsecured, committed revolving line of credit for $100 million expiring July 31, 2017. The agreement requires MGE to have a period of at least one day, during any 365-day period, on which the principal amount of all outstanding loans thereunder shall be zero. At December 31, 2013, no borrowings were outstanding under this facility.

The agreement requires MGE to maintain a ratio of consolidated debt to consolidated total capitalization not to exceed a maximum of 65%. The ratio calculation excludes assets, liabilities, revenues, and expenses included in MGE's financial statements as the result of the consolidation of VIEs, such as MGE Power West Campus and MGE Power Elm Road. A change in control constitutes a default under the agreement. Change in control events are defined as (i) a failure by MGE Energy to hold 100% of the outstanding voting equity interest in MGE or (ii) the acquisition of beneficial ownership of 30% or more of the outstanding voting stock of MGE Energy by one person or two or more persons acting in concert. As of December 31, 2013, MGE is in compliance with the covenant requirements.

c.       MGE Energy and MGE.

Information concerning short-term borrowings for the past three years is shown below:

		As of December 31,
(In thousands)		2013		2012		2011
MGE Energy(a)
Available lines of credit	$	150,000	$	115,000	$	115,000
During the year:
Maximum short-term borrowings	$	32,000	$	16,000	$	28,500
Average short-term borrowings	$	6,992	$	1,154	$	3,410
Weighted-average interest rate		0.18%		0.17%		1.43%
MGE
Available lines of credit	$	100,000	$	75,000	$	75,000
During the year:
Maximum short-term borrowings	$	32,000	$	16,000	$	9,500
Average short-term borrowings	$	6,992	$	1,154	$	349
Weighted-average interest rate		0.18%		0.17%		0.25%

(a)MGE Energy short-term borrowings include MGE Energy and MGE lines of credit and MGE commercial paper.

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Regulatory Assets and Liabilities

12 Months Ended

Dec. 31, 2013

Regulatory Assets and Liabilities Disclosure [Abstract]

Regulatory Assets and Liabilities

Regulatory Assets and Liabilities - MGE Energy and MGE.

The following regulatory assets and liabilities are reflected in MGE's consolidated balance sheet as of December 31:

(In thousands)		2013		2012
Regulatory Assets
Asset retirement obligation	$	4,863	$	4,608
Debt related costs		11,786		5,468
Derivatives		63,893		72,328
Elm Road		0		2,614
Environmental costs		920		1,154
Pension and OPRB costs		0		1,234
Tax recovery related to AFUDC equity		6,956		5,241
Unfunded pension and other postretirement liability		24,591		134,839
Other		534		1,694
Total regulatory assets	$	113,543	$	229,180
Regulatory Liabilities
Conservation costs	$	455	$	455
Deferred fuel savings		13,386		6,163
Elm Road		607		0
Income taxes		2,082		2,346
Non-ARO removal cost		15,182		13,957
Renewable energy credits		574		480
Other		1,044		1,137
Total regulatory liabilities	$	33,330	$	24,538

MGE expects to recover its regulatory assets and return its regulatory liabilities through rates charged to customers based on PSCW decisions made during the ratemaking process or based on PSCW long-standing policies and guidelines. The adjustments to rates for these regulatory assets and liabilities will occur over the periods either specified by the PSCW or over the corresponding period related to the asset or liability. We believe it is probable that MGE will continue to recover from customers the regulatory assets described above based on prior and current ratemaking treatment for such costs. All regulatory assets for which a cash outflow had been made are earning a return, except for amounts expended for environmental costs.

Asset Retirement Obligation

See Footnote 19 for further discussion.

Debt Related Costs

This balance includes debt issuance costs of extinguished debt and other debt related expenses. The PSCW has allowed rate recovery on unamortized issuance costs for extinguished debt facilities. When the facility replacing the old facility is deemed by the PSCW to be more favorable for the ratepayers, the PSCW will allow rate recovery of any unamortized issuance costs related to the old facility. These amounts are recovered over the term of the new facility.

In 2013, MGE issued long-term debt and used the net proceeds to redeem Medium-Term Notes and partially redeem Senior Notes. Included in the redemption prices were make-whole premiums totalling $6.8 million. The make-whole premiums are treated as a regulatory asset and will be amortized over the life of the long-term debt issued.

Derivatives

MGE has physical and financial contracts that are defined as derivatives. The amounts recorded for the net mark-to-market value of the commodity based contracts is offset with a corresponding regulatory asset or liability because these transactions are part of the PGA or fuel rules clause authorized by the PSCW. A significant portion of the recorded amount is related 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. This agreement is accounted for as a derivative contract.

Elm Road

Costs associated with Elm Road are estimated in MGE's rates utilizing escrow accounting and include costs for lease payments, management fees, community impact mitigation, and operating costs. Also, MGE has deferred payments made to MGE Power Elm Road for carrying costs during construction of the facility. MGE is collecting carrying costs in rates over a six year period that began in 2010. All other costs are collected in rates over a one to two year period.

Environmental Costs

MGE has been allowed to defer actual costs on certain environmental matters, including clean up of two landfill sites and legal expenditures pertaining to the response to the EPA Clean Air Act enforcement matter at Columbia. For further discussion of the Columbia Clean Air Act litigation, see Footnote 18.d.

Pension and OPRB Costs

The PSCW has allowed MGE to defer the 2009 incremental pension and OPRB costs above the amounts recovered in rates. Recovery of the costs began in 2010. The costs are being recovered in rates over a four year period for electric portion and a two year period for gas portion.

Tax Recovery Related to AFUDC Equity

AFUDC equity represents the after-tax equity cost associated with utility plant construction and results in a temporary difference between the book and tax basis of such plant. It is probable under PSCW regulation that MGE will recover in future rates the future increase in taxes payable represented by the deferred income tax liability. The amounts will be recovered in rates over the depreciable life of the asset for which AFUDC was applied. Tax recovery related to AFUDC equity represents the revenue requirement related to recovery of these future taxes payable, calculated at current statutory tax rates.

Unfunded Pension and Other Postretirement Liability

MGE is required to recognize the unfunded status of defined benefit pension and other postretirement pension plans as a net liability or asset on the balance sheet with an offset to other comprehensive income. The amount normally charged to other comprehensive income for the unfunded status represents future expenses that are expected to be recovered in rates.

Conservation Costs

MGE has received regulatory treatment for certain conservation expenditures. The expenditures are used for demand-side management programs to promote energy efficiency on the customer's premises. Costs for demand-side management programs are estimated in MGE's rates utilizing escrow accounting. The escrow accounting allows the utility to true-up its actual costs incurred and reflect the amount of the true-up in its next rate case filing and amortize the amount over the rate case period. The customer service - conservation escrow was discontinued as of January 1, 2013. These costs are expected to be trued up in MGE's next full base rate case.

Deferred Fuel Savings

The PSCW approved new fuel rules that became effective January 1, 2011. The new 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 fuel rules costs fall outside the lower end of the range and would defer costs, less any excess revenues, if the actual 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. See Footnote 17.b. for further discussion.

Income Taxes

Excess deferred income taxes result from past taxes provided at rates higher than current rates. The regulatory liability and deferred investment tax credit reflects the revenue requirement associated with the return of these tax benefits to customers.

Non-ARO Removal Costs

In connection with accounting for asset retirement obligations, companies are required to reclassify cumulative collections for non-ARO removal costs as a regulatory liability, with an offsetting entry to accumulated depreciation. Under the current rate structure, these removal costs are being recovered as a component of depreciation expense.

Renewable Energy Credits

MGE receives renewable energy credits from certain purchase power agreements. The value of the credits are recorded as inventory and expensed when the credit is redeemed or expired. A regulatory liability has been established for the value of the renewable energy credits included in inventory. In Wisconsin, renewable energy credits expire four years after the year of acquisition.

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Derivative and Hedging Instruments (Details-1) (USD $) In Thousands, unless otherwise specified						12 Months Ended										12 Months Ended
	Dec. 31, 2013 Other Current Assets [Member]	Dec. 31, 2012 Other Current Assets [Member]	Dec. 31, 2011 Other Current Assets [Member]	Dec. 31, 2013 Commodity Contracts and Financial Transimission Rights [Member]	Dec. 31, 2012 Commodity Contracts and Financial Transimission Rights [Member]	Dec. 31, 2013 Commodity Derivative Contracts [Member] MWh Dth	Dec. 31, 2012 Commodity Derivative Contracts [Member] MWh Dth	Dec. 31, 2013 Commodity Derivative Contracts [Member] Other Current Assets [Member]	Dec. 31, 2012 Commodity Derivative Contracts [Member] Other Current Assets [Member]	Dec. 31, 2013 Commodity Derivative Contracts [Member] Other Deferred Charges [Member]	Dec. 31, 2012 Commodity Derivative Contracts [Member] Other Deferred Charges [Member]	Dec. 31, 2013 Commodity Derivative Contracts [Member] Derivative Liability (Current) [Member]	Dec. 31, 2012 Commodity Derivative Contracts [Member] Derivative Liability (Current) [Member]	Dec. 31, 2013 Commodity Derivative Contracts [Member] Derivative Liability (Long-term) [Member]	Dec. 31, 2012 Commodity Derivative Contracts [Member] Derivative Liability (Long-term) [Member]	Dec. 31, 2013 Energy Related Commodity Contract [Member] Cash Flow Hedging [Member]	Dec. 31, 2013 Financial Transmission Rights [Member] MW	Dec. 31, 2012 Financial Transmission Rights [Member] MW	Dec. 31, 2013 Financial Transmission Rights [Member] Other Current Assets [Member]	Dec. 31, 2012 Financial Transmission Rights [Member] Other Current Assets [Member]	Dec. 31, 2013 Financial Transmission Rights [Member] Derivative Liability (Current) [Member]	Dec. 31, 2012 Financial Transmission Rights [Member] Derivative Liability (Current) [Member]	Dec. 31, 2013 Ten-year PPA [Member]	Dec. 31, 2012 Ten-year PPA [Member]	Dec. 31, 2013 Ten-year PPA [Member] Derivative Liability (Current) [Member]	Dec. 31, 2012 Ten-year PPA [Member] Derivative Liability (Current) [Member]	Dec. 31, 2013 Ten-year PPA [Member] Derivative Liability (Long-term) [Member]	Dec. 31, 2012 Ten-year PPA [Member] Derivative Liability (Long-term) [Member]
Derivatives Fair Value [Line Items]
Maximum term of derivative hedging contract																4 years
Gross Notional Volume of Open Derivatives
Notional amount, energy measure (in MWh)						458,660	444,650
Notional amount, decatherm measure (in Dth)						3,750,000	1,980,000
Notional amount, power measure (in MW)																	1,984	2,670
Derivative Fair Values [Abstract]
Derivative fair value, net	$ 411	$ 574	$ 1,604	$ 1,800	$ 300																		$ (65,700)	$ (72,600)
Derivative fair value, gross asset						1,523	460	1,356	365	167	95						363	206	363	206
Derivative fair value, gross liability						$ 99	$ 405					$ 51	$ 394	$ 48	$ 11						$ 0	$ 0	$ 65,680	$ 72,590	$ 7,750	$ 9,270	$ 57,930	$ 63,320

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Variable Interest Entities

12 Months Ended

Dec. 31, 2013

Variable Interest Entities Disclosure [Abstract]

Variable Interest Entities

Variable Interest Entities - MGE Energy and MGE.

a.       MGE Power Elm Road.

MGE Power Elm Road is not a subsidiary of MGE; however, it has been consolidated in the financial statements of MGE. MGE Power Elm Road was created for the purpose of owning new generating assets. Its sole principal assets are an undivided ownership interest in two coal-fired generating plants located in Oak Creek, Wisconsin, which it leases to MGE pursuant to long-term leases. Based on the nature and terms of the contractual agreements, MGE is expected to absorb a majority of the expected losses, residual value, or both, associated with the ownership of MGE Power Elm Road and therefore holds a variable interest in MGE Power Elm Road, even though it has no equity interest in MGE Power Elm Road. MGE Energy and MGE consolidate VIEs for which they are the primary beneficiary. MGE has the power to direct the activities that most significantly impact the Elm Road Units' economic performance and is also the party most closely associated with MGE Power Elm Road. As a result, MGE is the primary beneficiary. At December 31, MGE has included the following significant accounts on its consolidated balance sheet related to its interest in this VIE:

(In thousands)		2013		2012
Property, plant, and equipment, net	$	182,657	$	185,020
Construction work in progress		1,115		1,440
Deferred income tax asset - current		219		30,842
Deferred income tax liability		34,141		56,434
Long-term debt		70,639		73,306
Noncontrolling interest		69,876		69,803

Long-term debt consists of $70.6million of senior secured notes that require that MGE Power Elm Road maintain a projected and actual debt service coverage ratio at the end of any calendar quarter of not less than 1.25 to 1.00for the trailing 12-month period. The debt is secured by a collateral assignment of lease payments that MGE is making to MGE Power Elm Road for use of the Elm Road Units pursuant to the related long-term leases.As of December 31, 2013, MGE Power Elm Road is in compliance with the covenant requirements.

MGE has been and will continue to recover in rates the lease payments made to MGE Power Elm Road.MGE received approval from the PSCW to collect in rates the carrying costs incurred by MGE Power Elm Road. The total carrying costs on the Elm Road Units is $62.5 million. MGE is collecting carrying costs in rates over a six year period that began in 2010. Of these costs, $17.0 million relates to the capitalized interest and the debt portion of the units. These costs will be recognized over the period in which the generating units will be depreciated. The remaining $45.5 million represents the equity portion and is being recognized over the period allowed for recovery in rates.

b.       MGE Power West Campus.

MGE Power West Campus is not a subsidiary of MGE; however, it has been consolidated in the financial statements of MGE. MGE Power West Campus was created for the purpose of owning new generating assets. Its sole principal asset is the WCCF, which it leases to MGE pursuant to a long-term lease. MGE is responsible for operation of the plant during the term of the lease. Based on the nature and terms of these contractual relationships, MGE absorbs a majority of the expected losses, residual value, or both, associated with the ownership and operation of the WCCF and therefore holds a variable interest in MGE Power West Campus, even though it has no equity interest in MGE Power West Campus. MGE has the power to direct the activities that most significantly impact WCCF's economic performance and is also the party most closely associated with MGE Power West Campus. As a result, MGE is the primary beneficiary. At December 31, MGE has included the following significant accounts on its consolidated balance sheet related to its interest in this VIE:

(In thousands)		2013		2012
Property, plant, and equipment, net	$	89,564	$	90,339
Affiliate receivables		6,767		6,912
Accrued interest and taxes		4,888		3,327
Deferred income taxes		23,154		21,410
Long-term debt		49,653		50,000
Noncontrolling interest		29,089		30,682

Long-term debt consists of $49.7 million of senior secured notes that require that MGE Power West Campus maintain a projected debt service coverage ratio of not less than 1.25 to 1.00 and debt to total capitalization ratio of not more than .65 to 1.00. The debt is secured by a collateral assignment of lease payments that MGE is making to MGE Power West Campus for use of the cogeneration facility pursuant to the long-term lease. As of December 31, 2013, MGE Power West Campus is in compliance with the covenant requirements.

MGE has been and will continue to recover lease payments made to MGE Power West Campus in rates. Also, MGE received approval from the PSCW to collect approximately $12.1 million in carrying costs incurred by MGE Power West Campus during construction of the facility. The carrying costs are being recovered in rates over a 10 year period that started in 2005.

c.       Other Variable Interest Entities.

MGE has a variable interest in entities through purchase power agreements relating to purchased energy from the facilities. As of December 31,2013 and 2012, MGE had 61 megawatts and 65 megawatts, respectively, of capacity available under these agreements. MGE evaluated the variable interest entities for possible consolidation. The interest holder is considered the primary beneficiary of the entity and is required to consolidate the entity if the interest holder has the power to direct the activities that most significantly impact the economics of the variable interest entity. MGE examined qualitative factors such as the length of the remaining term of the contracts compared with the remaining lives of the plants, who has the power to direct the operations and maintenance of the facilities, and other factors, and determined MGE is not the primary beneficiary of the variable interest entities. There is not a significant potential exposure to loss as a result of involvement with these variable interest entities.

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Variable Interest Entities (Details) (USD $)	12 Months Ended
	Dec. 31, 2013		Dec. 31, 2012
Significant Balance Sheet Accounts Related to Interests in Variable Interest Entities
Property, plant, and equipment, net	$ 1,018,809,000		$ 975,053,000
Construction work in progress	141,415,000		98,411,000
Deferred income tax asset - current	0		23,483,000
Accrued interest and taxes	5,661,000		4,296,000
Other Variable Interest Entities
Other variable interest entities, purchase power agreement, plant capacity (in MW)	61		65
MGE Power Elm Road [Member]
Significant Balance Sheet Accounts Related to Interests in Variable Interest Entities
Property, plant, and equipment, net	182,657,000		185,020,000
Construction work in progress	1,115,000		1,440,000
Deferred income tax asset - current	219,000		30,842,000
Deferred income taxes	34,141,000		56,434,000
Long-term debt, gross, current and noncurrent	70,639,000		73,306,000
Noncontrolling interest	69,876,000	[1]	69,803,000	[1]
Total carrying costs	62,500,000
Total capitalized interest	17,000,000
Total capitalized cost of equity	45,500,000
Carrying cost rate recovery period	6 years
MGE Power Elm Road [Member] | Minimum [Member]
Significant Balance Sheet Accounts Related to Interests in Variable Interest Entities
Debt service coverage ratio	1.25
MGE Power West Campus [Member]
Significant Balance Sheet Accounts Related to Interests in Variable Interest Entities
Property, plant, and equipment, net	89,564,000		90,339,000
Affiliate receivables, current and noncurrent	6,767,000		6,912,000
Accrued interest and taxes	4,888,000		3,327,000
Deferred income taxes	23,154,000		21,410,000
Long-term debt, gross, current and noncurrent	49,653,000		50,000,000
Noncontrolling interest	29,089,000	[1]	30,682,000	[1]
Carrying costs recovered	$ 12,100,000
Carrying cost rate recovery period	10 years
MGE Power West Campus [Member] | Minimum [Member]
Significant Balance Sheet Accounts Related to Interests in Variable Interest Entities
Debt service coverage ratio	1.25
MGE Power West Campus [Member] | Maximum [Member]
Significant Balance Sheet Accounts Related to Interests in Variable Interest Entities
Debt to total capitalization ratio	0.65

[1] MGE Power Elm Road and MGE Power West Campus are not subsidiaries of MGE; however, they have been consolidated in the consolidated financial statements of MGE (see Footnote 2). MGE Power Elm Road and MGE Power West Campus are 100% owned by MGE Power, and MGE Power is 100% owned by MGE Energy. MGE Energy's proportionate share of the equity and net income (through its wholly owned subsidiary MGE Power) of MGE Power Elm Road and MGE Power West Campus is classified within the MGE financial statements as noncontrolling interest.

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Consolidated Statements of Common Equity (Parentheticals) (USD $)	3 Months Ended								12 Months Ended
	Dec. 31, 2013	Sep. 30, 2013	Jun. 30, 2013	Mar. 31, 2013	Dec. 31, 2012	Sep. 30, 2012	Jun. 30, 2012	Mar. 31, 2012	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Dividends per share of common stock	$ 0.272	$ 0.272	$ 0.263	$ 0.263	$ 0.263	$ 0.263	$ 0.255	$ 0.255	$ 1.07	$ 1.04	$ 1.01

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Summary of Significant Accounting Policies

12 Months Ended

Dec. 31, 2013

Accounting Policies [Abstract]

Summary of Significant Accounting Policies

Summary of Significant Accounting Policies.

a.Basis of Presentation - MGE Energy and MGE.

The consolidated financial statements are prepared in conformity with accounting principles generally accepted in the United States of America (GAAP), which give recognition to the rate makingaccounting policies for regulated operationsprescribed by the regulatory authorities having jurisdiction, principally the PSCW and FERC. MGE's accounting records conform to the FERC uniform system of accounts.

On December 20, 2013, MGE Energy's Board of Directors declared a three-for-two stock split of MGE Energy's common stock in the form of a stock dividend. The additional shares were distributed February 7, 2014 to all shareholders of record as of January 24, 2014. All shares and per sharedata provided in this reportgive effect to this stock split.

b.Principles of Consolidation - MGE Energy and MGE.

MGE, a wholly owned subsidiary of MGE Energy, is a regulated electric and gas utility headquartered in Madison, Wisconsin. MGE Energy and MGE consolidate all majority owned subsidiaries in which it has controlling influence. MGE is the majority owner of MGE Transco. MGE Transco is a nonregulated entity formed to manage the investment in ATC.

Wholly owned subsidiaries of MGE Energy include CWDC, MAGAEL, MGE Construct, MGE Power, NGV Fueling Services, and North Mendota. MGE Power owns 100% of MGE Power Elm Road and MGE PowerWest Campus. MGE Power and its subsidiaries are part of MGE Energy's nonregulated energy operations, which were formed to own and lease electric generation projects to assist MGE.

MGE Energy and MGE consolidate variable interest entities (VIEs) for which it is the primary beneficiary. Variable interest entities are legal entities that possess any of the following characteristics: equity investors who have an insufficient amount of equity at risk to finance their activities, equity owners who do not have the power to direct the significant activities of the entity (or have voting rights that are disproportionate to their ownership interest), or equity holders who do not receive expected losses or returns significant to the VIE. If MGE Energy or MGE is not the primary beneficiary and an ownership interest is held, the VIE is accounted for under the equity method of accounting. When assessing the determination of the primary beneficiary, all relevant facts and circumstances are considered, including: the power, through voting or similar rights, to direct the activities of the VIE that most significantly impact the VIE's economic performance and the obligation to absorb the expected losses and/or the right to receive the expected returns of the VIE. Ongoing reassessments of all VIEs are performed to determine if the primary beneficiary status has changed. MGE has consolidated MGE Power Elm Road and MGE PowerWest Campus. Both entities are VIEs. MGE is considered the primary beneficiary of these entities as a result of contractual agreements. See Footnote 2 for more discussion of these entities.

The consolidated financial statements reflect the application of certain accounting policies described in this note. All significant intercompany accounts and transactions have been eliminated in consolidation.

c.Use of Estimates - MGE Energy and MGE.

In order to prepare consolidated financial statements in conformity with GAAP, management must make estimates and assumptions. These estimates could affect reported amounts of assets, liabilities, and disclosures at the date of the financial statements, as well as the reported amounts of revenues and expenses during the reporting periods. Actual results could differ from management's estimates.

d.Cash Equivalents and Restricted Cash - MGE Energy and MGE.

MGE Energy and MGE consider all highly liquid investments purchased with an original maturity of three months or less to be cash equivalents.

MGE has certain cash accounts that are restricted to uses other than current operations and designated for a specific purpose. MGE's restricted cash accounts include cash held by trustees for certain employee benefits. These are included in other current assets.

e.Receivable – Margin Account - MGE Energy and MGE.

Cash amounts held by counterparties as margin for certain financial transactions are recorded as receivable – margin account. The balance is shown net of any collateral posted against derivative positions. As of December 31,2013, there was $0.2 million collateral posted against derivative positions. As of December 31,2012, there was no collateral posted against derivative positions. Changes in this cash account are considered cash flows from operating activities to match with the costs being hedged. The costs being hedged are fuel for electric generation, purchased power, and cost of gas sold.

f.Trade Receivables, Allowance for Doubtful Accounts, and Concentration Risk - MGE Energy and MGE.

Trade accounts receivable are recorded at the invoiced amount and do not bear interest. However, a 1% late payment charge is recorded on all receivables unpaid after the due date. The allowance for doubtful accounts associated with these receivables represents our best estimate of the amount of probable credit losses in our existing accounts receivable. We determine our allowance for doubtful accounts based on historical write-off experience, regional economic data, and review of the accounts receivable aging.

MGE is obligated to provide service to all electric and gas customers within its franchised territories. MGE's franchised electric territory includes a 316 square-mile area in Dane County, Wisconsin, and MGE's franchised gas territory includes a service area covering 1,649 square-miles in Wisconsin. MGE manages this concentration and the related credit risk through its credit and collection policies, which are consistent with state regulatory requirements.

g.Inventories - MGE Energy and MGE.

Inventories consist of natural gas in storage, fossil fuels, materials and supplies, SO2 allowances, and renewable energy credits (RECs). MGE values natural gas in storage, fossil fuels, and materials and supplies using average cost.

SO2 emission allowances are included in inventory and are recorded at weighted average cost. These allowances are charged to fuel expense as they are used in operations. MGE's emission allowance balances as of December 31,2013 and 2012, were $0.1 million.

REC allowances are included in inventory and are recorded based on specific identification. These allowances are charged to purchase power expense as they are used in operations. MGE's REC allowance balances as of December 31,2013 and 2012, were $0.6 million and $0.5 million, respectively.

h.Regulatory Assets and Liabilities - MGE Energy and MGE.

Regulatory assets and regulatory liabilities are recorded consistent with regulatory treatment. Regulatory assets represent costs which are deferred due to the probable future recovery from customers through regulated rates. Regulatory liabilities represent the excess recovery of costs or accrued credits which were deferred because MGE believes it is probable such amounts will be returned to customers through future regulated rates. Regulatory assets and liabilities are amortized in the consolidated statements of income consistent with the recovery or refund included in customer rates. MGE believes that it is probable that its recorded regulatory assets and liabilities will be recovered and refunded, respectively, in future rates. See Footnote 6 for further information.

i.Debt Issuance Costs - MGE Energy and MGE.

Premiums, discounts, and expenses incurred with the issuance of outstanding long-term debt are amortized over the life of the debt issue. Any call premiums or unamortized expenses associated with refinancing higher-cost debt obligations used to finance utility-regulated assets and operations are amortized consistent with regulatory treatment of those items.

j.Property, Plant, and Equipment - MGE Energy and MGE.

Property, plant, and equipment is recorded at original cost. Cost includes indirect costs consisting of payroll taxes, pensions, postretirement benefits, other fringe benefits, and administrative and general costs. Also, included in the cost is AFUDC for utility property and capitalized interest for nonregulated property. Additions for significant replacements of property are charged to property, plant, and equipment at cost; and minor items are charged to maintenance expense. Depreciation rates on utility property are approved by the PSCW, based on the estimated economic lives of property, and include estimates for salvage value and removal costs. Removal costs of utility property, less any salvage value, are adjusted through regulatory liabilities. Depreciation rates on nonregulated property are based on the estimated economic lives of the property. See Footnote 3 for further information.

Provisions at composite straight-line depreciation rates approximate the following percentages for the cost of depreciable property:

	2013	2012	2011
Electric	2.7%	2.9%	3.2%
Gas	1.7%	1.7%	1.6%
Nonregulated	2.3%	2.3%	2.3%

k.Asset Retirement Obligations - MGE Energy and MGE.

MGE Energy and MGE are required to record a liability for the fair value of an ARO to be recognized in the period in which it is incurred if it can be reasonably estimated. The offsetting associated asset retirement costs are capitalized as a long-lived asset and depreciated over the asset's useful life. The expected present value technique used to calculate the fair value of ARO liabilities includes assumptions about costs, probabilities, settlement dates, interest accretion, and inflation. Revisions to the assumptions, including the timing or amount of expected asset retirement costs, could result in increases or decreases to the AROs. All asset retirement obligations are recorded as other long-term liabilities on our balance sheets. MGE has regulatory treatment and recognizes regulatory assets or liabilities for the timing differences between when we recover legal AROs in rates and when we would recognize these costs. See Footnote 19 for further information.

l.Repairs and Maintenance Expense - MGE Energy and MGE.

MGE utilizes the direct expensing method for planned major maintenance projects. Under this method, MGE expenses all costs associated with major planned maintenance activities as incurred.

m.Purchased Gas Adjustment Clause - MGE Energy and MGE.

MGE's natural gas rates are subject to a fuel adjustment clause designed to recover or refund the difference between the actual cost of purchased gas and the amount included in rates. Differences between the amounts billed to customers and the actual costs recoverable are deferred and recovered or refunded in future periods by means of prospective monthly adjustments to rates. At December 31,2013, MGE had over collected $1.7 million. At December 31,2012, MGE had under collected $0.1 million. These amounts are netted in other current liabilities on the consolidated balance sheet.

n.Revenue Recognition - MGE Energy and MGE.

Operating revenues are recorded as service is rendered or energy is delivered to customers. Meters are read on a systematic basis throughout the month based on established meter-reading schedules. At the end of the month, MGE accrues an estimate for the unbilled amount of energy delivered to customers. The unbilled revenue estimate is based on daily system demand volumes, weather factors, estimated line losses, estimated customer usage by class, and applicable customer rates.

o.Utility Cost Recovery - MGE Energy and MGE.

MGE's rates include a provision for fuel costs. The PSCW allows Wisconsin utilities to defer electric fuel-related costs, less excess revenues, 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. Such deferred amounts will be recognized in “Purchased Power Expense” in MGE Energy's and MGE's income statement each period. The cumulative effects of these deferred amounts will be recorded in “Regulatory assets” or “Regulatory liabilities” on MGE Energy's and MGE's consolidated balance sheets until they are reflected in future billings to customers. See Footnote 17.b. for further information regarding the regulatory rules applicable to the recovery of electric fuel costs.

p.Allowance for Funds Used During Construction - MGE Energy and MGE.

Allowance for funds used during construction is included in utility plant accounts and represents the cost of borrowed funds used during plant construction and a return on shareholders' capital used for construction purposes. In the consolidated income statements, the cost of borrowed funds (AFUDC-debt) is presented as an offset to interest expense and the return on shareholders' capital (AFUDC-equity funds) is shown as an item within other income. For both 2012 and 2011, as approved by the PSCW, MGE capitalized AFUDC-debt and equity on 50% of applicable average construction work in progress at 8.36%.For 2013, MGE capitalized AFUDC-debt and equity on 50% of applicable average construction work in progress at8.21%.For both 2012 and 2011, MGE received specific approval to recover 100% AFUDC on certain environmental costs for Columbia and 50% in 2013. Although the allowance does not represent current cash income, it is recovered under the ratemaking process over the service lives of the related properties. See Footnote 20 for further information regarding Columbia AFUDC.

q.Investments - MGE Energy and MGE.

Investments in limited liability companies that have specific ownership accounts in which MGE Energy or MGE's ownership interest is more than minor are accounted for using the equity method. All other investments are carried at fair value or at cost, as appropriate. See Footnote 4 for further information.

r.Capitalized Software Costs - MGE Energy and MGE.

Property, plant, and equipment includes the capitalized costs of internal use software totaling $20.9 million and $14.5 million at December 31, 2013 and 2012, respectively. During 2013 and 2012, MGE recorded $1.5 million and $1.3 million, respectively, of amortization expense related to these costs. These costs are amortized on a straight-line basis over the estimated useful lives of the assets. For internal use software, the useful lives range from five to ten years.

s.Impairment of Long-Lived Assets - MGE Energy and MGE.

MGE reviews plant and equipment and other property for impairment when events or changes in circumstances indicate that the carrying amount of the assets may not be recoverable. MGE's policy for determining when long-lived assets are impaired is to recognize an impairment loss if the sum of the expected future cash flows (undiscounted and without interest charges) from an asset are less than the carrying amount of that asset. If an impairment loss is recognized, the amount that will be recorded will be measured as the amount by which the carrying amount of the asset exceeds the fair value of the asset. There is no impairment of long-lived assets at December 31, 2013, 2012, and 2011.

t.Income Taxes and Excise Taxes - MGE Energy and MGE.

Income taxes

Under the liability method, income taxes are deferred for all temporary differences between pretax financial and taxable income and between the book and tax basis of assets and liabilities using the tax rates scheduled by law to be in effect when the temporary differences reverse. Future tax benefits are recognized to the extent that realization of such benefits is more likely than not. A valuation allowance is recorded for those benefits that do not meet this criterion.

Accounting for uncertainty in income taxes applies to all tax positions and requires a recognition threshold and measurement standard for the financial statement recognition and measurement of a tax position taken, or expected to be taken, in an income tax return. The threshold is defined for recognizing tax return positions in the financial statements as "more likely than not" that the position is sustainable, based on its merits. Subsequent recognition, derecognition, and measurement is based on management's best judgment given the facts, circumstances, and information available at the reporting date.

Regulatory and accounting principles have resulted in a regulatory liability related to income taxes. Excess deferred income taxes result from past taxes provided at rates higher than current rates. The income tax regulatory liability and deferred investment tax credit reflect the revenue requirement associated with the return of these tax benefits to customers.

Investment tax credits from regulated operations are amortized over related property service lives.

Excise taxes

MGE Energy, through its utility operations, pays a state license fee tax in lieu of property taxes on property used in utility operations. License fee tax is calculated as a percentage of adjusted operating revenues of the prior year. The electric tax rate is 3.19% for retail sales and 1.59% for sales of electricity for resale by the purchaser. The tax rate on sales of natural gas is 0.97%. The tax is required to be estimated and prepaid in the year prior to its computation and expensing. License fee tax expense, included in other general taxes, was $13.8 million, $13.5 million, and $12.9 million for the years ended December 31,2013, 2012, and 2011, respectively.

Operating income taxes, including tax credits and license fee tax are included in rates for utility related items.

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

Under two separate incentive plans, eligible participants, including employees and non-employee directors, 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. Under the plans, these awards are subject to a prescribed vesting schedule and must be settled in cash. Accordingly, no new shares of common stock are issued in connection with the plans.

MGE Energy and MGE initially measure the cost of the employee or director 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 award is subsequently re-measured at each reporting date through the settlement date. Changes in fair value during the requisite period are recognized as compensation cost over that period.

See Footnote 14 for additional information regarding the plans.

v.Treasury Stock - MGE Energy.

Treasury shares are recorded at cost. Any shares of common stock repurchased are held as treasury shares unless cancelled or reissued. No treasury shares are held as of December 31, 2013.

w.Comprehensive Income - MGE Energy and MGE.

Total comprehensive income includes all changes in equity during a period except those resulting from investments by and distributions to shareholders. Comprehensive income is reflected in the consolidated statements of comprehensive income.

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

As part of regular operations, MGE enters into contracts, including options, swaps, futures, forwards, and other contractual commitments, to manage its exposure to interest rates, commodity prices, and gas revenues. MGE recognizes all derivatives in the consolidated balance sheets at fair value, with changes in the fair value of derivative instruments to be recorded in current earnings or deferred in accumulated other comprehensive income (loss), depending on whether a derivative is designated as, and is effective as, a hedge and on the type of hedge transaction. Derivative activities are in accordance with the company's risk management policy.

If the derivative qualifies for regulatory deferral, the derivatives are marked to fair value and any resulting loss or gain is offset with a corresponding regulatory asset or liability. Cash flows from such derivative instruments are classified on a basis consistent with the nature of the underlying hedged item.

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Property, Plant, and Equipment

12 Months Ended

Dec. 31, 2013

Property, Plant and Equipment [Abstract]

Property, Plant and Equipment

Property, Plant, and Equipment - MGE Energy and MGE.

Property, plant, and equipment consisted of the following at December 31:

		MGE Energy				MGE
(In thousands)		2013		2012		2013		2012
Utility:
Electric	$	953,290	$	912,273	$	953,307	$	912,289
Gas		351,694		332,767		351,705		332,779
Total utility plant		1,304,984		1,245,040		1,305,012		1,245,068
Less: Accumulated depreciation and amortization		560,066		546,483		560,066		546,483
In-service utility plant, net		744,918		698,557		744,946		698,585
Nonregulated:
Nonregulated		311,742		308,043		310,745		307,511
Less: Accumulated depreciation and amortization		37,851		31,547		37,814		31,547
In-service nonregulated plant, net		273,891		276,496		272,931		275,964
Construction work in progress:
Utility construction work in progress		140,301		96,863		140,301		96,863
Nonregulated construction work in progress		1,114		1,548		1,114		1,548
Total property, plant, and equipment	$	1,160,224	$	1,073,464	$	1,159,292	$	1,072,960

MGE's utility plant is subject to the lien of its Indenture of Mortgage and Deed of Trust. As of December 31,2013, there was $1.2 million of bonds outstanding under that indenture. See Footnote 9 for further discussion of the mortgage indenture.

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Investments (Details-3) (ATC [Member], USD $) In Thousands, unless otherwise specified	12 Months Ended
	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
ATC [Member]
Equity method investment summarized income statement [Abstract]
Operating revenues	$ 626,336	$ 603,254	$ 567,174
Operating expenses	(295,069)	(280,999)	(261,568)
Other income (expense)	831	(2,533)	(1,332)
Interest expense, net	(84,484)	(82,296)	(80,359)
Earnings before members' income taxes	247,614	237,426	223,915
Equity method investment balance sheet assets [Abstract]
Current assets	80,715	63,134	58,671
Noncurrent assets	3,509,517	3,274,704	3,053,742
Total assets	3,590,232	3,337,838	3,112,413
Equity method investment balance sheet liabilities [Abstract]
Current liabilities	381,467	251,541	298,473
Long-term debt	1,550,000	1,550,000	1,400,005
Other noncurrent liabilities	126,167	95,829	82,647
Members' equity	1,532,598	1,440,468	1,331,288
Total members' equity and liabilities	$ 3,590,232	$ 3,337,838	$ 3,112,413

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Derivative and Hedging Instruments (Details-2) (USD $) In Thousands, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012
Offsetting Assets [Line Items]
Collateral posted against derivative positions	$ (200)	$ 0
Commodity Derivative Contracts [Member]
Offsetting Assets [Line Items]
Gross asset	1,523	460
Gross amounts offset in balance sheet	(99)	(405)
Collateral posted against derivative positions	(175)	0
Net amount presented in balance sheet	1,249	55
Financial Transmission Rights [Member]
Offsetting Assets [Line Items]
Gross asset	363	206
Gross amounts offset in balance sheet	0	0
Collateral posted against derivative positions	0	0
Net amount presented in balance sheet	$ 363	$ 206

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Regulatory Assets and Liabilities (Details) (USD $) In Thousands, unless otherwise specified	12 Months Ended
	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Regulatory Assets [Line Items]
Regulatory Assets	$ 113,543	$ 229,180
Regulatory Liabilities [Line Items]
Regulatory Liabilities	33,330	24,538
Debt make-whole premium	6,757	0	0
Conservation Costs Regulatory Liability [Member]
Regulatory Liabilities [Line Items]
Regulatory Liabilities	455	455
Deferred Fuel Savings [Member]
Regulatory Liabilities [Line Items]
Regulatory Liabilities	13,386	6,163
Elm Road Regulatory Liability [Member]
Regulatory Liabilities [Line Items]
Regulatory Liabilities	607	0
Income Taxes [Member]
Regulatory Liabilities [Line Items]
Regulatory Liabilities	2,082	2,346
Non-ARO Removal Cost [Member]
Regulatory Liabilities [Line Items]
Regulatory Liabilities	15,182	13,957
Renewable Energy Credits [Member]
Regulatory Liabilities [Line Items]
Regulatory Liabilities	574	480
Other Regulatory Liability [Member]
Regulatory Liabilities [Line Items]
Regulatory Liabilities	1,044	1,137
Asset Retirement Obligation [Member]
Regulatory Assets [Line Items]
Regulatory Assets	4,863	4,608
Debt Related Costs [Member]
Regulatory Assets [Line Items]
Regulatory Assets	11,786	5,468
Derivatives [Member]
Regulatory Assets [Line Items]
Regulatory Assets	63,893	72,328
Elm Road Regulatory Asset [Member]
Regulatory Assets [Line Items]
Regulatory Assets	0	2,614
Environmental Costs [Member]
Regulatory Assets [Line Items]
Regulatory Assets	920	1,154
Pension and OPRB Costs [Member]
Regulatory Assets [Line Items]
Regulatory Assets	0	1,234
Tax Recovery AFUDC Equity [Member]
Regulatory Assets [Line Items]
Regulatory Assets	6,956	5,241
Unfunded Pension and Other Postretirement Plans Costs [Member]
Regulatory Assets [Line Items]
Regulatory Assets	24,591	134,839
Other Regulatory Asset [Member]
Regulatory Assets [Line Items]
Regulatory Assets	$ 534	$ 1,694

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Schedule I - Condensed Parent Company Finanical Statements (Details-Cash Flow Statement) (USD $) In Thousands, unless otherwise specified	12 Months Ended
	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Condensed Cash Flow Statements, Captions [Line Items]
Net Cash Flows Provided by (Used for) Operating Activities	$ 140,267	$ 146,004	$ 130,772
Investing Activities:
Other investing	(1,205)	(496)	1,985
Cash Provided by (Used for) Investing Activities	(121,922)	(101,353)	(66,351)
Financing Activities:
Cash dividends paid on common stock	(37,107)	(35,951)	(35,026)
Change in short-term debt	0	0	(22,500)
Other financing	(770)	(844)	(336)
Cash Provided by (Used for) Financing Activities	4,111	(39,463)	(30,362)
Change in Cash and Cash Equivalents:	22,456	5,188	34,059
Cash and cash equivalents at beginning of period	46,357	41,169	7,110
Cash and cash equivalents at end of period	68,813	46,357	41,169
MGE Energy [Member]
Condensed Cash Flow Statements, Captions [Line Items]
Net Cash Flows Provided by (Used for) Operating Activities	53,952	49,819	50,696
Investing Activities:
Return of investment - affiliates	0	0	30,000
Other investing	(2,425)	(1,558)	(3,022)
Cash Provided by (Used for) Investing Activities	(2,425)	(1,558)	26,978
Financing Activities:
Cash dividends paid on common stock	(37,107)	(35,951)	(35,026)
Change in short-term debt	0	0	(19,000)
Other financing	(97)	(49)	0
Cash Provided by (Used for) Financing Activities	(37,204)	(36,000)	(54,026)
Change in Cash and Cash Equivalents:	14,323	12,261	23,648
Cash and cash equivalents at beginning of period	36,881	24,620	972
Cash and cash equivalents at end of period	$ 51,204	$ 36,881	$ 24,620

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Investments (Details-2) (USD $) In Thousands, unless otherwise specified	12 Months Ended						1 Months Ended
	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011	Dec. 31, 2013 MGE Transco [Member] ATC [Member]	Dec. 31, 2012 MGE Transco [Member] ATC [Member]	Dec. 31, 2011 MGE Transco [Member] ATC [Member]	Jan. 31, 2014 MGE Transco [Member] ATC [Member] Subsequent Event [Member]
Schedule Of Equity Method Investments [Line Items]
Equity in earnings in ATC	$ 9,434	$ 9,079	$ 8,615	$ 9,400	$ 9,100	$ 8,600
Dividend income from ATC	7,404	7,146	6,728	7,400	7,100	6,700
Contributions to investments	$ 1,660	$ 2,419	$ 1,008	$ 1,400	$ 2,100	$ 900	$ 500
MGE Transco ownership interest in ATC				3.60%	3.60%

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Commitments and Contingencies (Details-3) (USD $)	12 Months Ended
	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Leases, Future Minimum Rental Payments [Abstract]
Operating lease renewal term	1 year
Minimum lease payments, 2014	$ 1,668,000
Minimum lease payments, 2015	1,478,000
Minimum lease payments, 2016	983,000
Minimum lease payments, 2017	718,000
Minimum lease payments, 2018	418,000
Minimum lease payments, Thereafter	8,179,000
Rental expense under operating leases	$ 2,700,000	$ 2,600,000	$ 3,200,000

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Adoption of Accounting Principles and Recently Issued Accounting Pronouncements

12 Months Ended

Dec. 31, 2013

New Accounting Pronouncements and Changes in Accounting Principles [Abstract]

Adoption of Accounting Principles and Recently Issued Accounting Pronouncements

Adoption of Accounting Principles and Recently Issued 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 16 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 became 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 became 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.

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Income Taxes (Tables)

12 Months Ended

Dec. 31, 2013

Income Tax Disclosure [Abstract]

Income Tax Provision

On a consolidated and separate company basis, MGE Energy's and MGE's income tax provision consists of the following provision (benefit) components for the years ended December 31:

		MGE Energy						MGE
(In thousands)		2013		2012		2011		2013		2012		2011
Current payable:
Federal	$	(1,508)	$	(6,053)	$	(1,504)	$	(448)	$	(5,030)	$	(607)
State		8,213		436		4,580		8,322		613		4,658
Net-deferred:
Federal		37,203		37,178		30,115		36,937		36,589		29,255
State		1,163		7,618		3,102		1,223		7,523		3,034
Amortized investment tax credits		(212)		(260)		(301)		(212)		(260)		(301)
Total income tax provision	$	44,859	$	38,919	$	35,992	$	45,822	$	39,435	$	36,039

Effective Tax Rate Reconciliation

MGE Energy's and MGE's consolidated income tax provision differs from the amount computed by applying the statutory federal income tax rate to income before income taxes, as follows:

	MGE Energy			MGE
	2013	2012	2011	2013	2012	2011
Statutory federal income tax rate	35.0%	35.0%	35.0%	35.0%	35.0%	35.0%
State income taxes, net of federal benefit	5.1%	5.0%	5.1%	5.1%	5.0%	5.1%
Amortized investment tax credits	(0.2)%	(0.3)%	(0.3)%	(0.2)%	(0.2)%	(0.3)%
Credit for electricity from wind energy	(1.5)%	(1.6)%	(1.8)%	(1.5)%	(1.5)%	(1.8)%
Domestic manufacturing deduction	(0.2)%	0.3%	(0.7)%	(0.2)%	0.3%	(0.7)%
AFUDC Equity, net	(0.7)%	(0.4)%	0.0%	(0.7)%	(0.4)%	0.0%
Other, net, individually insignificant	(0.0)%	(0.3)%	(0.2)%	(0.0)%	(0.5)%	(0.3)%
Effective income tax rate	37.5%	37.7%	37.1%	37.5%	37.7%	37.0%

Deferred Tax Liabilities (Assets)

The significant components of deferred tax liabilities (assets) that appear on MGE Energy's and MGE's consolidated balance sheets as of December 31 as follows:

		MGE Energy				MGE
(In thousands)		2013		2012		2013		2012
Property-related	$	263,881	$	248,545	$	263,881	$	248,545
Investment in ATC		32,696		29,147		27,073		24,993
Bond transactions		1,553		1,643		1,553		1,643
Pension and other postretirement benefits		34,478		82,072		34,478		82,072
Derivatives		26,361		29,134		26,361		29,134
Tax deductible prepayments		7,508		7,233		7,508		7,233
Other		1,995		10,662		1,911		10,634
Gross deferred income tax liabilities		368,472		408,436		362,765		404,254
Future federal tax benefit		0		(25,626)		0		(25,899)
Accrued expenses		(17,195)		(30,277)		(17,195)		(30,228)
Pension and other postretirement benefits		(26,838)		(69,941)		(26,838)		(69,941)
Deferred tax regulatory account		(1,402)		(1,551)		(1,402)		(1,551)
Derivatives		(26,361)		(29,134)		(26,361)		(29,134)
Other		(10,369)		(5,345)		(9,356)		(4,940)
Gross deferred income tax assets		(82,165)		(161,874)		(81,152)		(161,693)
Less valuation allowance		195		365		195		365
Net deferred income tax assets		(81,970)		(161,509)		(80,957)		(161,328)
Deferred income taxes	$	286,502	$	246,927	$	281,808	$	242,926

Unrecognized Tax Benefits and Interest

A tabular reconciliation of unrecognized tax benefits and interest from January 1, 2011 to December 31, 2013, is as follows:

(In thousands)
Unrecognized tax benefits:		2013		2012		2011
Unrecognized tax benefits, January 1,	$	3,204	$	2,364	$	4,377
Additions based on tax positions related to the current year		377		401		128
Additions based on tax positions related to the prior years		424		580		427
Reductions based on tax positions related to the current year		(40)		0		0
Reductions based on tax positions related to the prior years		(1,602)		(141)		(2,568)
Unrecognized tax benefits, December 31,	$	2,363	$	3,204	$	2,364
(In thousands)
Interest on unrecognized tax benefits:		2013		2012		2011
Accrued interest on unrecognized tax benefits, January 1,	$	314	$	216	$	214
Reduction in interest expense on uncertain tax positions		(275)		0		0
Interest expense on uncertain tax positions		62		98		2
Accrued interest on unrecognized tax benefits, December 31,	$	101	$	314	$	216

Tax Years that Remain Subject to Examination

The following table shows tax years that remain subject to examination by major jurisdiction:

Taxpayer	Open Years
MGE Energy and consolidated subsidiaries in federal return	2010 through 2013
MGE Energy Wisconsin combined reporting corporation return	2009 through 2013

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Noncontrolling Interest (MGE [Member])

12 Months Ended

Dec. 31, 2013

MGE [Member]

Noncontrolling Interest [Line Items]

Noncontrolling Interest

Noncontrolling Interest - MGE.

The noncontrolling interest on MGE's balance sheet at December 31 was as follows:

(In thousands)		2013		2012
MGE Power Elm Road (a)	$	69,876	$	69,803
MGE Power West Campus (a)		29,089		30,682
MGE Transco (b)		19,998		16,985
Total noncontrolling interest	$	118,963	$	117,470

The net income attributable to noncontrolling interest, net of tax, for the years ended December 31,2013, 2012, and 2011was as follows:

(In thousands)		2013		2012		2011
MGE Power Elm Road (a)	$	17,373	$	14,837	$	14,576
MGE Power West Campus (a)		7,657		7,506		7,501
MGE Transco (b)		2,408		2,146		1,893
Net income attributable to noncontrolling interest, net of tax	$	27,438	$	24,489	$	23,970

(a)MGE Power Elm Road and MGE Power West Campus are not subsidiaries of MGE; however, they have been consolidated in the consolidated financial statements of MGE (see Footnote 2). MGE Power Elm Road and MGE Power West Campus are100% owned by MGE Power, and MGE Power is 100% owned by MGE Energy. MGE Energy's proportionate share of the equity and net income (through its wholly owned subsidiary MGE Power) of MGE Power Elm Road and MGE Power West Campus is classified within the MGE financial statements as noncontrolling interest.

(b)At December 31, 2013, MGE is the majority owner, and MGE Energy 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.

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Pension Plans and Other Postretirement Benefits

12 Months Ended

Dec. 31, 2013

Compensation and Retirement Disclosure [Abstract]

Pension Plans and Other Postretirement Benefits

Pension Plans and Other Postretirement Benefits - MGE Energy and MGE.

MGE maintains qualified and nonqualified pension plans, health care, and life insurance benefits, and two defined contribution 401(k) benefit plans for its employees and retirees. MGE's costs for the 401(k) plans were $2.3 million, $2.1 million, and $1.8 million in 2013, 2012, and 2011, respectively. A measurement date of December 31 is utilized for all pension and postretirement benefit plans.

All employees hired after December 31, 2006, have been enrolled in the defined contribution pension plan, rather than the defined benefit pension plan previously in place.

a.Benefit Obligations.

						Other Postretirement
(In thousands)		Pension Benefits				Benefits
Change in benefit obligations:		2013		2012		2013		2012
Net benefit obligation at beginning of year	$	315,505	$	283,668	$	92,605	$	97,644
Service cost		7,705		7,139		2,380		2,528
Interest cost		12,656		12,704		3,871		4,431
Plan participants' contributions		0		0		665		718
Plan amendments(a)		0		(912)		(20,915)		0
Actuarial (gain) loss		(40,335)		22,266		(9,687)		(9,748)
Gross benefits paid		(11,573)		(9,360)		(2,998)		(3,155)
Less: federal subsidy on benefits paid		0		0		179		187
Benefit obligation at end of year	$	283,958	$	315,505	$	66,100	$	92,605

• In 2013, MGE capped the amount it pays each year toward retiree medical premiums at 175%of the 2013 employer contribution for qualified employees.

The accumulated benefit obligation for the defined benefit pension plans at the end of 2013 and 2012 was $254.5 million and $272.5 million, respectively.

			Other Postretirement
	Pension Benefits		Benefits
Weighted-average assumptions used to
determine end of year benefit obligations:	2013	2012	2013	2012
Discount rate	4.88%	4.09%	4.69%	4.14%
Rate of compensation increase	3.90%	4.60%	N/A	N/A

The following table shows assumed health care cost trend rates at December 31:

	2013	2012
Health care cost trend rate assumed for next year	7.0%	7.5%
Rate to which the cost trend rate is assumed to
decline (the ultimate trend rate)	5.0%	5.0%
Year that the rate reaches the ultimate trend rate	2018	2018

The assumed health care cost trend rates have a significant effect on the amounts reported for the health care plans.

The following table shows how an assumed 1% increase or 1% decrease in health care cost trends could impact postretirement benefits in 2013 dollars:

(In thousands)		1% Increase		1% Decrease
Effect on other postretirement benefit obligation	$	1,286	$	(1,840)

In 2003, the Medicare Prescription Drug, Improvement and Modernization Act of 2003 was signed into law authorizing Medicare to provide prescription drug benefits to retirees. For the year endedDecember 31,2013, the subsidy due to MGE was $0.2 million.

b.       Plan Assets.

						Other Postretirement
(In thousands)		Pension Benefits				Benefits
Change in plan assets:		2013		2012		2013		2012
Fair value of plan assets at beginning of year	$	212,277	$	173,311	$	32,124	$	23,456
Actual return on plan assets		45,816		27,511		5,000		3,046
Employer contributions		30,878		20,815		2,811		8,059
Plan participants' contributions		0		0		665		718
Gross benefits paid		(11,573)		(9,360)		(2,998)		(3,155)
Fair value of plan assets at end of year	$	277,398	$	212,277	$	37,602	$	32,124

The expected long-term rate of return on the pension plan assets is 8.10%for both2013 and 2012.

c.       Explanation of Long-Term Rate of Return.

MGE employs a building-block approach in determining the expected long-term rate of return for asset classes. Historical markets are studied and long-term historical relationships among asset classes are analyzed, consistent with the widely accepted capital market principle that assets with higher volatility generate a greater return over the long run. Current market factors, such as interest rates and dividend yields, are evaluated before long-term capital market assumptions are determined.

The expected long-term nominal rate of return for plan assets is primarily a function of expected long-term real rates of return for component asset classes and the plan's target asset allocation in conjunction with an inflation assumption. Peer data and historical returns are reviewed to check for appropriateness.

The asset allocation for MGE's pension plans at the end of 2013 and 2012, and the target allocation for 2014, by asset category, follows:

		Percentage of Plan
	Target	Assets at Year End
	Allocation	2013	2012
Equity securities	63.0%	66.0%	64.0%
Debt securities	30.0%	28.0%	29.0%
Real estate	7.0%	6.0%	7.0%
Total	100.0%	100.0%	100.0%

d.       Investment Strategy.

MGE employs a total return investment approach whereby a mix of equities, fixed income, and real estate investments are used to maximize the expected long-term return of plan assets for a prudent level of risk. Risk tolerance is established through careful consideration of plan liabilities, plan-funded status, and corporate financial condition. The investment portfolio contains a diversified blend of equity, fixed income, and real estate investments. Target asset allocations are as follows: 45.5% United States equity, 17.5% non-United States equity, 30.0% fixed income, and 7.0% real estate. Investment risk is measured and monitored on an ongoing basis through periodic investment portfolio reviews and liability measurements.

e.       Concentrations of Credit Risk.

       MGE evaluated its pension and other postretirement benefit plans' asset portfolios for the existence of significant concentrations of credit risk as of December 31, 2013. Types of concentrations that were evaluated include, but are not limited to, investment concentrations in a single entity, type of industry, and foreign country. As of December 31, 2013, there were no significant concentrations (defined as greater than 10 percent of plan assets) of risk in MGE pension and postretirement benefit plan assets.

f.        Fair Value Measurements of Plan Assets.

Fair value is defined as the price that would be received to sell an asset or 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.

The following is a description of the valuation methodologies used for assets measured at fair value as of December 31, 2013:

Cash and Cash Equivalents – This category includes highly liquid investments with maturities of less than three months which are traded in active markets.

Equity Securities – These securities consist of U.S. and international stock funds. The U.S. stock funds are primarily invested in domestic equities. Securities in these funds are typically priced using the closing price from the applicable exchange, NYSE, NASDAQ, etc. The international funds are composed of international equities. Securities are priced using the closing price from the appropriate local stock exchange.

Fixed Income Securities – These securities consist of U.S. bond funds and short-term funds. U.S. bond funds are priced by a pricing agent using inputs such as benchmark yields, reported trades, broker/dealer quotes, and issuer spreads. The short-term funds are valued initially at cost and adjusted for amortization of any discount or premium.

Real Estate – The fair value of real estate properties is determined through an external appraisal process.

Insurance Continuance Fund (ICF) – The fair value of the ICF is based on largely unobservable inputs, which are based on a commingled interest.

The fair value of MGE's plan assets, by asset category are as follows:

	Fair Value as of December 31, 2013
(In thousands)		Total		Level 1		Level 2		Level 3
Cash and Cash Equivalents	$	5,109	$	5,109	$	0	$	0
Equity Securities:
U.S. Large Cap		96,258		0		96,258		0
U.S. Mid Cap		22,741		0		22,741		0
U.S. Small Cap		28,854		0		28,854		0
International Blend		54,873		0		54,873		0
Fixed Income Securities:
Short-Term Fund		4,789		0		4,789		0
High Yield Bond		15,127		0		15,127		0
Long Duration Bond		66,193		0		66,193		0
Real Estate		19,628		0		0		19,628
Insurance Continuance Fund		1,428		0		0		1,428
Total	$	315,000	$	5,109	$	288,835	$	21,056
	Fair Value as of December 31, 2012
(In thousands)		Total		Level 1		Level 2		Level 3
Cash and Cash Equivalents	$	5,627	$	5,627	$	0	$	0
Equity Securities:
U.S. Large Cap		68,671		0		68,671		0
U.S. Mid Cap		16,741		0		16,741		0
U.S. Small Cap		21,222		0		21,222		0
International Blend		44,200		0		44,200		0
Fixed Income Securities:
Short-Term Fund		4,231		0		4,231		0
High Yield Bond		11,587		0		11,587		0
Long Duration Bond		53,515		0		53,515		0
Real Estate		17,141		0		0		17,141
Insurance Continuance Fund		1,466		0		0		1,466
Total	$	244,401	$	5,627	$	220,167	$	18,607

No transfers were made in or out of Level 1 or Level 2 for the year endedDecember 31, 2013.

The following table summarizes the changes in the fair value of the Level 3 plan assets.

		Level 3 Assets
				Insurance
				Continuance
(In thousands)		Real Estate		Fund
Balance as of January 1, 2012	$	15,565	$	906
Actual return on plan assets:
Relating to assets still held at the reporting date		682		33
Purchases, sales, and settlements		894		527
Transfers in and/or out of Level 3		0		0
Balance as of December 31, 2012	$	17,141	$	1,466
Actual return on plan assets:
Relating to assets still held at the reporting date		1,565		42
Purchases, sales, and settlements		922		(80)
Transfers in and/or out of Level 3		0		0
Balance as of December 31, 2013	$	19,628	$	1,428

g.        Other Postretirement Benefits.

The fair value of plan assets for the postretirement benefit plans is $37.6 million and $32.1 million at the end of 2013 and 2012, respectively. The expected long-term rate of return on these plan assets is 6.79% and 7.26% for2013 and 2012, respectively.

Of the above amounts, $31.1 million and $25.0 million at the end of 2013 and 2012, respectively, were held in the master pension trust and are allocable to postretirement health expenses. The target asset allocation and investment strategy for the portion of assets held in the master pension trust are the same as that explained for MGE's pension plans.

The remainder of postretirement benefit assets are held either in an insurance continuance fund for the payment of retiree life benefits or a health benefit trust for payment of retiree health claims. There is no formal target asset allocation for these assets, but the intent is to seek interest income and maintain stability of principal.

h.       Funded Status.

The funded status at the end of the year, and the related amounts recognized on the consolidated balance sheet are as follows:

						Other Postretirement
(In thousands)		Pension Benefits				Benefits
Funded status, end of year		2013		2012		2013		2012
Fair value of plan assets	$	277,398	$	212,277	$	37,602	$	32,124
Benefit obligations		283,958		315,505		66,100		92,605
Funded status	$	(6,560)	$	(103,228)	$	(28,498)	$	(60,481)

At December 31, 2013, MGE Energy and MGE included a $15.1 million long-term asset, a $1.0million current liability, a $49.2 million long-term liability, and a $24.6 million regulatory assetin the consolidated balance sheets to reflect the unfunded status of the plans.

At December 31, 2012, MGE Energy and MGE included a $0.9 million current liability, a $162.8 million long-term liability, and a $134.8 million regulatory asset in the consolidated balance sheets to reflect the unfunded status of the plans.

						Other Postretirement
(In thousands)		Pension Benefits				Benefits
Amounts recognized as regulatory asset		2013		2012		2013		2012
Net actuarial loss	$	37,499	$	112,637	$	7,761	$	21,529
Prior service cost		(209)		105		(20,495)		530
Transition obligation		0		0		35		38
Total	$	37,290	$	112,742	$	(12,699)	$	22,097

The projected benefit obligation and fair value of plan assets for pension plans with a projected benefit obligation in excess of plan assets were as follows:

(In thousands)		Pension Benefits
Projected benefit obligation in excess of plan assets		2013		2012
Projected benefit obligation, end of year	$	21,631	$	315,505
Fair value of plan assets, end of year		0		212,277

The projected benefit obligation, accumulated benefit obligation, and fair value of plan assets for pension plans with a projected benefit obligation in excess of plan assets and an accumulated benefit obligation in excess of plan assets were as follows:

(In thousands)		Pension Benefits
Accumulated benefit obligation in excess of plan assets		2013		2012
Projected benefit obligation, end of year	$	21,631	$	315,505
Accumulated benefit obligation, end of year		19,795		272,462
Fair value of plan assets, end of year		0		212,277

i.       Expected Cash Flows.

MGE does not expect to make contributions to the plans for 2014 or 2015.The contributions for years after 2015 are not yet currently estimated.MGE has adopted the asset smoothing as permitted in accordance with the Pension Protection Act of 2006, including modifications made by WRERA.

Due to uncertainties in the future economic performance of plan assets, discount rates, and other key assumptions, estimated contributions are subject to change. MGE may also elect to make additional discretionary contributions.

In 2013, MGE made $34.8 millionin employer contributions to its pension and postretirement plans.

j.       Benefit Payments.

The following benefit payments, which reflect expected future service, as appropriate, are expected to be paid as follows:

		Pension	Other Postretirement
			Gross	Expected		Net
		Pension	Postretirement	Medicare Part D		Postretirement
(In thousands)		Benefits	Benefits	Subsidy		Benefits
2014	$	11,474	2,924	(191)	$	2,733
2015		12,223	3,056	(219)		2,837
2016		12,844	3,308	(246)		3,062
2017		13,633	3,740	(266)		3,474
2018		14,755	4,198	(289)		3,909
2019 - 2023		87,676	27,110	(1,866)		25,244

k.       Net Periodic Cost.

MGE has elected to recognize the cost of its transition obligation (the accumulated postretirement benefit obligation as of January 1, 1993) by amortizing it on a straight-line basis over 20 years.

(In thousands)		Pension Benefits						Other Postretirement Benefits
Components of net periodic benefit cost		2013		2012		2011		2013		2012		2011
Service cost	$	7,705	$	7,139	$	6,013	$	2,380	$	2,528	$	1,920
Interest cost		12,656		12,704		12,281		3,871		4,431		3,980
Expected return on assets		(19,027)		(15,182)		(14,034)		(2,176)		(1,741)		(1,584)
Special termination benefits		0		0		13		0		0		0
Amortization of:
Transition obligation		0		0		0		3		425		427
Prior service cost		314		430		433		110		110		110
Actuarial loss		8,014		8,288		3,771		1,236		2,346		566
Net periodic benefit cost	$	9,662	$	13,379	$	8,477	$	5,424	$	8,099	$	5,419
Weighted-average assumptions used to
determine net periodic cost:
Discount rate		4.09%		4.50%		5.36%		4.14%		4.55%		5.42%
Expected return on plan assets		8.10%		8.10%		8.25%		6.79%		7.26%		7.39%
Rate of compensation increase		4.60%		4.59%		4.59%		N/A		N/A		N/A

Assumed health care cost trend rates have a significant effect on the amounts reported for the health care plans. A 1% change in the assumed health care cost trend rates would have had the following effect:

(In thousands)		1% Increase		1% Decrease
Effect on total service and interest cost components	$	1,104	$	(879)

The PSCW has allowed MGE to defer the 2009 incremental pension and OPRB costs above the amounts recovered in rates. During both the years endedDecember 31,2013 and 2012, $1.2 million has been recovered in rates.

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Asset Retirement Obligations (Details) (USD $)	12 Months Ended
	Dec. 31, 2013	Dec. 31, 2012
Asset Retirement Obligations [Roll Forward]
Asset retirement obligation, beginning balance	$ 18,768,000	$ 19,173,000
Liabilities incurred	296,000	49,000
Accretion expense	1,015,000	1,021,000
Liabilities settled	(744,000)	(221,000)
Revisions in estimated cash flows	24,000	(1,254,000)	[1]
Asset retirement obligation, ending balance	19,359,000	18,768,000
Revisions in estimated cash flows [Abstract]
Decrease in revisions in estimated cash flows for revised asbestos abatement related to the asset retirement obligation	$ 0	$ (1,300,000)

[1] (a) In 2012, MGE recorded a decrease in revisions in estimated cash flows of $1.3 million based on revised asbestos abatement estimates.

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Notes Payable to Banks, Commercial Paper, and Lines of Credit (Tables)

12 Months Ended

Dec. 31, 2013

Debt Disclosure [Abstract]

Schedule of Short-Term Borrowings

Information concerning short-term borrowings for the past three years is shown below:

		As of December 31,
(In thousands)		2013		2012		2011
MGE Energy(a)
Available lines of credit	$	150,000	$	115,000	$	115,000
During the year:
Maximum short-term borrowings	$	32,000	$	16,000	$	28,500
Average short-term borrowings	$	6,992	$	1,154	$	3,410
Weighted-average interest rate		0.18%		0.17%		1.43%
MGE
Available lines of credit	$	100,000	$	75,000	$	75,000
During the year:
Maximum short-term borrowings	$	32,000	$	16,000	$	9,500
Average short-term borrowings	$	6,992	$	1,154	$	349
Weighted-average interest rate		0.18%		0.17%		0.25%

(a)MGE Energy short-term borrowings include MGE Energy and MGE lines of credit and MGE commercial paper.

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Schedule I - Condensed Parent Company Finanical Statements (Details-Notes 2) (USD $)	0 Months Ended	12 Months Ended
	Dec. 20, 2013	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Dividends from Affiliates [Line Items]
Dividends from affiliates		$ 52,366,000	$ 44,343,000	$ 79,148,000
Stock Split
Stock split declared December 20, 2013, ratio (3:2)	1.5
First Mortgage Bonds [Member] | 7.70%, 2028 Series
Dividend Restrictions
Debt covenant, allowable amount available for payment of dividends		305,600,000
MGE [Member]
Dividends from Affiliates [Line Items]
Dividends from affiliates		25,000,000	20,404,000	26,648,000
Dividend Restrictions
Dividend restrictions, minimum common equity ratio		0.55
Common equity ratio		0.576
MGE [Member] | First Mortgage Bonds [Member] | 7.70%, 2028 Series
Dividend Restrictions
Debt covenant, allowable amount available for payment of dividends		305,600,000
MGE Construct [Member]
Dividends from Affiliates [Line Items]
Dividends from affiliates		0	239,000	0
MGE Power Elm Road [Member]
Dividends from Affiliates [Line Items]
Dividends from affiliates		17,300,000	16,000,000	43,000,000
MGE Power [Member]
Dividends from Affiliates [Line Items]
Dividends from affiliates		0	200,000	0
MGE Power West Campus [Member]
Dividends from Affiliates [Line Items]
Dividends from affiliates		9,250,000	7,500,000	9,500,000
MGE Transco [Member]
Dividends from Affiliates [Line Items]
Dividends from affiliates		$ 816,000	$ 0	$ 0

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Summary of Significant Accounting Policies (Tables)

12 Months Ended

Dec. 31, 2013

Accounting Policies [Abstract]

Straight-Line Depreciation Rates

Provisions at composite straight-line depreciation rates approximate the following percentages for the cost of depreciable property:

	2013	2012	2011
Electric	2.7%	2.9%	3.2%
Gas	1.7%	1.7%	1.6%
Nonregulated	2.3%	2.3%	2.3%

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Madison Gas and Electric Company Consolidated Statements of Comprehensive Income (USD $) In Thousands, unless otherwise specified	12 Months Ended
	Dec. 31, 2013		Dec. 31, 2012		Dec. 31, 2011
Other comprehensive income (loss), net of tax:
Unrealized gain (loss) on available for sale securities, net of tax	$ 283	[1]	$ (18)	[2]	$ (15)	[3]
Reclassification of realized gain on available-for-sale securities, net of tax	0	[4]	0	[4]	(15)	[3]
Comprehensive Income	75,188		64,428		60,898
MGE [Member]
Net Income	76,445		65,306		61,252
Other comprehensive income (loss), net of tax:
Unrealized gain (loss) on available for sale securities, net of tax	188	[5]	(43)	[6]	(9)	[7]
Reclassification of realized gain on available-for-sale securities, net of tax	0	[4]	0	[4]	(15)	[3]
Comprehensive Income Including Noncontrolling Interest	76,633		65,263		61,228
Less: Comprehensive Income Attributable to Noncontrolling Interest, net of tax	(27,438)		(24,489)		(23,970)
Comprehensive Income	$ 49,195		$ 40,774		$ 37,258

[1] Net of $189 tax

[2] Net of $12 tax

[3] Net of $10 tax

[4] Net of $0 tax

[5] Net of $126 tax

[6] Net of $29 tax

[7] Net of $7 tax

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Derivative and Hedging Instruments (Details-5) (USD $)	12 Months Ended
	Dec. 31, 2013	Dec. 31, 2012
Counterparties in net liability position or default [Abstract]
Number of counterparties in net liability position	0	0
Number of counterparties in default	0
Commodity Derivative Contracts [Member] | Fuel For Electric Generation Purchased Power [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Realized losses (gains)	$ (564,000)	$ 2,620,000
Commodity Derivative Contracts [Member] | Cost Of Gas Sold Expense [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Realized losses (gains)	868,000	3,072,000
Financial Transmission Rights [Member] | Fuel For Electric Generation Purchased Power [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Realized losses (gains)	(983,000)	(45,000)
Financial Transmission Rights [Member] | Cost Of Gas Sold Expense [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Realized losses (gains)	0	0
Ten-year PPA [Member]
Derivative collateral required to be posted for ten-year PPA [Abstract]
Minimum collateral that may be required to be posted	20,000,000
Maximum collateral that may be required to be posted	40,000,000
Collateral posted	0
Ten-year PPA [Member] | Fuel For Electric Generation Purchased Power [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Realized losses (gains)	4,209,000	3,232,000
Ten-year PPA [Member] | Cost Of Gas Sold Expense [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Realized losses (gains)	$ 0	$ 0

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Consolidated Balance Sheets (Parentheticals) (USD $) In Thousands, except Per Share data, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012
Receivables, Net
Reserve for uncollectible accounts receivable	$ 4,219	$ 3,885
Reserve for uncollectible other accounts receivable	750	931
Common shareholders' equity
Common stock, par value	$ 1	$ 1
Common stock, shares authorized	50,000	50,000
Common stock, shares issued	34,668	34,668
Common stock, shares outstanding	34,668	34,668
MGE [Member]
Receivables, Net
Reserve for uncollectible accounts receivable	4,219	3,885
Reserve for uncollectible other accounts receivable	$ 750	$ 931
Common shareholders' equity
Common stock, par value	$ 1	$ 1
Common stock, shares authorized	50,000	50,000
Common stock, shares outstanding	17,348	17,348

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Quarterly Summary of Operations (Tables)

12 Months Ended

Dec. 31, 2013

Quarterly Financial Information Disclosure [Abstract]

Quarterly Summary of Operations

(In thousands, except per share amounts)		Quarters Ended
2013		March 31		June 30		September 30		December 31
Operating revenues:
Regulated electric revenues	$	93,494	$	96,846	$	119,836	$	93,781
Regulated gas revenues		72,467		30,042		18,864		60,089
Nonregulated revenues		1,276		1,400		1,399		1,393
Total Operating Revenues		167,237		128,288		140,099		155,263
Operating expenses		129,609		103,791		100,199		129,301
Operating income		37,628		24,497		39,900		25,962
Interest and other income, net		(1,366)		(1,946)		(855)		(4,056)
Income tax provision		(13,678)		(8,660)		(14,692)		(7,829)
Earnings on common stock	$	22,584	$	13,891	$	24,353	$	14,077
Earnings per common share	$	0.65	$	0.40	$	0.70	$	0.41
Dividends per share	$	0.263	$	0.263	$	0.272	$	0.272
2012
Operating revenues:
Regulated electric revenues	$	89,936	$	96,339	$	118,914	$	87,176
Regulated gas revenues		57,019		18,629		16,587		47,492
Nonregulated revenues		2,304		2,253		2,337		2,337
Total Operating Revenues		149,259		117,221		137,838		137,005
Operating expenses		120,815		92,140		97,950		117,655
Operating income		28,444		25,081		39,888		19,350
Interest and other income, net		(2,534)		(2,215)		(1,993)		(2,656)
Income tax provision		(9,862)		(8,596)		(14,253)		(6,208)
Earnings on common stock	$	16,048	$	14,270	$	23,642	$	10,486
Earnings per common share	$	0.47	$	0.41	$	0.68	$	0.30
Dividends per share	$	0.255	$	0.255	$	0.263	$	0.263

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Share-Based Compensation (Details) (USD $) In Millions, except Share data, unless otherwise specified	12 Months Ended			0 Months Ended	1 Months Ended		0 Months Ended	12 Months Ended				1 Months Ended
	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011	Feb. 15, 2013 Performance Unit Plan [Member] Performance Units [Member]	Feb. 17, 2012 Performance Unit Plan [Member] Performance Units [Member]	Jan. 21, 2011 Performance Unit Plan [Member] Performance Units [Member]	Jan. 15, 2010 Performance Unit Plan [Member] Performance Units [Member]	Dec. 31, 2013 Performance Unit Plan [Member] Performance Units [Member]	Dec. 31, 2012 Performance Unit Plan [Member] Performance Units [Member]	Dec. 31, 2011 Performance Unit Plan [Member] Performance Units [Member]	Jan. 31, 2013 Performance Unit Plan [Member] Performance Units [Member]	Feb. 21, 2014 Performance Unit Plan [Member] Performance Units [Member] Subsequent Event [Member]	Jan. 31, 2014 Director Incentive Agreement [Member] Performance Units [Member] Subsequent Event [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Award vesting period								5 years					3 years
Awards granted (in units)				22,884	25,040	23,483	25,965					21,991	4,683
Compensation expense	$ 1.5	$ 1.4	$ 1.4
Cash payments distributed related to awards previously granted and now payable											1.0
Awards forfeited during period								0	0	0
Outstanding awards vested during period								$ 4.5

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Schedule II - Valuation and Qualifying Accounts (Details) (USD $)	12 Months Ended
	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Valuation and Qualifying Accounts [Roll Forward]
Balance at beginning of period	$ 4,816,118	$ 4,100,333	$ 4,588,675
Charged to costs and expenses	2,373,342	2,825,300	2,174,729
Charged to other accounts	37,200	44,400	49,500
Net accounts written off	(2,256,949)	(2,153,915)	(2,712,571)
Balance at end of period	$ 4,969,711	$ 4,816,118	$ 4,100,333

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Long-Term Debt (Details) (USD $)	12 Months Ended													0 Months Ended																									0 Months Ended																																																																	12 Months Ended														0 Months Ended																									0 Months Ended
	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011	Dec. 31, 2013 First Mortgage Bonds [Member] 7.70%, 2028 Series		Dec. 31, 2012 First Mortgage Bonds [Member] 7.70%, 2028 Series		Dec. 31, 2013 Tax Exempt Debt [Member] 3.45%, 2027 Series, Industrial Development Revenue Bonds	Dec. 31, 2012 Tax Exempt Debt [Member] 3.45%, 2027 Series, Industrial Development Revenue Bonds	Dec. 31, 2013 Medium-Term Notes [Member]		Dec. 31, 2012 Medium-Term Notes [Member]		Jul. 18, 2013 Medium-Term Notes [Member] 5.26%, due 2017	Dec. 31, 2013 Medium-Term Notes [Member] 5.26%, due 2017		Dec. 31, 2012 Medium-Term Notes [Member] 5.26%, due 2017		Dec. 31, 2013 Medium-Term Notes [Member] 5.25%, due 2017		Dec. 31, 2012 Medium-Term Notes [Member] 5.25%, due 2017		Dec. 31, 2013 Medium-Term Notes [Member] 6.12%, due 2028		Dec. 31, 2012 Medium-Term Notes [Member] 6.12%, due 2028		Dec. 31, 2013 Medium-Term Notes [Member] 7.12%, due 2032		Dec. 31, 2012 Medium-Term Notes [Member] 7.12%, due 2032		Dec. 31, 2013 Medium-Term Notes [Member] 6.247%, due 2037		Dec. 31, 2012 Medium-Term Notes [Member] 6.247%, due 2037		Dec. 31, 2013 Other Long-Term Debt [Member]		Dec. 31, 2012 Other Long-Term Debt [Member]		Jul. 18, 2013 Other Long-Term Debt [Member] 5.59%, due 2018	Dec. 31, 2013 Other Long-Term Debt [Member] 5.59%, due 2018		Dec. 31, 2012 Other Long-Term Debt [Member] 5.59%, due 2018		Dec. 31, 2013 Other Long-Term Debt [Member] 5.59%, due 2018 Minimum [Member]	Dec. 31, 2013 Other Long-Term Debt [Member] 5.59%, due 2018 Maximum [Member]	Dec. 31, 2013 Other Long-Term Debt [Member] 3.38%, due 2020		Dec. 31, 2012 Other Long-Term Debt [Member] 3.38%, due 2020		Dec. 31, 2013 Other Long-Term Debt [Member] 3.38%, due 2020 Minimum [Member]	Dec. 31, 2013 Other Long-Term Debt [Member] 3.38%, due 2020 Maximum [Member]	Dec. 31, 2013 Other Long-Term Debt [Member] 3.09%, due 2023		Dec. 31, 2012 Other Long-Term Debt [Member] 3.09%, due 2023		Dec. 31, 2013 Other Long-Term Debt [Member] 3.09%, due 2023 Minimum [Member]	Dec. 31, 2013 Other Long-Term Debt [Member] 3.09%, due 2023 Maximum [Member]	Dec. 31, 2013 Other Long-Term Debt [Member] 3.29%, due 2026		Dec. 31, 2012 Other Long-Term Debt [Member] 3.29%, due 2026		Dec. 31, 2013 Other Long-Term Debt [Member] 3.29%, due 2026 Minimum [Member]	Dec. 31, 2013 Other Long-Term Debt [Member] 3.29%, due 2026 Maximum [Member]	Dec. 31, 2013 Other Long-Term Debt [Member] 5.68%, due 2033		Dec. 31, 2012 Other Long-Term Debt [Member] 5.68%, due 2033		Dec. 31, 2013 Other Long-Term Debt [Member] 5.19%, due 2033		Dec. 31, 2012 Other Long-Term Debt [Member] 5.19%, due 2033		Dec. 31, 2013 Other Long-Term Debt [Member] 5.26%, due 2040		Dec. 31, 2012 Other Long-Term Debt [Member] 5.26%, due 2040		Dec. 31, 2013 Other Long-Term Debt [Member] 5.26%, due 2040 Minimum [Member]	Dec. 31, 2013 Other Long-Term Debt [Member] 5.26%, due 2040 Maximum [Member]	Dec. 31, 2013 Other Long-Term Debt [Member] 5.04%, due 2040		Dec. 31, 2012 Other Long-Term Debt [Member] 5.04%, due 2040		Dec. 31, 2013 Other Long-Term Debt [Member] 4.74%, due 2041		Dec. 31, 2012 Other Long-Term Debt [Member] 4.74%, due 2041		Dec. 31, 2013 Other Long-Term Debt [Member] 4.38%, due 2042		Dec. 31, 2012 Other Long-Term Debt [Member] 4.38%, due 2042		Dec. 31, 2013 Other Long-Term Debt [Member] 4.38%, due 2042 Minimum [Member]	Dec. 31, 2013 Other Long-Term Debt [Member] 4.38%, due 2042 Maximum [Member]	Dec. 31, 2013 Other Long-Term Debt [Member] 4.42%, due 2043		Dec. 31, 2012 Other Long-Term Debt [Member] 4.42%, due 2043		Dec. 31, 2013 Other Long-Term Debt [Member] 4.42%, due 2043 Minimum [Member]	Dec. 31, 2013 Other Long-Term Debt [Member] 4.42%, due 2043 Maximum [Member]	Dec. 31, 2013 Other Long-Term Debt [Member] 4.47%, due 2048		Dec. 31, 2012 Other Long-Term Debt [Member] 4.47%, due 2048		Dec. 31, 2013 Other Long-Term Debt [Member] 4.47%, due 2048 Minimum [Member]	Dec. 31, 2013 Other Long-Term Debt [Member] 4.47%, due 2048 Maximum [Member]	Dec. 31, 2013 MGE [Member]		Dec. 31, 2012 MGE [Member]	Dec. 31, 2011 MGE [Member]	Dec. 31, 2013 MGE [Member] First Mortgage Bonds [Member] 7.70%, 2028 Series		Dec. 31, 2012 MGE [Member] First Mortgage Bonds [Member] 7.70%, 2028 Series		Dec. 31, 2013 MGE [Member] Tax Exempt Debt [Member] 3.45%, 2027 Series, Industrial Development Revenue Bonds	Dec. 31, 2012 MGE [Member] Tax Exempt Debt [Member] 3.45%, 2027 Series, Industrial Development Revenue Bonds	Dec. 31, 2013 MGE [Member] Medium-Term Notes [Member]		Dec. 31, 2012 MGE [Member] Medium-Term Notes [Member]		Jul. 18, 2013 MGE [Member] Medium-Term Notes [Member] 5.26%, due 2017	Dec. 31, 2013 MGE [Member] Medium-Term Notes [Member] 5.26%, due 2017		Dec. 31, 2012 MGE [Member] Medium-Term Notes [Member] 5.26%, due 2017		Dec. 31, 2013 MGE [Member] Medium-Term Notes [Member] 5.25%, due 2017		Dec. 31, 2012 MGE [Member] Medium-Term Notes [Member] 5.25%, due 2017		Dec. 31, 2013 MGE [Member] Medium-Term Notes [Member] 6.12%, due 2028		Dec. 31, 2012 MGE [Member] Medium-Term Notes [Member] 6.12%, due 2028		Dec. 31, 2013 MGE [Member] Medium-Term Notes [Member] 7.12%, due 2032		Dec. 31, 2012 MGE [Member] Medium-Term Notes [Member] 7.12%, due 2032		Dec. 31, 2013 MGE [Member] Medium-Term Notes [Member] 6.247%, due 2037		Dec. 31, 2012 MGE [Member] Medium-Term Notes [Member] 6.247%, due 2037		Dec. 31, 2013 MGE [Member] Other Long-Term Debt [Member]		Dec. 31, 2012 MGE [Member] Other Long-Term Debt [Member]		Jul. 18, 2013 MGE [Member] Other Long-Term Debt [Member] 5.59%, due 2018	Dec. 31, 2013 MGE [Member] Other Long-Term Debt [Member] 5.59%, due 2018		Dec. 31, 2012 MGE [Member] Other Long-Term Debt [Member] 5.59%, due 2018		Dec. 31, 2013 MGE [Member] Other Long-Term Debt [Member] 5.59%, due 2018 Minimum [Member]	Dec. 31, 2013 MGE [Member] Other Long-Term Debt [Member] 5.59%, due 2018 Maximum [Member]	Dec. 31, 2013 MGE [Member] Other Long-Term Debt [Member] 3.38%, due 2020		Dec. 31, 2012 MGE [Member] Other Long-Term Debt [Member] 3.38%, due 2020		Dec. 31, 2013 MGE [Member] Other Long-Term Debt [Member] 3.38%, due 2020 Minimum [Member]	Dec. 31, 2013 MGE [Member] Other Long-Term Debt [Member] 3.38%, due 2020 Maximum [Member]	Dec. 31, 2013 MGE [Member] Other Long-Term Debt [Member] 3.09%, due 2023		Dec. 31, 2012 MGE [Member] Other Long-Term Debt [Member] 3.09%, due 2023		Dec. 31, 2013 MGE [Member] Other Long-Term Debt [Member] 3.09%, due 2023 Minimum [Member]	Dec. 31, 2013 MGE [Member] Other Long-Term Debt [Member] 3.09%, due 2023 Maximum [Member]	Dec. 31, 2013 MGE [Member] Other Long-Term Debt [Member] 3.29%, due 2026		Dec. 31, 2012 MGE [Member] Other Long-Term Debt [Member] 3.29%, due 2026		Dec. 31, 2013 MGE [Member] Other Long-Term Debt [Member] 3.29%, due 2026 Minimum [Member]	Dec. 31, 2013 MGE [Member] Other Long-Term Debt [Member] 3.29%, due 2026 Maximum [Member]	Dec. 31, 2013 MGE [Member] Other Long-Term Debt [Member] 5.68%, due 2033		Dec. 31, 2012 MGE [Member] Other Long-Term Debt [Member] 5.68%, due 2033		Dec. 31, 2013 MGE [Member] Other Long-Term Debt [Member] 5.19%, due 2033		Dec. 31, 2012 MGE [Member] Other Long-Term Debt [Member] 5.19%, due 2033		Dec. 31, 2013 MGE [Member] Other Long-Term Debt [Member] 5.26%, due 2040		Dec. 31, 2012 MGE [Member] Other Long-Term Debt [Member] 5.26%, due 2040		Dec. 31, 2013 MGE [Member] Other Long-Term Debt [Member] 5.26%, due 2040 Minimum [Member]	Dec. 31, 2013 MGE [Member] Other Long-Term Debt [Member] 5.26%, due 2040 Maximum [Member]	Dec. 31, 2013 MGE [Member] Other Long-Term Debt [Member] 5.04%, due 2040		Dec. 31, 2012 MGE [Member] Other Long-Term Debt [Member] 5.04%, due 2040		Dec. 31, 2013 MGE [Member] Other Long-Term Debt [Member] 4.74%, due 2041		Dec. 31, 2012 MGE [Member] Other Long-Term Debt [Member] 4.74%, due 2041		Dec. 31, 2013 MGE [Member] Other Long-Term Debt [Member] 4.38%, due 2042		Dec. 31, 2012 MGE [Member] Other Long-Term Debt [Member] 4.38%, due 2042		Dec. 31, 2013 MGE [Member] Other Long-Term Debt [Member] 4.38%, due 2042 Minimum [Member]	Dec. 31, 2013 MGE [Member] Other Long-Term Debt [Member] 4.38%, due 2042 Maximum [Member]	Dec. 31, 2013 MGE [Member] Other Long-Term Debt [Member] 4.42%, due 2043		Dec. 31, 2012 MGE [Member] Other Long-Term Debt [Member] 4.42%, due 2043		Dec. 31, 2013 MGE [Member] Other Long-Term Debt [Member] 4.42%, due 2043 Minimum [Member]	Dec. 31, 2013 MGE [Member] Other Long-Term Debt [Member] 4.42%, due 2043 Maximum [Member]	Dec. 31, 2013 MGE [Member] Other Long-Term Debt [Member] 4.47%, due 2048		Dec. 31, 2012 MGE [Member] Other Long-Term Debt [Member] 4.47%, due 2048		Dec. 31, 2013 MGE [Member] Other Long-Term Debt [Member] 4.47%, due 2048 Minimum [Member]	Dec. 31, 2013 MGE [Member] Other Long-Term Debt [Member] 4.47%, due 2048 Maximum [Member]	Dec. 31, 2013 MGE Power Elm Road [Member]	Dec. 31, 2012 MGE Power Elm Road [Member]	Dec. 31, 2013 MGE Power Elm Road [Member] Minimum [Member]	Dec. 31, 2013 MGE Power Elm Road [Member] Other Long-Term Debt [Member] 5.04%, due 2040 Minimum [Member]	Dec. 31, 2013 MGE Power Elm Road [Member] Other Long-Term Debt [Member] 4.74%, due 2041 Minimum [Member]	Dec. 31, 2013 MGE Power West Campus [Member]	Dec. 31, 2012 MGE Power West Campus [Member]	Dec. 31, 2013 MGE Power West Campus [Member] Minimum [Member]	Dec. 31, 2013 MGE Power West Campus [Member] Maximum [Member]	Dec. 31, 2013 MGE Power West Campus [Member] Other Long-Term Debt [Member] 5.68%, due 2033 Minimum [Member]	Dec. 31, 2013 MGE Power West Campus [Member] Other Long-Term Debt [Member] 5.68%, due 2033 Maximum [Member]	Dec. 31, 2013 MGE Power West Campus [Member] Other Long-Term Debt [Member] 5.19%, due 2033 Minimum [Member]	Dec. 31, 2013 MGE Power West Campus [Member] Other Long-Term Debt [Member] 5.19%, due 2033 Maximum [Member]
Debt Instrument [Line Items]
Long-term debt, gross				$ 1,200,000	[1]	$ 1,200,000	[1]	$ 19,300,000	$ 19,300,000	$ 100,000,000	[2]	$ 120,000,000	[2]		$ 0	[2],[3]	$ 20,000,000	[2],[3]	$ 30,000,000	[2]	$ 30,000,000	[2]	$ 20,000,000	[2]	$ 20,000,000	[2]	$ 25,000,000	[2]	$ 25,000,000	[2]	$ 25,000,000	[2]	$ 25,000,000	[2]	$ 283,293,000	[4]	$ 221,305,000	[4]		$ 20,000,000	[3],[4],[5]	$ 40,000,000	[3],[4],[5]			$ 15,000,000	[4],[5]	$ 15,000,000	[4],[5]			$ 30,000,000	[3],[4],[5]	$ 0	[3],[4],[5]			$ 15,000,000	[3],[4],[5]	$ 0	[3],[4],[5]			$ 29,797,000	[4],[6]	$ 30,000,000	[4],[6]	$ 19,857,000	[4],[6]	$ 20,000,000	[4],[6]	$ 15,000,000	[4],[5]	$ 15,000,000	[4],[5]			$ 43,472,000	[4],[7]	$ 45,138,000	[4],[7]	$ 27,167,000	[4],[7]	$ 28,167,000	[4],[7]	$ 28,000,000	[4],[5]	$ 28,000,000	[4],[5]			$ 20,000,000	[3],[4],[5]	$ 0	[3],[4],[5]			$ 20,000,000	[3],[4],[5]	$ 0	[3],[4],[5]							$ 1,200,000	[1]	$ 1,200,000	[1]	$ 19,300,000	$ 19,300,000	$ 100,000,000	[2]	$ 120,000,000	[2]		$ 0	[2],[3]	$ 20,000,000	[2],[3]	$ 30,000,000	[2]	$ 30,000,000	[2]	$ 20,000,000	[2]	$ 20,000,000	[2]	$ 25,000,000	[2]	$ 25,000,000	[2]	$ 25,000,000	[2]	$ 25,000,000	[2]	$ 283,293,000	[4]	$ 221,305,000	[4]		$ 20,000,000	[3],[4],[5]	$ 40,000,000	[3],[4],[5]			$ 15,000,000	[4],[5]	$ 15,000,000	[4],[5]			$ 30,000,000	[3],[4],[5]	$ 0	[3],[4],[5]			$ 15,000,000	[3],[4],[5]	$ 0	[3],[4],[5]			$ 29,797,000	[4],[6]	$ 30,000,000	[4],[6]	$ 19,857,000	[4],[6]	$ 20,000,000	[4],[6]	$ 15,000,000	[4],[5]	$ 15,000,000	[4],[5]			$ 43,472,000	[4],[7]	$ 45,138,000	[4],[7]	$ 27,167,000	[4],[7]	$ 28,167,000	[4],[7]	$ 28,000,000	[4],[5]	$ 28,000,000	[4],[5]			$ 20,000,000	[3],[4],[5]	$ 0	[3],[4],[5]			$ 20,000,000	[3],[4],[5]	$ 0	[3],[4],[5]			$ 70,639,000	$ 73,306,000				$ 49,653,000	$ 50,000,000
Long-term debt due within one year	(4,102,000)	(3,013,000)																																																																																																						(4,102,000)		(3,013,000)
Unamortized discount	(277,000)	(301,000)																																																																																																						(277,000)		(301,000)
Total Long-Term Debt	399,414,000	358,491,000																																																																																																						399,414,000		358,491,000
Interest rate				7.70%		7.70%		3.45%	3.45%						5.26%		5.26%		5.25%		5.25%		6.12%		6.12%		7.12%		7.12%		6.247%		6.247%							5.59%		5.59%				3.38%		3.38%				3.09%		0.00%				3.29%		0.00%				5.68%		5.68%		5.19%		5.19%		5.26%		5.26%				5.04%		5.04%		4.74%		4.74%		4.38%		4.38%				4.42%		0.00%				4.47%		0.00%								7.70%		7.70%		3.45%	3.45%						5.26%		5.26%		5.25%		5.25%		6.12%		6.12%		7.12%		7.12%		6.247%		6.247%							5.59%		5.59%				3.38%		3.38%				3.09%		0.00%				3.29%		0.00%				5.68%		5.68%		5.19%		5.19%		5.26%		5.26%				5.04%		5.04%		4.74%		4.74%		4.38%		4.38%				4.42%		0.00%				4.47%		0.00%
Debt covenant, allowable amount available for payment of dividends				305,600,000																																																																																																								305,600,000
Redemption of debt, amount														20,000,000																									20,000,000																																																																															20,000,000																									20,000,000
Debt make-whole premium	6,757,000	0	0											3,200,000																									3,600,000																																																																	6,757,000		0	0											3,200,000																									3,600,000
Debt covenant, ownership interest by outside party resulting in repurchase of notes at par value																																												30.00%						30.00%						30.00%						30.00%														30.00%														30.00%						30.00%						30.00%																																														30.00%						30.00%						30.00%						30.00%														30.00%														30.00%						30.00%						30.00%
Debt to total capitalization ratio																																													0.65						0.65						0.65						0.65														0.65														0.65						0.65						0.65																																														0.65						0.65						0.65						0.65														0.65														0.65						0.65						0.65									0.65		0.65		0.65
Priority debt to assets ratio																																												0.20						0.20						0.20						0.20														0.20														0.20						0.20						0.20																																														0.20						0.20						0.20						0.20														0.20														0.20						0.20						0.20
Debt service coverage ratio																																																																																																																																																																																																																		1.25	1.25	1.25			1.25		1.25		1.25
Long-Term Debt Maturities [Abstract]
Long term debt maturities in 2014	4,102,000																																																																																																							4,102,000	[8]
Long term debt maturities in 2015	4,182,000																																																																																																							4,182,000	[8]
Long term debt maturities in 2016	4,268,000																																																																																																							4,268,000	[8]
Long term debt maturities in 2017	34,358,000																																																																																																							34,358,000	[8]
Long term debt maturities in 2018	24,452,000																																																																																																							24,452,000	[8]
Long term debt maturities in future years	332,431,000																																																																																																							332,431,000	[8]
Total	$ 403,793,000																																																																																																							$ 403,793,000	[8]

[1] MGE's utility plant is subject to the lien of its Indenture of Mortgage and Deed of Trust, under which its first mortgage bonds are issued. The Mortgage Indenture provides that dividends or any other distribution or purchase of shares may not be made if the aggregate amount thereof since December 31, 1945 would exceed the earned surplus (retained earnings) accumulated subsequent to December 31, 1945. As of December 31, 2013, approximately $305.6 million was available for the payment of dividends under this covenant.

[2] The indenture under which MGE's Medium-Term notes are issued provides that those notes will be entitled to be equally and ratably secured in the event that MGE issues any additional first mortgage bonds.

[3] 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. 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 included 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 were used and are expected to continue to be used to help finance the Columbia environmental project.

[4] Unsecured notes issued pursuant to various Note Purchase Agreements with one or more purchasers. The notes are not issued under, or governed by, MGE’s Indenture dated as of September 1, 1998, which governs MGE’s Medium-Term Notes.

[5] Issued by MGE. Under that Note Purchase Agreement: (i) note holders have the right to require MGE to repurchase their notes at par in the event of an acquisition of beneficial ownership of 30% or more of the outstanding voting stock of MGE Energy, (ii) MGE must maintain a ratio of its consolidated indebtedness to consolidated total capitalization not to exceed a maximum of 65%, and (iii) MGE cannot issue "Priority Debt" in an amount exceeding 20% of its consolidated assets. Priority Debt is defined as any indebtedness of MGE secured by liens other than specified liens permitted by the Note Purchase Agreement and certain unsecured indebtedness of certain subsidiaries. As of December 31, 2013, MGE is in compliance with the covenant requirements.

[6] Issued by MGE Power West Campus. The Note Purchase Agreements require it to maintain a projected debt service coverage ratio of not less than 1.25 to 1.00, and debt to total capitalization ratio of not more than .65 to 1.00. The notes are secured by a collateral assignment of lease payments that MGE is making to MGE Power West Campus for use of its ownership interest in the West Campus Cogeneration Facility pursuant to a long-term lease. As of December 31, 2013, MGE Power West Campus is in compliance with the covenant requirements.

[7] Issued by MGE Power Elm Road. The Note Purchase Agreement requires MGE Power Elm Road to maintain a projected and actual debt service coverage ratio at the end of any calendar quarter of not less than 1.25 to 1.00 for the trailing 12-month period. The notes are secured by a collateral assignment of lease payments that MGE is making to MGE Power Elm Road for use of its ownership interest in the Elm Road Units pursuant to long-term leases. As of December 31, 2013, MGE Power Elm Road is in compliance with the covenant requirements.

[8] Includes $29.8 million and $19.9 million for MGE Power West Campus, and $43.5 million and $27.2 million for MGE Power Elm Road, all of which are consolidated with MGE's debt (see Footnote 2 for further information).

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Share-Based Compensation

12 Months Ended

Dec. 31, 2013

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

Share-Based Compensation

Share-Based Compensation - MGE Energy and MGE.

Under MGE Energy's Performance Unit Plan, eligible employees may receive performance units that entitle the holder to receive a cash payment equal to the value of a designated number of shares of MGE Energy's common stock, plus dividend equivalent payments thereon, at the end of the set performance period. In accordance with the plan's provisions, these awards are subject to a prescribed vesting schedule and must be settled in cash. Accordingly, no shares of common stock will be issued in connection with the plan.

On the grant date, MGE Energy and MGE measure the cost of the employee services received in exchange for a performance unit award based on the current market value of MGE Energy common stock. The fair value of the awards is re-measured quarterly, including at December 31, 2013, as required by applicable accounting standards. Changes in fair value as well as the original grant are recognized as compensation cost. Since this amount is re-measured throughout the vesting period, the compensation cost is subject to variability. These units are subject to a five year graded vesting schedule. Units have been adjusted to reflect the three-for-two stock split declared December 20, 2013.

	MGE Energy
Grant Date	Units Granted
January 15, 2010	25,965
January 21, 2011	23,483
February 17, 2012	25,040
February 15, 2013	22,884
February 21, 2014	21,991

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.

During the year ended December 31, 2013, MGE recorded $1.5 million in compensation expense as a result of awards under the Performance Unit Plan. Compensation expense during both theyears endedDecember 31, 2012and 2011was $1.4 million. 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 theyears ended December 31, 2013,2012, and 2011.At December 31, 2013, $4.5 million of outstanding awards are vested, and of this amount no cash settlements have occurred.

In December 2013, aDirector Incentive Planwas approved for the non-employee members of the Board of Directors. This plan is similar to MGE Energy's Performance Unit Plan for eligible employees described above. Under the plan, a non-employee director can receive performance units that entitle the holder to receive a cash payment equal to the value of a designated number of shares of MGE Energy's common stock, plus dividend payments, at the end of the set performance period. The units are subject to a three year graded vesting schedule. In January 2014, unit awards of 4,683 (post-split) were granted to the non-employee Directors. For accounting purposes, the awards will be measured similarly to the employee unit awards.

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Fair Value of Financial Instruments (Details-4) (USD $) In Thousands, unless otherwise specified	12 Months Ended
	Dec. 31, 2013		Dec. 31, 2012		Dec. 31, 2011
Fair Value, Liabilities Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Beginning balance	$ (72,346)		$ (40,661)		$ (19,216)
Realized and unrealized gains (losses):
Included in regulatory liabilities (assets)	7,718		(31,685)		(21,445)
Included in other comprehensive income	0		0		0
Included in earnings	(2,618)		(5,005)		868
Included in current assets	(108)		0		0
Purchases	23,726		13,370		341
Sales	(2)		92		144
Issuances	0		0		0
Settlements	(20,998)		(8,457)		(1,353)
Transfers in and/or out of Level 3	0		0		0
Ending balance	(64,628)		(72,346)		(40,661)
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]
Purchased Power Expense [Member]
Realized and unrealized gains (losses):
Included in earnings	$ (2,618)	[1]	$ (5,005)	[1]	$ 868	[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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Condensed Parent Company Financial Statements

12 Months Ended

Dec. 31, 2013

Condensed Financial Information of Parent Company Only Disclosure [Abstract]

Condensed Parent Company Financial Statements

Schedule I
Condensed Parent Company Financial Statements
MGE Energy, Inc.
Statements of Comprehensive Income
(Parent Company Only)
(In thousands)
		For the years ended December 31,
		2013		2012		2011
Operating Expenses:
Other operations and maintenance	$	613	$	649	$	718
Total Operating Expenses		613		649		718
Operating Loss		(613)		(649)		(718)
Equity in earnings of investments		76,362		65,132		61,075
Other income/(loss), net		(1,863)		(496)		505
Other interest		55		45		(22)
Income before income taxes		73,941		64,032		60,840
Income tax provision		964		414		88
Net Income		74,905		64,446		60,928
Other Comprehensive Income (Loss), Net of Tax:
Unrealized gain (loss) on available-for-sale securities, net of
tax ($189, $12, and $10)		283		(18)		(15)
Reclassification of realized gain on available-for-sale
securities, net of tax ($-, $-, and $10)		0		0		(15)
Comprehensive Income	$	75,188	$	64,428	$	60,898
The accompanying notes are an integral part of the above consolidated financial statements.

MGE Energy, Inc.
Statements of Cash Flows
(Parent Company Only)
(In thousands)
		For the years ended December 31,
		2013		2012		2011
Net Cash Flows Provided by Operating Activities	$	53,952	$	49,819	$	50,696
Investing Activities:
Return of investment - affiliates		0		0		30,000
Other investing		(2,425)		(1,558)		(3,022)
Cash Provided by (Used for) Investing Activities		(2,425)		(1,558)		26,978
Financing Activities:
Cash dividends paid on common stock		(37,107)		(35,951)		(35,026)
Change in short-term debt		0		0		(19,000)
Other financing		(97)		(49)		0
Cash Used for Financing Activities		(37,204)		(36,000)		(54,026)
Change in Cash and Cash Equivalents:		14,323		12,261		23,648
Cash and cash equivalents at beginning of period		36,881		24,620		972
Cash and cash equivalents at end of period	$	51,204	$	36,881	$	24,620
The accompanying notes are an integral part of the above consolidated financial statements.

Schedule I
Condensed Parent Company Financial Statements (continued)
MGE Energy, Inc.
Balance Sheets
(Parent Company Only)
(In thousands)
		At December 31,
ASSETS		2013		2012
Current Assets:
Cash and cash equivalents	$	51,204	$	36,881
Accounts receivable, net:
Accounts receivable from affiliates		125		795
Prepaid taxes and other		1,015		451
Total Current Assets		52,344		38,127
Other deferred assets and other		157		129
Investments:
Investments in affiliates		583,435		556,911
Other investments		948		787
Total Investments		584,383		557,698
Total Assets	$	636,884	$	595,954
LIABILITIES AND SHAREHOLDERS' EQUITY
Current Liabilities:
Accounts payable to affiliates	$	530	$	603
Accrued taxes		4,297		4,164
Other current liabilities		3,076		1,148
Total Current Liabilities		7,903		5,915
Other Credits:
Deferred income taxes		5,646		4,228
Accounts payable to affiliates		5,825		6,382
Total Other Credits		11,471		10,610
Shareholders' Equity:
Common shareholders' equity		350,936		350,936
Retained income		266,197		228,399
Other comprehensive income		377		94
Total Shareholders' Equity		617,510		579,429
Commitments and contingencies (see Footnote 18)		0		0
Total Liabilities and Shareholders' Equity	$	636,884	$	595,954
The accompanying notes are an integral part of the above consolidated financial statements.

Schedule I

Condensed Parent Company Financial Statements (continued)

Notes to Condensed Financial Statements

(Parent Company Only)

1.       Basis of Presentation.

MGE Energy is a holding company and conducts substantially all of its business operations through its subsidiaries. For Parent Company only presentation, investment in subsidiaries are accounted for using the equity method. These condensed Parent Company financial statements and related notes have been prepared in accordance with Rule 12-04, Schedule I of Regulation S-X. These statements should be read in conjunction with the financial statements and the notes in Item 8. Financial Statements and Supplementary Data of the Annual Report on Form 10-K for the year ended December 31, 2013.

2.       Credit Agreements.

As of December 31, 2013, MGE Energy had access to an unsecured, committed credit facility with aggregate bank commitments of $50.0 million. At December 31, 2013, no borrowings were outstanding under this facility.

See Footnote 10 of the Notes to Consolidated Financial Statements for further information regarding MGE Energy's credit agreements.

3.       Commitments and Contingencies.

See Footnote 18 of the Notes to Consolidated Financial Statements for commitments and contingencies.

4.       Dividends from Affiliates.

		Dividends from Affiliates
(In thousands)		2013		2012		2011
MGE	$	25,000	$	20,404	$	26,648
MGE Construct		0		239		0
MGE Power Elm Road		17,300		16,000		43,000
MGE Power		0		200		0
MGE Power West Campus		9,250		7,500		9,500
MGE Transco		816		0		0
Total	$	52,366	$	44,343	$	79,148

Dividend Restrictions

Dividend payments by MGE to MGE Energy are subject to restrictions arising under a PSCW rate order and, to a lesser degree, MGE's first mortgage bonds. The PSCW order restricts any dividends that MGE may pay MGE Energy if its common equity ratio, calculated in the manner used in the rate proceeding, is less than 55%. MGE's thirteen month rolling average common equity ratio at December 31, 2013 is 57.6% as determined under the calculation used in the rate proceeding. MGE paid cash dividends of $25.0million to MGE Energy in 2013.The rate proceeding calculation includes as indebtedness imputed amounts for MGE's outstanding purchase power capacity payments and other PSCW adjustments, but does not include the indebtedness associated with MGE Power Elm Roador MGE Power West Campus, which are consolidated into MGE's financial statements but are not direct obligations of MGE.

MGE has covenanted with the holders of its first mortgage bonds not to declare or pay any dividend or make any other distribution on or purchase any shares of its common stock unless, after giving effect thereto, the aggregate amount of all such dividends and distributions and all amounts applied to such purchases, after December 31, 1945, shall not exceed the earned surplus (retained earnings) accumulated subsequent to December 31, 1945. As of December 31, 2013, approximately $305.6 million was available for the payment of dividends under this covenant.

See Footnotes 9 and 10 of the Notes to Consolidated Financial Statement for long-term debt and lines of credit dividend restrictions.

Stock Split

On December 20, 2013, MGE Energy's Board of Directors declared a three-for-two stock split of MGE Energy's common stock in the form of a stock dividend. The additional shares were distributed February 7, 2014 to all shareholders of record as of January 24, 2014. All share and per share data provided in this report give effect to this stock split.

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Common Equity

12 Months Ended

Dec. 31, 2013

Equity [Abstract]

Common Equity

Common Equity.

a.       Common Stock - MGE Energy and MGE.

On December 20, 2013, MGE Energy's Board of Directors declared a three-for-two stock split of MGE Energy's outstanding shares of common stock, effective in the form of a stock dividend. Shareholders of record at the close of business on January 24, 2014 received one additional share of MGE Energy common stock for every two shares of common stock owned on that date. The additional shares were distributed on February 7, 2014. Shareholders received cash in lieu of any fractional shares of common stock they otherwise would have received in connection with the dividend. All share and per share data provided in this report give effect to this stock split.

MGE Energy sells shares of its common stock through its Stock Plan. Those shares may be newly issued shares or shares that MGE Energy has purchased in the open market for resale to participants in the Stock Plan. All sales under the stock plan are covered by a shelf registration statement that MGE Energy filed with the SEC. For the years ended December 31, 2013 and 2012, MGE Energy did not issue any new shares of common stock under the Stock Plan.

MGE Energy purchases shares on the open market 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 specific maximum number of shares to be repurchased and no specified termination date for the repurchases.

During the years ended December 31, 2013and 2012, MGE Energy paid $37.1 million (or $1.07 per share) and $36.0 million (or $1.04 per share), respectively, in cash dividends on its common stock. Dividends on common stock at MGE are subject to restrictions imposed by the PSCW and the covenants of MGE's outstanding first mortgage bonds. See Footnote 9 for further discussion of these covenants. During the years ended December 31, 2013 and 2012, MGE paid $25.0 million and $20.4 million, respectively, in cash dividends to MGE Energy.

b.       Preferred Stock - MGE Energy and MGE.

MGE had1,175,000 shares of $25 par value cumulative preferred stock authorized but unissued at December 31,2011. In October 2012, MGE amended and restated its existing Restated Articles of Incorporation, which eliminated the previously authorized cumulative preferred stock. There were no shares of cumulative preferred stock authorized, issued, or outstanding at December 31,2013 and 2012.

c.       Dilutive Shares Calculation - MGE Energy.

MGE Energy does not hold any dilutive securities.

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Schedule I - Condensed Parent Company Finanical Statements (Details-Comprehensive Income Statement Parentheticals) (USD $) In Thousands, unless otherwise specified	12 Months Ended
	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Condensed Income Statements, Captions [Line Items]
Unrealized gain (loss) on available-for-sale securities, taxes	$ 189	$ (12)	$ (10)
Reclassification of realized gain on available-for-sale securities, taxes	0	0	(10)
MGE Energy [Member]
Condensed Income Statements, Captions [Line Items]
Unrealized gain (loss) on available-for-sale securities, taxes	189	(12)	(10)
Reclassification of realized gain on available-for-sale securities, taxes	$ 0	$ 0	$ (10)