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

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

Indicate by checkmark 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. YesX No

Indicate by checkmark 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 checkmark whether the registrant is anregistrants are accelerated filerfilers (as defined in Rule 12b-2 of the Act).

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

The aggregate market value of the voting and nonvoting common equity held by nonaffiliates of MGE Energy, Inc.each registrant as of June 30, 2002 (based upon the average of the bid and asked prices of common stock of Madison Gas and Electric Company, which2003, was MGE Energy's predecessor): $478,331,322as follows:

The number of shares outstanding of each registrant's common stock as of March 1, 2003.2004, was as follows:

Portions of MGE Energy, Inc.'s definitive Proxy Statementproxy statement to be filed prior to April 30, 2003,29, 2004, 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)(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) certain(ii.) the information otherwise required by Item 6 of Form 10-K relating to Selected Financial Data, (iii) certain(iii.) the information otherwise required by Item 10 of Form 10-K relating to Directors and Executive Officers as permitted by General Instruction (I)(2)(c), and (iv) certain(iv.) the information otherwise required by Item 11 of Form 10-K relating to executive compensation as permitted by General Instruction (I)(2)(c).

This combined Form 10-K is separately filed, (v.) the information otherwise required by MGE Energy, Inc. and Madison Gas and Electric Company. Information contained hereinItem 12 relating to any individual registrant is filedSecurity Ownership of Certain Beneficial Owners and Management, and (vi.) the information otherwise required by such registrant in its own behalf. Neither registrant makes any representation asItem 13 to information relating to the other registrant.Certain Relationships and Related Transactions.

Filing Format

Forward-Looking Statements

Where to Find More Information

Definitions

PART I.

Item 1. Business.

Item 2. Properties.

Item 3. Legal Proceedings.

Item 4. Submission of Matters to a Vote of Security Holders.

PART II.

Item 5. Market for Registrant's Common Equity and Related ShareholderStockholder Matters.

Item 6. Selected Financial DataData.

Item 7. Management's Discussion and Analysis of Financial Condition and
Results of Operations.

Item 7A. Quantitative and Qualitative Disclosures about Market Risk.

Item 8. Financial Statements and Supplementary Data.

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

Item 9A. Controls and Procedures.

PART III.

Item 10. Directors and Executive Officers of the Registrants.

Item 11. Executive Compensation.

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

Item 13. Certain Relationships and Related Transactions.

Item 14. ControlsPrincipal Accountant Fees and Procedures.Services.

PART IV.

Item 15. Exhibits, Financial Statement Schedules, and Reports on Form 8-K.

Signatures - MGE Energy, Inc.

Signatures - Madison Gas and Electric Company

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

Item 1. Business.

This combined Form 10-K is being filed separately by MGE Energy, Inc. (MGE Energy), through its principal subsidiary and Madison Gas and Electric Company (MGE). MGE is a wholly owned subsidiary of MGE Energy and represents a substantial portion 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 nonutility business, does not relate to, and is not filed by, MGE. MGE makes no representation as to that information.

Forward-Looking Statements

This report, and other documents filed by MGE Energy and MGE with the Securities and Exchange Commission (SEC) from time to time, contain forward-looking statements that reflect management's current assumptions and estimates regarding future performance and economic conditions--especially as they relate to future load growth, revenues, expenses, capital expenditures, financial resources, regulatory matters, and the scope and expense associated with future environmental regulation. These forward-looking statements are made pursuant to the provisions of the Private Securities Litigation Reform Act of 1995. 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. Some of those risks and uncertainties include:

- Weather, which enters into the calculation of MGE's rates for service and which affects the demand for electricity and gas and the projected and actual need for electric generation capacity to serve customers.

- Economic and market conditions in MGE's service territory, which affect demand for electricity and gas and, consequently, our revenues and expenses as well as capital investment requirements to extend, improve, or reinforce the existing electricity and gas distribution systems.

- Magnitude and timing of capital expenditures, which affect capital needs, financing costs, and operating expenses.

- Regulatory environment in which we operate, which can affect the way in which we do business as well as the accounting treatment of expenses that we incur and our ability to continue carrying specified assets and liabilities on our books.

- Environmental regulation, which can affect the way in which we operate, our operating expenses, and our capital expenditures.

- Availability and cost of power supplies, which affect operating expenses and capital expenditure decisions with respect to sources of new generation.

- Completion of the West Campus Cogeneration Facility at the University of Wisconsin-Madison, which provides MGE Energy with an opportunity if construction is completed on or ahead of schedule, but exposes it to liquidated damages if construction is delayed or the facility fails to operate according to specifications.

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 publicly release any revision to these forward-looking statements to reflect events or circumstances after the date of this report.

Where to Find More Information

The public may read and copy any reports or other information that MGE Energy and MGE file with the SEC at the SEC's public reference room at 450 Fifth Street, NW, 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 are also available to the public from commercial document retrieval services, the Web site maintained by the SEC athttp://www.sec.gov, MGE Energy's Web site athttp://www.mgeenergy.com, and MGE's Web site athttp://www.mge.com. Copies may be obtained from our Web sites free of charge.

Definitions

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

PART I.

Item 1. Business.

MGE Energy operates in twothree business segments:

- Electric utility operations--generating and distributing electricity.
electricity through MGE.

- Gas utility operations--purchasing and distributing natural gas.gas through MGE.

- Nonutility energy operations--constructing and owning new electric generating capacity through its wholly owned subsidiaries MGE Construct, MGE Power, and MGE Power West Campus.

MGE Energy became the holding company for MGE on August 12, 2002, when shareholders exchanged each sharetheir shares of MGE common stock for one shareshares of MGE Energy common stock. The share exchange had no accounting effect on MGE's recorded assets, liabilities, revenues, or expenses.

MGE's utility operations represent substantially alla substantial portion of the assets, liabilities, revenues, expenses, and expensesoperations of MGE Energy. MGE Energy's nonutility energy operations relating, principally,currently relate to the development of a cogeneration project on the Madison campus of the University of Wisconsin (UW), are not significant at this time. Consequently, the following discussion focuses on the results of operations and financial condition of MGE.UW-Madison campus.

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 53703.

MGE Energy and MGE maintain a Web site at the address specified on the cover of this report where copies of its annual reports on Form 10-K, quarterly reports on Form 10-Q, current reports on Form 8-K, and any amendments thereto may be obtained free of charge. This address is inactive textural and the content of this Web site is not part of this Form 10-K.

MGE

As a public utility, MGE is subject to regulation by the Public Service Commission of Wisconsin (PSCW)PSCW and the Federal Energy Regulatory Commission (FERC).FERC. The PSCW has authority to regulate most aspects of MGE's business including rates, accounts, issuance of securities, and plant and transmission line siting. FERC has jurisdiction, under the Federal Power Act, over certain accounting practices and certain other aspects of MGE's business.

MGE is also subject to regulation under local, state, and federal laws regarding air and water quality and solid waste disposal. See Environmental section"Environmental" below.

MGE's business is seasonalfluctuates based on fluctuationschanges in weather conditions.conditions, with gas revenues generally higher during the winter months due to heating needs and electricity revenues generally higher in the summer months due to cooling needs.

Electric OperationUtility Operations

MGE generates and distributes electricity in a service area covering the 250-square-mile area of Dane County, Wisconsin. Its service area includes the city of Madison, Wisconsin.

At December 31, 2002,2003, MGE supplied electric service to nearly 130,000132,000 customers, of whom 115,000117,000 were located in the cities of Fitchburg, Madison, Middleton, and Monona and 15,000 in adjacent areas. Of the total number of customers, approximately 113,000114,500 were residential and 17,00017,500 were commercial and industrial. Electric revenues for 2003 were comprised of residential (35%), commercial (49%), industrial (6%), sales to public authorities including the UW (8%), and sales to other utilities and other (2%). Electric revenues for 2002 were comprised of residential (36%), commercial (48%), industrial (6%), sales to public authorities including the UW (7%), and sales to other utilities and other (3%). Electric operations accounted for approximately 60%, 65%, and 61% of MGE's total 2003, 2002, revenues.and 2001 revenues, respectively.

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

MGE is a member of Mid-America Interconnected Network, Inc. (MAIN),MAIN, a regional reliability group. MAIN members work together to utilize better reserve generating capacity and coordinate long-range system planning and day-to-day operations. MAIN seeks to maintain adequate planning reserve margins for generation in the region.

MGE is part owner of the American Transmission Company LLC (ATC),ATC, a for-profit transmission company resulting from Reliability 2000 legislation (Part of 1999 Wisconsin Act 9).enacted in Wisconsin. Part of Reliability 2000 createdthat legislation mandated the creation of a statewide transmission company to own the investor-owned utilities' transmission assets. TheATC's purpose of ATC 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.

Effective January 1, 2001, MGE transferred all of its electric utility transmission assets to ATC in exchange for an ownership interest. ATC is owned and governed by the utilities that contributed facilities or capital in accordance with Wisconsin Act 9. At December 31, 2003, MGE has approximately a 5% ownership interest in ATC. ATC is regulated by FERC for all rate terms and conditions of service and is a transmission-owning member of the Midwest ISO. MGE is a nontransmission-owning member of the Midwest ISO.

On February 1, 2002, MGE started taking network transmission service from the Midwest Independent Transmission System Operator, Inc. (Midwest ISO).ISO. Midwest ISO is a nonprofit Regional Transmission OrganizationRTO approved by the FERC. The Midwest ISO is responsible for monitoring the electric transmission system that delivers power from generating plants to wholesale power transmitters. The Midwest ISO'sIts role is to ensure equal access to the transmission system and to maintain or improve electric system reliability in the Midwest.

In connection with its role as a FERC-approved RTO, the Midwest ISO is in the process of developing a bid-based energy market, which is currently proposed to be implemented on December 1, 2004. In connection with the development of this energy market, the Midwest ISO is developing a market-based platform for valuing transmission congestion premised upon the LMP system that has been implemented in certain states. It is expected that the LMP system will include the ability to mitigate or eliminate congestion costs through the use of FTRs. The Midwest ISO will initially allocate FTRs, and it is anticipated that the FTRs will be available through an auction-based system run by the Midwest ISO. It is unknown at this time the quantity of FTRs that will be allocated by the Midwest ISO or what the financial impact of the LMP congestion pricing system might have on MGE.

Fuel Supplysupply and Generationgeneration

MGE estimates itsMGE's net kilowatt-hourkWh requirements for 2003 will bewere provided from the following sources: 64%61% from fossil-fueled steam plants, 33%38% from power purchases, and 3%1% from a combination of wind turbines, diesel generators, and combustion turbines. Actual sourcesSources used will dependdepended on generating unit availability, weather, and customer demand.

MGE has a 22% ownership interest in two 512-megawatt (MW)512-MW coal-burning units at the Columbia Energy Center (Columbia).Columbia. The coal inventory supply for the units decreased from 49 days on December 31, 2001, to 46 days on December 31, 2002.2002, to 45 days on December 31, 2003. The co-owners' current goal is to maintain approximately a 40-day35-day inventory. The units burn low-sulfur coal obtained (pursuant to long-term contracts) from the Powder River Basin coal fields located in Wyoming and Montana.

For information about a request from the U.S. Environmental Protection Agency (EPA) that affects Columbia, refer to the section on Air Quality under Environmental below.

Gas Utility Operations

MGE transports and distributes natural gas in a service area covering 1,375 square miles in seven south-central Wisconsin counties. Its service area includes the city of Madison, Wisconsin.

On December 31, 2002,2003, MGE supplied natural gas service to more than 126,000129,000 customers in the cities of Elroy, Fitchburg, Lodi, Madison, Middleton, Monona, Prairie du Chien, Verona, and Viroqua; 24 villages; and all or parts of 4546 townships. Gas revenues for 2003 were comprised of residential (58%), commercial (37%), industrial (2%), and transportation service and other (3%). Gas revenues for 2002 were comprised of residential (58%), commercial (37%), industrial (1%), and transportation service and other (1%(4%). Transportation service accounted for almost 3% of the total 2002 gas revenues. Gas operations accounted for approximately 40%, 35%, and 39% of MGE's total revenues.2003, 2002, and 2001 revenues, respectively.

MGE can curtail gas deliveries to its interruptible customers. Approximately 4% of gas sold in 20022003 was to interruptible customers.

Gas Supplysupply

MGE has physical interconnections with ANR Pipeline Company (ANR) and Northern Natural Gas Company (NNG).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 4,946,342 dekatherms4,946,852 Dth can be injected into ANR's storage fields from April 1 through October 31. These gas supplies are then available for withdrawal during the subsequent heating season, November 1 through March 31. ANR's storage fields are located in Michigan. 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. Storage quantities were close to planned levels on December 31, 2003.

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.

The prior heating season (November 2001 through March 2002) was warmer than normal (16% fewer heating degree days). The current heating season (November 2002 through March 2003) has been 2% warmer than normal (based on actual heating degree days through January) and storage quantities are at a normal level. A heating degree day is the number of degrees that the mean daily temperature is below 65 degrees Fahrenheit.

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

- 141,650 dekatherms143,650 Dth (including 86,078 dekathermsDth of storage withdrawals) on ANR.
- 54,719 dekatherms56,151 Dth on NNG.
- 2,457 dekathermsDth into Viroqua's NNG gate station.
- 1,432 dekatherms into Crawford County's NNG gate station.

Winter maximum daily quantities under these contracts are scheduled to increase an additional 15,000 Dth by November 2005.

Nonutility Energy Operations

MGE Energy, through subsidiaries, is seeking to develop generation sources that will assist MGE in meeting the electricity needs of its customers. It is currently engaged in the construction of a cogeneration facility on the UW-Madison campus and, with MGE, is examining other potential sources of electricity including new coal-fired plants through an initiative known as Power the Future as well as renewable forms of energy.

Decisions on the type of energy source and its size, timing, ownership, and financing depend upon a number of factors including the growth of customer demand in MGE's service area and surrounding areas, the effectiveness of customer demand management efforts, the costs and availability of alternative power sources, the availability of transmission capacity, issues associated with siting power generation sources, available financing and ownership structures, regulatory treatment and recovery, construction lead times and risks, and other factors. The decisions tend to involve long time horizons due to the lead time involved in siting and constructing new generation sources and the associated transmission infrastructure.

Power the Future Generation

On February 23, 2001, MGE secured an option to own a portion of the advanced technology, coal-fired, base-load generation proposed in We Energies' Power the Future plan. The plan included three new 600-MW coal-fired plants, which would be located in Wisconsin. On November 11, 2003, a PSCW order approved issuing a CPCN for We Energies' proposal for two of the coal facilities. Pursuant to an amended agreement reached on January 31, 2003, MGE has the option to acquire an undivided 8.33% (16.66% under certain conditions) ownership interest in each of the proposed coal plants or up to approximately 50 MW per unit. If the options on Units 1 and 2 are fully exercised, MGE Energy's share of capital costs is estimated to be $175 million. Unit 1 is expected to begin operating in 2009, and Unit 2 is scheduled to begin operating in 2010. MGE has filed its own Certificate of Authority with the PSCW for the coal facilities and a proposed lease structure with an MGE Energy affiliate. MGE expects PSCW approval on this filing in the first half of 2004.

WCCF

MGE Energy has undertaken, through MGE Construct, the construction of a chilled-water, steam, and electric generation facility on the UW-Madison campus. When completed in the spring of 2005, the facility will have the capacity to produce 20,000 tons of chilled water, 500,000 pounds per hour of steam, and approximately 150 MW of electricity. It will be jointly owned by the State, the UW, and MGE Power West Campus. MGE Power West Campus' share will be leased and the entire facility will be operated by MGE. The State and the UW will own a controlling interest in the chilled-water and steam plants in accordance with the EPC Agreement, which will be used to meet the UW's growing need for air-conditioning and steam-heat capacity. MGE Power West Campus will own a controlling interest in the electric generation plant, which will provide electricity for MGE's customers.

MGE Energy, MGE Power West Campus, and MGE Construct have assumed certain risks related to some of the executed agreements. In the EPC Agreement, MGE Power West Campus is responsible for cost overruns and MGE Construct is responsible for the construction process of the entire facility, paying liquidated damages relating to failure to achieve the Mechanical Completion Date Guarantee and/or the Acceptance Test Capacity Guarantee. MGE Energy is the guarantor of MGE Construct's obligations under the EPC Agreement.

The cost to construct WCCF is expected to be approximately $180 million in total, of which MGE Power West Campus' portion will be $103 million. On November 20, 2003, the State paid $19.4 million to MGE Construct for its share of construction costs incurred since its last payment in November 2002. MGE Construct now bills the State monthly for its share of the cost of WCCF in accordance with the EPC Agreement. As of December 31, 2003, MGE Power West Campus had incurred $48.6 million of costs on the project, which is reflected in construction work in progress on MGE Energy's and MGE's consolidated balance sheets. These costs largely represent amounts paid under long lead-time equipment contracts in order to meet project schedules.

Environmental

MGE is subject to local, state, and federal regulations concerning air quality, water quality, and solid waste disposal. Those regulations affect the manner in which MGE conducts its operations, the costs of those operations, as well as some capital and operating expenditures. It can also affect the siting, timing, and cost of new projects or other significant actions affecting the environment. MGE believes that it has met the requirements of current environmental regulations. MGE is not able to predict the direction of future regulations or if compliance with future pollution controlany such regulations will involve additional expenditures for pollution control equipment, or plant modifications, operations curtailments, reductions inor curtailment of operations. Such actions could reduce capacity or efficiency at existing plants or delays indelay the construction and operation of future generating facilities.

The Wisconsin Department of Natural Resources (DNR) regulatesEPA and DNR regulate pollution and environmental control matters at MGE's electric generating plants. The DNR has primary jurisdiction over air and water quality as well as solid and hazardous waste standards.

The ongoing issue of global warming could result in significant costs to reduce carbon dioxide CO₂emissions. MGE does not yet know the amounts of these expenditures or the period of time over which they may be required.

The National Environmental Policy Act and the Wisconsin Environmental Policy Act require MGE to conduct a complete environmental review and issue a detailed environmental impact statement before obtaining necessary authorizations or permits from regulatory agencies for certain projects. This applies to any new projects, such as generating plants, or other major actions that could significantly affect the environment.

Air Qualityquality

Proposed eight-hour ozone standard.In the summer of 1997, the EPA finalizedpromulgated a new stricter federaleight-hour ozone ambient air-quality standard. EPA has recommended that Dane County be designated as in attainment with that eight-hour ozone standard based upon a review of preliminary monitoring data for the county. The final nonattainment designations will not be made by the EPA until later in 2004 and will be based upon final monitoring data for 2001 through 2003. That data currently shows Dane County air quality standardsto be in attainment with the eight-hour ozone standard.

Dane County ozone levels have been increasing over time. MGE is working with the DNR and other Dane County sources to make voluntary reductions of ozone precursor emissions and prevent the county from being classified as a nonattainment area. If Dane County were classified as a nonattainment area, MGE facilities in Dane County may need to meet new limits for ozone precursor emissions.

Proposed utility MACT standards. Section 112 of the 1990 Clean Air Act Amendments requires the EPA to develop standards to control major sources of hazardous air pollutants to levels consistent with the lowest-emitting facilities in similar source categories. MGE operates several sources that may be subject to MACT standards including electric steam generating units; combustion turbines; reciprocating internal combustion engines; and fine particulate matter. Under the new standards, EPA anticipates designating new nonattainment areas by late 2003 or early 2004. Southeastern Wisconsin isindustrial, commercial, and institutional boilers. All sources, except Blount and Columbia coal-fired units, are expected to be classified as nonattainment. There is a possibility that Dane County, the location of the Blount Generating Station (Blount), will also be classified as nonattainment.

The DNR is required to develop a State Implementation Plan by 2007 to demonstrate how the state will attain and maintain compliance with the new ozone and fine particulate matter standards. The DNR is considering a plan that would require NO_x and fine particulate limits for sources throughout the state rather than focusing reductions on just those sources located in the nonattainment areas. If this approach is taken, MGE may need to evaluate emission control options for its facilities in order to comply. The EPA has set 2010 as the deadline for states to meet the new standards. However, emission control requirements could be imposed in Wisconsin as early as the spring of 2006.

On October 27, 1998, the EPA issued final rules requiring more NO_x emission reductionsexempt from sources in 22 states and the District of Columbia, including Wisconsin, to reduce the transport of ozone across state boundaries. However, a successful legal challenge resulted in excluding Wisconsin from part of this rule. After further modeling and research, theimplementing additional emission-control strategies. The EPA is expected to revise or amend these rules to impose additional NO_x emission reduction requirements on Wisconsin sourcesfinalize standards for electric-steam generating units in order to help other states meet ambient ozone standards.

2004. It is expected that MGE is evaluating NO_x compliance strategies, including fuel switching, emissions trading, purchased power agreements, new emission control devices, and/or installation of new fuel-burning and clean-coal technologies. Implementing any of these new measures would likely increase capital, operating, and maintenance expenditures.

Wisconsin's acid rain law imposes limitations on SO₂ emissions. Blount and MGE's share of Columbia arewill be required to meet a combined SO₂ emission rate of 1.20 pounds of SO₂ per million Btu. MGE does not anticipate any capital expenditure in order to comply with this standard.

The DNR continues to develop rules to limitnew mercury emissions from coal-fired boilers. The proposed rules require sources emitting mercury to reduce emissions over 15 years. It also currently sets a ceilinglimits by the current proposal date of 10 pounds of mercury per year for smaller sources. Depending onDecember 2007. Complying with the outcome of these regulations, they may require MGE to evaluate emission control options for its facilities in order to comply. These controlsMACT standards would likely increase capital expenditures and operating and maintenance expenses.

On January 1, 2000, Phase II of the 1990 Federal Clean Air Act amendments took effect, setting new emission limits for sulfur dioxide (SO₂) and nitrogen oxide (NO_x). MGE's generating units meet those limits. The units were modified well in advance to meet year 2000 NO_x requirements. Early modifications at Blount allow MGE to postpone meeting more stringent Phase II NO_x requirements at this plant until 2007.

In December 2000, February 2001, June 2002, and January 2003, Columbia received Requests for Information from the EPA to evaluate compliance with the Clean Air Act. Alliant Energy Corp. (Alliant), the plant operator, has responded to all requests and has not yet received a response from the EPA. On a broader basis, the EPA is assessing the regulatory consequences of investments in utility generation, energy efficiency, maintenance, and environmental protection. EPA is also assessing proposed multi-pollutant legislation. The EPA will be recommending clarification and revisions to the process in the future. The plant operator has not informed MGE of any likely increase in capital expenditures or operating and maintenance expenses arising from the EPA's inquiry.

In December 2002, the EPA issued proposed rules that will impose maximum achievable control technology limits for hazardous air-pollutant emissions for industrial boilers, combustion turbines, and stationary diesel generators. The EPA plans to have the final regulations published by 2004, and compliance deadlines are expected in 2007. The proposed rule for industrial boilers sets limits for particulate matter, hydrogen chloride, and mercury. The proposed rule for combustion turbines and stationary diesel generators sets limits for formaldehyde and carbon monoxide. Based on an initial review of the proposed rules, it is likely that emission control options will need to be evaluated for Blount and Columbia coal-fired boilers, such as scrubbers and/or baghouses. Control requirements for other generation facilities is less likely. Since Because the rules are still in the process of being developed and in the public comment stage, it is not possible to determine exactly what impact this compliance would have for MGE's generation facilities.

NO_x SIP Call. On October 27, 1998, the EPA issued the "NO_x SIP Call" rule that imposed a NO_x emission budget for emission sources in Wisconsin. The NO_x SIP Call was premised upon two theories: the downwind contribution of Wisconsin air emissions to existing one-hour ozone nonattainment areas and the downwind contribution of Wisconsin air emissions to potential future eight-hour nonattainment areas.

On March 2, 2000, the Court of Appeals for the District of Columbia held that the EPA "acted unlawfully by including Wisconsin in the [NO_x] SIP Call" for purposes of the State's alleged impacts to downwind one-hour ozone nonattainment areas. However, the Court and EPA stayed that portion of the challenge concerning Wisconsin's alleged impacts on downwind, eight-hour ozone nonattainment areas. If that stay is lifted and that portion of the NO_x SIP Call concerning eight-hour ozone nonattainment areas is upheld, the resulting NO_x emission budget for Wisconsin could potentially affect the level of permissible NO_x emissions from Blount, Columbia, and WCCF. The new NO_x limits could increase capital expenditures and operating and maintenance expenses at those facilities.

Interstate Air Quality Rule. This proposed rule was introduced in December 2003 and would reduce emissions of SO₂ and NO_x in 29 eastern states and the District of Columbia in two phases. SO₂ emissions would be reduced by 3.6 million tons in 2010 (approximately 40% below current levels) and by another 2 million tons per year when the rules are fully implemented (approximately 70% below current levels). Emissions of NO_x would be cut by 1.5 million tons in 2010 (approximately 55% below current levels) and 1.8 million tons annually in 2015 (approximately 65% below current levels). The EPA is expected to finalize the rule by the end of 2005. It is expected that MGE will be required to comply with NO_x and particulate limits by 2010. Complying with the rule would likely increase capital expenditures and operating and maintenance expenses at Blount and Columbia.

Columbia. In December 2000, February 2001, June 2002, and January 2003, Alliant received Requests for Information from the EPA seeking information concerning Columbia's compliance with the Clean Air Act. The requests appear to be part of an EPA initiative to assess the regulatory consequences of past investments in utility generation, energy efficiency, maintenance, and environmental protection within the utility sector. Alliant, the plant operator, has responded to all requests, but MGE has not been informed of any response from the EPA. The plant operator has not informed MGE of any definitive increase in capital expenditures or operating and maintenance expenses arising from the EPA's inquiry.

Water Qualityquality

MGE is subject to water quality regulations issued by the DNR. These regulations include categorical-effluent discharge standards and general water quality standards. The regulations limit discharges from MGE's plants into Lake Monona and other Wisconsin waters.

The categorical-effluent discharge standards require each discharger to use effluent-treatment processes equivalent to categorical "best practicable" or "best available" technologies under compliance schedules established under the Federal Water Pollution Control Act. The DNR has published categorical regulations for chemical and thermal discharges from electric-steam generating plants.

In February 2003, Columbia received a Notice of Violation from the DNR for exceeding limits in its Wisconsin Pollutant Discharge Elimination System permit. That matter has been referred to the Wisconsin Department of Justice for prosecution. In addition, the plant operator has been named in a Clean Water Act citizen suit action alleging similar violations. The Columbia plant operator has been working with the DNR to resolve the issues set forthallegations raised in the notice. Resolution of thosethese proceedings. Resolving these issues may require additional capital expenditures to install and implement new treatment techniques. While it is possible that the DNRa court may also seek to impose a civil penalty in these proceedings, the operator believes it can resolve these issues to the DNR's satisfaction in a manner that will not have a material adverse effect on their companies'the operator's financial conditions or results of operations. See Item 3, Legal Proceedings, regarding an action filed by Wisconsin Environmental Law Advocates U.A.

On April 9, 2002, theFebruary 16, 2004, EPA issuedsigned a proposed rule under the National Pollution Discharge Elimination System (NPDES, 40 CFR Parts 9, 122, 123, 124, and 125) that establishes requirementsestablishing performance standards for aquatic life entrapment and impingement in existing cooling water intake structures (also referredat large power plants. The rule applies to as the 316(b) rule). If the proposedstructures that withdraw at least 50 million gallons per day of water and use 25% of that withdrawal for cooling. The rule is finalized as written, capital improvementswill have no impact on MGE's wholly owned power plants but may be required. The final version of the rule is not expected for several years.impact power plants in which MGE has a partial interest.

Solid Wastewaste

MGE is listed as a potentially responsible party for a site the EPA has placed on the national priorities Superfund list. The Lenz Oil site in Lemont, Illinois, was used for storing and processing waste oil for several years. This site requires clean up under the Comprehensive Environmental Response, Compensation and Liability Act. A group of companies, including MGE, is currently working on cleaning up the site.

Management believes that its share of the final cleanup costs will not result in any materially adverse effects on MGE's operations, cash flows, or financial position. Insurance may cover a portion of the cleanup costs. Management believes that the cleanup costs not covered by insurance will be recovered in current and future rates. MGE estimates its future expense to clean up this site could range from $0.1 million to $0.2 million. At December 31, 2002,2003, MGE accrued a $0.1 million liability for these matters.this matter.

As a result of the Blount 69-kV transmission substation expansion, coal tar-contaminated soil and debris within the excavation zone are being removed and disposed of in accordance with a DNR-approved "Removal Action Work Plan." MGE estimates cleanup costs for this site will be $1.0 million. MGE has recorded a $1.0 million liability for the cleanup of this site with an offsetting regulatory asset (deferred charge). We expect to recover cleanup costs in future rates. Carrying costs associated with the cleanup expenditures will not be recoverable.

MiscellaneousEnvironmental Cooperative Agreement

On September 26, 2002, MGE and the DNR signed an Environmental Cooperative Agreement under which MGE committed to work toward superior environmental performance at its Blount plant. Among other things, the five-year agreement requires MGE to evaluate combustion efficiency improvements, enhance new pollution control on Boiler 8, increase use of alternative fuels, attempt to increase beneficial reuse of fly ash and bottom ash, study cogeneration possibilities, and upgrade MGE's environmental management system to be consistent with ISO 14001 standards. Implementing these and other actions required by the agreement will increase capital expenditures and operating and maintenance expenses over the next five years.

As part of the agreement, MGE conducted a voluntary audit of Blount's compliance with various environmental laws. The auditors identified several conformance exceptions which were addressed and disclosed pursuant to a state statute that provides for qualified civil enforcement immunity. MGE believes that it has adequately responded to the audit's findings and does not anticipate any further action by the state regulators.

Employees

As of December 31, 2002,2003, MGE had 683691 full-time employees. Of these employees, 242251 are covered by a collective bargaining agreement with Local Union 2304 of the International Brotherhood of Electrical Workers and 112107 are covered by a collective bargaining agreement with Local Union No. 39 of the Office and Professional Employees International Union. Both collective bargaining agreements expire on May 1, 2003.2006.

Executive Officers of the Registrants

Item 2. Properties.

MGE's net generating capability in service at December 31, 2002,2003, was as follows:

MGE sold its 17.8% ownership interest in Kewaunee Nuclear Power Plant (Kewaunee) to WPSC in 2001. Footnote 1018 of the Notes to Consolidated Financial Statements in this report includes information regarding that sale along with a description of MGE's continuing obligations for Kewaunee beyond the closing date and MGE's decision to exercisedate. MGE exercised an option to buy electric capacity and energy from WPSC for two years starting in 2001.through September 23, 2003.

Major electric distribution lines and substations in service at December 31, 2002,2003, are as follows:

On January 1, 2001,As required by Wisconsin law, MGE and other Wisconsin electric utilities transferred itstheir electric transmission assets to ATC. InATC on January 1, 2001. MGE received an approximate 5% ownership interest in ATC in exchange for its transmission plant and related deferred taxes and deferred investment tax credits,credits. MGE received approximately a 6% ownership interest in ATC. MGE expects to receivereceives a return on its investment in ATC that is approximately equal to the return it would have earned by retaining its transmission facilities. A small portion of the 69-kilovolt (kV)69-kV lines and substations has been classified as distribution assets.

Gas facilities include 2,1732,234 miles of distribution mains.

Item 3. Legal Proceedings.

MGE Energy

None.On November 6, 2003, Friends of Responsible Energy (FORE), an unincorporated citizen association, filed a petition with the Dane County, Wisconsin, Circuit Court seeking judicial review of various decisions made by the PSCW, the Wisconsin Department of Natural Resources, the UW, and the Wisconsin Department of Administration in connection with the WCCF. Those decisions include the grant of a CPCN by the PSCW and various environmental determinations made by the governmental parties. FORE alleges that those decisions were arbitrary, capricious, and contrary to law and seeks to have them set aside or remanded for further review.

MGE Energy, along with MGE and MGE Power West Campus, have intervened as a party to the proceeding. MGE Energy believes the suit is not likely to cause any material adverse change in the WCCF or its construction schedule.

MGE

In May 1999, MGE broughtBy letter dated October 23, 2003, the Wisconsin Environmental Law Advocates U.A. (WELA), an arbitration proceeding againstunincorporated, not-for-profit association, sent a Notice of Violation and Intent to File Suit under the Clean Water Act regarding alleged violations at Columbia to Alliant and to Wisconsin Power and Light Company (WPL), a subsidiary of Alliant, as well as to Columbia's joint owners and their parent companies. The notice is required by the Clean Water Act as a condition precedent to filing a lawsuit based on the alleged environmental law violations. The notice alleges numerous violations of the Clean Water Act and of Columbia's wastewater discharge permit. On December 16, 2003, WPL and Alliant responded to WELA that the parent companymajority of WPL. The arbitration was basedthe allegations are inaccurate and of those that are accurate, the Wisconsin DNR had already begun enforcement and many of the violations have been corrected and have ceased. This notwithstanding, on December 29, 2003, WELA filed a claim regarding WPL's merger into Alliant, the improper transfer of WPL's interest in Columbia to Alliant, and the manner in which it was running Columbia that triggered MGE's right to acquire WPL's interestcomplaint in the plant at book value.U.S. District Court, Western District of Wisconsin, against WPL and Alliant.

In March 2001, MGE received an arbitration decisiondoes not operate Columbia and was not named as a party in the dispute. Whilelitigation. WELA communicated to WPL and Alliant that it filed the arbitrators didaction in order to formally assert its claims in order to ensure WELA's participation in any enforcement resolution expected to be sought by the Wisconsin DNR. Although the complaint was filed, WELA indicated that it would not grantserve it on WPL and Alliant while good faith settlement negotiations were ongoing or unless otherwise directed by the specific relief MGE sought in the arbitration (the right to purchase WPL's interest in the plant), the arbitrators recognized onedistrict court.

Also see "Environmental" under Item 1, Business, for a description of MGE's primary arguments. MGE argued that WPL had transferred its interest in the Columbia plant to its parent company, Alliant, after the merger in 1998. The arbitrators required Alliant to fully assume the obligations of WPL as the operator and manager of the plant. The Dane County Circuit Court confirmed the arbitration award in late November 2001. In June 2002, an order enforcing the Circuit Court's judgment was entered and subsequently Alliant passed a resolution pursuant to the arbitration decision.several environmental proceedings involving MGE.

Item 4. Submission of Matters to a Vote of Security Holders.

MGE Energy and MGE

None.

PART II.

Item 5. Market for Registrant's Common Equity and Related ShareholderStockholder Matters.

MGE Energy

MGE Energy common stock is traded on The Nasdaq Stock Market (Nasdaq) under the symbol MGEE. On March 1, 2003,2004, there were approximately 18,52518,948 registered shareholders of record.

The following table shows high and low sale prices for the common stock on NASDAQNasdaq for each quarter over the past two years.

As of March 1, 2003, there was outstanding 17,347,889 shares of common stock, all of which was held by MGE Energy. There is no market for shares of common stock of MGE. *On August 12, 2002, MGE Energy became the holding company for MGE following a share exchange and began trading on NASDAQNasdaq under the symbol MGEE. Prior to the share exchange, MGE traded on NASDAQNasdaq under the symbol MDSN.

MGE

As of March 1, 2004, there were outstanding 17,347,889 shares of common stock, all of which were held by MGE Energy. There is no market for shares of common stock of MGE.

Dividends

The following table sets forth MGE Energy's quarterly cash dividends paid during 20022003 and 2001:2002:

The following table sets forth MGE's quarterly cash dividends paid during 20022003 and 2001:2002:

Item 6. Selected Financial DataData.

*The change in accounting principle in 2001 is due to MGE's adoption of SFAS No. 133.
**Includes current maturities.

Item 7. Management's Discussion and Analysis of Financial Condition and

Results of Operations.

General

MGE Energy Inc. (MGE Energy),is a holding company operating through itssubsidiaries in three business segments: electric utility operations, gas utility operations, and nonutility energy operations. Our principal subsidiary Madison Gasis MGE, which conducts our electric utility and Electric Company (MGE), operates in two business segments:

- Electric operations generategas utility operations. MGE generates and distributedistributes electricity to nearly 130,000132,000 customers in Dane County, Wisconsin, which includesincluding the Citycity of Madison. MGE contracts with American Transmission Company (ATC)Madison, and others for transmission service.

- Gas operations purchasepurchases and distributedistributes natural gas to more than 126,000129,000 customers in seventhe Wisconsin counties (Columbia,of Columbia, Crawford, Dane, Iowa, Juneau, Monroe, and Vernon). MGE also contracts with various pipelines for transporting natural gas.Vernon. Other subsidiaries, which constitute our nonutility energy operations, have been formed to own and construct new electric generating capacity. Those subsidiaries are currently undertaking the construction of a 150-MW, electricity, steam, and chilled-water cogeneration facility on the UW-Madison campus.

MGE EnergyWe became the holding company for MGE on August 12, 2002, when MGE shareholders exchanged each sharetheir shares of MGE common stock for one shareshares of MGE Energyour common stock. The share exchange had no accounting effect on MGE's recorded assets, liabilities, revenues, or expenses.

MGE's electric and gas utility operations represent substantially alla substantial part of theour assets, liabilities, revenues, and expenses of MGE Energy. MGE Energy'sexpenses. Our nonutility operations, relating, principally, to the development of a cogeneration project on the MadisonUW-Madison campus, of the University of Wisconsin (UW), are not significant at this time. Consequently, with the exception of the discussion under Nonutility Energy Outlook under Results of Operations, the following discussion focuses mainly on the results of operations and financial condition of MGE.

The following discussion provides informationExecutive Summary

In 2003, our utility operations experienced an increase in gas deliveries offset by a slight decline in electric sales due to cooler-than-normal summer weather. Operation and maintenance expenses increased due to higher employee benefit costs associated with pensions and health care, higher transmission costs, and higher distribution and maintenance costs. We also experienced lower interest costs as a result of debt refinancings that management believeswere completed in 2002 as well as the generally lower interest rates for our variable and short-term debt during 2003.

Our liquidity and capital position remained strong during 2003, although our overall debt increased as a result of a cogeneration facility that MGE Power West Campus is relevantconstructing on the UW-Madison campus. We anticipate relying on short- and long-term borrowings to support that construction and the associated capital expenditures. We also anticipate a need for additional equity capital during 2004 beyond the amounts we are able to raise through our Dividend Reinvestment and Direct Stock Purchase Plan.

Our primary focus today and for the foreseeable future is our core utility customers at MGE. MGE continues to face the challenge of providing its customers with reliable power at competitive prices. It plans to meet this challenge by building more efficient generation projects and continuing its efforts to control its operational costs. We believe it is critical to continue maintaining a strong credit standing and financial strength in MGE as well as the parent company in order to accomplish these goals.

Results of Operations

Earnings Overview - MGE Energy

In 2003, our earnings were $30.6 million, or $1.71 per share. MGE's increase in base rates to cover, in large part, rising fuel costs led to an assessmentincrease in utility revenues. Electric retail sales declined slightly, but retail gas deliveries increased 6.4%. Operations and understanding ofmaintenance costs increased due to higher costs for employee benefits (health care, pension, etc.), transmission wheeling charges, distribution costs, and maintenance. These costs were somewhat offset by a decrease in depreciation costs, as MGE was no longer required to contribute to the decommissioning fund for Kewaunee in 2003. Also, MGE Energy benefited from lower interest costs due to refinancing a large portion of its long-term debt in 2002 and MGE's consolidated results of operationsthe lower interest rates on its variable rate and financial condition. This discussion should be readshort-term debt in conjunction with the consolidated financial statements and notes.2003.

Forward-Looking Statements

This report, and certain other MGE Energy and MGE public documents, contain forward-looking statements that reflect management's current assumptions and estimates regarding future performance and economic conditions--especially as they relate to future revenues, expenses, financial resources, and regulatory matters. These forward-looking statements are made pursuant to the provisions of the Private Securities Litigation Reform Act of 1995. MGE Energy cautions investors that forward-looking statements are subject to known and unknown risks and uncertainties that may cause MGE Energy's actual results to differ materially from those projected, expressed, or implied. Some of those risks and uncertainties include:

- Weather
- Economic and market conditions in MGE's service territory.
- Magnitude and timing of capital expenditures.
- Regulatory environment (including restructuring the electric utility industry in Wisconsin).
- Availability and cost of power supplies.

MGE Energy and MGE undertake no obligation to publicly release any revision to these forward-looking statements to reflect events or circumstances after the date of this report.

Results of Operations

MGE Energy - Earnings Overview

In 2002, MGE Energy'sour earnings were $29.2 million, or $1.69 per share. MGE's 5.5% increase in electric retail sales, and higher average rate per customercoupled with an increase in base rates to cover rising fuel costs, contributed to a 10.7% increase in electric revenues. Purchased power costs increased substantially. 2002 was the first full year MGE purchased 90 megawatts (MW)MW of capacity and energy to replace its share of generation lost from Kewaunee. MGE sold its interest in Kewaunee to Wisconsin Public Service Corporation (WPSC)WPSC in September 2001. As a result, MGE's operations and maintenance costs were lower in 2002. MGE's gas margin (revenues less the cost of gas) increased $4.2 million due to growth in gas deliveries.

Earnings inIn 2001, MGE Energy's earnings were $27.2 million, or $1.62 per share. Electric revenues remained constant despite a third-quarter pretax adjustment of approximately $4.5 million, reducing electric unbilled revenues. Electric operating income was down due to increased fuel costs, transmission wheeling expenses paid to ATC, and higher distribution expenses. Gas operating income mainly decreased mainly because warm weather in the fourth quarter resulted in lower gas deliveries. Other income increased substantially due to MGE's equity in earnings inof ATC, gains on weather hedge instruments, and lower charitable contributions. Interest expense was down due to lower interest rates and less short-term debt.

Earnings in 2000 were $27.4 million or $1.67 per share. Electric Utility Operations

Electric sales and revenues

The following table compares MGE's electric retail revenues and electric kWh sales by customer class during each of the years ended December 31:

Electric operating income wasrevenues were up $5.9 million7.4% and 10.7% in 2003 and 2002 due to the following:

-Rates. The PSCW authorized increases in MGE's electric rates effective March 1, 2003, and January 1, 2002, to cover rising fuel costs, increased system demands, and the installation of an AMR system. Revenues in 2003 also reflect a surcharge of 2% on electric rates, effective October 24, 2002, and ending October 23, 2003, which the PSCW authorized to recover deferred costs associated with forming ATC and ongoing incremental transmission costs. See Footnote 15 of the Notes to Consolidated Financial Statements for additional information.

-Sales for resale. The change in 2003 reflects higher sales and new generating facilities that earnvolume as the result of a return for investors. An 8.8% increasecontract to sell 25 MW of electric capacity to Alliant from January through August 2003. The change in total gas deliveries added $1.7 million to gas operating income. Two other factors contributed significantly2002 was attributable to higher net income: gains on some performance-based natural gas incentives andprices, although the volume of sales was 14.3% lower pension costs due to strong performance in MGE's plan assets.

MGE - Electric Sales and Revenues

In 2002, electric retail sales rose 5.5% due to warmer-than-normal summer temperatures. Total cooling degree days were up 17.0% (see table). In 2001, total retail sales were down 1.8% because MGE changed its estimated unbilled sales calculation in the third quarter of that year.

Sales for resale were down 14.3% in 2002 due to lower off-peak sales during the first half of that year.

-Volume. Electric retail sales were slightly lower in 2003 due to cooler-than-normal summer temperatures, as reflected in the year.

Electric operating revenues26.2% reduction in cooling degree days. The opposite effect was felt in 2002 when warmer-than-normal temperatures caused electric retail sales to increase 5.5%. Total cooling degree days were up $21.8 million or 10.7%17% in 2002.

-Other effects. The higher revenues are attributed to:

- Customer growth and greater use per customer ($11.0 million).

- Another effects in 2003 reflect a fuel credit that was in effect from mid-August through year-end. In 2002, the increase in electric rates ($8.9 million, Footnote 7).

- An increase in other electric revenues due in large part towas associated with a vendor settlement and a true-up for thea spring 2000 outage at Kewaunee ($0.9 million).Kewaunee.

- A rise in sales for resale (despite a drop in sales volume) because electricity was sold at a higher rate per kilowatt-hour ($1.0 million).

Cooling degree days measure the extent to which the average daily temperature rises above 65 degrees Fahrenheit, increasing demand for cooling.

In 2001, electric retail sales decreased 1.6% despite warmer-than-normal summer temperatures.

In 2001, total electric revenues remained the same, even though electric sales dropped slightly. Retail revenues were up $6.7 million or 3.5%. These increases offset an approximate $4.5 million reduction in the third quarter that resulted from a change in estimated unbilled revenues (described below). Significant items affecting retail revenues included:

- A 3.9% electric rate increase effective January 1, 2001, combined with customer growth and greater use per customer ($5.8 million, net of the unbilled adjustment).

- A $0.001 kilowatt-hour electric fuel surcharge effective May 9 through September 2, 2001 ($0.8 million; see Footnote 7).

The increase in retail revenues was offset by:

- A $1.4 million decrease in other electric revenues.

- A $5.3 million decrease in sales for resale because a contract expired with Wisconsin Public Power Inc. MGE sold 30 MWs of firm energy and capacity to Wisconsin Public Power from March 1999 through September 30, 2000.

As noted above, MGE adjusted unbilled revenues in the third quarter of 2001, reducing revenues by approximately $4.5 million. The adjustment was made after reviewing MGE's assumptions regarding electricity lost in the process of transmission and distribution, or line loss. Prior to the adjustment, MGE estimated line loss based on a computer-modeled study performed in 1985. At times, the study has been reviewed for reasonableness and adjustments made, as needed. An analysis of various operating and financial statistics in the third quarter of 2001 (including the unbilled-to-billed sales ratio) indicated the estimate for unbilled revenues needed adjusting. MGE's adjustment aligned the unbilled-to-billed ratio with the 40% to 50% range it would normally expect.

MGE changed its method for incorporating unbilled consumption from prior periods into the calculation ofcalculating amounts available for sale to customers during the current period.customers. The revised calculation determines unbilled quantities available for sale in the current month based on the current month and the trailing two months. MGE previously brought forward the unbilled quantity from prior months, which had the effect of cumulatingaccumulating any underestimated line loss amounts. The three months is based on an assumption (which MGE believes is reasonable) that all electricity consumed by all classes of customers is billed within three months. MGE also determined the ratio of unbilled-to-billed sales had a sufficient relationship to include that statistic in validating results of its estimation methodology. This is in addition to the ratio between unbilled sales and accounts receivable that was previously used. See Footnote 1.b.1.c. for more information regarding the unbilled revenue estimation methodology.

MGE - Gas SalesElectric fuel and Revenuespurchased power

In 2002, retail gas deliveries2003, fuel used for electric generation increased 10.2%$3.3 million, or 8.8%, primarily due to:

- Colder weather during most of the 2002 heating season. Total heating degree days were up 3.7% (see table).

- A larger customer base in southwestern Wisconsin. On December 28, 2001, MGE purchased the Prairie du Chien-area natural gas system from We Energies for $3.9 million. MGE gained approximately 3,600 residential and commercial customersto a rise in the Prairie du Chien area.

Transport deliveries increased 17.0% in 2002 as alternative fuel customers used more natural gas during the first half of the year. In 2001, transport sales declined as customers turned to other fuels when the pricecost of natural gas hit record-high levels.

Despite growthused at certain MGE generating plants. MGE's internal generation increased 2.5% in gas deliveries, retail gas revenues were down $8.42003. Purchased power expense increased $4.9 million, or 6.5%11.0%, primarily due to an increase in the cost of natural gas ($6.4 million). The average price for purchased power was $39.309 per MWh in 2003 compared to $34.210 in 2002, due to lower gas costs.an increase of 14.9%. The average rate for residential customersincrease in purchased power expense was $0.78 per thermpartially offset by a 3.4% decrease in 2002 compared to $0.91 per thermvolume ($1.5 million) resulting from the expiration of a 90-MW purchased power agreement with WPSC in 2001.September 2003.

The following table shows total gas deliveries by customer class.

Heating degree days measure the extent to which the average daily temperature is below 65 degrees Fahrenheit, increasing demand for heating.

During 2001, retail gas deliveries were down 8.8%. Warmer weather in November and December resulted in lower gas use per customer. The average temperature for November and December 2001 was 38.5 degrees Fahrenheit, 65% warmer than the same period in 2000. Transport deliveries were up 5.2% primarily because customers who have the ability to switch fuels bought more gas to generate electricity or produce steam.

In 2001, gas revenues increased $9.6 million or 7.9%. Revenues were up due to significantly higher gas costs during the first half of the year and a 2.7% rate increase effective January 1, 2001 (see Footnote 7).

MGE - Electric Fuel and Purchased Power

In 2002, fuel used for electric generation decreased $2.1 million, or 5.2%., due to the following:

- Fuel costs for MGE's electric generating units--excluding Columbia and Kewaunee--were downunits (excluding Columbia) decreased $1.5 million, or 7.3%. MGE relied less on certain generating units because higher fuel costs made it generally cheaper to buy electricity than operate those units.

- Nuclear fuel expense decreased $2.3 million, or 89.5%, since MGE sold its ownership interest in Kewaunee in 2001.

- Fuel costs for the Columbia units increased $1.7 million, or 9.5%, due to higher coal costs.

- Nuclear fuel expense decreased $2.3 million or 89.5% since MGE sold its ownership interest in Kewaunee in 2001.

In 2002, purchased power expense increased $26.3 million, or 143.6%. MGE purchased electric capacity and energy to replace the energy generation lost from selling its ownership interest in Kewaunee and to meet expected load growth. In June 2001, MGE exercised an option to buy 90 MWsMW of electric capacity and energy at a fixed price from WPSC from September 24, 2001, through September 23, 2003.

Increased purchased power costs in 2002 reduced MGE's electric margin (revenues less fuel and purchased power) by $2.4Electric operating expenses

Electric operating expense increased $13.3 million, or 1.7%.

In 2001, fuel for electric generation increased $4.035.4%, in 2003 and decreased $0.8 million, or 10.9%1.4%, in 2002. The following changes contributed to the net change in electric operating expenses for the indicated year:

Maintenance expense

In 2003, electric maintenance expense increased $3.6 million, or 30.8%. Fuel costs for MGE's electric generating units were up primarilyThis is due to the following factors:

- Increase in maintenance of distribution assets ($2.1 million), including substation work, transformers, and overhead and underground lines. Maintenance and system upgrades help to improve the reliability of MGE's electric distribution system.

- Increase in other maintenance sources, including electric generating assets and Columbia ($1.5 million).

In 2002, electric maintenance expense was down $2.5 million, or 20.2%. This decrease is the net result of the following two factors:

- Maintenance expenses declined ($3.1 million) since MGE sold its 17.8% ownership interest in Kewaunee to WPSC.

- Maintenance expenses at Columbia increased use($0.6 million) as a result of base-load power plants at a marginally higher fuelscheduled seven-week outage during April and May 2002.

Depreciation

Electric depreciation expense decreased $6.6 million and $6.7 million in 2003 and 2002, respectively. The decrease in 2003 reflects lower decommissioning expense ($8.2 million) as a result of the sale of Kewaunee, offset in part by $1.6 million of increased depreciation associated with an increase in electric plant assets. The decrease in 2002 reflects reduced decommissioning expense ($4.0 million), reduced depreciation due to the sale of Kewaunee ($3.4 million, see Footnote 18), and is partially offset by increased depreciation expense for the addition of electric assets ($0.7 million).

Gas Utility Operations

Gas deliveries and revenues

The following table compares MGE's gas retail revenues and gas delivered by customer class during each of the years ended December 31:

Gas revenues were up 30.9% in 2003 and decreased 6.5% in 2002 due to the following:

-Gas costs/rates. The PSCW authorized increases in MGE's gas rates effective March 1, 2003, and January 1, 2002, to cover increased system demands. Gas costs increased significantly in 2003 from 2002. The average rate per therm in 2003 increased 23% compared to the prior year. The reverse was true for 2002. Despite a 10.2% increase in retail gas deliveries, revenues decreased due to the decrease -in the cost (especiallyof gas. See Footnote 15 of the Notes to Consolidated Financial Statements for additional information on gas base rates.

-Retail gas deliveries. The 6.4% increase in 2003 was due to colder-than-normal temperatures, as reflected in the second quarter)5.9% increase in heating degree days. The same effect was felt in 2002 when colder-than-normal temperatures caused gas deliveries to increase 10.2%. Total heating degree days were up 3.7% in 2002. The 2002 increase also reflects a full year of ownership of the Prairie du Chien-area natural gas system that was purchased on December 28, 2001, from We Energies for $3.9 million. MGE gained approximately 3,600 residential and commercial customers in southwestern Wisconsin as a result of the purchase.

-Gas transportation. The 10.1% decrease in deliveries in 2003 reflects fuel switching by customers with other fuel options, who switched due to the higher costprice of naturalgas. The reverse effect was observed in 2002 as alternative fuel customers used more gas used to generate electricity during the first half of 2002, causing a 17% increase in deliveries.

-Other effects. The other effects in 2003 reflect an increase of $0.6 million in the year. MGE customers set a record for peak demand (714 MWs) on August 7, 2001.GCIM and other miscellaneous increases totaling $0.1 million.

During 2001,Natural gas purchased power decreased $0.7 million or 3.4%. This decrease is attributed to the following:

- In the first three quarters of 2001, MGE did not need to buy additional capacity from outside sources because its base-load units operated at full capacity. In the second quarter of 2000, MGE purchased more expensive open-market replacement power during a six-week scheduled refueling and maintenance outage at Kewaunee.

- MGE purchased only 15 MWs from Commonwealth Edison in 2001 compared to 30 MWs in 2000.

The purchased power decreases described above were partially offset by the following:

- MGE executed its option to purchase 90 MWs of electric capacity and energy at a fixed price from WPSC from September 24, 2001, through September 23, 2003. This option was part of the Kewaunee sale agreement between WPSC and MGE (see Footnote 10).

Electric margin (revenues less fuel and purchased power) decreased $3.3 million or 2.2%, in 2001 reflecting constant revenues and the higher fuel costs as previously described.

MGE - Natural Gas Purchased

In 2002,2003, natural gas purchased was down $12.6increased $30.7 million, or 14.7%41.8%, primarily due to lowerhigher wellhead prices, on average. Natural gas prices (cost per therm) decreasedincreased more than 22.0%33% in 2002.2003. A purchased gas adjustmentPGA clause (PGA) allows MGE to pass along to customers the cost of gas, subject to certain limited incentives. The PGA is authorized by the PSCW.

MGE gas margin (revenues less gas purchased) increased $4.2 million or 9.4% in 2002. Customer growth increased deliveries and a 0.6% rate increase effective January 1,In 2002, contributed to the rise in gas margins (see Footnote 7).

In 2001, natural gas purchased increased $8.6decreased $12.6 million, or 11.0%14.7%, despite retail deliveries declining 8.8%. Even though customer use was down due to the warmer-than-normal winter weather, the average cost per therm of natural gas was up 21.8% over 2000. Gas margins increased $1.0 million or 2.4% primarily due to a 2.7% rate increase effective January 1, 2001.lower wellhead prices.

MGE - Other Operations and MaintenanceGas operating expenses

Electric

In 2002, electricGas operating expense decreased $0.8increased $2.3 million, or 1.4%.21.4%, in 2003 and increased $1.8 million, or 8.3%, in 2002. The following changes contributed to lower electric operating expenses for the year.

- MGE sold its 17.8% ownership interestnet change in Kewaunee to WPSC. As a result, operating expenses declined $5.3 million.

- Miscellaneous steam power expense decreased $1.1 million or 41.9%. MGE recovered through rates some carrying costs for actions taken at Columbia to reduce NO_x emissions.

- Employee health and pension expenses increased $2.6 million or 61.8%, due to dramatically rising health care costs and lower investment returns on plan assets.

- Outside service expenses increased $1.2 million primarily due to forming the holding company and participating in Power the Future.

- Miscellaneous steam power expenses for Columbia increased $0.7 million or 27.8% as a result of increased administrative and general overheads ($0.4 million) and employee pensions and benefits ($0.3 million).

- Transmission wheeling costs rose $0.6 million or 5.7% due to relying on more purchased power.

- Miscellaneous electric operating expenses increased $0.5 million.

In 2001, electric operating expense increased $6.1 million or 11.7%. The following changes contributed to higher electricgas operating expense for the year.indicated year:

- Increased transmission costs ($6.6 million). MGE started paying ATC a wheeling charge on January 1, 2001. The wheeling charge is offset by equity earnings for MGE's ownership interest in ATC. These equity earnings were recorded in other income.

- NO_x accrual ($0.9 million). The PSCW authorized utilities to defer all project costs for complying with the federal US Environmental Protection Agency's (EPA) new requirements on NO_x emissions. In its rate case (Docket 3270-UR-110), the PSCW allowed MGE to establish an escrow mechanism for these costs due to uncertainties regarding the amount and timing of NO_x emissions remediation expenditures. The annual recovery allowed in rates is $1.6 million, of which $0.7 million is recorded in depreciation expense and $0.9 million in operating expense.

- Increased miscellaneous distribution expenses ($1.0 million).

Increases in electric operating expenses were offset somewhat by:

- Lower Kewaunee operating expenses ($2.2 million) due to three fewer months of expense after MGE sold its ownership interest in the plant (see Footnote 10) and lower overhead for administrative and general.

- The PSCW decreasing MGE's energy conservation escrow amount ($0.8 million).

Gas

In 2002, gas operating expense increased $1.8 million or 8.3%. The following changes contributed to higher gas operating expenses for the year.

- Employee health and pension expenses increased $1.4 million or 64.0% due to dramatically rising health care costs and lower investment returns on plan assets.

- Other expenses increased $1.4 million due to increased administrative and general expenses ($0.4 million), increased injuries and damages ($0.3 million), and other miscellaneous expenses ($0.7 million).

- Outside service expenses increased $0.3 million or 44.4% primarily due to forming the holding company.

- Uncollectible account expenses were down $1.3 million or 75.8%. More customers paid their bills in 2002 as warmer-than-normal weather and lower-priced natural gas in the first quarter significantly reduced utility bills.

In 2001, gas operating expense increased $1.7 million or 8.2%. Uncollectible customer account balances were up due to significantly higher natural gas costs during the first half of the year ($1.0 million) and increased administrative and billing expenses ($0.7 million).

Maintenance Expense

In 2002, electric maintenance expense was down $2.5 million or 20.2%. It is the net result of the following two factors:

- Maintenance expenses declined ($3.1 million) since MGE sold its 17.8% ownership interest in Kewaunee to WPSC.

- Maintenance expenses at Columbia increased as a result of a scheduled seven-week outage during April and May 2002 ($0.6 million).

In 2001, electric maintenance expense was down $4.5 million or 26.5% primarily due to:

- Three fewer months of expense at Kewaunee after MGE sold its ownership interest in the plant (see Footnote 10) combined with lower maintenance expense compared to 2000 ($1.8. million).

- Lower maintenance expense at Columbia ($1.2 million).

Depreciation

In 2002, depreciation expense decreased $6.3 million or 17.7%.

- Electric depreciation decreased $6.7 million. The decrease is attributed to reduced decommissioning expense ($4.0 million), the sale of Kewaunee assets ($3.4 million, see Footnote 10), and offset by increased depreciation expense for the addition of electric assets ($0.7 million).

- Gas depreciation expense increased because MGE added plant assets ($0.4 million).

In 2001, depreciation expense increased $0.6 million or 1.6%.

- Electric depreciation expense increased $0.7 million. The change in depreciation expense is attributed to increased earnings on the decommissioning trust fund ($0.6 million), a NO_x accrual ($0.7 million), the addition of electric assets ($1.4 million), and somewhat offset by reduced transmission depreciation ($1.8 million, see Footnote 9) and the transfer of assets related to the Kewaunee sale ($0.5 million).

- There were no significant changes to gas depreciation in 2001.

Other General Taxes

Other general taxes, consisting mainly of the Wisconsin license fee tax and payroll taxes, were consistent between 2002 and 2001.

Income Taxes

The 2002 effective income tax rate increased to 39.1% from 36.8% for 2001 and 36.5% for 2000 due to a combination of reasons.

The increase in tax rate is partly attributable to lower amounts of amortized tax benefits from excess deferred income taxes and deferred investment tax credit. These lower amortized tax benefits are the result of MGE's investment in ATC and the sale of its interest in Kewaunee, both 2001 transactions. In 2002 compared to 2001, amortized excess deferred income taxes and amortized investment tax credits have decreased by a total of $0.4 million.

In 2002, MGE recorded a net deferred tax expense of $0.4 million to fully accrue its deferred tax liability for utility property. MGE is evaluating its ability to recover these taxes in rates.

On August 12, 2002, MGE Energy became the holding company for MGE and other subsidiaries. Certain one-time intercompany transactions for state tax purposes and costs of capital associated with forming MGE Energy have resulted in permanent differences between financial and income tax reporting and have increased the state tax component of the effective income tax rate.

Other Nonoperating Items

In 2002, other income decreased $6.3 million or 72.8%. The decrease in other income is attributed to the following:

- MGE transferred its Qualified Decommissioning Fund ($65.0 million, fair market value) and Nonqualified Decommissioning Fund ($28.1 million, fair market value) to WPSC with the sale of its 17.8% ownership interest in Kewaunee (Footnote 10). There was no impact on earnings. The lower decommissioning earnings on trust assets were offset by an equal decrease in accumulated depreciation expense. The related decrease in other income was $4.0 million.

- An increase in charitable contributions reduced other income by $1.6 million.

- During 2002, MGE did not benefit from a gain on a weather hedge. In 2001, MGE received a $0.8 million pretax gain from weather hedge instruments. The net effect was a $0.8 million decrease in other income in 2002.

In 2001, other income increased $6.7 million primarily due to:

- $3.3 million equity earnings in ATC (see Footnote 9).
- A $0.8 million gain from weather hedge instruments.
- A $0.6 million increase in earnings on the decommissioning funds.
- A $1.6 million reduction in charitable contributions.

In 2000, other income decreased $3.1 million. MGE donated $1.3 million to the MGE Innovation Center and the MGE Foundation. These donations provide substantial benefits to the community and MGE's service territory. Other income was also down because there was a gain from MGE's gas marketing subsidiaries in 1999 and not in 2000. Earnings on the decommissioning fund were up $0.4 million in 2000.

Interest Expense

In2003 and 2002, interest expense decreased $1.2 million or 9.0%. Lower rates on MGE's $20.0 million variable rate debt (which matured on May 3, 2002) reduced interest expense by $0.7 million. Lower short-term debt levels in the first quarter, coupled with significantly lower interest rates, reduced other interest expense by $0.5 million.

In 2001, total interest decreased $0.5 million or 3.6%. Lower short-term debt, due to proceeds received from ATC and the sale of Kewaunee, caused the decline in other interest expense of $0.6 million. In addition, MGE redeemed $6.1 million of its 6-1/2%, 2006 Series, Pollution Control Revenue Bonds, at par on November 1, 2001.

In 2000, total interest increased $2.1 million or 17.3%. Compared to 1999, MGE had higher levels of short-term debt and interest on $35.0 million in new long-term debt ($20.0 million issued on May 4, 2000, and $15.0 million issued on September 20, 2000).

MGE - Electric and Gas Operations Outlook

MGE anticipates electric and gas sales will grow at a compounded rate of 1.0% to 2.0% through 2007. Peak demand will grow an estimated 3.0% each year through 2007.

MGE expects to maintain a competitive advantage because of its:

- Service territory, which has one of the strongest economies in the nation. It is distinguished by consistent growth; high employment and wages; and a diversified base of business, industry, government, and education.

- Competitive distribution costs, low percentage of industrial customers, and lower risk of stranded investments.

- Size and agility, which allow employees to respond quickly and offer more flexibility as customers' needs change.

MGE sold its ownership interest in Kewaunee in the fall of 2001. This will help eliminate the risk of future stranded investment. The capacity lost from Kewaunee will be replaced with purchased power contracts.

The PSCW has focused on improving the infrastructure needed in Wisconsin to ensure reliable service for consumers. MGE invests in new facilities to meet its customers' needs. It also advocates statewide solutions that will keep pace with the growing demand for energy.

Nonutility Energy Outlook

MGE Energy's primary focus is its core utility customers. The holding company structure will facilitate competitive new electric generation projects. It will also allow financial returns from these projects to be retained for the benefit of MGE's system and MGE Energy's shareholders.

MGE Energy's nonutility energy operations will be conducted through its subsidiaries, MGE Construct, LLC, and MGE Power, LLC. Both were formed in 2002 to construct and own new generating capacity. It is expected that, subject to PSCW approval in each instance, MGE Power will lease-back new generating facilities to MGE under regulated, long-term lease agreements.

Power the Future Generation

On February 23, 2001, MGE secured an option to own a portion of the advanced technology, coal-fired, base-load generation proposed in We Energies' Power the Future plan. The plan includes three new 600-MW coal-fired plants, which would be located in Wisconsin. The plan is subject to pending regulatory proceedings. We Energies filed its Certificate of Public Convenience and Necessity (CPCN) proposal with the PSCW in early 2002. A PSCW decision is expected on the plan in 2003.

Pursuant to an amended agreement reached on January 31, 2003, MGE has the option to acquire an undivided 8.33% (16.66% under certain conditions) ownership interest in each of the proposed coal plants, up to a total of 150 MWs for all three plants. If these options are fully exercised, that exercise would require an estimated $150 million to $175 million investment over ten years.

West Campus Cogeneration Facility (WCCF)

MGE Energy, through MGE Power and MGE Construct, has assumed responsibility from MGE for the construction and ownership of a proposed natural gas-fired cogeneration facility to be built on the Madison campus of the UW. As planned, the facility would have 20,000 tons of chilled water capacity, 500,000 pounds per hour of steam capacity, and approximately 150 MWs of electricity capacity. The facility would be jointly-owned by the State of Wisconsin, the UW, and MGE Power and would be leased and operated by MGE. The State and the UW would own a controlling interest in the chilled water and steam plants, which would be used to meet the growing UW need for air-conditioning and steam heat capacity. MGE Power would own a controlling interest in the electric generation plant, which would be used to provide electricity to MGE's customers. MGE Construct would be responsible for the construction of the facility.

The ownership, construction, and operation of the facility requires various state approvals as well as the completion of definitive agreements, including a construction agreement. As part of this process, the State is reviewing its alternatives before entering final agreements. Depending on the approval process, construction could start in 2003, with the facility coming on-line in 2005. MGE also requires PSCW approval in order to lease and operate the facility. On October 21, 2002, the PSCW deemed MGE's CPCN application complete. A PSCW decision is expected on MGE's participation in the facility during 2003.

The facility is expected to cost approximately $180 million. On November 29, 2002, the State paid $11.9 million to MGE for its share of those costs under a September 2002 Pre-Certification Cost Sharing Agreement between MGE and the State. On December 31, 2002, MGE Power reimbursed MGE for the remainder of those costsrespectively, as a partresult of MGE Power's assumption of the project. As of December 31, 2002, MGE Power had incurred $18.9 million of costs on the project, which is reflected as construction work in progress on MGE Energy's consolidated balance sheets. These costs largely represent amounts paid under long-lead time equipment contracts in order to meet project schedules, although, as noted, several approvals remain outstanding. A failure to obtain these approvals could terminate the project and could result in the write-off of these costs to the extent that the associated equipment and efforts cannot be put to alternative uses.additional gas plant assets.

Liquidity And Capital ResourcesGas cost incentives

Cash Flows

The following summarizes MGE Energy's cash flows during 2002, 2001, and 2000:

Cash Provided by Operating Activities for MGE Energy

In 2002, cash provided by operating activities decreased $18.0 million or 24.0%. Working capital (current assets less current liabilities) decreased $0.8 million primarily due to an increase in customer payables. MGE deposited $5.0 million in an escrow account and granted ATC a security interest in the collateral. ATC will provide system upgrades for MGE in conjunction with the WCCF proposed on the UW-Madison campus. The collateral account complies with the Interconnection Agreement between ATC and MGE dated November 22, 2002.

Depreciation and other amortization expenses decreased $8.3 million, mainly because MGE sold its ownership interest in Kewaunee. Deferred income taxes for 2002 decreased $8.0 million compared to 2001. The significantly larger deferred tax expense in 2001 was attributable to the sale of Kewaunee, which resulted in reversal of temporary differences associated with the plant and decommissioning funds.

In 2001, cash provided by operating activities increased $26.9 million or 56.3%. Decreases in customer receivables ($13.1 million) and unbilled revenues ($11.4 million) were offset by higher stored gas inventories of $6.8 million and a $4.4 million reduction in accounts payable. Deferred income taxes increased in 2001 due to the sale of Kewaunee.

Capital Requirements and Investing Activities for MGE Energy

In 2002, cash used for investing activities increased $61.8 million. Utility plant additions were up $17.5 million due to installing an automated meter reading (AMR) system, installing NO_x emissions equipment at Columbia, and upgrading MGE substations to improve reliability. Capital expenditures related to the WCCF totaled $18.9 million. In 2001, MGE received a $15.0 million capital distribution from ATC and $15.4 million for selling its interest in Kewaunee.

In 2001, MGE's cash used for investing activities was down $60.3 million or 71.1% mainly because of a significant decrease in plant additions. In 2000, MGE paid $31.6 million for an 83-MW gas-fired combustion turbine. MGE also received a capital distribution of $15.0 million from ATC for debt repayment and a cash payment of $15.4 million from the sale of Kewaunee (see Footnote 10).

MGE Energy's and MGE's liquidity are primarily affected by their construction requirements. Capital expenditures in 2002 totaled $78.3 million, which included $18.9 million of capital commitments for the WCCF. MGE's capital requirements were higher in 2002 due to installing an AMR system ($17.6 million), upgrading MGE substations to improve reliability ($4.7 million), and installing NO_x emissions equipment at Columbia ($2.4 million). MGE anticipates 2003 capital expenditures will be $51.6 million and include substation improvements ($5.1 million), AMR project costs ($3.4 million), and upgrading its Energy Management System ($1.8 million).

Capital expenditures for 2003 through 2007 will average an estimated $46 million per year (excluding the WCCF and MGE's option to purchase a portion of Power the Future coal plants). The following table shows MGE's estimated expenditures for 2003, actual for 2002, and the three-year average for 1999 to 2001.

In 2002, MGE used internally generated funds and short-term debt to satisfy most of its capital requirements. For the larger capital investments, MGE issues additional long-term debt and common stock. MGE Energy used existing lines of credit to satisfy capital commitments related to the WCCF.

Financing Activities and Capitalization Matters for MGE Energy

In 2002, cash provided by financing activities was $30.2 million. Short-term debt increased $24.8 million. Two long-term debt issues occurred in the fourth quarter of 2002. A $20.0 million issue replaced the $20.0 million in debt that matured in May, which was rolled into short-term debt at that time. Another $15.0 million issue financed capital expenditures for the AMR project, which had been financed with short-term debt.

MGE Energy's capitalization ratios were as follows:

In 2001, cash used for financing activities was $52.0 million as MGE reduced its short-term debt by $34.5 million. MGE reduced short-term debt and redeemed $6.1 million in long-term debt by using the cash distribution from ATC and cash received from the sale of its interest in Kewaunee. MGE raised $10.9 million by issuing common stock for its Dividend Reinvestment and Direct Stock Purchase Plan (the Plan). MGE issues new shares of common stock for the Plan to improve cash flow and capitalization ratios.

MGE's First Mortgage Bonds are currently rated Aa2 by Moody's Investors Service, Inc. (Moody's) and AA by Standard & Poor's Corp. (S&P). MGE's medium-term notes are rated Aa3 by Moody's and AA- by S&P. MGE's dealer-issued commercial paper carries the highest ratings assigned by Moody's and S&P. MGE Energy is not yet rated because it has not issued any debt securities.

MGE's access to the capital markets, including the commercial paper market, and its financing costs in those markets are dependent on its securities' ratings. None of MGE's borrowing is subject to default or prepayment due to downgrading of securities' ratings.

Contractual Obligations and Commercial Commitments for MGE Energy and MGE

MGE Energy and MGE's contractual obligations as of December 31, 2002, representing cash obligations that are considered to be firm commitments, are as follows:

For additional information about:

- Long-term debt consisting of secured First Mortgage Bonds and unsecured medium-term notes, see Footnote 6.c. of the Notes to Consolidated Financial Statements.

- Short-term debt consisting of commercial paper issued by MGE, which is supported by unused lines of credit from banks and bank loans to MGE Energy, see Footnote 6.d. of the Notes to Consolidated Financial Statements.

- Operating leases, see Footnote 8 of the Notes to Consolidated Financial Statements.

- Purchase obligations consisting of obligations to purchase electricity and to purchase and transport natural gas, see Footnote 8 of the Notes to Consolidated Financial Statements.

- Other long-term obligations, see Footnotes 1.c. and 10 of the Notes to Consolidated Financial Statements.

MGE Energy and MGE's commercial commitments as of December 31, 2002, 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:

Other Factors

Due to the performance of the United States debt and equity markets, the value of assets held in trusts to satisfy the obligations of pension and postretirement benefit plans has decreased. These factors may also result in additional future funding requirements of the pension and postretirement benefit plans.

Business And Regulatory Environment

Electric Transmission - ATC

On January 1, 2001, MGE transferred substantially all of its electric transmission facilities to ATC in exchange for approximately a 6.0% interest in this joint venture. ATC is comprised of Wisconsin investor-owned utilities and some Wisconsin municipal utilities, cooperatives, and power supply agencies.

Effective October 24, 2002, the PSCW authorized an electric rate surcharge of $4.5 million or 2.0% for MGE to recover deferred costs associated with ATC's formation and ongoing incremental transmission costs during 2001 and 2002. The surcharge will be in effect for a 12-month period ending October 23, 2003.

On November 21, 2002, MGE and ATC entered into a Generation-Transmission Interconnection Agreement related to transmission system upgrades due to the WCCF. MGE issued to ATC a "Notice to Proceed for the Procurement of the Equipment" for the system upgrades. In accordance with the agreement, MGE had to provide ATC with a form of security, such as a Letter of Credit or a collateral account, in the amount of $5.0 million. MGE set up a collateral (escrow) account to satisfy the security interest to ATC until MGE was able to secure a Letter of Credit from a commercial bank, which it received on December 30, 2002. The collateral account was terminated on January 2, 2003. MGE will make an estimated $10 million capital payment for transmission equipment and work done by ATC throughout 2003 related to the WCCF. MGE expects to be reimbursed by ATC for its capital outlay once the project is completed.

Kewaunee

Effective September 23, 2001, MGE sold to WPSC its 17.8% ownership interest in Kewaunee. In exchange for a cash payment of $15.4 million, MGE transferred its net book value of utility plant ($8.2 million), net nuclear fuel ($7.9 million), inventories ($1.5 million), and other assets ($0.1 million). These assets were offset by $2.3 million owed to WPSC. On the closing date, MGE also transferred its Qualified Decommissioning Fund ($65.0 million fair market value) and Nonqualified Decommissioning Fund ($28.1 million fair market value), which decreased accumulated depreciation by an equal amount. This transaction occurred in accordance with an agreement between MGE and WPSC dated September 29, 1998. That agreement required certain continuing obligations of MGE and WPSC after the closing date, as described below.

MGE made monthly contributions to the MGE Nonqualified Decommissioning Fund from September 23, 2001, in the amount of approximately $0.7 million (the level authorized by the PSCW) through December 31, 2002. These costs were recovered from customers in rates. MGE's decommissioning liability is limited to the fund balances at the closing date plus all decommissioning collections through 2002. MGE's Nonqualified Decommissioning Fund is shown on the balance sheet in the Utility Plant section. As of December 31, 2002, this fund totaled $8.8 million (pretax fair market value) and was offset by an equal amount recorded in accumulated provision for depreciation. The securities and uninvested cash balances in the fund, net of trust investment expenses and taxes on investment income, were transferred to the WPSC Nonqualified Decommissioning Fund on January 3, 2003.

The federal government is responsible for the disposition and storage of spent nuclear fuel. Federal legislation is being considered to establish an interim storage facility. Spent nuclear fuel is currently stored at Kewaunee. Minor plant modifications to the spent fuel pools in 2001 should ensure Kewaunee has sufficient fuel storage capacity until the end of its licensed life in 2013. MGE retains its spent fuel obligations for all fuel burned at Kewaunee for MGE's generation from the opening of the plant to the closing date. WPSC took title to such fuel at the closing date.

A surcharge imposed by the National Energy Policy Act of 1992 requires nuclear power companies to fund the decontamination and decommissioning of US Department of Energy facilities that process nuclear fuel. As a result, the Kewaunee co-owners are required to pay a surcharge on uranium enrichment services purchased from the federal government prior to October 23, 1992. On an inflation-adjusted basis, MGE's portion of the obligation related to Kewaunee is approximately $1.1 million at December 31, 2002. MGE is required to continue paying its portion of this annual assessment.

In accordance with the sale agreement, MGE exercised its option in June 2001 to buy electric capacity and energy at a fixed price from WPSC. MGE purchased 90 MWs of electric capacity and energy from September 24, 2001, through December 31, 2002, and will continue to do so through September 23, 2003, to help meet customers' electric needs.

Formation of Holding Company

On August 12, 2002, MGE Energy became the holding company for MGE following a share exchange. Each share of MGE common stock was exchanged for one share of MGE Energy common stock. MGE Energy's consolidated financial statements reflect this transaction for all periods presented. MGE Energy's operations are based primarily on the operations of MGE. Consequently, MGE constitutes a majority of the assets, liabilities, and results of operations of MGE Energy and is expected to continue to do so for the foreseeable future.

Industry Restructuring in Wisconsin

Wisconsin has focused on building the infrastructure needed to provide reliable electric service to customers. State regulators realize a competitive market cannot exist when supply is short. The PSCW will decide when it is appropriate for retail competition to proceed in the electric industry. MGE cannot predict what impact future PSCW actions may have on its future financial condition, cash flows, and results of operations. However, MGE believes it is well-positioned to compete.

Restructuring the electric industry could affect MGE's ability to continue establishing certain regulatory asset and liability amounts allowed under Statement of Financial Accounting Standards (SFAS) No. 71,Accounting for the Effects of Certain Types of Regulation. MGE is unable to predict whether any adjustments to regulatory assets and liabilities will occur in the future. However, the PSCW has recognized the need to allow recovery for commitments made under prior regulation.

Gas Cost Incentives

Under MGE's gas cost incentives,GCIM, if actual gas commodity costs are above or below a benchmark set by the PSCW, then MGE's gas sales service customers and shareholders share equally in any increased costs or savings up to $1.5 million. Any costs or savings that exceed $1.5 million will be passed on to gas sales service customers. The PSCW allows MGE to resell gas pipeline capacity reserved to meet peak demands but not needed every day to serve customers. Revenues from capacity release that exceed or fall short of PSCW-targeted levels are shared equally. In 2002,2003, MGE shareholders benefited $0.5$0.9 million (after tax) from capacity release revenues and commodity savings under the GCIM.

The PSCW recently lowered the formula used in establishing the benchmark for gas commodity costs. Beginning February 1, 2004, the benchmark will be 99.5% of what it would have been under the prior formula. This change is intended to better reflect market conditions.

Other General Taxes

The 6.7% increase ($0.7 million) in other general taxes from 2002 to 2003 is due to an increase in MGE's license fee tax, which for any year is based on adjusted operating revenues of the prior year. The Wisconsin license fee tax is in lieu of all property taxes on utility property.

Income Taxes

The 2003 effective income tax rate increased slightly from 2002 from 39.1% to 39.4% due to constant amounts of tax credits (amortized investment tax credits and credit for electricity from wind energy) in relation to pretax income (see Footnote 9).

The increase in effective income tax rates from 2001 to 2002 (36.8% to 39.1%) is partly attributable to lower amounts of amortized tax benefits from excess deferred income taxes and deferred investment tax credit. These lower amortized tax benefits are the result of the MGE's investment in ATC and the sale of its interest in Kewaunee, both 2001 transactions. In 2002 compared to 2001, amortized excess deferred income taxes and amortized investment tax credits decreased by a total of $0.4 million.

Additionally, the state tax component of the effective income tax rate was greater in 2002 than in 2001 due to permanent differences for certain one-time intercompany transactions for state tax purposes and for costs of capital incurred in forming MGE Energy on August 12, 2002.

Other Nonoperating Items

In 2003, MGE Construct received a service fee from the State in relation to WCCF of $1.0 million. This was offset by an increase in charitable contributions of $1.2 million. Dividend and interest income increased in 2003 by $0.4 million.

In 2002, other income decreased $6.3 million, or 72.8%. The decrease in other income is attributed to the following:

- MGE transferred its qualified decommissioning fund ($65.0 million, fair market value) and nonqualified decommissioning fund ($28.1 million, fair market value) to WPSC with the sale of its 17.8% ownership interest in Kewaunee (Footnote 18). There was no impact on earnings. The lower decommissioning earnings on trust assets were offset by an equal decrease in accumulated depreciation expense. The related decrease in other income was $4.0 million.

- An increase in charitable contributions reduced other income by $1.6 million.

- In 2001, MGE received a $0.8 million pretax gain from weather hedge instruments. During 2002, MGE did not receive a similar benefit. The net effect was a $0.8 million decrease in other income in 2002.

Interest Expense

In 2003, interest expense decreased by $0.8 million, or 6.1%, due to the following factors:

- MGE refinanced a large portion of its long-term debt in 2002, helping to decrease interest expense by $0.5 million.

- Lower short-term interest rates coupled with reduced borrowing levels helped to decrease other interest expense by $0.3 million.

In 2002, interest expense decreased $1.2 million, or 9.0%, due to the following factors:

- Lower rates on MGE's $20.0 million variable rate debt (which matured on May 3, 2002) reduced interest expense by $0.7 million.

- Lower short-term debt levels in the first quarter, coupled with significantly lower interest rates, reduced other interest expense by $0.5 million.

Liquidity and Capital Resources

Cash Flows

The following summarizes cash flows for MGE Energy and MGE during 2003, 2002, and 2001:

Cash Provided by Operating Activities for MGE Energy

In 2003, cash provided by operating activities increased $12.4 million, or 22.0%. Working capital increased $6.6 million primarily due to increases in unbilled revenues ($3.1 million), stored natural gas ($5.6 million), prepayments ($3.4 million), and accounts receivable ($1.4 million). These increases in current assets were offset by higher accounts payable of $3.0 million and other current liabilities totaling $3.7 million.

Deferred income taxes increased $13.1 million in 2003 due to the impact of 50% additional bonus depreciation, which went into effect in May 2003. An increase in other noncurrent items net, of $5.2 million, also contributed to the increase in cash provided by operating activities.

In 2002, cash provided by operating activities decreased $17.7 million, or 24.0%. Working capital decreased $0.3 million primarily due to an increase in customer payables. Depreciation and other amortization expenses decreased $6.3 million, mainly because MGE sold its ownership interest in Kewaunee. Deferred income taxes for 2002 decreased $8.0 million compared to 2001. The significantly larger deferred tax expense in 2001 was due to selling Kewaunee, which resulted in reversal of temporary differences associated with the plant and decommissioning funds.

Cash Provided by Operating Activities for MGE

In 2003, cash provided by operating activities increased $19.7 million, or 36.8%. Working capital increased $3.2 million in 2003 due to a decrease in accounts receivable of $1.8 million and increases in accounts payable of $3.7 million. Other current assets, such as unbilled revenues, inventories, and prepayments, increased in total $12.1 million. Other current liabilities increased $3.6 million. Deferred income taxes increased $13.2 million in 2003, while depreciation decreased $6.0 million, due to lower decommissioning expenses. Other noncurrent items, net, increased $6.6 million, which contributed to the increase in cash provided by operating activities.

In 2002, cash provided by operating activities decreased $20.0 million. Working capital increased $2.5 million in 2002 due to an increase in accounts receivable of $11.2 million and increases in unbilled revenues and prepayments of $2.0 million each. The increases in current assets were offset by an increase in accounts payable of $6.5 million, an increase in other current liabilities of $3.9 million, and a decrease in inventories of $2.4 million. Decreases in depreciation of $6.3 million and deferred taxes of $8.0 million attributed to the decrease in operating activities. The decreases in these items was attributable to the sale of Kewaunee as discussed earlier.

Capital Requirements and Investing Activities for MGE Energy and MGE

In 2003, MGE Energy's cash used for investing activities increased $6.8 million. Capital expenditures increased $6.0 million in 2003. Utility plant additions decreased $3.4 million, while capital expenditures related to the WCCF increased $9.4 million over last year. MGE's advance to ATC in connection with the installation of equipment and system upgrades for WCCF increased $7.9 million in 2003. In 2002, MGE was still contributing to the decommissioning fund for Kewaunee.

In 2002, cash used for investing activities increased $61.8 million. Utility plant additions were up $16.2 million due to installing an AMR system, installing NO_x emissions equipment at Columbia, and upgrading MGE substations to improve reliability. Capital expenditures related to WCCF totaled $18.9 million. The increase in 2002 also reflects an unfavorable comparison to 2001, in which MGE received a $15.0 million capital distribution from ATC and $15.4 million for selling its interest in Kewaunee.

The following table shows MGE Energy's and MGE's estimated capital expenditures for 2004, actual for 2003, and the three-year average for 2000 to 2002:

MGE Energy's and MGE's liquidity are primarily affected by their construction requirements. MGE's major 2003 capital projects included substation improvements ($3.5 million), AMR project costs ($7.0 million), upgrading its energy management system ($1.6 million).

MGE Energy used funds received as dividend payments from MGE as well as short- and long-term external financing to meet its 2003 capital requirements and cash obligations, including dividend payments. External financing included short-term financing under existing lines of credit and longer-term financing through the issuance of $30 million of 5.68% senior secured notes due September 25, 2033, and the issuance of 165,000 shares of its common stock pursuant to a Distribution Agreement with Banc One Capital Markets, Inc. While dividends from MGE will remain a significant source for the cash needs of MGE Energy, MGE Energy expects that revenues from the WCCF will supplement those dividends starting in 2005 when the WCCF becomes operational. In the interim, MGE Energy expects to continue to use existing lines of credit and to issue additional long-term debt and shares of common stock, in addition to cash dividends from MGE, to meet its capital requirements and other cash obligations, including dividends.

Dividend payments by MGE to MGE Energy are subject to restrictions arising under a January 12, 2004, PSCW rate order and, to a lesser degree, MGE's First Mortgage Bonds. The PSCW order limits the amount of dividends that MGE may pay MGE Energy when its common equity ratio, calculated in the manner used in the rate proceeding, is less than 55%. Under those circumstances, MGE may not pay dividends in excess of $25.1 million plus dividends on shares issued in excess of the shares issued in the rate proceeding forecast if the proceeds are invested in MGE. MGE's common equity ratio at December 31, 2003, as determined under the calculation used in the rate proceeding, is estimated to be 55.4%. The rate proceeding calculation includes as indebtedness imputed amounts for MGE's outstanding purchase power capacity payments and other PSCW adjustments and excludes the indebtedness associated with MGE Power West Campus, which is consolidated in accordance with FIN No. 46-R into MGE's financial statements.

In addition, 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, 2003, approximately $145 million was available for the payment of dividends under this covenant.

MGE used internally generated funds, short-term debt, and proceeds from common stock issued through MGE Energy's Dividend Reinvestment and Direct Stock Purchase Plan to satisfy most of its 2003 capital requirements and expects to do the same in 2004. For the larger capital investments, MGE would expect to finance these with additional long-term debt and capital contributions from MGE Energy.

Financing Activities and Capitalization Matters for MGE Energy and MGE

In 2003, cash provided by MGE Energy's financing activities was $26.2 million. On September 30, 2003, MGE Energy's subsidiary, MGE Power West Campus, issued $30 million in private-placement debt, increasing long-term debt and using the proceeds from this issue to pay off short-term debt. MGE Energy was temporarily financing the capital expenditures for WCCF with short-term debt. MGE refinanced $20.0 million of its 7.70%, 2028 Series, First Mortgage Bonds with lower cost incentives.debt.

Proceeds from the issuance of common stock increased $9.6 million when compared to last year. In addition to its Dividend Reinvestment and Direct Stock Purchase Plan, MGE Energy also has been selling additional shares of stock through Banc One Capital Markets, Inc., under a Distribution Agreement.

Short-term debt decreased $2.6 million in 2003. MGE Energy, through its affiliate MGE Construct, received a reimbursement of $19.4 million in November from the State for its share of the capital expenditures related to WCCF. This reimbursement was used to pay down MGE Energy's bank loan.

In 2002, MGE Energy's cash provided by financing activities was $30.7 million. Short-term debt increased $24.8 million. Two long-term debt issues occurred in the fourth quarter of 2002. A $20.0 million issue replaced the $20.0 million in debt that matured in May, which was rolled into short-term debt at that time. Another $15.0 million issue financed capital expenditures for the AMR project, which had been financed with short-term debt.

In 2003, MGE's cash used for financing activities was $18.9 million. In conformity with FIN No. 46-R, MGE includes the consolidation of MGE Power West Campus (see Footnote 2). MGE Power West Campus had $10.5 million of affiliate loans for the financing of WCCF. MGE benefited from $19.6 million in equity contributions from its parent, which was offset by $29.7 million in cash dividends paid to parent. MGE's short-term debt increased $2.0 million.

In 2002, MGE's cash provided by financing activities was $14.1 million. MGE refinanced $20.0 million of debt in 2002 and issued an additional $15.0 million in November of 2002 to help finance the AMR project.

MGE Energy's and MGE's capitalization ratios were as follows:

Below is a table of MGE's current credit ratings. MGE Energy is not rated because it has not issued any debt securities.

MGE's access to the capital markets, including the commercial paper market, and its financing costs in those markets are dependent on its securities' ratings. None of MGE's borrowing is subject to default or prepayment due to downgrading of securities' ratings.

Contractual Obligations and Commercial Commitments for MGE Energy and MGE

MGE Energy's and MGE's contractual obligations as of December 31, 2003, representing cash obligations that are considered to be firm commitments, are as follows:

For additional information about:

- Long-term debt consisting of secured First Mortgage Bonds and unsecured medium-term notes, see Footnotes 13.c. The long-term debt under MGE Energy is the obligation of MGE Power West Campus. This debt is being consolidated into MGE's financials in accordance with FIN No. 46-R, see Footnote 13.d.

- Short-term debt consisting of commercial paper issued by MGE, which is supported by unused lines of credit from banks and bank loans to MGE Energy, see Footnote 14.

- Operating leases, see Footnote 16.

- Purchase obligations for MGE consist of the purchase of electricity and the purchase and transport of natural gas, see Footnote 16.

- MGE has made a commitment to ATC for an additional capital contribution.

- Commitment to advance funds to ATC for the construction of transmission equipment related to WCCF, see Footnote 17.

- Purchase obligations for MGE Energy related to contracts for equipment and services related to the construction of WCCF, see Footnote 16.f.

- Other long-term obligations are related to a special assessment for decontaminating and decommissioning of nuclear facilities, see Footnotes 3 and 18, and investment in a limited partnership.

MGE Energy's and MGE's commercial commitments as of December 31, 2003, 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:

(a) Lines of credit consisting of a 364-day credit facility to support commercial paper issuances. At December 31, 2003, there were no borrowings against the credit facility. Additionally, at December 31, 2003, there was $15.5 million of commercial paper outstanding.

(b) MGE has a letter of credit with a commercial bank established as collateral for equipment purchases that ATC will make to provide necessary system upgrades for WCCF.

(c) MGE Energy has established a $60.0 million line of credit for temporary financing of the capital commitments for WCCF and for general corporate purposes. Additionally, at December 31, 2003, MGE Energy had $16.2 million in bank loans outstanding.

(d) MGE has guaranteed repayment of certain receivables it sold to a financial institution under a Chattel Paper Agreement (see Footnote 16 of the Notes to Consolidated Financial Statements).

Other Factors

Due to the performance of the United States debt and equity markets, the value of assets held in trusts to satisfy the obligations of pension and postretirement benefit plans has decreased. These factors may also result in additional future funding requirements of the pension and postretirement benefit plans.

Business and Regulatory Environment

Electric Transmission - ATC

On January 1, 2001, MGE transferred substantially all of its electric transmission facilities to ATC in exchange for approximately a 5.0% interest in this joint venture. ATC is comprised of Wisconsin investor-owned utilities and some Wisconsin municipal utilities, cooperatives, and power supply agencies.

The PSCW authorized an electric rate surcharge of $4.5 million, or 2.0%, over a twelve-month period ended October 23, 2003, for MGE to recover deferred costs associated with ATC's formation and ongoing incremental transmission costs during 2001 and 2002.

On November 21, 2002, MGE and ATC entered into an interconnection agreement related to transmission system upgrades for WCCF. MGE issued to ATC a "Notice to Proceed for the Procurement of the Equipment" for the system upgrades. MGE has advanced funds for construction of transmission equipment and work done by ATC related to WCCF in the amounts of $9.2 million and $1.3 million in 2003 and 2002, respectively. MGE expects to advance an additional $0.8 million in 2004. MGE will be reimbursed by ATC upon completion of the project.

Kewaunee Sale

MGE sold to WPSC its 17.8% ownership interest in Kewaunee in September 2001. In exchange for a cash payment of $15.4 million, MGE transferred its net book value of utility plant ($8.2 million), net nuclear fuel ($7.9 million), inventories ($1.5 million), and other assets ($0.1 million). These assets were offset by $2.3 million owed to WPSC. On the closing date, MGE also transferred its qualified decommissioning fund ($65.0 million, fair market value) and nonqualified decommissioning fund ($28.1 million, fair market value), which decreased accumulated depreciation by an equal amount.

Under the Kewaunee sale agreement, MGE was obligated to continue collecting decommissioning costs from its customers during 2002 and to remit those amounts, net of trust investment expenses and taxes on investment income, to the WPSC nonqualified decommissioning fund, which it did on January 3, 2003. MGE has no further obligation with respect to the decommissioning of Kewaunee except as described in the next paragraph with respect to spent nuclear fuel.

The federal government is responsible for the disposition and storage of spent nuclear fuel. Federal legislation is being considered to establish an interim storage facility. Spent nuclear fuel is currently stored at Kewaunee. Minor plant modifications to the spent fuel pools completed in 2001 should ensure Kewaunee has sufficient fuel storage capacity until the end of its licensed life in 2013. MGE retained its spent fuel obligations for all fuel burned at Kewaunee for MGE's share of the generation from the opening of the plant to the closing date. WPSC took title to such fuel at the closing date.

A surcharge imposed by the National Energy Policy Act of 1992 requires nuclear power companies to fund the decontamination and decommissioning of U.S. Department of Energy facilities that process nuclear fuel. As a result, the Kewaunee co-owners are required to pay a surcharge on uranium enrichment services purchased from the federal government prior to October 23, 1992. On an inflation-adjusted basis, MGE's portion of the obligation related to Kewaunee is approximately $0.8 million at December 31, 2003. MGE is required to continue paying its portion of this annual assessment.

As allowed under the Kewaunee sale agreement, MGE exercised an option to purchase 90 MW of electric capacity and energy at a fixed price from September 24, 2001, through September 23, 2003, to help meet customers' electric needs.

Industry Restructuring in Wisconsin

Wisconsin has focused on building the infrastructure needed within the state to provide reliable electric service to customers. Wisconsin has been building new generating capacity, improving existing and adding new electric transmission lines, and continues to develop an independent electric transmission system operator. State regulators realize a competitive market cannot exist when supply is short. The PSCW will decide if or when it is appropriate for retail competition to proceed in the electric industry. MGE cannot predict what impact future PSCW actions may have on its future financial condition, cash flows, and results of operations.

Restructuring the electric industry could affect MGE's ability to continue establishing certain regulatory asset and liability amounts allowed under SFAS No. 71,Accounting for the Effects of Certain Types of Regulation. MGE is unable to predict whether any adjustments to regulatory assets and liabilities will occur in the future. However, the PSCW has recognized the need to allow recovery for commitments made under prior regulation.

Nonutility Energy Outlook

Power the Future Generation

On February 23, 2001, MGE secured an option to own a portion of the advanced technology, coal-fired, base-load generation proposed in We Energies' Power the Future plan. The plan included three new 600-MW coal-fired plants, which would be located in Wisconsin. On November 11, 2003, a PSCW order approved issuing a CPCN for We Energies' proposal for two of the coal facilities. Pursuant to an amended agreement reached on January 31, 2003, MGE has the option to acquire an undivided 8.33% (16.66% under certain conditions) ownership interest in each of the proposed coal plants or up to approximately 50 MW per unit. If the options on Units 1 and 2 are fully exercised, MGE Energy's share of capital costs is estimated to be $175 million. Unit 1 is expected to begin operating in 2009 and Unit 2 is scheduled to begin operating in 2010. MGE has filed its own Certificate of Authority with the PSCW for the coal facilities and a proposed lease structure with an MGE Energy affiliate. MGE expects PSCW approval on this filing in the first half of 2004.

WCCF

The cost to construct WCCF is expected to be approximately $180 million in total, of which MGE Power West Campus' portion will be $103 million. On November 20, 2003, the State paid $19.4 million to MGE Construct for its share of construction costs incurred since its last payment in November 2002. MGE Construct now bills the State monthly for its share of the cost of WCCF in accordance with the EPC Agreement. As of December 31, 2003, MGE Power West Campus had incurred $48.6 million of costs on the project, which is reflected in construction work in progress on MGE Energy's and MGE's consolidated balance sheets. These costs largely represent amounts paid under long lead-time equipment contracts in order to meet project schedules. In 2003, MGE Construct received a service fee of $1.0 million (pretax) from the State in relation to its role as EPC contractor for WCCF. The total fee of $5.0 million will be recognized as services are rendered and will be collected over a 22-month period.

MGE Energy, MGE Power West Campus, and MGE Construct have assumed certain risks related to some of the executed agreements. In the EPC Agreement, MGE Power West Campus is responsible for cost overruns and MGE Construct is responsible for the construction process of the entire facility, paying liquidated damages relating to failure to achieve the Mechanical Completion Date Guarantee and/or the Acceptance Test Capacity Guarantee. MGE Energy is the guarantor of MGE Construct's obligations under the EPC Agreement.

Critical Accounting Policies -MGE Energy and MGE

The preparation of financial statements in conformity with generally accepted accounting principles requires management to apply policies and make estimates and assumptions that affect results of operations and the reported amounts of assets and liabilities in the financial statements. Because of the inherent uncertainty in the nature of the matters where estimates are used, actual amounts could differ from estimated amounts. The following accounting policies represent those that management believes are particularly important to the financial statements and require the use of judgment in estimating matters that are inherently uncertain.

Unbilled Revenues

Revenues from the sale of electricity and gas to customers are generally 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 and, thus, those metersend. 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 therefore, the amount of electricity actually delivered to customers.

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

During 2003, many of MGE's largest customers were shifted to a calendar month bill. As a result of this shift, the majority of these customers' electricity usage is now accounted for in the unbilled calculation. The unbilled amounts are based on actual usage billed the following month and are therefore very reliable. Due to this billing shift, MGE believes thathas seen the ratio of unbilled-to-billed electric sales should typically fall inclimb. The ratio has settled into a 40%range of 45% to 50% range on a monthly basis. A ratio outside that range would indicate a need for further review65%, and analysis. It should be noted that a small change in line loss could have a significant impact on estimated electric unbilled revenues.MGE will continue to monitor and track this range.

Pension Plans

MGE maintains qualified and nonqualified pension plans. MGE also provides health care and life insurance benefits for its retired employees. MGE's pensions are funded through an outside trust. The recent declines in the stock market have resulted in equally consistent declines in the investments in the trusts. The years 2000 through 2002 have been the worst three-year period of pension plan financing ever, which produced the lowest returns since 1929 through 1932. Due to the loss in asset value, MGE is required to record an additional minimum pension liability and corresponding charge to equity at the end of the year.

In addition to the market returns, various other assumptions also affect the investment returns and pension costs.

-Assumed Returnreturn on Assetsassets.. An This assumption as tois the rate of return on plan assets reflecting the average rate of earnings expected on the funds invested or(or to be investedinvested) to provide for the benefits included in the projected benefit obligation. For the year 2002,2003, MGE used a 9.5%9.0% assumed return on assets. This rate was set at the end of 2001.2002. One of the approaches MGE used in determining its assumed return on assets is based on historical returns. As of December 31, 2001,2003, the ten-year historical return was 11.9%11.3%. For 2003, MGE has reduced the assumed return on assets to 9.0%.

-Discount Raterate.. The discount rate for SFAS No. 87 pension cost purposes is a rate at which pension obligations could be effectively settled. MGE bases its rate on high-grade bond yields with a 25 basis point adder. This adder is based on the relatively long duration of pension plan liabilities, benefit payments that are in the form of an annuity, and the rate used has historically been at the top of the range. Moody's Aa Corporate Bond Yield was 6.52%6.01% on December 31, 2002.2003. This approach generated a 6.75%6.25% discount rate (i.e., 6.52%6.01% + 0.25%), rounded).

-Medical Trend Assumptionstrend assumptions.. The health care cost trend rate is the assumed rate of increase in per capitaper-capita health care charges. For 2002, the health trend was reset to 10% with the ultimate trend of 5% reached in 2007. In 2003, the health trend was again reset to 14% with the ultimate trend of 5% reached in 2012.

Tax Provision

MGE Energy's and MGE's 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.

Accounting for Derivative Instruments

MGE accounts for derivative financial instruments under SFAS No. 133,Accounting for Derivatives and Hedging Activities, and SFAS No. 149,Amendment of SFAS No. 133 on Derivative Instruments and Hedging Activities. Under the provisions of SFAS No. 133, all derivatives except those qualifying for the normal purchase normal sale exception are recognized on the balance sheet at their fair value. Fair value is determined using current quoted market prices. If a contract is designated as a cash flow hedge, the change in its market value is generally deferred as a component of other comprehensive income until the transaction it is hedging is completed. Conversely, the change in the market value of a derivative not designated as a cash flow hedge is recorded in current period earnings. A cash flow hedge is a hedge of a forecasted transaction or the variability of cash flows to be received or paid related to a recognized asset or liability. To qualify as a cash flow hedge, the fair value changes in the derivative must be expected to offset 80% to 120% of the changes in fair value or cash flows of the hedged item.

In the third quarter of 2002, MGE received approval from the PSCW to establish a regulatory asset or liability for the deferral of the effects of mark-to-market accounting as required by SFAS No. 133 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 or certain that the regulator will allow future recovery of those costs through rates. MGE bases its assessment of recovery by precedents established by the regulatory body. Regulatory liabilities represent previous collections from customers to fund future expected costs or amounts received in rates that are expected to be refunded to customers in future periods. These costs typically include the recovery of stranded costs due to deregulation, deferral of energy costs, the normalization of income taxes, and the deferral of losses incurred on debt retirements. The accounting for these regulatory assets and liabilities is in accordance with the provisions of SFAS No. 71.

MGE continually assesses whether the regulatory assets continue to meet the criteria for probability of future recovery. 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 periodcurrent-period revenue or expense.

Amortization of regulatory assets is provided over the recovery period as allowed in the related regulatory agreement. It is also included in depreciation and amortization expense. The most significant regulatory assets recorded by MGE include demand-side management programs, decommissioning and decontaminating enrichment facilities, environmental costs, deferred charges related to the setup of ATC, deferred charges on the interest expense of its 2027A Series First Mortgage Bonds, deferred charges related to the effects of mark-to-market accounting as required by SFAS No. 133, and deferred charges related to tax recovery on AFUDC equity (seeequity. See Footnote 1.f.).6 for a listing of these assets and liabilities.

New Accounting Pronouncements

SFAS Nos. 141The most significant regulatory liabilities recorded by MGE include decommissioning and 142

In June 2001,decontaminating enrichment facilities, deferred credits related to the Financial Accounting Standards Board (FASB) issuedaccounting of deferred taxes as required by SFAS No. 141,Business Combinations, and109, amounts recorded for certain gas supply contracts that are considered derivatives under SFAS No. 142,Goodwill133 but are part of the PGA clause authorized by the PSCW, and Other Intangible Assets, that supersedea customer fuel credit.

Adoption of Accounting Principles Board (APB) Opinion No. 16,Business Combinations, and APB Opinion No. 17,Intangible Assets. The two statements modify the method of accounting for business combinationsRecently Issued Accounting Pronouncements - MGE Energy and address the accounting and reporting for goodwill and intangible assets. SFAS No. 141 is effective for all business combinations initiated after June 30, 2001 and, with acquisitions completed after June 30, 2001, for all business combinations accounted for by the purchase method for which the date of acquisition is completed after June 30, 2001. SFAS No. 142 is effective for fiscal years beginning after December 15, 2001. The adoption of SFAS No. 141 and 142 had no impact on the consolidated financial statements.MGE

SFAS No. 143

In June 2001, the FASB issued SFAS No. 143,Accounting for Asset Retirement Obligations. SFAS No. 143 provides accounting requirements for retirement obligations associated with tangible long-lived assets. MGE Energy and MGE were required to adopt SFAS No. 143 as of January 1, 2003. Retirement obligations associated with long-lived assets included within the scope of SFAS No. 143 are those for which there is effectivea legal obligation under existing or enacted law, statute, written or oral contract, or by legal construction under the doctrine of promissory estoppel.

Effective January 1, 2003, requires entities to recordMGE recorded an obligation for the fair value of aits legal liability for an asset retirement obligation inobligations associated with removing an electric substation, a combustion turbine generating unit, wind generating facilities, and the period inphotovoltaic generating facilities, all of which it is incurred. When a neware located on property not owned by MGE and would be removed upon the ultimate end of the lease. At December 31, 2003, this liability is recorded beginningestimated at $1.4 million and is included in 2003,other deferred liabilities.

At the entity will capitalizepoint the costliability for asset retirement is incurred, SFAS No. 143 requires capitalization of the liability by increasingcosts to the carrying amountrelated asset, property, plant, and equipment, net. For asset retirement obligations existing at the time of adoption, the statement requires capitalization of costs at the level that existed at the point of incurring the liability. These capitalized costs are depreciated over the same period as the related property. At the date of adoption, the depreciation expense for past periods was recorded as a regulatory asset in accordance with SFAS No. 71 because MGE believes the PSCW will allow it to recover these costs in future rates. Current depreciation of the related long-lived asset. asset retirement cost is also being deferred as a regulatory asset under SFAS No. 71.

The initial liability is accreted to its present value each period, and the capitalized cost is depreciated over the useful life of the related asset. Upon settlement of the liability, an entity settles the obligation forperiod. MGE defers this accretion as a regulatory asset based on its recorded amount or incurs a gain or loss upon settlement.

determination that these costs can be collected from customers. MGE adopted SFAS No. 143 on January 1, 2003. MGE completed an assessment of the specific applicability and implications of SFAS No. 143. MGE found that SFAS No. 143 has specific applicabilityalso may have asset retirement obligations relating to various electricassets, such as combustion turbine generating units, small distributed generating units, aboveground and substationunderground storage tanks, facilities located on leased property, as well as variousat Columbia (co-owned with Alliant and WPSC), and certain electric and gas distribution facilities. These facilities installedare generally located on easementsproperty owned by third parties, on which MGE is permitted to operate by lease, permit, easement, license, or permits. The asset retirement obligation associated with electric generating and substationservice agreement, but also include some facilities is approximately $1 million.located on property owned by MGE. The asset retirement obligations associated with the electric and gas distributionthese facilities cannot be reasonably estimateddetermined due to anthe indeterminate life of the associatedrelated assets.

The pro forma asset retirement obligation MGE believeswould have recognized as of January 1, 2002, had MGE implemented SFAS No. 143 as of that date, was approximately $1.2 million based on the information, assumptions, and interest rates as of January 1, 2003, used to determine the $1.4 million liability recognized upon initial adoption of SFAS No. 143. Because MGE's regulators are allowing these costs to be recovered in future rates, adoption of SFAS No. 143 results primarily in timing differences in the recognitionfirst quarter of the legal asset retirement obligations2002 would have had no impact on net income and earnings per share of common stock. Accordingly, pro forma impacts are not presented.

The following table shows costs as of January 1, 2003, and changes to the asset retirement obligation and accumulated depreciation during the twelve months ended December 31, 2003.

As of December 31, 2003, MGE's regulatory asset, included in deferred charges, is the total accumulated accretion ($675,000) and accumulated depreciation ($175,000) or $850,000.

MGE made a significant reclassification related to the reporting of accumulated costs which MGE is currently recovering in rates and will be deferring such differences under SFAS No. 71. Early in 2003, MGE received assurance from the PSCWof removal that the adoption of SFASare non-SFAS No. 143 would not result in a change toobligations. The reclass removed the current ratemaking process at this time.costs from accumulated depreciation and recorded them as regulatory liability.

SFAS No. 144

In August 2001, the FASB issued SFAS No. 144,Accounting for the Impairment or Disposal of Long-Lived Assets, which supersedes SFAS No. 121,Accounting for the Impairment of Long-lived Assets and for Long-lived Assets to be Disposed of, and the accounting and reporting provisions of APB No. 30,Reporting the Results of Operations, Reporting the Effects of Disposal of a Segment of a Business, and Extraordinary, Unusual and Infrequently Occurring Events and Transactions. SFAS No. 144 addresses financial accounting and reporting for the impairment or disposal of long-lived assets and is effective for fiscal years beginning after December 15, 2001, and interim periods within those fiscal years. This statement had no material impact on the consolidated financial statements.

SFAS No. 145

In May 2002, the FASB issued SFAS No. 145,Rescission of FASB Statements No. 4, 44, and 64, Amendment of FASB Statement No. 13, and Technical Corrections as of April 2002. SFAS No. 145 rescinds both FASB Statement No. 4 (SFAS 4),Reporting Gains and Losses from Extinguishment of Debt, and the amendment to SFAS 4, FASB Statement No. 64 (SFAS 64),Extinguishments of Debt Made to Satisfy Sinking-Fund Requirements. SFAS No. 145 is effective for transactions occurring after May 15, 2002. This statement does not have a material impact on the consolidated financial statements.

SFAS No. 146

In June 2002, the FASB issued SFAS No. 146,Accounting for Costs Associated with Exit or Disposal Activities. This statement addresses financial accounting and reporting for costs associated with exit or disposal activities and nullifies Emerging Issues Task Force (EITF) Issue No.EITF 94-3,Liability Recognition for Certain Employee Termination Benefits and Other Costs to Exit an Activity (including Certain Costs Incurred in a Restructuring). SFAS No. 146 is effective for transactions initiated after December 31, 2002. ThisAdoption of this statement doesdid not have a material impact on the consolidated financial statements.

SFAS No. 148

In December 2002, the FASB issued SFAS No. 148,Accounting for Stock-Based Compensation- TransitionCompensation-Transition and Disclosure. This statement amends FASB Statement No. 123,Accounting for Stock-Based Compensation, to provide alternative methods of transition for a voluntary change to the fair value-based method of accounting for stock-based employee compensation. In addition, the statement amends the disclosure requirements of Statement 123 to require prominent disclosures in both annual and interim financial statements about the method of accounting for stock-based employee compensation and the effect of the method used on reported results. MGE Energy has no stock options as of December 31, 2002,2003, and therefore SFAS No. 148 willdid not have no impact.

EITF Issue 02-3

EITF Issue 02-3,Accounting for Contracts Involved in Energy Trading and Risk Management Activities (EITF 02-3), issued by the FASB EITF in June 2002, requires revenues and energy costs related to energy trading contracts to be presented on a net basis in the income statement. This EITF has no currentmaterial impact on the consolidated financial statements.

SFAS No. 149

On April 30, 2003, the FASB issued SFAS No. 149,Amendment of SFAS No. 133 on Derivative Instruments and Hedging Activities. This statement amends and clarifies accounting for derivative instruments including certain derivative instruments embedded in other contracts for hedging activities. SFAS No. 149 amends certain other existing pronouncements. The amendments will result in a more consistent reporting of contracts that are derivatives in their entirety or that contain embedded derivatives that warrant separate accounting. SFAS No. 149 is effective for contracts entered into or modified after June 30, 2003. Adoption of this statement did not have a material impact on the consolidated financial statements.

SFAS No. 150

In May 2003, the FASB issued SFAS No. 150,Accounting for Certain Financial Instruments with Characteristics of both Liabilities and Equity. This statement establishes standards for how an issuer classifies and measures certain financial instruments with characteristics of both liabilities and equity. It requires that an issuer classify a financial instrument that is within the scope of SFAS No. 150 as a liability (or an asset in some circumstances). Many of those instruments were previously classified as equity. SFAS No. 150 is effective for interim periods beginning after June 15, 2003, for financial instruments entered into or modified after May 31, 2003, except for mandatorily redeemable financial instruments of nonpublic entities which will be effective for interim periods beginning after December 15, 2003. Adoption of this statement did not have a material impact on the consolidated financial statements.

SFAS No. 132

In December 2003, the FASB issued an amended SFAS No. 132,Employers' Disclosures about Pensions and Other Postretirement Benefits. This revised statement requires additional disclosures to those in the original SFAS No. 132 about the plan assets, obligations, cash flows, and net periodic benefit cost of defined benefit pension plans and other defined benefit postretirement plans.

FIN No. 45

In November 2002, the FASB issued Financial InterpretationFIN No. (FIN) 45,Guarantor's Accounting and Disclosure Requirements for Guarantees, Including Indirect Guarantees of Indebtedness of Others. This interpretation provides the disclosures to be made by a guarantor in interim and annual financial statements about obligations under certain guarantees. The interpretation also clarifies that a guarantor is required to recognize, at the inception of a guarantee, a liability for the fair value of the obligation. The initial recognition

MGE makes available to qualifying customers a financing program for the purchase and measurement requirements are effective prospectively for guarantees issuedinstallation 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 modified after December 31, 2002. However, the disclosure requirementsfinance an undivided interest with recourse, in up to $7.5 million of the interpretationfinancing program receivables, until February 28, 2004. Loans totaling $1.1 million have been sold to the financial institution during 2003. The liability for the fair value of the obligation associated with these loans is not material.

MGE would be required to perform under the guarantee if the customer defaulted on its loan. The energy-related equipment installed at the customer sites is used to secure the customer loans. The length of the MGE guarantee to the financial institution varies from one to ten years depending on the term of the customer loan. Principal payments for the next five years on the loans are effective for this Form 10-K$0.9 million in 2004 and included2005 and $0.8 million in Footnote 8.2006, 2007, and 2008.

FIN No. 46

In January 2003, the FASB issued FIN No. 46,Consolidation of Variable Interest Entities - an Interpretation of ARB No. 51." In December 2003, the FASB issued the updated and final interpretation FIN No. 46-R. FIN No. 46-R requires that an equity investor in a VIE have significant equity at risk (generally a minimum of 10%, that addresses conditions whenwhich is an entity should be consolidated based upon variable interests rather than voting interests. Variable interests are ownership interests or contractual relationships that enableincrease from 3% required under the holder to share in the financial risksprevious guidance) and rewards resulting from the activities ofhold a Variable Interest Entity (VIE). A VIE is a corporation, partnership, trust, or any other legal structure used for business purposes that either does not have equity investors withcontrolling interest, evidenced by voting rights, or has equity investors that do not provide sufficient financial resources for the entity to support its activities.

In order to apply FIN 46, MGE must evaluate every entity with which it is involved through variable interests to determine whether the entity isand absorb a VIE and, if it is, whether or not MGE is the primary beneficiary of the entity. The primary beneficiary of a VIE is the entity that receives the majority of the entity's expected losses, receive a majority of the entity's expected returns, or both. If the equity investor is unable to evidence these characteristics, the entity that retains these ownership characteristics will be required to consolidate the VIE as the primary beneficiary. FIN No. 46 was applicable immediately to VIEs created or obtained after January 31, 2003. FIN No. 46-R was effective on December 31, 2003, for interests in entities that were previously considered special purpose entities under then existing authoritative guidance.

MGE Power West Campus is a VIE pursuant to FIN No. 46-R, as the equity investment at December 31, 2003, was not sufficient to permit the entity to finance its activities without additional support. MGE concluded a VIE relationship exists due to the long-term lease arrangement between MGE and MGE Power West Campus. MGE Power West Campus will lease all of its assets, a power plant, to MGE, pursuant to this leasing arrangement and MGE will absorb a majority of the expected losses, residual returns, or both. As a result, FIN 46 could result in consolidationThe VIE was consolidated into MGE as of an entityDecember 31, 2003.

EITF 03-11

In July 2003, FASB issued EITF 03-11,Reporting Realized Gains and Losses on Derivative Instruments that MGE is associated with other than by (and evenare subject to SFAS No. 133 (Accounting for Derivative Instruments and Hedging Activities), and Not Held for Trading Purposes. This issue addresses whether realized gains and losses should be shown gross or net in the absence of) a voting ownership interest. FIN 46 isincome statement, for contracts that are not believed toheld for trading purposes. This issue will not have a material impact on the consolidated financialfinancials statements.

FSP 106-1

In January 2004, the FASB issued FASB Staff Position No. FAS 106-1 (FSP 106-1),Accounting and Disclosure Requirements Related to the Medicare Prescription Drug, Improvement and Modernization Act of 2003 (the Act). FSP 106-1 permits employers that sponsor postretirement benefit plans (plan sponsors) that provide prescription drug benefits to retirees to make a one-time election to defer accounting for any effects of the Act. The FSP 106-1 requires all plan sponsors to provide certain disclosures, regardless of whether they choose to account or defer accounting. FSP 106-1 is effective for annual fiscal periods ending after December 7, 2003. If deferral is elected, the deferral must remain in effect until the earlier of (1) the issuance of guidance by the FASB on how to account for the federal subsidy to be provided to plan sponsors under the Act or (2) the remeasurement of plan assets and obligations subsequent to January 31, 2004. MGE has elected to defer recognition of the Act.

SEC SAB No. 104

In December 2003, the SEC issued SAB No. 104 regarding revenue recognition. SAB No. 104 revises or rescinds portions of the interpretive guidance included in Topic 13 of the codification of Staff Accounting Bulletins to make the guidance consistent with current authoritative accounting and auditing guidance and SEC rules and regulations. MGE Energy and MGE will comply with the revised guidance.

Inflation

The current financial statements report operating results in terms of historical cost, but they do not evaluate the impact of inflation. Because utilities can depreciate only the historical cost of utility plant, there may not be adequate cash flows from existing plant to replace this investment. Under PSCW rate treatment, projected operating costs, including the impacts of inflation, are recovered in revenues.

Item 7A. Quantitative and Qualitative Disclosures aboutAbout Market Risk.Risk - MGE Energy and MGE.

Market Risks

MGE isEnergy and MGE are potentially exposed to market risk associated with interest rates, commodity prices, weather, and equity returns. MGE currently has no exposure to foreign currency risk. MGE manages some risk exposure through risk management policies and uses derivative instruments. MGE's market risk has not changed between 2003 and 2002. MGE does not enter into speculative trading transactions.

Interest Rate Risk

MGE issues commercial paper at varying interest rates for its short-term borrowings (see Footnote 6.d.)14). MGE also has $15.0 million in variable rate long-term debt outstanding as of December 31, 2002.2003. Borrowing levels under commercial paper arrangements 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 has a swap agreement with a commercial bank at a notional amount of $5.0 million, backed by MGE's commercial paper. MGE pays a fixed rate of 6.91% on the swap, which was used to replace a portion of MGE's 7.70%, 2028 Series, First Mortgage Bonds. MGE manages its interest rate risk by limiting its 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. MGE records the changes in the fair market value of its commercial paper swap agreement currently in the income statement as required by SFAS No. 133 each period, which is then offset by a corresponding regulatory asset or liability in accordance with authorization received from the PSCW.

Commodity Price Risk

MGE has commodity price risk exposure with respect to the price of natural gas, electricity, coal, and oil. MGE employs established policies and procedures to reduce the market risks associated with changing commodity prices, including the use of commodity and financial instruments (see Footnote 5)12). MGE's commodity risks are somewhat mitigated by the current ratemaking process in place for recovering electric fuel, purchased energy, and the cost of natural gas purchased for resale. MGE's electric fuel costs are subject to fuel rules established by the PSCW, which further mitigate commodity risk. Under the fuel rules, if electric fuel costs exceed or fall below a 3.0% bandwidth set by the PSCW, MGE can apply for a fuel surcharge or may have a fuel credit to its customers. Under the PGA authorized by the PSCW, MGE passes through to customers the cost of gas, subject to certain limited incentives.

Under the fuel rules, MGE may include the costs and benefits of fuel price risk management tools implemented under a risk management plan approved by the PSCW. In 2003, the PSCW approved MGE's Electric Procurement Risk Management Program, with conditions, through December 31, 2004. No transactions have occurred under this program through December 31, 2003.

MGE has a limited number of financial gas commodity contracts. These contracts are primarily comprised of exchange-traded option contracts to manage the cost of gas and over-the-counter financial floating-to-fixed price swaps and calls for the Winter"Winter Set-Price Firm Gas Sales ServiceService" pilot program. The derivative amounts recorded as a result of these gas contracts are offset with a corresponding regulatory asset or liability because these transactions are part of the PGA and not subject to incentive participation.

Weather Risk

MGE's sales forecasts, used to establish rates, are set by the PSCW based upon estimated temperatures, which approximate 20-year averages. MGE's electric revenues are sensitive to the summer cooling season and, to some extent, to the winter heating season. A significant portion of MGE's gas system demand is driven by heating. MGE's gas margin (revenues less gas purchased) areis collected under a combination of fixed and volumetric rates set by the PSCW based on "normal weather." As a result of weather-sensitive demand and volumetric rates, a portion of MGE's gas margin is at risk for warmer-than-normal weather. MGE usesmay use weather derivatives, pursuant to its risk management program, to reduce the impact of weather volatility on its gas margins.margin.

In August 2003, MGE purchased a nonexchange-traded Heating Degree Day (HDD) Put Option with a strike of 5,500 HDD and sold a nonexchange-traded HDD Call Option with a strike of 5,800 HDD. The options have a net premium cost of $0.1 million; notional amounts of $2,500 per HDD; a maximum HDD-related receipt or payment of $1.0 million; terms covering November 1, 2003, through March 31, 2004; and financial settlements against Madison weather. If the total actual HDD, as calculated under the contract, is greater than 5,800, MGE will pay. If the total actual HDD is less than 5,500, MGE receives payment. For the contract period, MGE's average gas margin per HDD at risk is estimated to exceed $2,500. MGE is accounting for the HDD options using the intrinsic value method pursuant to EITF 99-2,Accounting for Weather Derivatives. Through December 31, 2003, actual HDD were 1,984 and contract allocated HDD strikes were 2,087 and 2,201, resulting in a $0.3 million gain for MGE.

A summary of actual weather information in the utility segment's service territory during 2003, 2002, 2001, and 2000,2001, as measured by degree days, may be found above in Results of Operations.

Regulatory Recovery Risk

TheMGE's electric operations of MGE burn natural gas in several of its peak power plants or as a supplemental fuel at several coal-fired plants--and in many cases, the cost of purchased power is tied to the cost of natural gas. MGE bears significant 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.

As noted above in Commodity Price Risk, the electric operations of MGE operate under a "fuel rules" adjustment clause for fuel and purchased power costs associated with the generation and delivery of electricity. This clause establishes a base rate for fuel and purchased power. MGE assumes the risks and benefits of variances that are within a 3.0% bandwidth. For 20022003 and 2001,2002, fuel and purchased power costs included in MGE's base fuel rates were $85.1$81.0 million and $60.1$85.1 million, respectively. In 2003 and 2002, the base fuel rates included a fuel credit in the amount of $4.0 million and $1.2 million.million, respectively.

Equity Price RisksRisk

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. 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.

Credit RisksRisk

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 includes 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.

MGE is obligated to provide service to all electric and gas customers within its respective franchised territories. As a result, MGE has a broad customer base. For the year ended December 31, 2002,2003, MGE's ten largest electric customers represented approximately 18.3%17.3% of its retail electric revenues. MGE's ten largest gas customers represented approximately 5.4% of its gas revenues. Credit risk for electric and gas is managed by MGE's credit and collection policies, which are consistent with state regulatory requirements.

Item 8. Financial Statements and Supplementary Data.

ReportsReport of Independent AccountantsAuditors

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

In our opinion, the consolidated financial statements listed in the accompanying index appearing under Item 15(a)15 (a)(1) present fairly, in all material respects, the financial position of MGE Energy, Inc. and its subsidiaries at December 31, 20022003 and December 31, 2001,2002, and the results of their operations and their cash flows for each of the three years in the period ended December 31, 20022003 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 accompanying index appearing under Item 15(a)15 (a)(2) presentspresent 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'sCompany'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 auditing standards generally accepted in the United States of America, which 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.

As discussed in Note 1 to the consolidated financial statements, effective August 12, 2002, MGE Energy, Inc. became the holding company for Madison Gas and Electric Company (MGE). As a result of the formation of the holding company, an exchange of shares of MGE Energy, Inc. common stock for shares of MGE common stock occurred. The MGE Energy, Inc.Inc financial statements reflect this transaction for all periods presented.

/s/ PricewaterhouseCoopers LLP
Chicago, Illinois
February 6, 200327, 2004

Report of Independent Auditors

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

In our opinion, the consolidated financial statements listed in the accompanying index appearing under Item 15(a)15 (a)(1) present fairly, in all material respects, the financial position of Madison Gas and Electric Company and its subsidiaries at December 31, 20022003 and December 31, 2001,2002, and the results of their operations and their cash flows for each of the three years in the period ended December 31, 20022003 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 accompanying index appearing under Item 15(a)15 (a)(2) presentspresent 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'sCompany'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 auditing standards generally accepted in the United States of America, which 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.

As discussed in Note 2 to the consolidated financial statements, the Company adopted certain provisions of Financial Accounting Standards Board Interpretation No. 46, "Consolidation of Variable Interest Entities - an interpretation of ARB 51 (revised December 2003)," as of December 31, 2003.

/s/ PricewaterhouseCoopers LLP
Chicago, Illinois
February 6, 200327, 2004

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