10-K

United States

SECURITIES AND EXCHANGE COMMISSION

Washington, D.C. 20549

FORM 10-K

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

For the fiscal year ended:

December 31, 2022

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

For the transition period from _______________ to _______________


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

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

 
Title of Class

 
Trading Symbol

Name of Each Exchange on which Registered

MGE Energy, Inc.

Common Stock, $1 Par Value Per Share

MGEE

The NASDAQ Stock Market

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


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

Indicate by check mark if the registrants are well-known seasoned issuers, as defined in Rule 405 of the Securities Act.

MGE Energy, Inc. Yes ☒ No ☐ Madison Gas and Electric Company Yes ☒ No ☐

Indicate by check mark if the registrants are not required to file reports pursuant to Section 13 or Section 15(d) of the Act.

MGE Energy, Inc. Yes ☐ No ☒ Madison Gas and Electric Company Yes ☐ No ☒

Indicate by check mark whether the registrants (1) have filed all reports required to be filed by Section 13 or 15(d) of the Securities Exchange Act of 1934 during the preceding 12 months (or for such shorter period that the registrants were required to file such reports) and (2) have been subject to such filing requirements for the past 90 days.

MGE Energy, Inc. Yes ☒ No ☐ Madison Gas and Electric Company Yes ☒ No ☐

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

MGE Energy, Inc. Yes ☒ No ☐ Madison Gas and Electric Company Yes ☒ No ☐

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


	Large Accelerated Filer	Accelerated Filer	Non-accelerated Filer	Smaller Reporting Company	Emerging Growth Company
MGE Energy, Inc.	☒	☐	☐	☐	☐
Madison Gas and Electric Company	☐	☐	☒	☐	☐

If an emerging growth company, indicate by checkmark if the registrants have elected not to use the extended transition period for complying with any new or revised financial reporting standards provided pursuant to Section 13(a) of the Exchange Act.

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

Indicate by check mark whether the registrant has filed a report on and attestation to its management’s assessment of the effectiveness of its internal control over financial reporting under Section 404(b) of the Sarbanes-Oxley Act (15 U.S.C. 7262(b)) by the registered public accounting firm that prepared or issued its audit report.

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

If securities are registered pursuant to Section 12(b) of the Act, indicate by check mark whether the financial statements of the registrant included in the filing reflect the correction of an error to previously issued financial statements.

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

Indicate by check mark whether any of those error corrections are restatements that required a recovery analysis of incentive-based compensation received by any of the registrant’s executive officers during the relevant recovery period pursuant to §240.10D-1(b).

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

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

MGE Energy, Inc. Yes ☐ No ☒ Madison Gas and Electric Company Yes ☐ No ☒

The aggregate market value of the voting and nonvoting common equity held by nonaffiliates of each registrant as of June 30, 2022 was as follows:


MGE Energy, Inc.	$2,808,969,657
Madison Gas and Electric Company	$0

The number of shares outstanding of each registrant's common stock as of January 31, 2023, were as follows:


MGE Energy, Inc.	36,163,370
Madison Gas and Electric Company	17,347,894

DOCUMENTS INCORPORATED BY REFERENCE

Portions of MGE Energy, Inc.'s definitive proxy statement to be filed before April 30, 2023, relating to its annual meeting of shareholders, are incorporated by reference into Part III of this annual report on Form 10-K.

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

Table of Contents


Filing Format.		4
Forward-Looking Statements.		4
Where to Find More Information.		4
Definitions, Abbreviations, and Acronyms Used in the Text and Notes of this Report.		5
PART I.		7
	Item 1. Business.	7
	Item 1A. Risk Factors.	18
	Item 1B. Unresolved Staff Comments.	26
	Item 2. Properties.	27
	Item 3. Legal Proceedings.	29
	Item 4. Mine Safety Disclosures.	29
PART II.		30
	Item 5. Market for Registrants' Common Equity, Related Stockholder Matters, and Issuer Purchases of Equity Securities.	30
	Item 6. [Reserved].	30
	Item 7. Management's Discussion and Analysis of Financial Condition and Results of Operations.	31
	Item 7A. Quantitative and Qualitative Disclosures About Market Risk.	49
	Item 8. Financial Statements and Supplementary Data.	51
	Item 9. Changes in and Disagreements with Accountants on Accounting and Financial Disclosure.	108
	Item 9A. Controls and Procedures.	108
	Item 9B. Other Information.	108
	Item 9C. Disclosure Regarding Foreign Jurisdictions that Prevent Inspections.	108
PART III.		109
	Item 10. Directors, Executive Officers, and Corporate Governance.	109
	Item 11. Executive Compensation.	109
	Item 12. Security Ownership of Certain Beneficial Owners and Management and Related Stockholder Matters.	109
	Item 13. Certain Relationships and Related Transactions, and Director Independence.	110
	Item 14. Principal Accounting Fees and Services.	110
PART IV.		111
	Item 15. Exhibits and Financial Statement Schedules.	111
	Item 16. Form 10-K Summary.	114
	Signatures - MGE Energy, Inc.	119
	Signatures - Madison Gas and Electric Company.	120

Filing Format

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

Forward-Looking Statements

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

The factors that could cause actual results to differ materially from the forward-looking statements made by a registrant include (a) those factors discussed in Item 1A. Risk Factors, Item 7. Management's Discussion and Analysis of Financial Condition and Results of Operations, and Item 8. Financial Statements and Supplementary Data, Footnote 16. Commitments and Contingencies, and (b) other factors discussed herein and in other filings made by that registrant with the SEC.

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

Where to Find More Information

We file annual reports on Form 10-K, quarterly reports on Form 10-Q and current reports on Form 8-K and other information with the SEC. The SEC maintains an internet site at www.sec.gov that contains reports, proxy and information statements, and other information regarding issuers that file electronically with the SEC.

MGE Energy maintains a website at mgeenergy.com, and MGE maintains a website at mge.com. Copies of the reports and other information that we file with the SEC may be obtained from our websites free of charge. Information contained on MGE Energy's and MGE's websites shall not be deemed incorporated into, or to be a part of, this report.

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

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


MGE Energy and Subsidiaries:

CWDC		Central Wisconsin Development Corporation
MAGAEL		MAGAEL, LLC
MGE		Madison Gas and Electric Company
MGE Energy		MGE Energy, Inc.
MGE Power		MGE Power, LLC
MGE Power Elm Road		MGE Power Elm Road, LLC
MGE Power West Campus		MGE Power West Campus, LLC
MGE Services		MGE Services, LLC
MGE State Energy Services		MGE State Energy Services, LLC
MGE Transco		MGE Transco Investment, LLC
MGEE Transco		MGEE Transco, LLC
North Mendota		North Mendota Energy & Technology Park, LLC

Other Defined Terms:

2017 Tax Act		Tax Cuts and Jobs Act of 2017
2020 Plan		MGE Energy's 2020 Performance Unit Plan
2021 Incentive Plan		MGE Energy's 2021 Long-Term Incentive Plan
AFUDC		Allowance for Funds Used During Construction
ANR		ANR Pipeline
ARO		Asset Retirement Obligation
ATC		American Transmission Company LLC
ATC Holdco		ATC Holdco, LLC
Badger Hollow I		Badger Hollow I Solar Farm
Badger Hollow II		Badger Hollow II Solar Farm
BART		Best Available Retrofit Technology
Blount		Blount Station
BTA		Best Technology Available
CA		Certificate of Authority
CAA		Clean Air Act
CASAC		Clean Air Scientific Advisory Committee
CBP		United States Customs and Border Patrol
CAVR		Clean Air Visibility Rule
CCR		Coal Combustion Residual
CO2		Carbon Dioxide
codification		Financial Accounting Standards Board Accounting Standards Codification
Columbia		Columbia Energy Center
Cooling degree days (CDD)		Measure of the extent to which the average daily temperature is above 65 degrees Fahrenheit, which is considered an indicator of possible increased demand for energy to provide cooling
COVID-19		Coronavirus Disease 2019 and its variants
COSO		Committee of Sponsoring Organizations
CSAPR		Cross-State Air Pollution Rule
CWA		Clean Water Act
D.C. Circuit		United States Court of Appeals for the District of Columbia Circuit
Dth		Dekatherms
EEI		Edison Electric Institute
ELG		Effluent Limitations Guidelines
Elm Road Units		Elm Road Generating Station
EPA		United States Environmental Protection Agency
FASB		Financial Accounting Standards Board
FIP		Federal Implementation Plan
FERC		Federal Energy Regulatory Commission
Forward Wind		Forward Wind Energy Center
FTR		Financial Transmission Rights
GAAP		Generally Accepted Accounting Principles
GHG		Greenhouse Gas


heating degree days (HDD)		Measure of the extent to which the average daily temperature is below 65 degrees Fahrenheit, which is considered an indicator of possible increased demand for energy to provide heating
ICF		Insurance Continuance Fund
IPCC		Intergovernmental Panel on Climate Change
IRA		Inflation Reduction Act
IRS		Internal Revenue Service
kVA		Kilovolt Ampere
KW		Kilowatt, a measure of electric energy generating capacity
kWh		Kilowatt-hour
MISO		Midcontinent Independent System Operator, Inc. (a regional transmission organization)
MW		Megawatt
MWh		Megawatt-hour
NAAQS		National Ambient Air Quality Standards
Nasdaq		The Nasdaq Stock Market
NERC		North American Electric Reliability Corporation
NNG		Northern Natural Gas Company
NOx		Nitrogen Oxides
NSPS		New Source Performance Standards
NYSE		New York Stock Exchange
O'Brien		O'Brien Solar Fields
OSCE		State of Wisconsin's Office of Sustainability and Clean Energy
Paris		Paris Solar and Battery Park
Paris Agreement		Paris Agreement under the United Nations Framework Convention on Climate Change
PCBs		Polychlorinated Biphenyls
the Petition		Petition for Judicial Review of Agency Action
PGA		Purchased Gas Adjustment clause
PM		Particulate Matter
PPA		Purchased power agreement
PSCW		Public Service Commission of Wisconsin
REC		Renewable Energy Credit
RER		Renewable Energy Rider
Riverside		Riverside Energy Center in Beloit, Wisconsin
ROE		Return on Equity
RTO		Regional Transmission Organization
Saratoga		Saratoga Wind Farm
SCR		Selective Catalytic Reduction
SEC		Securities and Exchange Commission
SIP		State Implementation Plan
SO2		Sulfur Dioxide
SOFR		Secured Overnight Funding Rate
the State		State of Wisconsin
Stock Plan		Direct Stock Purchase and Dividend Reinvestment Plan of MGE Energy
Two Creeks		Two Creeks Solar Farm
USDOC		United States Department of Commerce
UW		University of Wisconsin at Madison
VIE		Variable Interest Entity
WCCF		West Campus Cogeneration Facility
WDNR		Wisconsin Department of Natural Resources
WEPCO		Wisconsin Electric Power Company
working capital		Current assets less current liabilities
WOTUS		Waters of the United States
WPDES		Wisconsin Pollutant Discharge Elimination System
WPL		Wisconsin Power and Light Company
WPSC		Wisconsin Public Service Corporation
WRERA		Worker, Retiree and Employer Recovery Act of 2008
XBRL		eXtensible Business Reporting Language

PART I.

Item 1. Business.

MGE Energy operates in the following business segments:

•

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

•

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

•

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

•

Transmission investments – representing our investment in American Transmission Company LLC, a company engaged in the business of providing electric transmission services primarily in Wisconsin, and our investment in ATC Holdco LLC, a company created to facilitate out-of-state electric transmission development and investments.

•

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

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

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

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

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

Electric Utility Operations

MGE distributes electricity in a service area covering a 264 square-mile area of Dane County, Wisconsin. The service area includes the city of Madison, Wisconsin. It owns or leases ownership interests in electric generation facilities located in Wisconsin and Iowa.

As of December 31, 2022, MGE supplied electric service to approximately 161,000 customers, with approximately 90% located in the cities of Fitchburg, Madison, Middleton, and Monona and 10% in adjacent areas.

Electric sales, customers, and revenues for 2022 were comprised of the following:

Electric operations accounted for approximately 65.2%, 69.4%, and 73.2% of MGE's total 2022, 2021, and 2020 regulated revenues, respectively.

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

MGE is registered with North American Electric Reliability Corporation (NERC) and one regional entity, the Midwest Reliability Organization. The essential purposes of these entities are to develop and implement regional and NERC reliability standards and determine compliance with those standards, including enforcement mechanisms.

Transmission

American Transmission Company LLC (ATC) was formed by Wisconsin-based utilities who were required by Wisconsin law to contribute their transmission facilities to it in 2001 and is owned by those utilities and their affiliates. ATC's purpose is to provide reliable, economic transmission service to all customers in a fair and equitable manner. ATC plans, constructs, operates, maintains, and expands transmission facilities that it owns to provide adequate and reliable transmission of power. ATC is regulated by FERC for all rate terms and conditions of service. ATC is also regulated by the PSCW for some aspects of its governance and is a transmission-owning member of the MISO.

Regional Transmission Organizations (RTO)

MISO

MGE is a nontransmission owning member of MISO. MISO, a FERC-approved RTO, is responsible for monitoring the electric transmission system that delivers power from generating plants to wholesale power customers. MISO's role is to ensure equal access to the transmission system and to maintain or improve electric system reliability across 15 U.S. states and the Canadian province of Manitoba.

MISO operates a bid-based energy market. MGE offers substantially all of its generation to the MISO market and purchases its load requirement from the MISO market in accordance with the MISO tariff. MGE also participates in the ancillary services market operated by MISO, which is an extension of the existing energy market. Through the operation of the ancillary services market, MISO provides the reserves for MGE's load, and MGE may offer to sell reserves from its generating units.

MGE participates in the MISO capacity auction, which provides a forum for buyers and sellers of planning resource credits to interact. Load serving entities such as MGE may participate in the capacity auction to obtain the necessary aggregate planning resource credits needed to meet their planning reserve margin requirement established by the PSCW. Generator owners may participate to sell any excess aggregate planning resource credits.

Fuel supply and generation

MGE satisfies its customers' electric demand with internal generation and purchased power. MGE's current fuel mix for generation fluctuates from year-to-year due to fuel pricing in the market, generating unit availability, weather, and customer demand. MGE has a responsibility to its customers to dispatch the lowest cost generation available pursuant to regulatory requirements.

MGE's electric energy delivery requirements were satisfied from the following fuel sources:


(in MWh)	2022		2021		2020
Coal		1,219,793		1,797,017		1,566,204
Natural gas		539,265		405,696		502,387
Renewable sources(a)		759,194		581,374		485,965
Fuel oil		475		884		472
Purchased power - other(b)(c)		919,052		726,008		789,058
Total fuel sources		3,437,779		3,510,979		3,344,086

Adjusted total fuel sources(c)		3,741,207		3,743,743		3,663,569

(a)

Includes both internal generation and purchased power.

(b)

Includes third-party purchased power and MISO market activity. A significant percentage of MGE's electric supply comes from internal generation sources. MGE supplements this internal generation with long-term purchase power agreements and spot purchases in the MISO market.

(c)

The MISO market consists of two energy markets, the Day-ahead market and the Real-time market. The table above nets purchases and sales within the same hour in the two MISO markets. For the years ended December 31, 2022, 2021, and 2020, the amount netted between Day-ahead and the Real-time MISO markets was 303,428 MWh, 232,764 MWh, and 319,483 MWh, respectively. These amounts are reflected in "Adjusted total fuel sources."

MGE is working toward a more sustainable future for the benefit of all its investors, employees, customers and the broader community. MGE is targeting net-zero carbon electricity by 2050. In early 2022, MGE committed to achieving carbon reductions of at least 80% by 2030, from 2005 levels.

MGE's carbon reduction goals are aligned with those of the scientific community, specifically the Intergovernmental Panel on Climate Change (IPCC) and its recommendation of limiting global temperature increases to 1.5 degrees Celsius above pre-industrial levels. In 2020, the University of Wisconsin-Madison's Nelson Institute for Environmental Studies released its analysis of MGE's goal of reaching net-zero carbon electricity by 2050. The IPCC modeling available suggested that by 2050, emissions from electricity generation in industrialized countries should be 87% to 99% lower than the 2005 baseline. The study determined that our 2050 goal is in line with model benchmarks to limit global warming to 1.5 degrees Celsius above pre-industrial levels.

MGE is working to achieve a more sustainable energy future using the best, most cost-effective technologies as they become available. MGE's future path to achieve its new target of 80% carbon reduction by 2030 is based on the transition away from coal and the addition of new renewable generation to reach our ultimate target of net-zero carbon by 2050. MGE already has taken action toward its goals:

•

Transition away from coal - In February 2021, MGE and the other co-owners of Columbia, a two-unit coal-fired generation facility located near Portage, Wisconsin, announced plans to retire that facility. MGE currently owns 19% of the facility. The co-owners intend to retire Unit 1 and Unit 2 by June 2026. Final timing and retirement dates are subject to change depending on operational, regulatory, and other factors. By 2027, with the planned retirement of both units at Columbia, MGE will have eliminated approximately two-thirds of the company’s current coal-fired generation capacity. MGE's remaining use of coal is expected to be further reduced as the Elm Road Units transition to natural gas. MGE is a minority owner of the coal-fired Elm Road Generating Station in Oak Creek, Wisconsin. In late 2021, MGE announced plans to end the use of coal as a primary fuel at the Elm Road Units and transition the plant to natural gas. Transition plans and costs will be subject to PSCW approval. By the end of 2030, MGE expects coal to be used only as a backup fuel at the Elm Road Units. This transition will help MGE meet its 2030 carbon reduction goal. By 2035, MGE expects that the Elm Road Units will be fully transitioned away from coal, which will eliminate coal as an owned generation source for MGE.

•

Renewable generation - Our solar, wind, and battery storage projects, as described below, are a major step toward deep decarbonization and greater use of clean energy sources in pursuit of our net-zero carbon goal. Additionally, MGE seeks to reduce its use of fossil fuels and work to help customers with energy efficiency and electrification, including the electrification of transportation.

Since 2015, MGE has announced several new joint and wholly-owned utility-scale wind and solar projects, which are expected to increase MGE's owned renewable capacity by more than nine times when completed. The following is a timeline of when these renewable energy projects have been completed, expected to be completed, or proposed to be completed, and MGE's share of capacity.


Year of Commercial Operation	Renewable Energy Project	Fuel Type	Share of Generation
2017	Shared Solar	Solar	.5 MW
2018	Forward Energy Center	Wind	17.6 MW
2019	Saratoga	Wind	66 MW
2020	Morey Field (RER/Shared Solar)	Solar	2.5 MW/3.5 MW
	Two Creeks	Solar	50 MW
	Dane County Airport (RER)	Solar	10 MW
2021	Badger Hollow I	Solar	50 MW
	O’Brien (RER)	Solar	22 MW
2022	Hermsdorf (RER)	Solar	8 MW
2023	Red Barn - under construction	Wind	9.16 MW
	Badger Hollow II - under construction	Solar	50 MW
	Paris - under construction	Solar/Battery(b)	20 MW/11 MW
	Tyto - under construction	Solar	6 MW
2024	Darien	Solar/Battery(b)	25 MW/7.5 MW
2025	Koshkonong – proposed(a)	Solar/Battery(b)	30 MW/16.5 MW

(a)

Pending approval by the PSCW.

(b)

Battery storage timing to be determined.

MGE is working to achieve a more sustainable energy future by investing in cost-effective renewable generation and innovative new technologies and services for customers. MGE has emphasized this innovation by developing customer programs to address climate change and encourage our customers to use clean energy. Our Renewable Energy Rider and Shared Solar programs reduce MGE's carbon emissions while providing customers the ability to purchase renewable energy to meet their energy needs, and we have been working on many fronts in the community to further the electrification of transportation.

Renewable Energy Rider (RER) – Under this program, MGE partners with large energy users on customized renewable energy solutions. MGE owns the generation assets and RER customers are billed a contractual renewable resource rate for all costs associated with the construction and ongoing operations of the renewable generation facility. This contractual rate is approved by the PSCW and subject to terms and conditions specified in the RER rate schedule. The program entitles RER customers to the contractually-specified energy output of the renewable energy resource. MGE will continue to recover the distribution system costs related to the energy consumed by these customers. Dane County Solar serves the Dane County municipal government. Morey Field RER serves the City of Middleton and Middleton-Cross Plains School District. The O'Brien Solar Fields primarily serve governmental entities such as UW-Madison, Wisconsin Department of Administration, and the City of Fitchburg. Hermsdorf serves the City of Madison and Madison Metropolitan School District. MGE has completed construction of 42.5 MW of capacity for the RER program.

Shared Solar Program – This program provides an opportunity for residential and small business customers the option to power their household or business with locally generated solar energy for up to half of their annual energy use. It's an affordable option for customers who want to support local solar. The first solar array associated with this program, owned by MGE, became operational in 2017 and was fully subscribed for its capacity value of 500 KW. MGE expanded the program by completing construction of a second solar facility (Morey Field), which added 3.5 MW of capacity to the program.

Electrifying transportation - The electrification of transportation is a key strategy for reducing carbon emissions. MGE has a network of more than 45 charging stations, powered by renewable energy, serving the growing number of electric vehicles (EV) in our service area. The new EV fast charging hub began serving drivers in late 2021 and features some of the most powerful EV chargers in the Midwest. Charge@Home, MGE's home EV charging program, makes it easy for EV drivers to charge efficiently and conveniently. We have continued to add EVs to our fleet and are targeting 100% all-electric or plug-in hybrid light-duty vehicles by 2030. Additionally, we are working with the City of Madison to further the electrification of its vehicles and buses. The City of Madison currently has a goal of 100% electric buses used for its' new Bus Rapid Transit system located in the downtown region.

•

Natural gas as a fuel source - In December 2022, the PSCW approved MGE's request for its purchase of an ownership interest in the West Riverside Energy Center, a highly efficient, state-of-the-art natural gas-fired plant in Beloit, Wisconsin. MGE's share of West Riverside will be 25 MW. The acquisition of that ownership interest is expected to occur in March 2023. MGE also has an option to purchase an additional 25 MW of capacity from West Riverside until May 2025. MGE currently expects to file in the first half of 2023 with the PSCW a request for a purchase of the additional 25 MW. Natural gas has much lower carbon emission rates compared to coal-fired generation. The investment in the West Riverside plant will help MGE to retire the Columbia coal-fired facility ahead of schedule.

Generation sources

MGE receives electric generation supply from coal-fired, gas-fired, and renewable energy sources. These sources include owned facilities as well as facilities leased from affiliates and accounted for under our nonregulated energy operations. See Item 2. Properties for more information regarding these generation sources, including location, capacity, ownership or lease arrangement, and fuel source. See "Nonregulated Energy Operations" below for more information regarding generating capacity leased to MGE by nonregulated subsidiaries.

Purchased power

MGE enters into short- and long-term purchase power commitments with third parties to meet a portion of its anticipated electric energy supply needs. As of December 31, 2022, MGE has 30 MW of a renewable purchase power commitment for each of the next five years.

Gas Utility Operations

MGE transports and distributes natural gas in a service area covering 1,684 square miles in seven south-central Wisconsin counties. The service area includes the city of Madison, Wisconsin and surrounding areas.

As of December 31, 2022, MGE supplied natural gas service to approximately 173,000 customers in the cities of Elroy, Fitchburg, Lodi, Madison, Middleton, Monona, Prairie du Chien, Verona, and Viroqua; 25 villages; and all or parts of 50 townships. Gas sales, customers, and revenues for 2022 were comprised of the following:

Gas operations accounted for approximately 34.8%, 30.6%, and 26.8% of MGE's total 2022, 2021, and 2020 regulated revenues, respectively.

MGE can curtail gas deliveries to interruptible customers. These are customers who agree to reduce their load in the case of an emergency interruption. Approximately 3% of retail gas deliveries in 2022, 2021 and 2020 were to interruptible customers.

Gas supply

MGE has physical interconnections with ANR Pipeline Company (ANR) and Northern Natural Gas Company (NNG). MGE's primary service territory, which includes Madison and the surrounding area, receives deliveries at one NNG and four ANR gate stations. MGE's outlying territory 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 the mid-continent and Gulf Coast regions of the United States.

During the winter months, when customer demand is high, MGE is primarily concerned with meeting its obligation to 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 6,515,510 Dth of gas can be injected into ANR's storage fields in Michigan from April 1 through October 31. These gas supplies are then available for withdrawal during the subsequent heating season, November 1 through March 31. Using storage allows MGE to buy gas supplies during the summer season, when prices are normally lower, and withdraw these supplies during the winter season, when prices are typically higher. Storage also gives MGE more flexibility in meeting daily load fluctuations.

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

•

185,650 Dth (including 116,078 Dth of storage withdrawals) on ANR.

•

80,410 Dth on NNG.

Nonregulated Energy Operations

MGE Energy, through our subsidiaries, has developed generation sources that assist MGE in meeting the electricity needs of our customers. These sources consist of the Elm Road Units and the WCCF, which are owned by subsidiaries of MGE Energy and leased to MGE. See Item 2. Properties for a description of these facilities, their joint owners, and the related lease arrangements.

Transmission Investments

ATC owns and operates electric transmission facilities primarily in Wisconsin. MGE received an interest in ATC when it, like other Wisconsin electric utilities, contributed its electric transmission facilities to ATC as required by Wisconsin law. That interest is presently held by MGE Transco, a wholly-owned subsidiary of MGE Energy. As of December 31, 2022, MGE Transco held a 3.6% ownership interest in ATC.

In 2016, ATC Holdco was formed by several of the members of ATC, including MGE Energy, to facilitate electric transmission development and investments outside of Wisconsin, which typically have long development and investment lead times before becoming operational. ATC Holdco's future transmission development activities have been suspended for the near term. MGE Energy's ownership interest in ATC Holdco is held by MGEE Transco, a wholly-owned subsidiary. As of December 31, 2022, MGEE Transco held a 4.4% ownership interest in ATC Holdco.

Environmental

MGE Energy and MGE are subject to frequently changing local, state, and federal regulations concerning air quality, water quality, land use, threatened and endangered species, hazardous materials handling, and solid waste disposal. These regulations affect the manner in which we conduct our operations, the costs of those

operations, as well as capital and operating expenditures. Regulatory initiatives, proposed rules, and court challenges to adopted rules, have the potential to have a material effect on our capital expenditures and operating costs. In addition to the regulations discussed below, MGE continues to track state and federal initiatives such as potential state and federal regulations governing surface water and/or groundwater containing per- and polyfluoroalkyl substances, potential changes to regulations governing polychlorinated biphenyl (PCB), potential changes to air and water standards, and potential climate change legislation.

In February 2021, MGE and the other co-owners of Columbia announced plans to retire that facility. The co-owners intend to retire Unit 1 and Unit 2 by June 2026. Final timing and retirement dates are subject to change depending on operational, regulatory, and other factors. Effects of environmental compliance discussed below will depend upon the final approved retirement dates and compliance requirement dates.

Water Quality

Effluent Limitations Guidelines and Standards for Steam Electric Power Generating Point Source Category

The EPA has promulgated water Effluent Limitations Guidelines (ELG) and standards for steam electric power plants which focus on the reduction of metals and other pollutants in wastewater from new and existing power plants. MGE's Columbia plant and Elm Road Units are subject to this rule.

See Footnote 16.a. of the Notes to the Consolidated Financial Statements in this Report for further discussion of compliance plans for Columbia and the Elm Road Units. Based on previous treatment of environmental compliance projects, management believes that any compliance costs will be recovered in future rates.

Cooling Water Intake Rules (Section 316(b))

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

WCCF, Blount, and Columbia are subject to this rule. WCCF employs a system that meets the Section 316(b) rule. Blount's WPDES permit assumes that the plant meets BTA standards for the duration of the permit, which expires in 2023. Before the next permit renewal, MGE is required to complete an entrainment study and recommend a BTA along with other technologies considered. MGE completed the entrainment study in 2021 and submitted the results to the WDNR. The WDNR will make the final BTA determination and include any BTA requirements in Blount's next permit renewal, which is expected to be completed and effective in 2023. Management believes that the BTA determination at Blount will not be material for MGE.

Management believes that the Section 316(b) rule will not have a material effect on its existing plants and that any compliance costs will be recovered in future rates based on previous treatment of environmental compliance projects.

Air Quality

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

Ozone NAAQS

The Elm Road Units are located in Milwaukee County, Wisconsin, a nonattainment area. In October 2022, the EPA reclassified Milwaukee County from "marginal" to "moderate" nonattainment under the 2015 ozone NAAQS. The Wisconsin Department of Natural Resources (WDNR) must develop a State Implementation Plan (SIP) for the area, and this reclassification will result in more stringent SIP requirements for both constructing new development and modifying or expanding existing plants in the area. The deadline for moderate classified areas to meet attainment standards is August 2024. MGE will continue to monitor the WDNR's SIP development and the extent to which the requirements will impact the Elm Road Units. At this time, the operator of the Elm Road Units does not expect that the 2015 Ozone NAAQS will have a material effect on its existing plants based on final designations.

Fine Particulate Matter (PM2.5) NAAQS

In January 2023, the EPA published a proposed rule to lower the average annual PM2.5 NAAQS from its current level. The EPA also solicited comments on whether to lower the annual standard further than the proposed level, and whether or not to also lower the maximum 24-hour limit to be consistent with recommendations from its Clean Air Scientific Advisory Committee (CASAC). As the rule is currently proposed, the annual PM2.5 NAAQS and the 24-hour limit recommended by the CASAC is not expected to impact the counties where Columbia and the Elm Road Units are located. However, if the annual PM2.5 NAAQS is lowered further than the EPA's currently proposed value, the county where the Elm Road Units are located may be in nonattainment with the standard. A nonattainment designation would require the State of Wisconsin to develop a plan to get into attainment. However, we will not know the impact of this rule with any certainty until it is finalized, counties' attainment status is determined by the EPA, and the State of Wisconsin develops an attainment implementation plan. MGE will continue to follow the rule's developments.

Cross-State Air Pollution Rule (CSAPR): Proposed Ozone Season Update based on 2008 Ozone NAAQS

In April 2022, the EPA published a proposed Federal Implementation Plan (FIP) to address state obligations under the Clean Air Act "good neighbor" provisions for the 2015 Ozone NAAQS. See Footnote 16.a. of the Notes to the Consolidated Financial Statements in this Report for further discussion of the proposed rule. MGE expects the rule, if finalized as written, to impact our fossil-fueled generation assets. However, we will not know the impact of this rule with any certainty until it is finalized. We will continue to monitor rule developments.

Clean Air Visibility Rule (CAVR)

Columbia is subject to the best available retrofit technology (BART) regulations, a subsection of CAVR, which may require pollution control retrofits. Columbia's existing pollution control upgrades, and the EPA's stance that compliance with the CSAPR equals compliance with BART, should mean that Columbia will not need to do additional work to meet BART requirements. Wisconsin's 2021 SIP argues that Wisconsin will meet its current regional haze goals based on expected emissions reductions, which include Columbia unit retirements. Given that the Wisconsin SIP recognizes the Columbia unit retirements as part of its emission reduction plan, MGE does not anticipate further obligations with this rule at Columbia. MGE will continue to monitor legal developments and any future updates to this rule.

Global Climate Change

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

MGE has taken steps to address GHG emissions through voluntary actions. In 2005, MGE implemented its Energy 2015 Plan. Under the Plan and other actions, our CO2 emissions declined from 2005 to 2015 by approximately 20% even though total system delivered energy increased. In 2015, MGE announced its Energy 2030 framework that

continues steps to reduce CO2 emissions. Subject to regulatory approvals and other conditions, MGE aims to increase renewable energy to 25% of retail electric sales by 2025 and to 30% by 2030. Under our Energy 2030 framework prior to the announcement of the Columbia retirement, our plan was to reduce CO2 emissions from electricity by 40% from 2005 levels by 2030. In January 2022, MGE announced a new target of 80% carbon reduction from electricity, significantly exceeding the original 2030 goal. Beyond 2030, we are targeting net-zero carbon electricity by 2050, including our commitment to work with our co-owners at our Elm Road Units to reduce coal use by 2030 and eliminate coal use by 2035.

Natural gas continues to be a critical resource for meeting reliable, efficient, and affordable energy needs. About half of U.S. households use natural gas for heating. In 2022, MGE completed an in-depth analysis and inventory of our GHG emissions associated with electric generation and distribution, purchase and distribution of natural gas, and other sources, such as indirect emissions from gas usage by our customers. Throughout the natural gas distribution system, MGE already has replaced and upgraded all piping made of material considered to be leak-prone. Additionally, MGE's leak inspection schedule already exceeds federal requirements. MGE is building on our Energy 2030 framework to further address emissions associated with MGE's purchase and distribution of natural gas. The 2030 framework includes strategies for working with our suppliers, pipeline operators, customers, regulators, and other industry stakeholders. The framework also includes the exploration of new and emerging technologies, such as renewable natural gas, to serve our customers more sustainably.

Greenhouse Gas Reduction Guidelines under the Clean Air Act 111(d) Rule

WCCF, the Elm Road Units, Blount, and Columbia could be impacted by GHG reduction guidelines and approval criteria established under the Clean Air Act for the control of GHG emissions from fossil fuel-fired electric generating units (EGUs). The EPA is undertaking a new rulemaking under section 111(d) of the Clean Air Act to establish emission guidelines and limit GHG emissions from existing fossil fuel-fired EGUs. The EPA is also conducting a comprehensive review of the New Source Performance Standards (NSPS) and may set new emission standards for GHG emissions from new, modified, and/or reconstructed fossil fuel-fired power plants. The EPA anticipates issuing a proposed rule in spring 2023 and a final rule by summer 2024. MGE will continue to evaluate greenhouse gas rule developments, including any new EPA actions towards rule development, and any further court decisions on the EPA's authority to regulate greenhouse gases.

Federal Action on Climate Change

President Biden's actions on climate change, including multiple executive orders and the recommitment of the U.S. to the Paris Agreement under the United Nations Framework Convention on Climate Change (the Paris Agreement), indicate that climate considerations are a broad focus.

In December 2021, President Biden signed an executive order that sets goals for the federal government agencies and operations to have, among other things, 100% carbon-free electricity by 2030, acquisitions of vehicles to be 100% zero-emissions light-duty vehicles by 2027, and all vehicles by 2035, and net-zero emissions from federal operations by 2050. Efforts at the federal level are expected to spur the carbon-neutral economy in the private sector.

In August 2022, the federal government enacted the Inflation Reduction Act (IRA). Included in the IRA are federal funds for investment in infrastructure, transportation, energy, and climate change. MGE is monitoring actions on climate change to determine the impact to MGE's decarbonization plans. In September 2022, President Biden signed an executive order on the Implementation of the Energy and Infrastructure Act of 2022. The order directs agencies to implement the energy and infrastructure provisions of the 2022 IRA and directs agencies to take actions towards implementing U.S. climate change priorities to be in line with the Paris Agreement. The Paris Agreement includes progress towards achieving greenhouse gas reductions of 50-52% below 2005 levels in 2030, achieving a carbon pollution-free electricity sector by 2035, and achieving net-zero emissions no later than 2050.

MGE is following the development of recommendations and plans developed by agencies as a result of IRA and executive orders, as well as other executive actions taken by the Biden administration, to determine their applicability to MGE's decarbonization plans and to evaluate any potential impact to our operations.

State and Regional Action on Climate Change

In August 2019, Wisconsin Governor Tony Evers signed an executive order to establish the Office of Sustainability and Clean Energy (OSCE). The order tasks the OSCE with, among other things, ensuring that the actions of the State of Wisconsin are aligned with the goals and recommendations of the Paris Agreement, verifying that electricity consumed by the State of Wisconsin is 100% carbon-free by 2050, and developing a comprehensive multi-sector clean energy plan for the state. In April 2022, the OSCE released Wisconsin's Clean Energy Plan. The plan includes a goal to achieve net zero carbon by 2050. MGE is engaged in this process by participating on a Stakeholder Advisory Team in a voluntary capacity. MGE will continue to evaluate this plan for its applicability to MGE's decarbonization plans and to evaluate potential impact to our operations.

Solid Waste

Coal Combustion Residuals Rule

The CCR rule regulates as a solid waste coal ash from burning coal for the purpose of generating electricity and defines what ash use activities would be considered generally exempt beneficial reuse of coal ash. The CCR rule also regulates landfills, ash ponds, and other surface impoundments used for coal combustion residuals by regulating their design, location, monitoring, and operation. The CCR rule requires owners or operators of coal-fired power plants to stop transporting CCR and non-CCR wastewater to unlined surface impoundments. In addition, regulated entities must initiate impoundment closure as soon as feasible and in no event later than April 2021, unless the EPA grants an extension. A site-specific extension to initiate closure of the primary ash pond at Columbia by March 31, 2023, was requested. The EPA has not formally approved the extension.

Review of the Elm Road Units has indicated that the costs to comply with this rule are not expected to be significant. See Footnote 16.a. of the Notes to the Consolidated Financial Statements in this Report for further discussion.

Renewable Energy Standards

Wisconsin law establishes a minimum amount of energy MGE must supply from renewable sources. MGE currently exceeds the applicable minimum requirement of approximately 8%. The costs to comply with this requirement are being recovered in rates.

Human Capital

The energy industry is ever-changing. MGE Energy and MGE believe it is important to continue to engage our human capital resources as our industry evolves. We are committed to sustainable workforce practices such as career development and training. We offer all employees the opportunity to learn and grow—whether the goal is to increase job proficiency, improve decision-making skills, or prepare for new roles and responsibilities. We work to provide our employees with the tools they need to be successful in their careers. This strategy is essential given our aging workforce.

We value equity, diversity, and inclusion. We promote an inclusive, respectful work environment where individuals and groups can achieve their full potential. All employees have equitable access to employment and development opportunities. Everyone is responsible for helping to meet the objectives of our diversity and inclusion policy as well as supporting the concepts of equal opportunity and affirmative action. We believe that our diversity makes us stronger.

"We power safety. Work safe. Home safe." That is our commitment at MGE, and it is embraced by our employees. Our journey to safety excellence is guided by our Safety Steering Team. The team meets regularly to examine safety topics and to identify and to prioritize continuous improvement opportunities.

For about two years during the COVID-19 pandemic, about half of MGE employees worked remotely. In April 2022, MGE formally began a hybrid work schedule for remote-enabled employees.

As of December 31, 2022, MGE had 701 employees, 322 of which are covered by collective bargaining agreements as described below:


Union	Number of Employees Represented	Expiration of Collective Bargaining Agreement
Local Union 2304 of the International Brotherhood of Electrical Workers	231	April 30, 2023
Local Union No. 39 of the Office and Professional Employees International Union	86	May 31, 2023
Local Union No. 2006, Unit 6 of the United Steel, Paper and Forestry, Rubber, Manufacturing, Energy, Allied Industrial, and Service Workers International Union	5	October 31, 2023

Financial Information About Segments

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

Information About our Executive Officers

As of December 31, 2022, the executive officers of the registrants were as follows:


Executive	Title	Effective Date	Service Years as an Officer
Jeffrey M. Keebler(a)	Chairman of the Board, President, and Chief Executive Officer	10/01/2018	11
Age: 51	President and Chief Executive Officer	03/01/2017

Jared J. Bushek(a)	Vice President – Finance, Chief Information Officer and Treasurer	09/01/2020	7
Age: 42	Assistant Vice President – Chief Information Officer	07/23/2015

Lynn K. Hobbie(b)	Executive Vice President – Marketing and Communications	03/01/2017	28
Age: 64

Tamara J. Johnson(a)	Vice President – Accounting and Controller	09/01/2020	7
Age: 58	Assistant Vice President – Controller	07/23/2015

Cari Anne Renlund(a)	Vice President, General Counsel and Secretary	09/01/2020	7
Age: 49	Vice President and General Counsel	11/02/2015

Note: Ages, years of service, and positions as of December 31, 2022.

(a)

Executive officer of MGE Energy and MGE.

(b)

Executive officer of MGE.

Item 1A. Risk Factors.

MGE Energy and our subsidiaries, including MGE, operate in a regulated market environment that involves significant risks, many of which are beyond our control. The following risk factors may adversely affect our results of operations, cash flows and financial position and market price for our publicly traded securities. While we believe we have identified and discussed below the key risk factors affecting our business, additional unknown risks and uncertainties may adversely affect our performance or financial condition in the future.

Regulatory Risk

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

Our business is subject to regulation at the State and Federal levels. We are subject to regulation as a holding company by the PSCW. The PSCW regulates MGE's rates; terms and conditions of service; various business practices and transactions; financing; the closure of generating facilities and related cost recovery; and transactions between it and its affiliates, including MGE Energy. MGE is also subject to regulation by the FERC, which regulates certain aspects of its business. We are also subject to oversight and monitoring by MISO. Possible changes to MISO's methodology establishing capacity planning reserve margin requirements may impact new generating facilities such as solar and wind and its accredited energy capacity which may require adjustments to the current resource plan and the need to add additional resources to comply with MISO's proposal or procure capacity in the market whereby such costs might not be recovered in rates. The lack of availability of new and existing generating facilities may also impact our current resource plan to be in accordance with MISO's methodology. ATC, in which we have an investment, is subject to regulation by FERC as to, among other things, rates. The regulations adopted by the State and Federal agencies affect how we do business, our ability to undertake specified actions since pre-approval or authorization may be required for projects, the costs of operations, and the rates charged to recover those costs. Our ability to attract capital also depends, in part, upon our ability to recover our costs and obtain a fair return for shareholders.

Our utility revenues are subject to regulatory proceedings, which can affect our ability to recover, and the timing of recovery of, costs that we incur in our operations.

Our utility customer rates have a material impact on our financial condition, results of operations, and liquidity. Our ability to obtain adjustments to those rates depends upon timely regulatory action under applicable statutes and regulations. Rate regulation is based on providing an opportunity to recover costs that have been reasonably incurred and the ability to earn a reasonable rate of return on invested capital. However, we have no assurance that our regulators will consider all of our costs to have been reasonably incurred. In addition, our rate proceedings may not always result in rates that fully recover our costs or provide a reasonable return on equity. Certain costs and revenues are deferred as regulatory assets and liabilities for future recovery or refund to customers, as authorized by our regulators. If recovery of regulatory assets is not approved or is no longer deemed probable, these costs would be recognized as a current period expense and could materially and adversely impact our operations and financial performance in that period.

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

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

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

We are subject to environmental laws and regulations that affect the manner in which we conduct business, including capital expenditures, operating costs, and potential liabilities. The current presidential administration has and continues to undertake an active effort on climate change-related matters, including restrictions on greenhouse gas emissions, such as carbon. While it is difficult to know the extent of possible legislation or

regulatory activity, it is expected there will be an increase in the number and scope of environmental laws and regulations aimed at fossil-fueled generation and the transportation of natural gas. These possible changes, as well as evolving consumer sentiment, have affected and may continue to affect our business plans, make them more costly, or expose us to liabilities for past, present, or future operations.

Numerous environmental laws and regulations govern many aspects of our present and future operations. These include: air emissions limits and reporting; ambient air quality standards; water quality; water intake and discharges; wetlands; solid and hazardous waste; handling and disposal of hazardous substances; protection of endangered resources, such as threatened and endangered species, protection of cultural resources and archaeological sites; remediation and management of contaminated sites; and control of potential pollution from electric and gas construction sites. These evolving regulations affect us by:

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Introducing uncertainty into our planning and capital expenditures processes, as changes in requirements may affect the timing and choice of compliance methods and require costly revisions to prior plans and commitments.

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Imposing or modifying limits on the operations of our facilities in order to meet restrictions on air emissions, water use or water discharges.

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Requiring capital expenditures and changes in operating procedures and costs as a result of the need to install additional pollution controls or more advanced technology or equipment at new or existing facilities.

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Mandating increasing purchases of renewable energy, which affects the use of existing generation, and energy efficiency initiatives, which affect revenues.

We may be subject to future laws, regulations, or actions associated with public concern with fossil-fuel generation, greenhouse gases, and the effects of global climate change.

Our subsidiaries operate or co-own electric power plants that burn fossil fuels, deliver natural gas, and deliver electricity to customers. These business activities are subject to evolving public concern regarding greenhouse gases (GHG), legislative and regulatory action, and possible litigation in response to that public concern. The primary greenhouse gas associated with our subsidiaries' combustion of fossil fuels, and the largest emission in our system overall, is carbon dioxide (CO2).

Our subsidiaries have incurred and are expected to continue to incur costs from more stringent regulation of GHG from power plants, natural gas delivery, GHG used in power distribution, and efficiencies lost during power distribution. While it is difficult to know the extent of possible legislation or regulatory activity, the federal government is likely to consider and pass some form of greenhouse gas legislation or regulations. In addition, litigation by environmental nongovernment organizations targeting GHG emissions from the electric power industry is also likely if the federal government fails to act on greenhouse gas initiatives.

Climate change could affect us in several other ways:

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Changes in weather patterns, including swings in intensity, could affect use of electricity and gas by our customers, affecting revenues; and could affect the condition of our facilities, affecting our costs.

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We may also incur costs associated with actions taken due to investor interest in reducing our subsidiaries' reliance on fossil fuel generation, and coal in particular. Investors may also move away from investing in fossil fuel generated electricity for reputational or perceived risk-related reasons, which could raise our costs of attracting capital.

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If we are not seen as being proactive in addressing concerns:

we may experience reputational issues among our customers and the communities that we serve. Those issues could affect customers' energy choices, including efforts at self-supply, and could affect the handling and treatment of our rate requests and cost recovery.

we may experience difficulty in attracting investors, which could affect the availability and cost of capital and financing.

These matters represent uncertainties in the operation and management of our business.

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

MGE has price risk exposure with respect to the price of natural gas, electricity, coal, emission credits, and oil. MGE burns natural gas in several of its peak electric generation facilities. In many cases, the cost of purchased power is tied to the cost of natural gas. In the event of an interruption in energy supply, whether due to equipment problems, transmission constraints, or otherwise, we may incur additional costs to obtain alternative sources of energy supply, in order to meet our contractual or regulatory obligations to our customers. Electric fuel rules require Wisconsin utilities to defer electric fuel-related costs that fall outside a symmetrical cost tolerance band around the amount approved for a utility in its annual fuel proceedings. Any over- or under-recovery of the actual costs is determined in the following year and is then reflected in future billings to electric retail customers. The electric fuel-related costs are subject to an excess revenue test. Excess revenues are defined as revenues in the year in question that provide MGE with a greater return on common equity than authorized by the PSCW in MGE's latest rate order. The recovery of under-collected electric fuel-related costs would be reduced by the amount that exceeds the excess revenue test. These costs are subject to the PSCW's annual review of fuel costs completed in the year following the deferral. MGE assumes the risks and benefits of variances that are within the cost tolerance band.

Changes in federal income tax policy may adversely affect our financial condition, results of operations, and cash flows, as well as our credit ratings.

We currently own and operate renewable energy generating facilities. These facilities generate production tax credits and investment tax credits that we use to reduce our federal tax obligations. The amount of tax credits we earn depends on multiple factors, including facility generation, transmission availability, the cost of qualifying property, and the applicable tax credit rate. In August 2022, the Inflation Reduction Act (IRA) was signed into law. Among other provisions, the IRA: extends current PTC and ITC for renewable technologies (e.g., wind and solar); restores full value of the PTC and ITC for qualifying facilities placed into service after 2021 that satisfy prevailing wage and apprenticeship requirements; creates a PTC for solar, clean hydrogen and nuclear; establishes an ITC for energy storage, microgrids, and interconnection facilities; and allows companies to monetize or sell credits to unrelated parties. Implementation of IRA provisions is subject to the issuance of additional guidance by the U.S. Treasury Department. We continue to monitor new developments in the IRA.

If corporate tax rates or policies are changed with future federal or state legislation, we may be required to take material charges against earnings.

There is still uncertainty as to when or how credit rating agencies, capital markets, the FERC, or state public utility commissions will treat impacts of the Inflation Reduction Act or any new tax regulation. These impacts could subject us to credit rating downgrades. In addition, certain financial metrics used by credit rating agencies, such as our funds from operations-to-debt percentage, could be negatively impacted by future rulings.

We may not be able to use or transfer to a third party all tax credits for which we are eligible.

We have historically reduced our consolidated federal and state income tax liability with the use of various tax credits under the applicable tax codes. We may not be able to fully use tax credits if our future federal and state taxable income and related income tax liability is insufficient to permit their use or transfer tax credits to a third party. In addition, any future disallowance of some or all of those tax credits as a result of legislation or an adverse determination by one of the applicable taxing jurisdictions could materially affect our tax obligations and financial results.

Operating Risk

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

The demand for electricity and gas is affected by weather. Very warm and very cold temperatures, especially for prolonged periods, can dramatically increase the demand for electricity and gas for cooling and heating, respectively, as opposed to the softening effect of more moderate temperatures. Our electric revenues are sensitive to the summer cooling season and, to a lesser extent, the winter heating season. Similarly, very cold temperatures can dramatically increase the demand for gas for heating. A significant portion of our gas system

demand is driven by heating. Extreme summer conditions or storms may stress electric systems, resulting in increased maintenance costs and limiting the ability to meet peak customer demand.

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

Our revenues and the timing of the recovery of our costs could be adversely affected by improvements in power generation, storage, and use technology.

Advancements in power generation technology, including commercial and residential solar generation installations and commercial micro turbine installations, are improving the cost-effectiveness of customer self-supply of electricity. Improvements in energy storage technology, including batteries and fuel cells, could also better position customers to meet their around-the-clock electricity requirements. It is possible that legislation or regulations could be adopted supporting the use of these technologies that permit third-party sales from such facilities, and allow these facilities to interconnect to our distribution system. Improvements in the energy efficiency of lighting, appliances, and equipment will also affect energy consumption by customers. Such developments could reduce customer purchases of electricity but may not necessarily reduce our investment and operating requirements due to our obligation to serve customers, including those self-supply customers whose equipment has failed for any reason to provide the power they need whether due to inadequate on-site resources, restricted operating hours, or equipment failure. In addition, since a portion of our costs are recovered through charges based upon the volume of power delivered, a reduction in electricity deliveries will affect the timing of our recovery of those costs and may require changes to our rate structures.

Changes in power generation, storage, and use technologies could have significant effects on customer behaviors and their energy consumption. Customers could engage in individual conservation efforts by voluntarily reducing their consumption of electricity through changes in energy use and through the use of more energy efficient lighting, appliances, and equipment. They could also change their consumption of electricity through the installation of alternative energy sources, such as rooftop solar panels and micro turbines for self-supply. Customer energy conservation could adversely affect our results of operations by reducing our revenues without necessarily changing our operating costs due to our obligation to serve.

We are affected by local, national, and worldwide economic activity.

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

Higher levels of development and business activity within our service area generally increases the number of customers and their use of electricity and gas. Likewise, recessionary economic conditions generally have an adverse impact on our results of operations. Our business activities, including those of our subsidiaries, are concentrated in the State of Wisconsin. Changes in our local economy could negatively impact the financial condition of our customers, the growth opportunities available to us and our subsidiaries, and our results from operations.

More recently, our operations have been impacted by domestic and global supply chain disruptions which are delaying the delivery of materials, equipment, and other resources that are critical to our business operations and projects under construction, including our renewable energy projects. Supply interruptions could affect our ability to operate and maintain our system and ability to implement our long-term goals. Inflation has also increased prices of equipment, materials, and other resources. Inflationary pressures in the economy could lead to higher expenses which may adversely impact our financial condition and results of operations.

The ability to obtain an adequate supply of coal could limit the ability to operate the co-owned coal-fired facilities from which we receive a significant portion of our electric supply.

The availability of coal and the means to transport coal could:

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Affect our operating costs due to increased costs associated with lower levels of owned generation or the need for alternate coal supply or transportation,

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Limit the ability to generate electricity if the plant operator is unable to arrange timely deliveries of adequate supplies of coal, and

•

Result in potentially higher costs for replacement purchased power as well as potential lost market sales opportunities.

A significant portion of our electric generating capacity is dependent on coal. Demand for coal has been impacted by prevailing prices for natural gas and coal plant closures and may affect mine performance. Consequently, we are exposed to the risk that counterparties to these contracts will not be able to fulfill their obligations. Disruption in the delivery of fuel, including disruptions as a result of transportation delays, weather, labor relations, force majeure events, or environmental regulations affecting any of our fuel suppliers, has affected, and could affect our ability to generate electricity at our facilities at the desired level. Should counterparties fail to perform, or other unplanned disruptions occur, we may be forced to fulfill the underlying obligation at higher prices. The Columbia plant operator has been, and the plant operators may be, forced to reduce generation at our jointly-held coal units, which would cause us to replace this generation through additional power purchases from third parties. These factors may also affect the terms under which any of the existing coal supply or transportation agreements are renewed or replaced upon the expiration of their current terms.

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

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

•

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

•

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

•

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

•

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

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

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

Weather conditions, accidents, and catastrophic events can result in damage or failures of equipment or facilities and disrupt or limit our ability to generate, transmit, transport, purchase, or distribute electricity and gas. Efforts to repair or replace equipment and facilities may take place over prolonged periods or may be unsuccessful. We may also be unable to make the necessary improvements to our operational system, causing service interruptions. Furthermore, our facilities are interconnected with third-party transmission providers. Damage to or failures of these providers' equipment or facilities is out of our control but could lead to service interruptions. The resulting interruption of services would result in lost revenues and additional costs. We are also exposed to the risk of accidents or other incidents that could result in damage to or destruction of our facilities or damage to persons or property. Such issues could adversely affect revenues or increase costs to repair and maintain our systems.

We could be adversely affected by production disruptions at our wind and solar generating facilities.

We own and operate wind and solar generating facilities, which generate production tax credits used to reduce our federal tax obligations. Various operating and economic factors, including transmission constraints, unfavorable trends in pricing for wind or solar energy, adverse weather conditions and the breakdown or failure of equipment, could significantly reduce the production tax credits generated by our wind or solar farms, resulting in increased federal income tax expense. We could also be forced to replace lost generation capacity with additional power purchases from third parties, potentially leading to increased costs. These factors could have an adverse impact on our financial condition and results of operations, which could be material depending upon the cause of the disruption and its duration.

Our operations and confidential information are subject to the risk of cyber-attacks.

Cyber-attacks targeting our electronic control systems used in generation and electric and gas distribution, including denial of service and ransomware attacks, could result in a full or partial disruption of our operations. Any disruption of these control systems could result in a loss of service to customers and loss of revenue, as well as significant expense to repair system damage and remedy security breaches.

Our business includes the collection and retention of personally identifiable information of our customers, shareholders, and employees, who expect that we will adequately protect such information. In some cases, we outsource certain functions to vendors that could be targets of cyber-attacks. A significant theft, loss, or fraudulent use of personally identifiable information may cause our business reputation to be adversely impacted and could lead to potentially large costs to notify and protect the impacted persons and subject us to legal claims, fines, or penalties.

The safeguards we have may not always be effective due to the evolving nature of cyber-attacks. We cannot guarantee that such protections will be completely successful in the event of a cyber-attack. If the technology systems were to fail or be breached by a cyber-attack, and not be recovered in a timely fashion, we may be unable to fulfill critical business functions and confidential data could be compromised, any additional costs may not be recoverable in rates, or may exceed insurance limits, or may not be covered by insurance and could adversely impact our results of operations.

We rely on the performance of our information technology systems, the failure of which could have an adverse effect on our business and performance.

We operate in a highly engineered industry that requires the continued operation of sophisticated information technology systems and network infrastructure to manage our finances, to operate our control facilities, to provide electric and gas service to our customers, and to enable compliance with applicable regulatory requirements. Our computer-based systems are vulnerable to interruption, the introduction of viruses, malware, ransomware, security breaches, fire, power loss, system malfunction, network outages and other events that may be beyond our control. System interruptions or failures, whether isolated or more widespread, could impact our ability to provide service to our customers, which could have a material adverse effect on our operations and financial performance.

Catastrophic and unpredictable events, including the ongoing COVID-19 pandemic, could have a material adverse effect on our business.

A terrorist attack, war, natural disaster, pandemic virus or disease, including the COVID-19 pandemic, or other catastrophic or unpredictable event could adversely affect our future revenues, expenses and operating results by: interrupting our normal business operations; causing employee absences or casualties, including loss of our key employees; interrupting or affecting supplier operations; requiring substantial expenditures and expenses to repair, replace and restore normal business operations; and reducing investor confidence. Facilities for electric generation, transmission, and gas and electric distribution are potential targets of terrorist threats and activities. A terrorist act or catastrophic event at our facilities or the facilities of other companies to which we are interconnected could result in a disruption of our ability to generate, transmit, transport, purchase, or distribute electricity or natural gas. Such an event would have additional adverse effects, including environmental ramifications, increased security and insurance costs, as well as general economic volatility or uncertainty within

our service territories. The inability to maintain operational continuity and any additional costs incurred for repairing our facilities or making alternative arrangements could materially and adversely affect our financial condition and results of operations.

In particular, the COVID-19 pandemic has negatively impacted, and we expect it will continue to impact, our operations, economy, and financial markets. The nature, extent, and duration of the impact of the COVID-19 pandemic or any future disease or adverse health condition is highly uncertain and beyond our control. The impacts of the pandemic on our business have included and may continue to include the following: reduced economic activity impacting the use of electricity and gas services; delay in, and possible loss of, payments for utility service; supply chain disruptions and inflation, resulting in increased costs for labor, materials, and services, which could adversely impact our ability to implement our corporate strategy; increase in employee absences impacting our ability to operate and maintain our system; or volatility in the capital markets. Moreover, the effects of the COVID-19 pandemic may heighten many of the other risks described in this section including interest rate changes, rating agency actions, governmental actions, and market volatility.

We face risk in connection with the completion of significant capital projects.

Our capital projects, such as our renewable generation projects, are subject to various completion risks that could cause costs to increase or delays in completion. These risks include shortages of, the inability to obtain, the cost of, and the consistency of, labor, materials and equipment; the inability of the contractors to perform under their contracts; the inability to agree to terms of contracts or disputes in contract terms; work stoppages; adverse weather conditions; the inability to obtain necessary permits in a timely manner; changes in applicable laws or regulations; adverse interpretation or enforcement of permit conditions; governmental actions or tariffs; legal action; and unforeseen engineering or technology issues. In the case of our renewable generation projects, we may face delays in the completion of the necessary transmission system connections or upgrades to accommodate the project.

If a capital project exceeds the approved project costs approved by the PSCW, we may not be able to recover those excess costs through regulated customer rates. If that happens, we may have to finance overruns through cash from operations, which may delay other projects, or by securing additional financing. Any or all of these methods may not be available when or in the amounts needed or may adversely affect our financial condition, results of operations and cash flows.

Inability to recover excess costs, or inability to complete the project in a timely manner, could adversely impact our financial condition and results of operations. Further, our revenues and cash flows may not increase immediately following our expenditure of funds on a particular project, which could affect our liquidity and financial position.

Our stated long-term goals are based on various assumptions and beliefs that may not prove to be achievable in the time frame projected.

Some of our current long-term goals include MGE's targeting of a net‐zero carbon electricity by 2050 and MGE's Energy 2030 framework, which describes our plan for growth in renewables generation. MGE is working to achieve a more sustainable energy future using cost‐effective renewable generation technologies. Management established these goals in conjunction with our board of directors based upon a number of different internal and external factors that characterize and influence our current and expected future activities. These long-term goals are based on certain assumptions regarding the timing, scope and relative costs of technological advancements, including generation, storage and energy use technologies; levels of customer participation in programs and partnerships, which will be critical to the achievement of the goals; our ability to transition or displace existing coal-fired resources; our ability to complete renewable generation projects in a timely manner and within approved budgets; our ability to obtain recovery of costs in rates; and our ability to obtain the necessary permits or licenses for such projects. These assumptions may differ materially from actual future results. Accordingly, we may not achieve our stated long-term goals in the timeframe projected or at all.

We do not own all of the land on which our facilities are located, and interruption in access rights could disrupt our operations.

We do not own all of the land on which certain of our facilities are located, and we are, therefore, subject to the risk of increased costs to maintain necessary land use. We obtain the rights to construct and operate certain of our related facilities on land owned by third parties for a specific period of time. Our loss of these rights, through our inability to renew right-of-way contracts on acceptable terms or increased costs to renew such rights, could have a material adverse effect on our financial condition, results of operations and cash flows.

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

We must attract, train, and retain a workforce to meet current and future needs. Events such as an aging workforce without appropriate replacements, mismatch of skill sets to future needs, or unavailability of contract resources may lead to operating challenges and increased costs. Some of the challenges include lack of resources, loss of knowledge, and time required for replacement employees to develop necessary skills. Failure to identify qualified replacement employees could result in decreased productivity and increased safety costs. If we are unable to attract and retain an appropriately qualified workforce, our operations could be negatively affected. We are also subject to multiple collective bargaining agreements covering approximately 322 employees. Future negotiation of these collective bargaining agreements could lead to work stoppages or other disruptions to our operations, which could adversely affect our financial condition and results of operations.

Financial Risk

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

We face commodity price risk exposure with respect to the purchase of natural gas, electricity, coal, oil, and environmental allowances. We also face risk through our use of derivatives such as futures, forwards, and swaps, to manage our commodity price risk. We could experience increased costs as a result of volatility in the market values of those commodities. We could also experience losses on our derivative contracts as a result of that market value volatility or if a counterparty fails to perform under a contract.

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

Prevailing interest rates affect our assessment and determination of discount rates and are a key assumption in the determination of the costs and funding of our defined benefit pension plans. Changes in rates may impact the amount of expense and timing of contributions to those plans. The performance of the capital markets affects the values of the assets that are held in trust to satisfy the future obligations under our pension and postretirement benefit plans. We have significant obligations in these areas and hold significant assets in these trusts. A decline in the market value of those assets may increase our current and longer-term funding requirements for these obligations. Changes in the value of trust fund assets may affect the level of required contributions to these trusts to meet benefit obligations. Reduced benefit plan assets could result in increased benefit costs in future years and may increase the amount and accelerate the timing of required future funding contributions.

We are exposed to interest rate risk.

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

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

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

where prices may be more volatile. That risk may be increased during periods of weak or stressed economic conditions.

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

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

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

The credit markets have experienced disruption and uncertainty in prior years. To the extent that such issues affect the ability or willingness of credit providers or investors to participate in the credit markets or particular types of investments, or affect their perception of the risk associated with particular types of investments, our cost of borrowing could be affected. Furthermore, if we are unable to access the capital and credit markets on favorable terms, it could have a material adverse effect on our business, financial condition, results of operations, cash flows and liquidity and our ability to repay or refinance our debt. We also rely on our credit ratings to access the credit markets. If our credit ratings are downgraded for any reason, borrowing costs would increase, the number of potential investors could decrease, or we could be required to provide additional credit assurance, including cash collateral, to contract counterparties.

General Risk Factors

Our insurance coverage may not be sufficient to cover losses caused by an operating failure or catastrophic events, such as severe weather events or a cyber attack, or it may not be available at a reasonable cost, or available at all.

We may experience increased costs and difficulties in obtaining insurance coverage for risks that could arise from our ordinary operations. We or our contractors and customers could continue to experience coverage reductions and/or increased insurance costs in future years. No assurance can be given that future losses will not exceed the limits of our insurance coverage. Uninsured losses and increases in the cost of insurance may not be recoverable in customer rates. A loss that is not fully insured or cannot be recovered in customer rates could materially affect our financial condition, results of operations, liquidity, and cash flows. In addition, we are unable to predict whether we would be allowed to recover in rates the increased costs of insurance or the costs of any uninsured losses. If the amount of insurance is insufficient or otherwise unavailable, or if we are unable to obtain insurance at a reasonable cost or recover in rates the costs of any uninsured losses, our financial condition, results of operations, liquidity, and cash flows could be materially affected.

The stock market can be volatile, and various factors could cause our stock price to decline.

The stock market has experienced, and may continue to experience, fluctuations that significantly impact the market prices of securities issued by many companies. Many factors affect the volatility and price of our common stock in addition to our operating results and prospects, including changes in conditions locally and in the broader economy. These conditions include technological change, the level of interest rates and yields on other investments, and the effects of the other risk factors discussed in this report. Our stock price could fluctuate significantly in response to our quarterly or annual results, as well as factors affecting the broader economy that are beyond our control.

Item 1B. Unresolved Staff Comments.

MGE Energy and MGE

None.

Item 2. Properties.

Electric Generation

Net summer rated capacity in service as of December 31, 2022, was as follows:


Plants	Location	Commercial Operation Date	Fuel	Nameplate Capacity (MW)		Net Summer Rated Capacity (MW)(a)(b)		No. of Units
Steam plants:
Blount	Madison, WI	1957 & 1961	Natural Gas	100		92		2
Columbia	Portage, WI	1975 & 1978	Low-sulfur Coal	211		216	(c)(d)	2
WCCF	Madison, WI	2005	Natural Gas/Oil	157		130	(e)	2
Elm Road Units	Oak Creek, WI	2010 & 2011	Coal	106		108	(c)(f)	2

Combustion Turbines:
Nine Springs	Madison, WI	1964	Natural Gas	16		13		1
Sycamore	Madison, WI	1967 & 1971	Natural Gas	38		30		2
Fitchburg	Fitchburg, WI	1973	Natural Gas	53		31		2
West Marinette	Marinette, WI	2000	Natural Gas/Oil	90		70		1

Distributed Generators:
Multiple Locations	Madison, WI	1998-2021	ULSFO(i)	60		52		60

Wind Facilities:
Lincoln-Red River	Kewaunee County, WI	1999	Wind	11		1		17
Top of Iowa	Brookfield, IA	2008	Wind	30		4		18
Forward	Dodge & Fond du Lac Counties, Wi	2008	Wind	18		2	(g)	86
Saratoga	Howard County, IA	2019	Wind	66		17		33

Solar Facilities:
Morey Field	Middleton, WI	2020	Solar	6	(j)	4		1
Two Creeks	Two Creeks, WI	2020	Solar	50		37	(h)	1
Dane County	Madison, WI	2020	Solar	10	(j)	7		1
O'Brien	Fitchburg, WI	2021	Solar	22	(j)	14		1
Badger Hollow I	Monfort, WI	2021	Solar	50		36	(h)	1
Hermsdorf	Madison, WI	2022	Solar	8		6		1
Total				1,102		870

(a)

Net summer rated capacity is determined by annual testing (measured in June, July or August) and may vary from year to year due to, among other things, the operating and physical conditions of the units.

(b)

All facilities shown are owned by MGE unless footnoted otherwise.

(c)

Baseload generation.

(d)

This facility is jointly-owned. Amount shown represents MGE's ownership share. See "Columbia" below.

(e)

This facility is jointly-owned between MGE and UW-Madison. Per the joint plant agreement, the UW is allocated 17 MW of the net capability of these units during the summer cooling season. The net summer-rated capacity shown reflects this decrease. See "WCCF" below.

(f)

This facility is jointly-owned. Amount shown represents MGE's ownership share. See "Elm Road Units" below.

(g)

Facility is jointly owned by WPL, WPSC, and MGE. Power from this facility is shared in proportion to each owner's ownership interest. Commercial operation date of facility was 2008. MGE purchased its ownership interest in 2018. MGE's share is 12.8%.

(h)

These facilities are jointly owned with WPSC. Capacity and energy from this facility is shared in proportion to each owners' ownership interest. The amount shown represents MGE's 33% ownership share.

(i)

ULSFO is ultra low-sulfur fuel oil.

(j)

To improve annual energy production, maximum inverter MW was increased on these sites.

Columbia

MGE and two other utilities jointly own Columbia, a coal-fired generating facility consisting of two units, which, as of December 31, 2022, accounted for 25% of MGE's net summer rated capacity. Power from this facility is shared in proportion to each owner's ownership interest. As of December 31, 2022, MGE had a 19% ownership interest in Columbia. The other owners are WPL, which operates Columbia, and WPSC. MGE and the other co-owners announced plans to retire Columbia. The co-owners intend to retire Unit 1 and 2 by June 2026. Final timing and retirement dates are subject to change depending on operational, regulatory, and other factors.

The Columbia units burn low-sulfur sub-bituminous coal obtained from the Powder River Basin coal fields located in Wyoming. The coal inventory supply for the Columbia units was approximately 49 days as of December 31, 2021, and approximately 46 days as of December 31, 2022.

Elm Road Units and WCCF

MGE Power Elm Road and two other utilities own undivided interests in the Elm Road Units, consisting of two units, which, as of December 31, 2022, accounted for 12% of MGE's net summer rated capacity. Power from these units is shared in proportion to each owner's ownership interest. MGE Power Elm Road owns an 8.33% ownership interest in the Elm Road Units, and its interest in the Elm Road Units is leased to MGE. The other owners are Wisconsin Energy Corporation, which operates the units, and WPPI Energy, Inc. The Elm Road Units burn bituminous coal obtained from northern West Virginia and southwestern Pennsylvania, and sub-bituminous coal from the Powder River Basin in Wyoming. MGE's share of the coal inventory supply for the Elm Road Units increased from approximately 52 days as of December 31, 2021, to approximately 81 days as of December 31, 2022. MGE Power Elm Road's share of the Elm Road Units is reflected in "Property, plant, and equipment, net" on MGE Energy's and MGE's consolidated balance sheets. In November 2021, MGE announced plans to end the use of coal as a primary fuel at the Elm Road Units and transition the plant to natural gas. By the end of 2030, MGE expects coal to be used only as a backup fuel at the Elm Road Units. This transition will help MGE meet its 2030 carbon reduction goals. By 2035, MGE expects that the Elm Road Units will be fully transitioned away from coal, which will eliminate coal as an internal generation source for MGE.

MGE Power West Campus and the UW jointly own undivided interests in a natural gas-fired cogeneration facility on the UW campus. The facility has the capacity to produce 30,000 tons of chilled water, 500,000 pounds per hour of steam, and approximately 150 MW of electricity. The UW owns 45% of the facility, which represents its interest in the chilled-water and steam assets. These assets are used to meet a part of the UW's need for air-conditioning and steam-heat capacity. MGE Power West Campus owns 55% of the facility, which represents its interest in the electric generating assets. These assets are used to provide electricity to MGE's customers. The UW's share of the plant and portion of the earnings from the WCCF are not reflected in the consolidated financial statements of MGE Energy or MGE. MGE Power West Campus's share of the plant is reflected in "Property, plant, and equipment, net" on MGE Energy's and MGE's consolidated balance sheets.

MGE leases MGE Power Elm Road's ownership interest in the Elm Road Units pursuant to two separate facility leases. MGE leases the electric generating assets owned by MGE Power West Campus and is responsible for operating the entire facility. At the end of the respective lease terms, MGE may, at its option, renew the facility lease for an additional term, purchase the leased ownership interest at fair market value, or allow the lease to end. The financial terms of the facility lease agreements are as follows:


Facilities	Assumed Capital Structure	Assumed Return on Equity	Lease Expiration
Elm Road Units	55% equity and 45% long-term debt	12.7%	Unit 1: 2040 Unit 2: 2041
WCCF	53% equity and 47% long-term debt	12.1%	2035

Electric and Gas Distribution Facilities

As of December 31, 2022, MGE owned 841 miles of overhead electric distribution line and 1,316 miles of underground electric distribution cable, all of which are located in Wisconsin. These electric distribution facilities are connected by 50 substations, installed with a capacity of 1,207,750 kVA. MGE's gas facilities include 3,046 miles of distribution mains, which are all owned by MGE.

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

Encumbrances

The principal plants and properties of MGE are subject to the lien of its Indenture of Mortgage and Deed of Trust dated as of January 1, 1946, as amended and supplemented, under which MGE's first mortgage bonds are issued. As of December 31, 2022, there were $1.2 million of first mortgage bonds outstanding. MGE Power Elm Road has collaterally assigned its right to lease payments from MGE for the Elm Road Units in order to secure the repayment of $46.6 million of senior secured notes issued by MGE Power Elm Road. MGE Power West Campus has collaterally assigned its right to lease payments from MGE for the WCCF in order to secure the repayment of $33.4 million of senior secured notes issued by MGE Power West Campus. See Footnote 14 of the Notes to Consolidated Financial Statements in this Report for additional information regarding these first mortgage bonds and the entitlement of certain senior notes issued by MGE to be equally and ratably secured if MGE issues additional first mortgage bonds.

Item 3. Legal Proceedings.

MGE Energy and MGE

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

See "Environmental" under Item 1. Business and Footnote 16.a. of the Notes to Consolidated Financial Statements in this Report for a description of several environmental proceedings involving MGE. See Footnote 16b. of the Notes to Consolidated Financial Statements under Item 8. Financial Statements and Supplementary Data in this Report for a description of other legal matters.

Item 4. Mine Safety Disclosures.

MGE Energy and MGE - Not applicable.

PART II.

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

Market for Common Equity

MGE Energy

MGE Energy common stock is traded on Nasdaq under the symbol MGEE. As of January 31, 2023, there were 39,837 shareholders of record. For additional information regarding dividends and dividend restrictions, see Footnote 15 of the Notes to the Consolidated Financial Statements under Item 8. Financial Statements and Supplementary Data in this Report.

MGE

As of January 31, 2023, there were 17,347,894 outstanding shares of MGE common stock, all of which were held by MGE Energy. There is no market for shares of common stock of MGE.

Stock Performance Graph

The performance graph below illustrates a five-year comparison of cumulative total returns based on an initial investment of $1,000 in MGE Energy common stock, as compared with the Russell 2000 and the EEI Index for the period 2017 through 2022. The EEI Index reflects the consolidated performance of Edison Electric Institute investor-owned electric utilities.

Cumulative Five-Year Total Return Comparison

(assumes $1,000 invested on 12/31/2017 with dividends reinvested)

Value of Investment as of December 31,


	2017		2018		2019		2020		2021		2022
MGEE	$	1,000	$	971	$	1,302	$	1,181	$	1,417	$	1,238
Russell 2000		1,000		890		1,117		1,340		1,539		1,224
EEI Index		1,000		1,037		1,304		1,289		1,510		1,527

Item 6. [Reserved]

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

General

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

•

Regulated electric utility operations, conducted through MGE,

•

Regulated gas utility operations, conducted through MGE,

•

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

•

Transmission investments, representing our equity investment in ATC and ATC Holdco, and

•

All other, which includes corporate operations and services.

Our principal subsidiary is MGE, which generates and distributes electric energy, distributes natural gas, and represents a majority portion of our assets, liabilities, revenues, and expenses. MGE generates, purchases, and distributes electricity to approximately 161,000 customers in Dane County, Wisconsin, including the city of Madison, and purchases and distributes natural gas to approximately 173,000 customers in the Wisconsin counties of Columbia, Crawford, Dane, Iowa, Juneau, Monroe, and Vernon.

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

We have not included a discussion of results of operations and changes in financial position for the year ended

December 31, 2021, as compared to the year ended December 31, 2020. That discussion can be found in Item 7. Management's Discussion and Analysis of Financial Condition and Results of Operations in our annual report on Form 10-K for the year ended December 31, 2021, which was filed with the SEC on February 23, 2022.

Executive Overview

Our primary focus today and for the foreseeable future is our core utility customers at MGE as well as creating long-term value for our shareholders. MGE continues to face the challenge of providing its customers with reliable power at competitive prices. MGE works on meeting this challenge by investing in more efficient generation projects, including renewable energy sources. As we work toward achieving 80% carbon reduction by 2030 (from 2005 levels), MGE continues to examine and pursue opportunities to reduce the proportion that coal generation represents in its generation mix, as evidenced by its most recent announcements of the retirement of Columbia (a coal generation plant), the planned change in the Elm Road Units fuel source from coal to natural gas, and its growing ownership of renewable generation sources. MGE will continue to focus on growing earnings while controlling operating and fuel costs. MGE's goal is to provide safe and efficient operations in addition to providing customer value. We believe it is critical to maintain a strong credit rating consistent with financial strength in MGE in order to accomplish these goals.

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

•

Weather, and its impact on customer sales,

•

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

•

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

•

Energy commodity prices, including natural gas prices,

•

Equity price risk pertaining to pension related assets,

•

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

•

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

•

Other factors listed in Item 1A. Risk Factors of this Report.

During the year ended December 31, 2022, MGE Energy's earnings were $111.0 million or $3.07 per share compared to $105.8 million or $2.92 per share for the same period in the prior year. MGE's earnings for the year ended December 31, 2022, were $83.9 million compared to $78.4 million for the same period in the prior year.

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


(In millions)	Year Ended December 31,
Business Segment:	2022			2021
Electric Utility	$	65.2		$	63.9
Gas Utility		18.2			15.5
Nonregulated Energy		22.1			21.4
Transmission Investments		6.7			6.9
All Other		(1.2	)		(1.9	)
Net Income	$	111.0		$	105.8

Our net income during 2022 compared to 2021 primarily reflects the effects of the following factors:

Electric Utility

An increase in electric investments contributed to earnings for 2022. The new customer information system went live in September 2021 and Badger Hollow I was completed in November 2021.

Gas Utility

An increase in gas investments contributed to increased earnings for 2022. Higher gas retail sales resulting from colder weather in 2022 contributed to higher earnings for 2022. Heating degree days (a measure for determining the impact of weather during the heating season) increased by approximately 9% in 2022 compared to 2021.

During 2022, the following events occurred:

2022/2023 Rate Settlement Agreement: In December 2021, the PSCW approved a settlement agreement for MGE's 2022 rate case. The settlement agreement provides for an 8.81% increase to electric rates and a 2.15% increase to gas rates for 2022. As part of that settlement agreement, the PSCW approved a 0.96% increase in 2023 gas rates and a potential 2023 electric rate change to be addressed through a limited rate case reopener. See "Other Matters" below for additional information on the 2022/2023 rate case settlement.

Utility Solar: Large solar generation projects were recently completed or are under construction, as shown in the following table. Incurred costs are reflected in "Property, plant, and equipment, net" for projects placed in service, or "Construction work in progress" for projects under construction on the consolidated balance sheets.


Project	Ownership Interest	Share of Generation	Share of Estimated Costs(a)	Costs Incurred as of December 31, 2022(a)	Estimated Date of Commercial Operation
Red Barn	10%	9.16 MW	$18 million	$0.4 million(b)	Early 2023
Badger Hollow II	33%	50 MW	$76 million	$52.0 million(b)	Second half of 2023(c)
Paris	10%	31 MW	$51 million	$23.4 million	2023(d)

(a)

Excluding AFUDC.

(b)

MGE received specific approval to recover 100% AFUDC on Badger Hollow II and Paris. After tax, MGE recognized $2.6 million and $0.8 million of AFUDC equity earnings through December 31, 2022, on Badger Hollow II and Paris, respectively, during construction. AFUDC has been excluded from the costs incurred in the table above.

(c)

Includes an allocation of common facilities at Badger Hollow placed in service in November 2021.

(d)

Battery storage timing to be determined.

Deferred Fuel Costs: MGE under-recovered fuel costs in 2022. As of December 31, 2022, MGE had deferred $8.8 million of 2022 fuel costs. Coal transportation constraints resulted in reduced generation at Columbia, which required MGE to purchase power in the market at higher cost. We may continue to see increased fuel costs in the near term because of these coal transportation constraints. These costs will be subject to the PSCW's annual review of 2022 fuel costs, expected to be completed during 2023. See Footnote 9.b. of the Notes to Consolidated Financial Statements in this Report for further information regarding fuel proceedings.

During 2023, several items may affect us, including:

2021 Annual Fuel Proceeding: MGE under-recovered fuel costs in 2021. As of December 31, 2021, MGE had deferred $3.3 million of 2021 fuel costs. In August 2022, the PSCW issued a final decision in the 2021 fuel rules proceedings for MGE to include the recovery of these costs as part of the 2023 electric limited rate case reopener. There was no change to the costs to be recovered in the fuel rules proceedings from the amount MGE deferred in the previous year.

2023 Electric Limited Rate Case Reopener: In December 2022, the PSCW approved an 9.01% increase to electric rates for 2023. See "Other Matters" below for additional information on the 2023 electric limited rate case reopener.

ATC Return on Equity: As discussed in "Other Matters" below, ATC's authorized ROE, which is used in calculating its rates and revenues, is the subject of a challenge before FERC. A decrease in ATC's ROE could result in lower equity earnings and distributions from ATC in the future. We derived approximately 5.9% and 6.7% of our net income for the years ended December 31, 2022 and 2021, respectively, from our investment in ATC.

Environmental Initiatives: There are proposed legislative rules and initiatives involving matters related to air emissions, water effluent, hazardous materials, and greenhouse gases, all of which affect generation plant capital expenditures and operating costs as well as future operational planning. Legislation and rulemaking addressing climate change and related matters could significantly affect the costs of owning and operating fossil-fueled generating plants. We would expect to seek and receive recovery of any such costs in rates. However, it is difficult to estimate the amount of such costs due to the uncertainty as to the timing and form of any legislation or rules, and the scope and time of the recovery of costs in rates, which may occur after those costs have been incurred and paid.

Future Generation - 80% carbon reduction target by 2030 (from 2005 levels): MGE has outlined initiatives to achieve our raised target.

•

Transitioning away from coal. Columbia: MGE, along with the other plant co-owners, announced plans to retire Columbia Unit 1 and Unit 2 by June 2026. Final timing and retirement dates for Units 1 and 2 are subject to change depending on operational, regulatory, and other factors. MGE continues to evaluate additional investments to replace the generation from Columbia while maintaining electric service reliability. These investments include cost-effective, clean energy projects to help achieve MGE's carbon reduction goals.

Elm Road Units: MGE, along with the plant co-owner, announced plans to end the use of coal as a primary fuel at the Elm Road Units and transition the plant to natural gas. Transition plans and costs will be subject to PSCW approval. MGE's remaining use of coal is expected to be further reduced as the Elm Road Units transition to natural gas. By the end of 2030, coal is expected to be used only as a backup fuel at the Elm Road Units. This transition will help MGE meet its 2030 carbon reduction goals. By 2035, MGE expects that the Elm Road Units will be fully transitioned away from coal, which will eliminate coal as an internal generation source for MGE.

•

Growing renewable generation. MGE is seeking to acquire a joint interest in several renewable generation projects. See our 2023-2027 capital expenditures forecast included under "Liquidity and Capital Resources" below for information on these projects.

•

Natural gas as a fuel source. West Riverside: MGE received PSCW approval for its purchase of an ownership interest in West Riverside. See the 2023-2027 capital expenditures forecast included under "Liquidity and Capital Resources" below for additional information on West Riverside.

Solar Procurement Disruptions – Import Regulations: In June 2021, the U.S. Customs and Border Protection (CBP) issued a Withhold Release Order (WRO) against silica-based products made by Hoshine Silicon Industry Co. Ltd., a company located in China's Xinjiang Uyghur Autonomous Region. As a result of this WRO, CBP is holding many solar panels imported into the United States until importers can prove that the panels do not contain materials originating from this region. The Uyghur Forced Labor Protection Act, a federal law that became effective on June 21, 2022, further established that all goods mined, produced, or manufactured wholly or in part in Xinjiang or by certain defined entities are prohibited from U.S. importation. MGE is currently assessing the potential impact of these disruptions on current and future solar projects which may result in an increase in costs or delays in construction timelines. In the event that such disruptions cause costs to exceed the levels approved for specific projects, we expect to file a notification with the PSCW and expect to request recovery of any increases in MGE's next rate proceeding.

Solar Procurement Disruptions – Solar Tariff Investigation: In March 2022, the U.S. Department of Commerce (USDOC) announced a solar tariff investigation on solar panels from four Southeast Asian countries. This investigation could result in additional tariffs on solar panels. In June 2022, the USDOC issued a 24-month exemption from tariffs for solar panel and module imports from these four countries. MGE is currently assessing the potential impact of these disruptions on current and future solar projects which may result in an increase in costs or delays in construction timelines. In the event that such disruptions cause costs to exceed the levels approved for specific projects, we expect to file a notification with the PSCW and expect to request recovery of any increases in MGE's next rate proceeding.

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

Results of Operations

Year Ended December 31, 2022, Versus the Year Ended December 31, 2021

Electric sales and revenues

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


	Revenues					Sales (kWh)
(In thousands, except CDD)	2022		2021		% Change	2022	2021	% Change
Residential	$	161,300	$	151,646	6.4%	884,476	896,710	(1.4)%
Commercial		232,057		210,475	10.3%	1,790,397	1,779,725	0.6%
Industrial		13,303		12,529	6.2%	152,734	162,803	(6.2)%
Other-retail/municipal		37,323		35,169	6.1%	363,213	360,292	0.8%
Total retail		443,983		409,819	8.3%	3,190,820	3,199,530	(0.3)%
Sales to the market		19,385		9,499	104.1%	132,079	211,270	(37.5)%
Other revenues		1,799		968	85.8%	—	—	—%
Total	$	465,167	$	420,286	10.7%	3,322,899	3,410,800	(2.6)%

Cooling degree days (normal 699)						787	846	(7.0)%

Electric revenue increased $44.9 million during 2022 compared to 2021, due to the following:


(In millions)
Rate changes	$	38.0
Sales to the market		9.9
Customer fixed and demand charges		1.2
Other		0.8
Net increase in commercial, industrial and other-retail/municipal volume		0.3
Revenue subject to refund, net		(3.7	)
Decrease in residential volume		(1.6	)
Total	$	44.9

•

Rate changes. In December 2021, the PSCW authorized MGE to increase 2022 rates for retail electric customers by approximately 8.81%. Rates charged to retail customers during 2022 were $38.0 million higher than those charged during 2021. See Footnote 9 of the Notes to Consolidated Financial Statements in this Report for further information on rate increase. Any increase in rates associated with fuel or purchase power costs are generally offset in fuel and purchased power costs and do not have a significant impact on net income.

•

Sales to the market. Sales to the market typically occur when MGE has more generation and purchases in the MISO market than are needed for its customer demand. The excess electricity is then sold to other utilities or power marketers in the MISO market. During 2022, sales were made at higher market prices and partially offset by decreased market volume compared to 2021, reflecting a decrease in sales. The revenue generated from these sales is included in fuel rules monitored costs. See fuel rules discussion in Footnote 9 of the Notes to Consolidated Financial Statements.

•

Customer fixed and demand charges. During 2022, fixed and demand charges increased $1.2 million primarily attributable to the increase in demand charges for commercial customers.

•

Revenue subject to refund. For cost recovery mechanisms, any over-collection of revenues resulting from costs authorized to be collected from customers in rates exceeding actual costs is recorded as a reduction of revenue in the period incurred, as the over-collection is expected to be refunded to customers in a subsequent period. In the year the over-collection is refunded, rates are reduced and offset as revenue subject to refund. There is no net income impact in the year the costs are refunded.

•

Residential volume. During 2022, residential sales decreased by approximately 1% compared to 2021. This decrease was driven by a shift in usage patterns reflecting a reduction in remote work associated with the COVID-19 pandemic.

Electric fuel and purchased power


	Year Ended December 31,
(In millions)	2022		2021		$ Change
Fuel for electric generation	$	61.3	$	54.6	$	6.7
Purchased power		46.8		39.4		7.4

The $6.7 million increase in fuel for electric generation was due to an approximately 25% increase in the average cost offset by an approximately 10% decrease in internal generation. Coal transportation constraints resulted in reduced generation at Columbia, which required MGE to purchase power in the market at higher cost.

The $7.4 million increase in purchased power was due to an approximately 26% increase in market purchases as a result of lower internal generation. Also, fuel costs deferred as a regulatory asset increased $5.5 million contributing to the change in purchased power.

Fuel and purchased power costs are generally offset by electric revenue and do not have a significant impact on net income. MGE expects to seek and receive recovery of fuel and purchased power costs outside the fuel rules bandwidth in customer rates. See Footnote 9 of the Notes to Consolidated Financial Statements in this Report for further information on the fuel rules bandwidth.

Gas deliveries and revenues

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


(In thousands, except HDD and average	Revenues					Therms Delivered
rate per therm of retail customer)	2022		2021		% Change	2022	2021	% Change
Residential	$	143,544	$	110,442	30.0%	114,162	100,173	14.0%
Commercial/Industrial		99,165		68,895	43.9%	106,911	92,554	15.5%
Total retail		242,709		179,337	35.3%	221,073	192,727	14.7%
Gas transportation		5,780		6,185	(6.5)%	78,966	76,217	3.6%
Other revenues		183		98	86.7%	—	—	—%
Total	$	248,672	$	185,620	34.0%	300,039	268,944	11.6%
Heating degree days (normal 6,977)						7,210	6,619	8.9%
Average rate per therm of retail customer	$	1.098	$	0.931	17.9%

Gas revenue increased $63.1 million during 2022 compared to 2021, due to the following:


(In millions)
Rate changes	$	45.3
Increase in volume		16.1
Other		1.8
Revenue subject to refund, net		(0.1	)
Total	$	63.1



Rate changes. In December 2021, the PSCW authorized MGE to increase 2022 rates for retail gas customers by 2.15%.

MGE recovers the cost of natural gas in its gas segment through the purchased gas adjustment clause (PGA). Under the PGA, MGE is able to pass through to its gas customers the cost of gas. Changes in PGA recoveries affect revenues but do not change net income in view of the pass-through treatment of the costs. Payments for natural gas increased driving higher rates during 2022. The average retail rate per therm for 2022, increased approximately 18% compared to 2021, reflecting an increase in natural gas commodity costs (recovered through the PGA).

•

Volume. For 2022 retail gas deliveries increased approximately 15% compared to 2021 primarily related to favorable weather conditions in the current year.

•

Other. Other revenues increased primarily related to increase in gas customers in 2022 increasing revenue recorded for fixed customer charge compared to 2021.

Cost of gas sold

A $52.9 million increase in cost of gas sold driven by higher cost per therm of gas. Average cost per therm increased approximately 35%. An increase in volume of approximately 13% also contributed to the increase in cost. MGE recovers the cost of natural gas in its gas segment through the PGA as described under gas deliveries and revenue above.

Consolidated operations and maintenance expenses

For 2022, operations and maintenance expenses increased $10.5 million, compared to 2021. The following contributed to the net change:


(In millions)
Increased administrative and general costs	$	5.6
Increased customer accounts costs		2.9
Increased electric production expenses		0.7
Increased electric distribution expenses		0.6
Increased gas distribution expenses		0.6
Increased other expenses		0.1
Total	$	10.5

•

Increased administrative and general costs are primarily related to an increase in pension and OPEB service costs.

•

Increased customer accounts are primarily related to increased costs associated with the new customer information system, which went live in September 2021.

Consolidated depreciation expense

Electric depreciation expense increased $6.2 million and gas depreciation expense increased $2.4 million for 2022, compared to 2021. MGE placed Badger Hollow I in service in November 2021. The timing of the in-service date contributed to the increase in electric depreciation expense. The new customer information system went live in September 2021, which increased depreciation expense for both electric and gas in 2022.

Electric and gas other income

Electric other income increased $2.9 million and gas other income increased $5.6 million during 2022, compared to 2021, primarily related to the collection in 2021 of the deferred pension and other postretirement other than service costs from 2019.

Nonregulated Energy Operations - MGE Energy and MGE

The nonregulated energy operations are conducted through MGE Energy's subsidiaries: MGE Power Elm Road (the Elm Road Units) and MGE Power West Campus (WCCF), which have been formed to own and lease electric generating capacity to assist MGE. For 2022 and 2021, net income at the nonregulated energy operations segment was $22.1 million and $21.4 million, respectively.

Transmission Investment Operations - MGE Energy

The transmission investment segment holds our interest in ATC and ATC Holdco, and its income reflects our equity in the earnings of those investments. ATC Holdco was formed in December 2016 to pursue transmission development opportunities that typically have long development and investment lead times before becoming operational. ATC Holdco's transmission development activities have been suspended for the near term. During 2022 and 2021, other income at the transmission investment segment primarily reflects ATC's operations and was $9.1 million and $9.3 million, respectively. In August 2022, the U.S. Court of Appeals for the D.C. Circuit vacated the underlying FERC orders regarding methodology for setting authorized return on equity resulting in an additional estimated possible loss. See Footnote 7 of the Notes to Consolidated Financial Statements in this Report and "Other Matters" below for additional information concerning ATC and summarized financial information regarding ATC.

Consolidated Income Taxes - MGE Energy and MGE

In 2022, the effective electric tax rate increased as a result of the return of electric excess deferred taxes related to the 2017 Tax Act not governed by IRS normalization rules in 2021. These costs were recorded as a regulatory

liability in the year of remeasurement. See Footnote 10 of the Notes to Consolidated Financial Statements in this Report for the effective tax rate reconciliation.

Noncontrolling Interest, Net of Tax - MGE

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


	Year Ended December 31,
(In millions)	2022		2021
MGE Power Elm Road	$	14.3	$	15.2
MGE Power West Campus		7.3		7.2

Liquidity and Capital Resources

MGE Energy and MGE expect to have adequate liquidity to support future operations and capital expenditures over the next twelve months. Available resources include cash and cash equivalents, operating cash flows, liquid assets, borrowing working capacity under revolving credit facilities, and access to equity and debt capital markets. MGE Energy expects to generate funds from operations and both long-term and short-term debt financing. See "Credit Facilities" below for information regarding MGE Energy's and MGE's credit facilities.

Cash Flows

The following summarizes cash flows for MGE Energy and MGE during 2022 and 2021:


	MGE Energy						MGE
(In thousands)	2022			2021			2022			2021
Cash provided by (used for):
Operating activities	$	153,735		$	137,527		$	151,067		$	130,240
Investing activities		(180,145	)		(156,975	)		(176,095	)		(154,878	)
Financing activities		25,543			(8,756	)		27,730			26,032

Cash Provided by Operating Activities

Cash flows from operating activities for MGE Energy and MGE principally reflect the receipt of customer payments for electric and gas service and outflows related to fuel for electric generation, purchased power, gas, and operation and maintenance expenditures.

MGE Energy

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

Cash provided by operating activities during 2022 was $153.7 million, an increase of $16.2 million when compared to 2021.

MGE Energy's net income increased $5.2 million for 2022 when compared to 2021.

MGE Energy's net federal and state taxes paid decreased $0.8 million during 2022, when compared to 2021.

Working capital accounts (excluding prepaid and accrued taxes) resulted in $40.5 million in cash used for operating activities for 2022, primarily due to increased gas inventory driven by the increase cost of gas, increased unbilled

revenues, and customer receivables. These increases in cash used for operations were partially offset by an increase in accounts payable.

Working capital accounts (excluding prepaid and accrued taxes) resulted in $36.5 million in cash used for operating activities for 2021, primarily due to increased accounts receivable, increased other receivables, increased unbilled revenues, increase in gas inventory, and decrease in other current liabilities. Natural gas costs increased significantly throughout the central part of the country in February 2021 related to extreme weather conditions. In addition to those increased natural gas costs, we incurred higher natural gas costs throughout 2021, as a result of an increase in the price of natural gas. The decrease in other current liabilities is attributable to a $3.2 million one-time fuel credit returned to retail customers in 2021. These increases in cash used for operations were partially offset by an increase in accounts payable.

Hosted software asset expenditures during 2022 were $0.5 million. This amount represents a decrease of $2.9 million in cash used when compared to 2021.

MGE

Cash provided by operating activities for 2022 was $151.1 million, an increase of $20.8 million when compared to 2021.

Net income increased $4.7 million for 2022 when compared to 2021.

MGE's net federal and state taxes paid decreased $2.4 million during 2022, when compared to 2021.

Working capital accounts (excluding prepaid and accrued taxes) resulted in $40.0 million in cash used for operating activities for 2022, primarily due to increased gas inventory driven by the increase cost of gas, increased unbilled revenues, and customer receivables. These increases in cash used for operations were partially offset by an increase in accounts payable.

Working capital accounts (excluding prepaid and accrued taxes) resulted in $39.0 million in cash used for operating activities for 2021, primarily due to increased accounts receivable, increased other receivables, increased unbilled revenues, increase in gas inventory, and decreased other current liabilities. Natural gas costs increased significantly throughout the central part of the country in February 2021 related to extreme weather conditions. In addition to those increased natural gas costs, we incurred higher natural gas costs throughout 2021, as a result of an increase in the price of natural gas. The decrease in other current liabilities is attributable to a $3.2 million one-time fuel credit returned to retail customers in 2021. These increases in cash used for operations were partially offset by an increase in accounts payable.

Hosted software asset expenditures during 2022 were $0.5 million. This amount represents a decrease of $2.9 million in cash used when compared to 2021.

Capital Requirements and Investing Activities

Cash outflows for MGE Energy and MGE principally reflect capital expenditures. See "Capital Expenditures" below for more information.

MGE Energy

MGE Energy's cash used for investing activities increased $23.2 million for 2022 when compared to 2021.

Capital expenditures for 2022 were $175.0 million. This amount represents an increase of $21.9 million from the expenditures made in 2021. This increase primarily reflects the increase of expenditures for Badger Hollow II and Paris.

Capital contributions in ATC and other investments increased $1.2 million for 2022 when compared to 2021.

Proceeds from the sale of investments decreased $0.8 million during 2022, when compared to 2021.

MGE

MGE's cash used for investing activities increased $21.2 million for 2022 when compared to 2021.

Capital Expenditures

The following table shows MGE Energy's actual capital expenditures for both 2021 and 2022, and forecasted capital expenditures for 2023 through 2027:


(In thousands)	Actual				Forecasted
For the years ended December 31,	2021		2022		2023		2024		2025		2026		2027
Electric	$	115,234	$	141,273	$	174,500	$	186,200	$	181,800	$	185,700	$	161,100
Gas		34,071		27,656		34,300		30,000		31,000		29,400		30,800
Utility plant total		149,305		168,929		208,800		216,200		212,800		215,100		191,900
Nonregulated		3,864		6,101		6,400		10,100		6,100		4,000		5,200
MGE Energy total	$	153,169	$	175,030	$	215,200	$	226,300	$	218,900	$	219,100	$	197,100

Forecasted capital expenditures are based upon management's assumptions with respect to future events, including the timing and amount of expenditures associated with environmental compliance initiatives, legislative and regulatory action, supply chain and market disruptions, customer demand and support for electrification and renewable energy resources, energy conservation programs, load growth, the timing of any required regulatory approvals, and the adequacy of rate recovery. Actual events may differ materially from these assumptions and result in material changes to those forecasted amounts.

MGE is targeting at least 80% carbon reduction from electric generation by 2030 (from 2005 levels) and net-zero carbon electricity by 2050. Solar, wind, and battery storage projects are a major step toward deep decarbonization and greater use of clean energy sources in pursuit of our goal. MGE continues to evaluate solar, wind, and battery storage projects that align with its goals as legacy fossil fuel-fired facilities are retired. The target early retirement date for Columbia is June 2026. MGE has included forecasted capital expenditures for the years 2023 through 2026 for projects to replace Columbia's generation.

The following table provides further detail of MGE Energy's forecasted capital expenditures, separating spending into capital project categories for 2023 through 2027:


(In thousands)	Forecasted
For the years ended December 31,	2023	2024	2025	2026	2027
Electric renewables(a)	$76,300	$88,200	$98,400	$117,200	$85,600
Electric production	37,600	37,100	18,500	5,700	9,300
Electric distribution	60,600	60,900	64,900	62,800	66,200
Gas distribution	34,300	30,000	31,000	29,400	30,800
Utility plant total	208,800	216,200	212,800	215,100	191,900
Nonregulated	6,400	10,100	6,100	4,000	5,200
MGE Energy total	$215,200	$226,300	$218,900	$219,100	$197,100

(a)

Includes solar and wind generation and battery storage.

Our forecasted capital expenditures reflect the following significant renewable projects that are proposed or currently under construction:


Project	Source	Ownership Interest	Share of Generation/Battery Storage	Share of Costs(c)	Estimated Date of Commercial Operation
Red Barn(a)	Wind	10%	9.16MW	$18 million(e)	Early 2023
Badger Hollow II(a)	Solar	33%	50MW	$76 million(d)(e)	Second Half of 2023
Paris(a)	Solar/Battery	10%	20MW/11MW	$51 million(d)(e)	2023(f)
Darien(a)	Solar/Battery	10%	25MW/7.5MW	$45 million(d)	2024(f)
Koshkonong(b)	Solar/Battery	10%	30MW/16.5MW	$65 million(d)	2025(f)

(a)

Approved by the PSCW.

(b)

Pending approval by the PSCW. There is no certainty that this project will be approved by the PSCW.

(c)

Excluding AFUDC.

(d)

Requested, in the case of projects pending PSCW approval, or received, in the case of Badger Hollow II, Paris, and Darien, approval to recover 100% AFUDC.

(e)

See Footnote 6 of Notes to Consolidated Financial Statements in the Report for information on costs incurred.

(f)

Battery storage timing to be determined.

In 2022, MGE notified the PSCW of increases in projected costs at Badger Hollow II and Paris. The main drivers were increases in the costs of key commodities, labor, and solar modules resulting from supply chain and market disruptions. See Footnote 6 of Notes to Consolidated Financial Statements in this Report for more information on these projects. Furthermore, solar procurement disruptions have also shifted construction timelines for Darien and Koshkonong. Projected completion dates of these projects are one year later than originally anticipated. MGE continues to assess the potential impact of these disruptions on current and future solar projects that may result in an increase in costs or delays in construction timelines. See further information on procurement disruptions discussed earlier under "Executive Overview."

West Riverside: In December 2022, the PSCW approved MGE's request for its purchase of an ownership interest in the West Riverside Energy Center, a highly efficient, state-of-the-art natural gas-fired plant in Beloit, Wisconsin. MGE's share of West Riverside will be 25 MW at a purchase price of approximately $25 million. The acquisition of that ownership interest is expected to occur in March 2023. MGE also has an option to purchase an additional 25 MW of capacity from West Riverside until May 2025. MGE currently expects to file in the first half of 2023 with the PSCW a request for a purchase of the additional 25 MW.

Electric and Gas Distribution: In 2023 through 2027, electric and gas capital expenditures include investment in enhanced metering solutions to provide customers with more timely and detailed energy use information. Investments in advanced metering infrastructure will provide additional benefits including outage and demand response and automated meter reading capabilities. Forecasted capital expenditures in those years is approximately $36 million.

Financing Activities

The principal sources and uses of cash are related to short-term and long-term borrowings and repayments and the payment of cash dividends.

MGE Energy

Cash provided by MGE Energy's financing activities was $25.5 million for 2022, compared to $8.8 million of cash used for financing activities in 2021.

For 2022, cash dividends paid were $57.5 million compared to $54.8 million in 2021. The increase reflected a higher dividend rate per share ($1.59 vs. $1.52).

During 2022, MGE borrowed $25.0 million of senior unsecured notes whose proceeds were used to assist with the payment of additional capital expenditures and other corporate obligations compared to $100.0 million of borrowings in 2021.

For 2022, net short-term debt borrowings were $65.0 million, compared to $47.0 million of repayments in 2021.

MGE

During 2022, cash provided by MGE's financing activities was $27.7 million, compared to $26.0 million of cash provided by financing activities in 2021.

Cash dividends to parent (MGE Energy) were $33.5 million in 2022, compared to $5.0 million in 2021.

Distributions to parent (MGE Energy) from noncontrolling interest, which represent distributions from MGE Power Elm Road and MGE Power West Campus, were $22.0 million for 2022, compared to $15.0 million in 2021. The noncontrolling interest arises from the accounting required for the entities, which are not owned by MGE but are consolidated as VIEs.

During 2022, MGE issued $25.0 million of senior unsecured notes whose proceeds were used to assist with the payment of additional capital expenditures and other corporate obligations compared to $100.0 million of borrowings in 2021.

For 2022, net short-term debt borrowings were $65.0 million compared to $47.0 million of repayments in 2021.

Dividend Restrictions

Dividend payments by MGE to MGE Energy are subject to restrictions arising under a PSCW rate order and, to a lesser degree, MGE's first mortgage bonds. The PSCW order restricts any dividends that MGE may pay MGE Energy if its common equity ratio, calculated in the manner used in the rate proceeding, is less than 55%. MGE's thirteen month rolling average common equity ratio as of December 31, 2022, is 60.5%, as determined under the calculation used in the rate proceeding. This restriction did not restrict MGE's payment of dividends in 2022. Cash dividends of $33.5 million and $5.0 million, respectively, were paid by MGE to MGE Energy in 2022 and 2021. The rate proceeding calculation includes indebtedness imputed amounts for MGE's outstanding purchase power capacity payments and other PSCW adjustments but does not include the indebtedness associated with MGE Power Elm Road and MGE Power West Campus, which are consolidated into MGE's financial statements but are not direct obligations of MGE.

MGE has covenanted with the holders of its first mortgage bonds not to declare or pay any dividend or make any other distribution on or purchase any shares of its common stock unless, after giving effect thereto, the aggregate amount of all such dividends and distributions and all amounts applied to such purchases, after December 31, 1945, shall not exceed the earned surplus (retained earnings) accumulated subsequent to December 31, 1945. As of December 31, 2022, approximately $650.1 million was available for the payment of dividends under this covenant.

MGE Power West Campus has covenanted with the holders of its outstanding senior secured notes not to declare or make distributions to us in the event that, both before and after giving effect to such distribution, its total debt to total capitalization would exceed 0.65 to 1.00 or its projected debt service coverage ratio for the following four fiscal quarters would be less than 1.25 to 1.00. Projected debt service coverage considers the projected revenues available for debt service, after deducting expenses other than debt service, in relation to projected debt service on indebtedness.

MGE Power Elm Road has covenanted with the holders of its outstanding senior secured notes not to declare or make distributions to us in the event that, both before and after giving effect to such distribution, its projected debt service coverage ratio for the following four fiscal quarters would be less than 1.25 to 1.00. Projected debt service coverage considers the projected revenues available for debt service, after deducting expenses other than debt service, in relation to projected debt service on indebtedness.

Credit Facilities

As of December 31, 2022, MGE Energy and MGE had the following aggregate bank commitments and available capacity under their credit agreements:


Borrower	Aggregate Bank Commitments		Outstanding Commercial Paper		Letters of Credit Issued Inside Credit Facilities		Outstanding Borrowings		Available Capacity		Expiration Date
(In millions)
MGE Energy	$	50.0	$	—	$	—	$	—	$	50.0	November 8, 2027
MGE	$	100.0	$	70.5	$	0.7	$	—	$	28.8	November 8, 2027

In January 2023, MGE amended one of its credit agreements to increase the available credit by an additional $30 million, increasing MGE's aggregate bank commitments to $130 million.

Borrowings under the Credit Agreements may bear interest at a rate based upon either a "floating rate" or an "Adjusted Term SOFR Rate," plus an adder based upon the credit ratings assigned to MGE's senior unsecured long-term debt securities. The "floating rate" is calculated on a daily basis as the highest of a prime rate and several adjusted interest rate indices (as set forth in the Credit Agreements), subject to a floor of one percent per annum or zero, depending on the credit agreement. The "floating rate" adder ranges from zero to 0.125%. The "Adjusted Term SOFR Rate" is calculated as provided in the Credit Agreements. The "Adjusted Term SOFR Rate" adder ranges from 0.625% to 1.125%.

The credit agreements require the borrower to maintain a ratio of consolidated debt to consolidated total capitalization not to exceed a maximum of 65%. In the case of MGE, the ratio calculation excludes assets, liabilities, revenues, and expenses included in MGE's financial statements as a result of the consolidation of VIEs, such as MGE Power Elm Road and MGE Power West Campus. As of December 31, 2022, the ratio of consolidated debt to consolidated total capitalization for each of MGE Energy and MGE, as calculated under the credit agreements' covenant, were 39.6% and 42.4%, respectively. See Footnote 13 of the Notes to Consolidated Financial Statements in this Report for additional information regarding the credit facilities.

Capitalization Ratios

MGE Energy's capitalization ratios were as follows:


	MGE Energy
	2022			2021
Common shareholders' equity		60.4	%		62.2	%
Long-term debt(a)		35.7	%		37.5	%
Short-term debt		3.9	%		0.3	%

(a)

Includes the current portion of long-term debt.

Credit Ratings

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

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

Contractual Obligations and Commercial Commitments for MGE Energy and MGE

MGE Energy's and MGE's contractual obligations as of December 31, 2022, representing cash obligations that are considered to be firm commitments, are as follows:


			Payment Due Within:						Due After
(In thousands)	Total		1 Year		2-3 Years		4-5 Years		5 Years
MGE Energy
Long-term debt(a)	$	643,560	$	54,314	$	10,431	$	56,021	$	522,794
Short-term debt(b)		70,500		70,500		-		-		-
Interest expense(c)		379,818		25,988		49,189		47,154		257,487
Leases(d)		58,660		2,154		3,307		2,456		50,743
Purchase obligations(e)		284,531		116,752		93,775		35,908		38,096
Construction obligations(f)		47,633		47,633		-		-		-
Other obligations(g)		15,350		9,754		1,866		1,398		2,332
Total MGE Energy contractual obligations	$	1,500,052	$	327,095	$	158,568	$	142,937	$	871,452

MGE
Long-term debt(a)	$	643,560	$	54,314	$	10,431	$	56,021	$	522,794
Short-term debt(b)		70,500		70,500		—		—		—
Interest expense(c)		379,818		25,988		49,189		47,154		257,487
Leases(d)		58,660		2,154		3,307		2,456		50,743
Purchase obligations(e)		284,531		116,752		93,775		35,908		38,096
Construction obligations(f)		47,633		47,633		—		—		—
Other obligations(g)		6,483		887		1,866		1,398		2,332
Total MGE contractual obligations	$	1,491,185	$	318,228	$	158,568	$	142,937	$	871,452

(a)

Long-term debt consisting of secured first mortgage bonds, unsecured medium-term notes, and Industrial Development Revenue Bonds issued by MGE, and private placement debt issued by MGE, MGE Power Elm Road, and MGE Power West Campus. In November 2022, MGE entered into a private placement Note Purchase Agreement in which it committed to issue $25 million of new long-term debt (Series A), $15 million of new long-term debt (Series B), carrying an interest rate of 5.43% per annum over its 10-year life, and $35 million of new long-term debt (Series C), carrying an interest rate of 5.53% per annum over its 12-year life. Funding occurred on December 1, 2022, for Series A and will occur on February 28, 2023, for Series B and Series C. The proceeds of the debt financing will be used to assist with capital expenditures and other corporate obligations.

(b)

Short-term debt consisting of commercial paper for MGE. See Footnote 13 of the Notes to Consolidated Financial Statements in this Report.

(c)

Amount represents interest expense on long-term debt. See Footnote 14 of the Notes to Consolidated Financial Statements in this Report for further discussion of the long-term debt outstanding as of December 31, 2022.

(d)

Leases. See Footnote 5 of the Notes to Consolidated Financial Statements in this Report.

(e)

Purchase obligations consist primarily of the purchase of electricity and natural gas, electric transmission, natural gas storage capacity, natural gas pipeline transportation, and the purchase and transport of coal. See Footnote 16.c. of the Notes to Consolidated Financial Statements in this Report.

(f)

Construction obligations consist primarily of Badger Hollow II, Paris, and other renewable projects. In January 2023, MGE entered into an asset purchase agreement for approximately $10 million for a solar generating facility. The project is expected to be in service in 2023. This amount is excluded from the table above.

(g)

Other obligations are primarily related to investment commitments, environmental projects, and uncertain tax positions.

The above amounts do not include any contributions for MGE's pension and postretirement plans. MGE does not expect to need to make any required contributions to the qualified plans for 2023. The contributions for years after 2023 are not yet currently estimated. Due to uncertainties in the future economic performance of plan assets, discount rates, and other key assumptions, estimated contributions are subject to change. MGE may also elect to make additional discretionary contributions to the plans.

The above amounts do not include future capital calls by ATC and ATC Holdco. In January 2023, MGE Transco made a $0.4 million contribution to ATC. The amount and timing of future capital calls to these entities is uncertain and primarily dependent on the operations and expansion of ATC and the resumption of development activities by ATC Holdco.

MGE Energy's and MGE's commercial commitments as of December 31, 2022, representing commitments triggered by future events and including financing arrangements to secure obligations of MGE Energy and MGE, are as follows:


			Expiration Within:						Due After
(In thousands)	Total		1 Year		2-3 Years		4-5 Years		5 Years
MGE Energy
Lines of credit(a)(c)	$	150,000	$	—	$	—	$	150,000	$	—

MGE
Lines of credit(b)(c)	$	100,000	$	—	$	—	$	100,000	$	—

(a)

Amount includes the facilities discussed in (b) plus an additional line of credit. MGE Energy has available at any time a $50 million committed revolving credit agreement, expiring in November 2027. As of December 31, 2022, MGE Energy had no borrowings outstanding under this credit facility.

(b)

Amount includes two committed revolving credit agreements totaling $100 million expiring in November 2027. These credit facilities are used to support commercial paper issuances. As of December 31, 2022, MGE had $70.5 million of commercial paper outstanding backed by the facilities but no borrowings outstanding. As of December 31, 2022, MGE had $0.7 million of letters of credit issued inside credit facilities.

(c)

In January 2023, MGE amended its credit agreement to increase the line of credit available an additional $30 million. This amount has been excluded from the table above.

Other Matters

Rate Matters

In December 2021, the PSCW approved a settlement agreement for MGE's 2022 rate case. The settlement agreement provides for an 8.81% increase for electric rates and a 2.15% increase to gas rates for 2022. As part of the settlement agreement, the PSCW approved a 0.96% increase in 2023 gas rates and a potential 2023 electric rate change to be addressed through a limited rate case reopener.

In December 2022, the PSCW approved the electric rate case reopener. The reopener provides for a 9.01% increase to electric rates for 2023.

Details related to MGE's 2022/2023 approved settlement agreement and 2023 electric limited reopener are shown in the table below:


(Dollars in thousands)	Authorized Average Rate Base(a)		Authorized Average CWIP(b)		Authorized Return on Common Equity(c)			Common Equity Component of Regulatory Capital Structure			Effective Date
Electric (2022 Test Period)	$	1,044,362	$	19,976		9.8	%		55.63	%	1/1/2022
Gas (2022 Test Period)		299,319		11,410		9.8	%		55.63	%	1/1/2022
Electric (2023 Test Period)	$	1,162,516	$	19,976		9.8	%		55.63	%	1/1/2023
Gas (2023 Test Period)		312,270		8,228		9.8	%		55.63	%	1/1/2023

(a)

Average rate base amounts reflect MGE's allocated share of rate base and do not include construction work in progress (CWIP) or a cash working capital allowance and were calculated using a forecasted 13-month average for the test periods. The PSCW provides a return on selected CWIP and a cash working capital allowance by adjusting the percentage return on rate base.

(b)

50% of the forecasted 13-month average CWIP for the test periods which earns an AFUDC return. Projects eligible to earn 100% AFUDC are excluded from this balance and discussed further in the Management Discussion and Analysis of Financial Condition and Results of Operations - Executive Overview section.

(c)

Authorized returns on common equity may not be indicative of actual returns earned or projections of future returns, as actual returns will be affected by the volume of electricity or gas sold.

See Footnote 9.a. of the Notes to Consolidated Financial Statements in this Report for further discussion of rate proceedings.

ATC

MISO transmission owners, including ATC, are involved in two complaints filed at FERC by several parties challenging that the base ROE in effect for MISO transmission owners, including ATC, was no longer just and reasonable. Each complaint provided for a 15-month statutory refund period: November 12, 2013 through February 11, 2015 (the "First Complaint Period") and February 12, 2015 through May 11, 2016 (the "Second Complaint Period").

In May 2020, FERC issued an order further refining the methodology for setting authorized ROE. This refined methodology increased the authorized ROE from 9.88% to 10.02%. This base ROE is effective for the First Complaint Period and for all periods following September 2016. This order also dismissed the second complaint. Accordingly, no refunds were ordered for the Second Complaint Period.

As a result of the May 2020 FERC order, our share of ATC's earnings reflected a $0.6 million reduction of our reserve. Additionally, our share of ATC's earnings reflected the derecognition of a possible refund related to the Second Complaint Period as ATC considered such a refund to be no longer probable. However, due to pending requests for rehearing, a loss related to the 2015 complaint remains possible. Our share of the estimated refund for the Second Complaint Period is approximately $2.3 million. MGE has not recorded a possible loss for the Second Complaint Period.

Several petitions for review of FERC’s prior orders were filed with the U.S. Court of Appeals for the D.C. Circuit (the "Court") and an oral argument was held in November 2021. In August 2022, the Court ruled that four of the five arguments made by the complaining parties were unpersuasive. However, the Court agreed that FERC’s decision to reintroduce a risk-premium model into its ROE methodology was arbitrary and capricious. The Court vacated the underlying orders for the First Complaint Period and remanded to FERC for further proceedings. In 2022, our share of ATC's earnings reflected an estimated possible loss of approximately $0.9 million, inclusive of interest and net of tax, for a possible additional refund for the First Complaint Period and for the period following the Second Complaint Period. Although the Court agreed that FERC was correct to use the base ROE established in the first complaint to adjudicate the second, and that FERC was right to dismiss the second complaint, the second complaint was also remanded for FERC to reopen proceedings. Any reduction in ATC's ROE could result in lower equity earnings and distributions from ATC in the future.

We derived approximately 5.9%, 6.7%, and 8.0%, respectively, of our net income for 2022, 2021, and 2020 from our investment in ATC.

Inflation Reduction Act

In August 2022, the Inflation Reduction Act (IRA) was signed into law. Among other provisions, the IRA: extends current PTC and ITC for renewable technologies (e.g., wind and solar); restores full value of the PTC and ITC for qualifying facilities placed into service after 2021 that satisfy prevailing wage and apprenticeship requirements; creates a PTC for solar, clean hydrogen and nuclear; establishes an ITC for energy storage, microgrids, and interconnection facilities; and allows companies to monetize or sell credits to unrelated parties. In addition, the IRA created a new corporate alternative minimum tax (AMT). MGE Energy does not expect to be subject to the AMT in the near term. Implementation of IRA provisions is subject to the issuance of additional guidance by the U.S. Treasury Department. While the final impact cannot be determined at this time, the IRA did not have a material impact on MGE Energy and MGE for the year ending December 31, 2022.

Critical Accounting Estimates - MGE Energy and MGE

The preparation of financial statements in conformity with accounting principles generally accepted in the United States of America requires management to make estimates and judgments that affect the reported amounts of assets, liabilities, revenues and expenses, and related disclosure of contingent assets and liabilities. On an on-going basis, we evaluate our estimates, including those related to regulatory assets and liabilities, unbilled revenues, pension obligations, and income taxes. We base our estimates on historical experience and on various assumptions that are believed to be reasonable under the circumstances, the results of which form the basis for making judgments about the carrying values of assets and liabilities that are not readily apparent from other sources. Those values may differ from these estimates under different assumptions or conditions. We believe the following critical accounting estimates affect our more significant judgments used in the preparation of our consolidated financial statements.

Regulatory Assets/Liabilities

Regulatory assets represent costs that have been deferred to future periods when it is probable that the regulator will allow future recovery of those costs through rates. MGE bases its assessment of recovery on precedents

established by the regulatory body. Regulatory liabilities represent previous collections from customers that are expected to be refunded to customers in future periods. Regulatory assets and regulatory liabilities typically include deferral of energy costs, the normalization of income taxes, pension and other postretirement costs, the deferral of certain operating expenses, and non-ARO removal costs. The accounting for these regulatory assets and liabilities is in accordance with regulatory accounting standards.

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

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

Unbilled Revenues

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

•

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

•

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

•

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

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

Pension and Other Postretirement Benefit Plans

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

MGE uses third-party specialists to assist with evaluating its assumptions and measurement of the costs and obligations associated with these retirement benefits. The discount rate and expected return on plan assets are based primarily on available investment yields and the historical performance of plan assets. They are critical accounting estimates because they are subject to management's judgment and can materially affect financial performance.

•

Assumed return on assets. This assumption represents the rate of return on plan assets reflecting the average

rate of earnings expected on the funds invested (or to be invested) to provide for the benefits included in the projected benefit obligation. For 2022, MGE used an assumed return on assets of 6.75% for pension and 6.40% for other postretirement benefits. In 2023, the pension asset assumption will increase to 7.00% and the postretirement benefit assumption will increase to 6.59%. The annual expected rate of return is based on projected long-term equity and bond returns, maturities and asset allocations. Holding other assumptions constant, for every 1% reduction in the expected rate of return on plan assets, annual pension and other postretirement cost would increase by approximately $5.2 million, before taxes.

•

Discount rate. The discount rate represents the rate at which pension obligations could effectively be settled on a present-value basis. MGE uses high-grade bond yields as a benchmark for determining the appropriate discount rate. MGE uses individual spot rates rather than a weighted average of the yield curve spot rates to measure the service cost and interest cost components for net periodic benefit cost. Holding other assumptions constant, a 0.5% decrease in the discount rate on the obligation balance as of December 31, 2022, would increase annual pension and other postretirement cost by approximately $1.9 million, before taxes.

•

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

•

Mortality rate assumption. Expected mortality rates are used in the valuation to determine the expected duration of future benefit payments to the plan participants. MGE utilizes mortality tables and projection scales developed by the society of actuaries. These tables and scales were last updated in 2021.

See Footnote 11 of the Notes to Consolidated Financial Statements in this Report for additional discussion of these plans.

Income Tax Provision

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

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

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

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

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

Commodity Price Risk

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

The recovery of MGE's electric fuel costs is subject to fuel rules established by the PSCW. Fuel rules require Wisconsin utilities to defer electric fuel-related costs that fall outside a symmetrical cost tolerance band. Any over or under recovery of the actual costs is determined in the following year and is then reflected in future billings to electric retail customers. MGE is subject to a plus or minus 1% range in 2022 increasing to 2% in 2023. MGE assumes the risks and benefits of variances that are within the cost tolerance band. For 2023, $95.9 million in fuel and purchased power costs will be recovered in rates and are subject to this rule and included in MGE's fuel monitoring level rates. See Footnote 9.b. of the Notes to Consolidated Financial Statements in this Report for additional information on fuel rules.

MGE recovers the cost of natural gas in its gas utility segment through the purchased gas adjustment clause (PGA). Under the PGA, MGE is able to pass through to its gas customers the cost of gas. If the commodity costs of gas exceed a monthly benchmark amount, the excess amount is subject to a prudence review and approval by the PSCW before it can be passed through to customers.

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

MGE has financial gas and electric commodity contracts to hedge commodity price risk in the gas and electric utility segments. These contracts are primarily comprised of exchange-traded option and future contracts. MGE also holds financial transmission rights (FTRs), which are used to hedge the risk of increased transmission congestion charges. As of December 31, 2022, the cost basis of exchange traded derivatives and FTRs exceeded their fair value by $5.1 million. Under the PGA clause and electric fuel rules, MGE may include the costs and benefits of the aforementioned fuel price risk management tools in the costs of fuel (natural gas or power). Because these costs or benefits are recoverable, the related unrealized loss or gain has been deferred on the consolidated balance sheets as a regulatory asset or liability, respectively.

Interest Rate Risk

Both MGE Energy and MGE may have short term borrowings at varying interest rates. MGE issues commercial paper for its short-term borrowings, while MGE Energy draws from its current credit facility to meet short-term borrowing needs. Borrowing levels vary from period to period depending upon capital investments and other factors. Future short-term interest expense and payments will reflect both future short-term interest rates and borrowing levels. MGE Energy and MGE manage interest rate risk by limiting their variable rate exposure and continually monitoring the effects of market changes on interest rates. MGE is not exposed to changes in interest rates on a substantial portion of its long-term debt until that debt matures and is refinanced at market rates. Assuming the current level of variable rate borrowings and assuming a 1% change in the 2022 average interest rate under those borrowings, it is estimated that our 2022 interest expense and net income would have changed $0.7 million for both MGE Energy and MGE.

Equity Price Risk - Pension-Related Assets

MGE currently funds its liabilities related to employee benefits through trust funds. These funds, which include investments in debt and equity securities, are managed by various third-party investment managers. Changes in the market value of these investments can have an impact on the future expenses related to these liabilities. Holding other assumptions constant, for every 1% reduction in the expected rate of return on plan assets, annual pension and other postretirement cost would increase by approximately $5.2 million, before taxes. MGE's risk of expense and annuity payments, as a result of changes in the market value of the trust funds, is mitigated in part through future rate actions by the PSCW. The value of employee benefit plans trusts' assets have decreased in value by approximately 18% for the year ended December 31, 2022 and increased 15% for the year ended December 31, 2021.

Credit Risk - Counterparty

Credit risk is the loss that may result from counterparty nonperformance. MGE is exposed to credit risk primarily through its merchant energy business. MGE uses credit policies to manage credit risk, which include an established credit approval process, counterparty limits, 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 could include: the loss in value of mark-to-market contracts, the amount owed for settled transactions, and additional payments to settle unrealized losses. As of December 31, 2022, no counterparties had defaulted.

MGE is obligated to provide service to all electric and gas customers within its franchised territories. MGE's franchised electric territory includes a 264 square-mile area in Dane County, Wisconsin, and MGE's franchised gas territory includes a service area covering 1,684 square miles in Wisconsin. Based on results for the year ended December 31, 2022, no one customer constituted more than 10% of total operating revenues for MGE Energy and MGE. Credit risk for electric and gas is managed by MGE's credit and collection policies, which are consistent with state regulatory requirements.

Cash, cash equivalents, and customer accounts receivable are the financial instruments that potentially subject MGE Energy and MGE to concentrations of credit risk. MGE Energy and MGE place their cash and cash equivalents with high credit-quality financial institutions. MGE has limited concentrations of credit risk from customer accounts receivable because of the large number of customers and relatively strong economy in its service territory.

Item 8. Financial Statements and Supplementary Data.

Index to Financial Statements


Reports of Independent Registered Public Accounting Firms (PCAOB ID No. 238).	53
MGE Energy, Inc.	53
Madison Gas and Electric	55
MGE Energy, Inc.	57
Consolidated Statements of Income.	57
Consolidated Statements of Cash Flows.	58
Consolidated Balance Sheets.	59
Consolidated Statements of Common Equity.	60
Madison Gas and Electric.	61
Consolidated Statements of Income.	61
Consolidated Statements of Cash Flows.	62
Consolidated Balance Sheets.	63
Consolidated Statements of Common Equity.	64
MGE Energy, Inc., and Madison Gas and Electric Company - Notes to Consolidated Financial Statements.	65
1. Summary of Significant Accounting Policies.	65
2. New Accounting Standards.	71
3. Variable Interest Entities.	71
4. Property, Plant, and Equipment.	72
5. Leases.	72
6. Joint Plant Ownership.	74
7. Investments.	74
8. Regulatory Assets and Liabilities.	77
9. Rate Matters.	79
10. Income Taxes.	80
11. Pension Plans and Other Postretirement Benefits.	83
12. Share-Based Compensation.	88
13. Notes Payable to Banks, Commercial Paper, and Lines of Credit.	90
14. Long-Term Debt.	91
15. Common Equity.	92
16. Commitments and Contingencies.	93
17. Asset Retirement Obligations.	97
18. Derivative and Hedging Instruments.	98
19. Fair Value of Financial Instruments.	101
20. Revenue.	104
21. Noncontrolling Interest.	105
22. Segment Information.	105

MGE Energy

Management's Report on Internal Control Over Financial Reporting

Our management is responsible for establishing and maintaining adequate internal control over financial reporting, as such term is defined in Exchange Act Rule 13a-15(f). Under the supervision and with the participation of our management, including our principal executive officer and principal financial officer, we conducted an assessment of the effectiveness of our internal control over financial reporting based on the framework in the Internal Control - Integrated Framework (2013) issued by the Committee of Sponsoring Organizations of the Treadway Commission. Based on our assessment under the framework in the Internal Control - Integrated Framework (2013), our management concluded that our internal control over financial reporting was effective as of December 31, 2022.

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

The effectiveness of MGE Energy's internal control over financial reporting as of December 31, 2022, has been audited by PricewaterhouseCoopers LLP, an independent registered public accounting firm, as stated in their report which appears herein.

February 22, 2023

MGE

Management's Report on Internal Control Over Financial Reporting

February 22, 2023

Report of Independent Registered Public Accounting Firm

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

Opinions on the Financial Statements and Internal Control over Financial Reporting

We have audited the consolidated financial statements, including the related notes, as listed in the index appearing under Item 15(a)(1), and the financial statement schedules listed in the index appearing under Item 15(a)(2), of MGE Energy, Inc. and its subsidiaries (the “Company”) (collectively referred to as the “consolidated financial statements”). We also have audited the Company's internal control over financial reporting as of December 31, 2022, based on criteria established in Internal Control - Integrated Framework (2013) issued by the Committee of Sponsoring Organizations of the Treadway Commission (COSO).

In our opinion, the consolidated financial statements referred to above present fairly, in all material respects, the financial position of the Company as of December 31, 2022 and 2021, and the results of its operations and its cash flows for each of the three years in the period ended December 31, 2022 in conformity with accounting principles generally accepted in the United States of America. Also in our opinion, the Company maintained, in all material respects, effective internal control over financial reporting as of December 31, 2022, based on criteria established in Internal Control - Integrated Framework (2013) issued by the COSO.

Basis for Opinions

The Company's management is responsible for these consolidated financial statements, for maintaining effective internal control over financial reporting, and for its assessment of the effectiveness of internal control over financial reporting, included in Management’s Report on Internal Control Over Financial Reporting appearing under Item 8. Our responsibility is to express opinions on the Company’s consolidated financial statements and on the Company's internal control over financial reporting based on our audits. We are a public accounting firm registered with the Public Company Accounting Oversight Board (United States) (PCAOB) and are required to be independent with respect to the Company in accordance with the U.S. federal securities laws and the applicable rules and regulations of the Securities and Exchange Commission and the PCAOB.

We conducted our audits in accordance with the standards of the PCAOB. Those standards require that we plan and perform the audits to obtain reasonable assurance about whether the consolidated financial statements are free of material misstatement, whether due to error or fraud, and whether effective internal control over financial reporting was maintained in all material respects.

Our audits of the consolidated financial statements included performing procedures to assess the risks of material misstatement of the consolidated financial statements, whether due to error or fraud, and performing procedures that respond to those risks. Such procedures included examining, on a test basis, evidence regarding the amounts and disclosures in the consolidated financial statements. Our audits also included evaluating the accounting principles used and significant estimates made by management, as well as evaluating the overall presentation of the consolidated financial statements. Our audit of internal control over financial reporting included obtaining an understanding of internal control over financial reporting, assessing the risk that a material weakness exists, and testing and evaluating the design and operating effectiveness of internal control based on the assessed risk. Our audits also included performing such other procedures as we considered necessary in the circumstances. We believe that our audits provide a reasonable basis for our opinions.

Definition and Limitations of Internal Control over Financial Reporting

A company’s internal control over financial reporting is a process designed to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles. A company’s internal control over financial reporting includes those policies and procedures that (i) pertain to the maintenance of records that, in reasonable detail, accurately and fairly reflect the transactions and dispositions of the assets of the company; (ii) provide reasonable assurance that transactions are recorded as necessary to permit preparation of financial statements in accordance with generally accepted accounting principles, and that receipts and expenditures of the company are being made only in accordance with authorizations of management and directors of the company; and (iii) provide reasonable

assurance regarding prevention or timely detection of unauthorized acquisition, use, or disposition of the company’s assets that could have a material effect on the financial statements.

Critical Audit Matters

The critical audit matter communicated below is a matter arising from the current period audit of the consolidated financial statements that was communicated or required to be communicated to the audit committee and that (i) relates to accounts or disclosures that are material to the consolidated financial statements and (ii) involved our especially challenging, subjective, or complex judgments. The communication of critical audit matters does not alter in any way our opinion on the consolidated financial statements, taken as a whole, and we are not, by communicating the critical audit matter below, providing a separate opinion on the critical audit matter or on the accounts or disclosures to which it relates.

Accounting for Rate Regulation

As described in Notes 1 and 8 to the consolidated financial statements, the Company applies the authoritative guidance for accounting for certain types of regulation, which requires the Company to record regulatory assets and regulatory liabilities. Regulatory assets represent costs which are deferred due to the probable future recovery from customers through regulated rates while regulatory liabilities represent the excess recovery of costs or accrued credits which were deferred because management believes it is probable such amounts will be returned to customers through future regulated rates. As disclosed by management, management continually assesses whether the regulatory assets and liabilities meet the criteria for probability of future recovery or deferral. This assessment considers factors such as changes in the regulatory environment, recent rate orders to other regulated entities under the same jurisdiction, and the status of any pending or potential deregulation legislation. Regulatory assets and liabilities are amortized in the consolidated statements of income consistent with the recovery or refund included in customer rates. As of December 31, 2022, there was $113.4 million of deferred costs in regulatory assets and $168.9 million of accrued credits within regulatory liabilities.

The principal considerations for our determination that performing procedures relating to the Company’s accounting for the effects of rate regulation is a critical audit matter are the significant judgment by management in estimating the probability of future recovery of regulatory assets and refunds of regulatory liabilities; this in turn led to a high degree of auditor judgment, subjectivity, and effort in performing procedures and evaluating audit evidence related to the recoverability of regulatory assets and the refund of regulatory liabilities.

Addressing the matter involved performing procedures and evaluating audit evidence in connection with forming our overall opinion on the consolidated financial statements. These procedures included testing the effectiveness of controls relating to management’s assessment of the probability of recoverability of regulatory assets and refunds of regulatory liabilities. These procedures also included, among others, evaluating (i) management’s assessment of correspondence with regulators, (ii) the reasonableness of management’s judgments regarding the probability of recovery of regulatory assets and refund of regulatory liabilities, and (iii) the application of the impacts of changes to new or existing commission orders.

/s/ PricewaterhouseCoopers LLP

Chicago, Illinois

February 22, 2023

We have served as the Company's auditor since 1993.

Report of Independent Registered Public Accounting Firm

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

Opinion on the Financial Statements

We have audited the consolidated financial statements, including the related notes, as listed in the index appearing under Item 15(a)(1), and the financial statement schedule listed in the index appearing under Item 15(a)(2), of Madison Gas and Electric Company and its subsidiaries (the “Company”) (collectively referred to as the “consolidated financial statements”). In our opinion, the consolidated financial statements present fairly, in all material respects, the financial position of the Company as of December 31, 2022 and 2021, and the results of its operations and its cash flows for each of the three years in the period ended December 31, 2022 in conformity with accounting principles generally accepted in the United States of America.

Basis for Opinion

These consolidated financial statements are the responsibility of the Company’s management. Our responsibility is to express an opinion on the Company’s consolidated financial statements based on our audits. We are a public accounting firm registered with the Public Company Accounting Oversight Board (United States) (PCAOB) and are required to be independent with respect to the Company in accordance with the U.S. federal securities laws and the applicable rules and regulations of the Securities and Exchange Commission and the PCAOB.

We conducted our audits of these consolidated financial statements in accordance with the standards of the PCAOB. Those standards require that we plan and perform the audits to obtain reasonable assurance about whether the consolidated financial statements are free of material misstatement, whether due to error or fraud. The Company is not required to have, nor were we engaged to perform, an audit of its internal control over financial reporting. As part of our audits we are required to obtain an understanding of internal control over financial reporting but not for the purpose of expressing an opinion on the effectiveness of the Company's internal control over financial reporting. Accordingly, we express no such opinion.

Our audits included performing procedures to assess the risks of material misstatement of the consolidated financial statements, whether due to error or fraud, and performing procedures that respond to those risks. Such procedures included examining, on a test basis, evidence regarding the amounts and disclosures in the consolidated financial statements. Our audits also included evaluating the accounting principles used and significant estimates made by management, as well as evaluating the overall presentation of the consolidated financial statements. We believe that our audits provide a reasonable basis for our opinion.

Critical Audit Matters

Accounting for Rate Regulation

assets and liabilities are amortized in the consolidated statements of income consistent with the recovery or refund included in customer rates. As of December 31, 2022, there was $113.4 million of deferred costs in regulatory assets and $168.9 million of accrued credits within regulatory liabilities.

/s/ PricewaterhouseCoopers LLP

Chicago, Illinois

February 22, 2023

We have served as the Company's auditor since 1993.

MGE Energy, Inc.

Consolidated Statements of Income

(In thousands, except per share amounts)


	For the Years Ended December 31,
	2022			2021			2020
Operating Revenues:
Electric revenues	$	465,847		$	420,964		$	394,372
Gas revenues		248,672			185,620			144,261
Total Operating Revenues		714,519			606,584			538,633

Operating Expenses:
Fuel for electric generation		61,329			54,633			41,684
Purchased power		46,821			39,395			42,883
Cost of gas sold		152,570			99,690			63,697
Other operations and maintenance		209,875			199,316			186,430
Depreciation and amortization		85,549			76,983			74,188
Other general taxes		20,632			19,273			19,754
Total Operating Expenses		576,776			489,290			428,636
Operating Income		137,743			117,294			109,997

Other income, net		26,080			16,694			25,365
Interest expense, net		(26,647	)		(24,112	)		(23,521	)
Income before income taxes		137,176			109,876			111,841
Income tax provision		(26,224	)		(4,115	)		(19,423	)
Net Income	$	110,952		$	105,761		$	92,418

Earnings Per Share of Common Stock
Basic	$	3.07		$	2.92		$	2.60
Diluted	$	3.07		$	2.92		$	2.60

Dividends per share of common stock	$	1.59		$	1.52		$	1.45

Weighted Average Shares Outstanding
Basic		36,163			36,163			35,612
Diluted		36,174			36,167			35,612

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

MGE Energy, Inc.

Consolidated Statements of Cash Flows

(In thousands)


	For the Years Ended December 31,
	2022			2021			2020
Operating Activities:
Net income	$	110,952		$	105,761		$	92,418
Items not affecting cash:
Depreciation and amortization		85,549			76,983			74,188
Deferred income taxes		23,435			4,837			10,363
Provision for doubtful receivables		1,764			1,550			1,415
Employee benefit plan (credit) cost		(8,142	)		(2,203	)		(3,716	)
Equity earnings in investments		(9,136	)		(9,270	)		(10,221	)
Other items		(1,535	)		120			(2,750	)
Changes in working capital items:
Accounts receivable and unbilled revenues		(16,726	)		(24,651	)		(5,451	)
Inventories		(22,226	)		(6,342	)		(842	)
Prepaid taxes		1,082			(5,035	)		1,713
Other current assets		(3,729	)		(192	)		(1,057	)
Accounts payable		5,102			2,729			14,353
Other current liabilities		(5,562	)		(6,734	)		(5,635	)
Dividends from investments		7,090			7,832			8,998
Cash contributions to pension and other postretirement plans		(7,308	)		(6,935	)		(6,296	)
Other noncurrent items, net		(6,875	)		(923	)		4,963
Cash Provided by Operating Activities		153,735			137,527			172,443
Investing Activities:
Capital expenditures		(175,030	)		(153,169	)		(203,139	)
Capital contributions to investments		(5,185	)		(4,027	)		(5,601	)
Other		70			221			(1,672	)
Cash Used for Investing Activities		(180,145	)		(156,975	)		(210,412	)
Financing Activities:
Issuance of common stock, net		—			—			79,635
Cash dividends paid on common stock		(57,500	)		(54,788	)		(51,729	)
Repayment of long-term debt		(4,889	)		(4,771	)		(38,959	)
Issuance of long-term debt		25,000			100,000			19,300
Proceeds from (repayments of) short-term debt		65,000			(47,000	)		52,500
Other		(2,068	)		(2,197	)		(1,553	)
Cash Provided by (Used for) Financing Activities		25,543			(8,756	)		59,194
Change in cash, cash equivalents, and restricted cash		(867	)		(28,204	)		21,225
Cash, cash equivalents, and restricted cash at beginning of period		18,835			47,039			25,814
Cash, cash equivalents, and restricted cash at end of period	$	17,968		$	18,835		$	47,039

Supplemental Disclosures of Cash Flow Information:
Interest paid	$	25,957		$	23,502		$	23,898
Income taxes paid	$	7,966		$	4,000		$	8,127
Income taxes received	$	(4,800	)	$	—		$	—
Significant noncash investing activities:
Accrued capital expenditures	$	5,970		$	14,414		$	5,719

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

MGE Energy, Inc.

Consolidated Balance Sheets

(In thousands)


	As of December 31,
ASSETS	2022		2021
Current Assets:
Cash and cash equivalents	$	11,604	$	17,438
Accounts receivable, less reserves of $7,050 and $6,940, respectively		55,407		46,205
Other accounts receivable, less reserves of $1,323 and $1,364, respectively		11,418		16,094
Unbilled revenues		43,086		34,812
Materials and supplies, at average cost		33,465		29,863
Fuel for electric generation, at average cost		7,962		6,429
Stored natural gas, at average cost		32,848		15,668
Prepaid taxes		19,132		20,214
Regulatory assets - current		9,541		1,465
Other current assets		19,017		11,183
Total Current Assets		243,480		199,371
Other long-term receivables		556		1,155
Regulatory assets		103,900		107,547
Pension and other postretirement benefit asset		68,872		58,757
Other deferred assets and other		23,809		27,548
Property, Plant, and Equipment:
Property, plant, and equipment, net		1,865,352		1,828,171
Construction work in progress		105,748		50,603
Total Property, Plant, and Equipment		1,971,100		1,878,774
Investments		105,883		98,754
Total Assets	$	2,517,600	$	2,371,906

LIABILITIES AND CAPITALIZATION
Current Liabilities:
Long-term debt due within one year	$	54,314	$	4,889
Short-term debt		70,500		5,500
Accounts payable		59,334		64,149
Accrued interest and taxes		7,868		10,385
Accrued payroll related items		13,064		12,951
Regulatory liabilities - current		11,925		9,365
Other current liabilities		8,057		10,608
Total Current Liabilities		225,062		117,847
Other Credits:
Deferred income taxes		252,190		231,149
Investment tax credit - deferred		48,735		44,836
Regulatory liabilities		156,988		154,298
Accrued pension and other postretirement benefits		53,607		73,085
Finance lease liabilities		17,108		17,322
Other deferred liabilities and other		96,990		91,690
Total Other Credits		625,618		612,380
Capitalization:
Common shareholders' equity:
Common Stock - $1 par value - 75,000 shares authorized; 36,163 shares issued and outstanding		36,163		36,163
Additional paid-in capital		395,657		394,903
Retained earnings		649,854		596,402
Total Common Shareholders' Equity		1,081,674		1,027,468
Long-term debt		585,246		614,211
Total Capitalization		1,666,920		1,641,679
Commitments and contingencies (see Footnote 16)
Total Liabilities and Capitalization	$	2,517,600	$	2,371,906

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

MGE Energy, Inc.

Consolidated Statements of Common Equity

(In thousands, except per share amounts)


										Accumulated
					Additional					Other
	Common Stock				Paid-in		Retained			Comprehensive
	Shares		Value		Capital		Earnings			Income/(Loss)		Total
2020
Beginning balance - December 31, 2019		34,668	$	34,668	$	316,268	$	504,740		$	—	$	855,676
Net income								92,418					92,418
Common stock dividends declared ($1.45 per share)								(51,729	)				(51,729	)
Common stock issued, net		1,495		1,495		78,140							79,635
Ending balance - December 31, 2020		36,163		36,163		394,408		545,429			—		976,000

2021
Net income								105,761					105,761
Common stock dividends declared ($1.52 per share)								(54,788	)				(54,788	)
Equity-based compensation plans and other						495							495
Ending balance - December 31, 2021		36,163		36,163		394,903		596,402			—		1,027,468

2022
Net income								110,952					110,952
Common stock dividends declared ($1.59 per share)								(57,500	)				(57,500	)
Equity-based compensation plans and other					754								754
Ending balance - December 31, 2022		36,163	$	36,163	$	395,657	$	649,854		$	—	$	1,081,674

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

Madison Gas and Electric Company

Consolidated Statements of Income

(In thousands)


	For the Years Ended December 31,
	2022			2021			2020
Operating Revenues:
Electric revenues	$	465,847		$	420,964		$	394,372
Gas revenues		248,672			185,620			144,261
Total Operating Revenues		714,519			606,584			538,633

Operating Expenses:
Fuel for electric generation		61,329			54,633			41,684
Purchased power		46,821			39,395			42,883
Cost of gas sold		152,570			99,690			63,697
Other operations and maintenance		209,007			198,552			185,450
Depreciation and amortization		85,549			76,983			74,188
Other general taxes		20,627			19,269			19,750
Total Operating Expenses		575,903			488,522			427,652
Operating Income		138,616			118,062			110,981

Other income, net		17,626			9,121			15,019
Interest expense, net		(26,687	)		(24,153	)		(23,642	)
Income before income taxes		129,555			103,030			102,358
Income tax provision		(24,063	)		(2,248	)		(16,835	)
Net Income	$	105,492		$	100,782		$	85,523
Less Net Income Attributable to Noncontrolling Interest, net of tax		(21,576	)		(22,391	)		(22,393	)
Net Income Attributable to MGE	$	83,916		$	78,391		$	63,130

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

Madison Gas and Electric Company

Consolidated Statements of Cash Flows

(In thousands)


	For the Years Ended December 31,
	2022			2021			2020
Operating Activities:
Net income	$	105,492		$	100,782		$	85,523
Items not affecting cash:
Depreciation and amortization		85,549			76,983			74,188
Deferred income taxes		22,767			3,654			8,543
Provision for doubtful receivables		1,764			1,550			1,415
Employee benefit plan (credit) cost		(8,142	)		(2,203	)		(3,716	)
Other items		672			2,002			(1,828	)
Changes in working capital items:
Accounts receivable and unbilled revenues		(16,697	)		(24,680	)		(5,453	)
Inventories		(22,226	)		(6,342	)		(842	)
Prepaid taxes		912			(4,531	)		616
Other current assets		(3,774	)		(148	)		(1,157	)
Accounts payable		5,104			2,775			14,603
Accrued interest and taxes		(2,737	)		244			1,651
Other current liabilities		(2,541	)		(11,107	)		(4,909	)
Cash contributions to pension and other postretirement plans		(7,308	)		(6,935	)		(6,296	)
Other noncurrent items, net		(7,768	)		(1,804	)		3,980
Cash Provided by Operating Activities		151,067			130,240			166,318
Investing Activities:
Capital expenditures		(175,030	)		(153,169	)		(203,139	)
Other		(1,065	)		(1,709	)		(2,122	)
Cash Used for Investing Activities		(176,095	)		(154,878	)		(205,261	)
Financing Activities:
Cash dividends paid to parent by MGE		(33,500	)		(5,000	)		—
Distributions to parent from noncontrolling interest		(22,000	)		(15,000	)		(21,500	)
Capital contribution from parent		—			—			30,000
Repayment of long-term debt		(4,889	)		(4,771	)		(38,959	)
Issuance of long-term debt		25,000			100,000			19,300
Proceeds from (repayments of) short-term debt		65,000			(47,000	)		52,500
Other		(1,881	)		(2,197	)		(1,523	)
Cash Provided by Financing Activities		27,730			26,032			39,818
Change in cash, cash equivalents, and restricted cash		2,702			1,394			875
Cash, cash equivalents, and restricted cash at beginning of period		7,798			6,404			5,529
Cash, cash equivalents, and restricted cash at end of period	$	10,500		$	7,798		$	6,404

Supplemental disclosures of cash flow information:
Interest paid	$	25,957		$	23,502		$	23,898
Significant noncash investing activities:
Accrued capital expenditures	$	5,970		$	14,414		$	5,719

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

Madison Gas and Electric Company

Consolidated Balance Sheets

(In thousands)


	As of December 31,
ASSETS	2022		2021
Current Assets:
Cash and cash equivalents	$	4,136	$	6,401
Accounts receivable, less reserves of $7,050 and $6,940, respectively		55,407		46,205
Other accounts receivable, less reserves of $1,323 and $1,364, respectively		11,416		16,092
Unbilled revenues		43,086		34,812
Materials and supplies, at average cost		33,465		29,863
Fuel for electric generation, at average cost		7,962		6,429
Stored natural gas, at average cost		32,848		15,668
Prepaid taxes		18,467		19,379
Regulatory assets - current		9,541		1,465
Other current assets		19,479		11,629
Total Current Assets		235,807		187,943
Affiliate receivable long-term		1,059		1,589
Regulatory assets		103,900		107,547
Pension and other postretirement benefit asset		68,872		58,757
Other deferred assets and other		23,758		27,907
Property, Plant, and Equipment:
Property, plant, and equipment, net		1,865,380		1,828,199
Construction work in progress		105,748		50,603
Total Property, Plant, and Equipment		1,971,128		1,878,802
Investments		115		230
Total Assets	$	2,404,639	$	2,262,775

LIABILITIES AND CAPITALIZATION
Current Liabilities:
Long-term debt due within one year	$	54,314	$	4,889
Short-term debt		70,500		5,500
Accounts payable		59,317		64,130
Accrued interest and taxes		7,912		10,649
Accrued payroll related items		13,064		12,951
Regulatory liabilities - current		11,925		9,365
Other current liabilities		6,062		8,108
Total Current Liabilities		223,094		115,592
Other Credits:
Deferred income taxes		219,258		198,885
Investment tax credit - deferred		48,735		44,836
Regulatory liabilities		156,988		154,298
Accrued pension and other postretirement benefits		53,607		73,085
Finance lease liabilities		17,108		17,322
Other deferred liabilities and other		98,217		92,152
Total Other Credits		593,913		580,578
Capitalization:
Common shareholder's equity:
Common Stock - $1 par value - 50,000 shares authorized; 17,348 shares outstanding		17,348		17,348
Additional paid-in capital		252,917		252,917
Retained earnings		583,958		533,542
Total Common Shareholder's Equity		854,223		803,807
Noncontrolling interest		148,163		148,587
Total Equity		1,002,386		952,394
Long-term debt		585,246		614,211
Total Capitalization		1,587,632		1,566,605
Commitments and contingencies (see Footnote 16)
Total Liabilities and Capitalization	$	2,404,639	$	2,262,775

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

Madison Gas and Electric Company

Consolidated Statements of Equity

(In thousands)


										Accumulated
					Additional					Other		Non-
	Common Stock				Paid-in		Retained			Comprehensive		Controlling
	Shares		Value		Capital		Earnings			Income/(Loss)		Interest			Total
2020
Beginning balance - December 31, 2019		17,348	$	17,348	$	222,917	$	397,021		$	—	$	140,303		$	777,589
Net income								63,130					22,393			85,523
Capital contributions from parent						30,000										30,000
Distributions to parent from noncontrolling interest													(21,500	)		(21,500	)
Ending balance - December 31, 2020		17,348	$	17,348	$	252,917	$	460,151		$	—	$	141,196		$	871,612

2021
Net income								78,391					22,391			100,782
Cash dividends paid to parent by MGE								(5,000	)							(5,000	)
Distributions to parent from noncontrolling interest													(15,000	)		(15,000	)
Ending balance - December 31, 2021		17,348	$	17,348	$	252,917	$	533,542		$	—	$	148,587		$	952,394

2022
Net income								83,916					21,576			105,492
Cash dividends paid to parent by MGE								(33,500	)							(33,500	)
Distributions to parent from noncontrolling interest													(22,000	)		(22,000	)
Ending balance - December 31, 2022		17,348	$	17,348	$	252,917	$	583,958		$	—	$	148,163		$	1,002,386

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

Notes to Consolidated Financial Statements

December 31, 2022, 2021, and 2020

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

Summary of Significant Accounting Policies.

Basis of Presentation - MGE Energy and MGE.

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

Principles of Consolidation - MGE Energy and MGE.

MGE, a wholly owned subsidiary of MGE Energy, is a regulated electric and gas utility headquartered in Madison, Wisconsin. MGE Energy and MGE consolidate all majority owned subsidiaries in which they have a controlling influence.

Additional wholly owned subsidiaries of MGE Energy include CWDC, MAGAEL, MGE Power, MGE State Energy Services, MGE Services, MGE Transco, and MGEE Transco. CWDC owns 100% of North Mendota, a subsidiary created to serve as a development entity for property. MGE Power owns 100% of MGE Power Elm Road and MGE Power West Campus. MGE Power and its subsidiaries are part of MGE Energy's nonregulated energy operations, which were formed to own and lease electric generation projects to assist MGE. MGE Transco and MGEE Transco are nonregulated entities formed to own the investments in ATC and ATC Holdco, respectively. MGE did not own any subsidiaries as of December 31, 2022.

MGE Energy and MGE consolidate variable interest entities (VIEs) for which it is the primary beneficiary. Variable interest entities are legal entities that possess any of the following characteristics: equity investors who have an insufficient amount of equity at risk to finance their activities, equity owners who do not have the power to direct the significant activities of the entity (or have voting rights that are disproportionate to their ownership interest), or equity holders who do not receive expected losses or returns significant to the VIE. If MGE Energy or MGE is not the primary beneficiary and an ownership interest is held, the VIE is accounted for under the equity method of accounting. When assessing the determination of the primary beneficiary, all relevant facts and circumstances are considered, including: the power, through voting or similar rights, to direct the activities of the VIE that most significantly impact the VIE's economic performance and the obligation to absorb the expected losses and/or the right to receive the expected returns of the VIE. Ongoing reassessments of all VIEs are performed to determine if the primary beneficiary status has changed. MGE has consolidated MGE Power Elm Road and MGE Power West Campus. Both entities are VIEs. MGE is considered the primary beneficiary of these entities as a result of contractual agreements. See Footnote 3 for more discussion of these entities.

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

Use of Estimates - MGE Energy and MGE.

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

Cash, Cash Equivalents, and Restricted Cash – MGE Energy and MGE.

The following table presents the components of total cash, cash equivalents, and restricted cash on the consolidated balance sheets.


(In thousands)	MGE Energy				MGE
As of December 31,	2022		2021		2022		2021
Cash and cash equivalents	$	11,604	$	17,438	$	4,136	$	6,401
Restricted cash		867		847		867		847
Receivable - margin account		5,497		550		5,497		550
Cash, cash equivalents, and restricted cash	$	17,968	$	18,835	$	10,500	$	7,798

Cash Equivalents

All highly liquid investments purchased with an original maturity of three months or less are considered to be cash equivalents.

Restricted Cash

MGE has certain cash accounts that are restricted to uses other than current operations and designated for a specific purpose. MGE's restricted cash accounts include cash held by trustees for certain employee benefits and cash deposits held by third parties. These are included in "Other current assets" on the consolidated balance sheets.

Receivable – Margin Account

Cash amounts held by counterparties as margin collateral for certain financial transactions are recorded as Receivable – margin account in "Other current assets" on the consolidated balance sheets. The costs being hedged are fuel for electric generation, purchased power, and cost of gas sold.

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

Trade accounts receivable are recorded at the invoiced amount and do not bear interest. A 1% late payment charge is recorded on all receivables unpaid after the due date. The allowance for credit losses associated with these receivables represents MGE's best estimate of the amount of probable credit losses for existing accounts receivable. MGE manages concentration of credit risk through its credit and collection policies, which are consistent with state regulatory requirements. The allowance for credit losses is estimated based on historical write-off experience, regional economic data, review of the accounts receivable aging, and reasonable and supportable forecasts that affect the collectability of the reported amount.

As of December 31, 2022 and 2021, MGE had a reserve balance of $8.4 million and $8.3 million, respectively, against accounts receivable. For the years ended December 31, 2022 and 2021, MGE recorded $3.8 million and $2.2 million, respectively, in write-offs. For the years ended December 31, 2022 and 2021, MGE recorded $3.9 million and $3.4 million, respectively, of additional reserves. The current accounting treatment for bad debt expense allows MGE to defer any differential between bad debt expense reflected in rates and actual costs incurred in its next rate case filing. See Footnote 8 for further details of deferred bad debt expense.

Inventories - MGE Energy and MGE.

Inventories consist of natural gas in storage, fuel for electric generation, materials and supplies, and renewable energy credits (RECs). MGE values natural gas in storage, fuel for electric generation, and materials and supplies using average cost.

REC allowances are included in "Materials and supplies" on the consolidated balance sheets and are recorded based on specific identification. These allowances are charged to purchase power expense as they are used in operations. MGE's REC allowance balance as of December 31, 2022 and 2021, was $0.2 million and $1.0 million, respectively.

Derivative and Hedging Instruments - MGE Energy and MGE.

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

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

Regulatory Assets and Liabilities - MGE Energy and MGE.

Regulatory assets and regulatory liabilities are recorded consistent with regulatory treatment. Regulatory assets represent costs which are deferred due to the probable future recovery from customers through regulated rates. Regulatory liabilities represent the excess recovery of costs or accrued credits which were deferred because MGE believes it is probable such amounts will be returned to customers through future regulated rates. Regulatory assets and liabilities are amortized in the consolidated statements of income consistent with the recovery or refund included in customer rates. MGE believes it is probable that its recorded regulatory assets and liabilities will be recovered and refunded, respectively, in future rates. See Footnote 8 for further information.

Debt Issuance Costs - MGE Energy and MGE.

Premiums, discounts, and expenses incurred with the issuance of outstanding long-term debt are amortized over the life of the debt issue. Any call premiums or unamortized expenses associated with refinancing higher-cost debt obligations used to finance utility-regulated assets and operations are amortized consistent with regulatory treatment of those items. These costs are included as a direct reduction to the related debt liability on the consolidated balance sheets.

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

Property, plant, and equipment is recorded at original cost. Cost includes indirect costs consisting of payroll taxes, pensions, postretirement benefits, other fringe benefits, and administrative and general costs. Also, included in the cost is AFUDC for utility property and capitalized interest for nonregulated property. Additions for significant replacements of property are charged to property, plant, and equipment at cost; and minor items are charged to maintenance expense. Depreciation rates on utility property are approved by the PSCW, based on the estimated economic lives of property, and include estimates for salvage value and removal costs. Removal costs of utility property, less any salvage value, are adjusted through regulatory liabilities. Depreciation rates on nonregulated property are based on the estimated economic lives of the property. See Footnote 4 for further information.

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


	2022		2021		2020
Electric	3.2	%	3.2	%	3.5	%
Gas	2.1	%	2.2	%	2.2	%
Nonregulated	2.3	%	2.4	%	2.3	%

Asset Retirement Obligations - MGE Energy and MGE.

A liability is recorded for the fair value of an asset retirement obligation (ARO) to be recognized in the period in which it is incurred if it can be reasonably estimated. The offsetting associated asset retirement costs are capitalized as a long-lived asset and depreciated over the asset's useful life. The expected present value technique used to calculate the fair value of ARO liabilities includes assumptions about costs, probabilities, settlement dates, interest accretion, and inflation. Revisions to the assumptions, including the timing or amount of expected asset retirement costs, could result in increases or decreases to the AROs. All asset retirement obligations are recorded as "Other long-term liabilities" on the consolidated balance sheets. MGE has regulatory treatment and recognizes regulatory assets or liabilities for the timing differences between when it recovers legal AROs in rates and when it would recognize these costs. See Footnote 17 for further information.

Repairs and Maintenance Expense - MGE Energy and MGE.

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

Purchased Gas Adjustment Clause - MGE Energy and MGE.

MGE's natural gas rates are subject to a fuel adjustment clause designed to recover or refund the difference between the actual cost of purchased gas and the amount included in rates. Differences between the amounts billed to customers and the actual costs recoverable are deferred and recovered or refunded in future periods by means of prospective monthly adjustments to rates. As of December 31, 2022 and 2021, MGE had over collected $4.9 million and $1.4 million, respectively. These amounts are included in "Regulatory liabilities – current" on the consolidated balance sheets.

Revenue Recognition - MGE Energy and MGE.

Operating revenues are recorded as service is rendered or energy is delivered to customers. Meters are read on a systematic basis throughout the month based on established meter-reading schedules. At the end of the month, MGE accrues an estimate for the unbilled amount of energy delivered to customers. The unbilled revenue estimate is based on daily system demand volumes, weather factors, estimated line losses, estimated customer usage by class, and applicable customer rates. See Footnote 20 for further information.

Utility Cost Recovery - MGE Energy and MGE.

MGE's tariff rates include a provision for fuel cost recovery. The PSCW allows Wisconsin utilities to defer electric fuel-related costs that fall outside a symmetrical cost tolerance band around the amount approved for a utility in its annual fuel proceedings. Any over- or under-recovery of the actual costs is determined in the following year and is then reflected in future billings to electric retail customers. Over-collection of fuel-related costs that are outside the approved range will be recognized as a reduction of revenue. Under-collection of these costs will be recognized in "Purchased power" expense in the consolidated statements of income. The cumulative effects of these deferred amounts will be recorded as a regulatory asset or regulatory liability until they are reflected in future billings to customers. See Footnote 9.b. for further information.

Regional Transmission Organizations - MGE Energy and MGE.

MGE reports on a net basis transactions on the MISO markets in which it buys and sells power within the same hour to meet electric energy delivery requirements.

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

Allowance for funds used during construction is included in utility plant accounts and represents the cost of borrowed funds used during plant construction and a return on shareholder's capital used for

construction purposes. In the consolidated income statements, the cost of borrowed funds (AFUDC-debt) is presented as an offset to "Interest expense" and the return on shareholder's capital (AFUDC-equity funds) is shown as an item within "Other income." For 2022, 2021, and 2020, as approved by the PSCW, MGE capitalized AFUDC-debt and equity on 50% of applicable average construction work in progress as shown in the following table:


	2022		2021		2020
Approved AFUDC retail rates	7.11	%	6.89	%	7.03	%

MGE received specific approval to recover 100% AFUDC on certain costs for Saratoga, Two Creeks, Badger Hollow I and II, Paris, its customer information and billing project, and on certain environmental costs for Columbia. These amounts are recovered under the ratemaking process over the service lives of the related properties. For the years ended 2022, 2021, and 2020, MGE recorded AFUDC-debt and AFUDC-equity as shown in the following table:


(In millions)	2022		2021		2020
AFUDC-debt	$	1.1	$	1.7	$	2.1
AFUDC-equity	$	3.0	$	5.0	$	5.9

Investments - MGE Energy and MGE.

Investments in limited liability companies that have specific ownership accounts in which MGE Energy or MGE's ownership interest is more than minor and are considered to have significant influence are accounted for using the equity method. For equity security investments without readily determinable fair values and for which MGE Energy and MGE do not have significant influence, MGE Energy and MGE have elected to use the practicability exception to measure these investments, defined as cost adjusted for changes from observable transactions for identical or similar investments of the same issuer, less impairment. Changes in measurement are reported in earnings. Equity security investments with readily determinable fair values are carried at fair value. Realized and unrealized gains and losses are included in earnings. See Footnote 7 for further information on investments and Footnote 19 for further information on fair value of investments.

Capitalized Software Costs - MGE Energy and MGE.

The net book value of capitalized costs of internal use software included in property, plant, and equipment was $76.2 million and $85.8 million as of December 31, 2022 and 2021, respectively. As of December 31, 2022 and 2021, accumulated amortization was $53.4 million and $42.6 million, respectively. For the years ended December 31, 2022, 2021, and 2020, MGE recorded $10.8, million, $5.7 million and $5.1 million, respectively, of amortization expense. MGE implemented a new customer information system which went live in September 2021. Capitalized software costs are amortized on a straight-line basis over the estimated useful lives of the assets. The useful lives range from four to fifteen years.

Capitalized Software Assets – Hosting Arrangements – MGE Energy and MGE.

The net book value of capitalized costs of internal use software incurred in a hosting arrangement was $12.9 million and $15.6 million as of December 31, 2022 and 2021, respectively. As of December 31, 2022 and 2021, accumulated amortization was $8.5 million and $5.4 million, respectively. Capitalized software assets for hosted arrangements and the related accumulated amortization expense are recorded in "Other deferred assets and other" on the consolidated balance sheets.

For the years ended December 31, 2022, 2021, and 2020, MGE recorded $3.1 million, $2.2 million, and $1.8 million, respectively, of amortization expense related to software assets for hosted arrangements. These costs are recognized in "Other operations and maintenance" expense in the consolidated statements of income and are amortized on a straight-line basis over the term of the hosted contract, which includes renewable option periods. Software assets for hosted arrangements have terms ranging from three to ten years.

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

MGE reviews plant and equipment and other property for impairment when events or changes in circumstances indicate that the carrying amount of the assets may not be recoverable. MGE's policy for determining when long-lived assets are impaired is to recognize an impairment loss if the sum of the expected future cash flows (undiscounted and without interest charges) from an asset are less than the carrying amount of that asset. If an impairment loss is recognized, the amount that will be recorded will be measured as the amount by which the carrying amount of the asset exceeds the fair value of the asset.

When it becomes probable that a generating unit will be retired before the end of its useful life, MGE assesses whether the generating unit meets the criteria for probability of abandonment. If a generating unit meets the applicable criteria to be considered probable of abandonment, MGE assesses the likelihood of recovery of the remaining net book value of that generating unit at the end of each reporting period. If it becomes probable that regulators will disallow full recovery or a return on the remaining net book value of a generating unit that is either abandoned or probable of being abandoned, an impairment loss would be required. An impairment loss would be recorded for the difference of the remaining net book value of the generating unit that is greater than the present value of the amount expected to be recovered from ratepayers. There was no significant impairment of long-lived assets during 2022, 2021, and 2020.

Income Taxes and Excise Taxes - MGE Energy and MGE.

Income taxes

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

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

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

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

Excise taxes

MGE Energy, through its utility operations, pays a state license fee tax in lieu of property taxes on property used in utility operations. License fee tax is calculated as a percentage of adjusted operating revenues of the prior year. The electric tax rate is 3.19% for retail sales and 1.59% for sales of electricity for resale by the purchaser. The tax rate on sales of natural gas is 0.97%. The tax is required to be estimated and prepaid in the year prior to its computation and expensing. License fee tax expense, included in "Other general taxes," was $14.7 million, $13.5 million, and $14.1 million for the years ended December 31, 2022, 2021, and 2020, respectively.

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

Share-Based Compensation - MGE Energy and MGE.

Eligible employees and non-employee directors may receive awards of restricted stock, restricted stock units, performance units, and dividend equivalents, or any combination of the foregoing. Stock-based compensation expense is recognized on a straight-line basis over the requisite service period. Awards classified as equity awards are measured based on their grant-date fair value. Awards classified as liability awards are recorded at fair value each reporting period. Forfeitures are recognized as they occur, rather than estimating potential future forfeitures and recording them over the vesting period. See Footnote 12 for additional information on MGE's share-based compensation plans.

New Accounting Standards - MGE Energy and MGE.

MGE Energy and MGE reviewed FASB authoritative guidance recently issued, none of which are expected to have a material impact on the consolidated results of operations, financial condition, or cash flows.

Variable Interest Entities - MGE Energy and MGE.

MGE Power Elm Road and MGE Power West Campus are not subsidiaries of MGE, but they have been consolidated in the financial statements of MGE. MGE Power Elm Road and MGE Power West Campus were created for the purpose of owning new generating assets and leasing those assets to MGE. MGE Power Elm Road's sole principal asset is an undivided ownership interest in two coal-fired generating plants (the Elm Road Units) located in Oak Creek, Wisconsin, which it leases to MGE pursuant to long-term leases. MGE Power West Campus's sole principal asset is an ownership interest in WCCF, which it leases to MGE pursuant to a long-term lease. Based on the nature and terms of the contractual agreements, MGE is expected to absorb a majority of the expected losses or residual value associated with the ownership of the generation assets by MGE Power Elm Road and MGE Power West Campus and therefore MGE holds a variable interest despite the absence of an equity interest.

In accordance with applicable accounting guidance, MGE Energy and MGE consolidate VIEs of which they are the primary beneficiary. MGE has the power to direct the activities that most significantly impact both the Elm Road Units' and the WCCF's economic performance and is also the party most closely associated with MGE Power Elm Road and MGE Power West Campus. As a result, MGE is the primary beneficiary.

MGE has included the following significant accounts on its consolidated balance sheets related to its interest in these VIEs as of December 31:


	MGE Power Elm Road				MGE Power West Campus
(In thousands)	2022		2021		2022			2021
Property, plant, and equipment, net	$	161,167	$	163,325	$	77,280		$	79,183
Construction work in progress		3,410		898		809			493
Affiliate receivables		—		—		1,668			2,211
Accrued interest and accrued (prepaid) taxes		51		37		(8	)		(75	)
Deferred income taxes		30,770		30,696		14,986			14,726
Long-term debt(a)		46,343		48,968		33,354			35,563
Noncontrolling interest		103,333		101,507		44,830			47,080

(a)

MGE Power Elm Road's long-term debt includes debt issuance costs of $0.3 million as of December 31, 2022 and 2021. The debt is secured by a collateral assignment of lease payments that MGE makes to MGE Power Elm Road for use of the Elm Road Units pursuant to the related long-term leases. MGE Power West Campus's long-term debt includes debt issuance costs of $0.1 million as of December 31, 2022 and 2021. The debt is secured by a collateral assignment of lease payments that MGE makes to MGE Power West Campus for use of the cogeneration facility pursuant to the long-term lease. See Footnote 14 for further information on the long-term debt securities.

MGE is permitted by PSCW order to recover lease payments made to MGE Power Elm Road and MGE Power West Campus in customer rates.

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

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


	MGE Energy				MGE
(In thousands)	2022		2021		2022		2021
Utility:
Electric	$	1,585,847	$	1,516,533	$	1,585,864	$	1,516,550
Plant anticipated to be retired early(a)		147,659		158,983		147,659		158,983
Gas		566,551		546,390		566,562		546,401
Utility property, plant, and equipment, gross		2,300,057		2,221,906		2,300,085		2,221,934
Less: Accumulated depreciation and amortization		673,669		636,804		673,669		636,804
Utility property, plant, and equipment, net		1,626,388		1,585,102		1,626,416		1,585,130
Nonregulated:
Nonregulated		318,443		317,881		318,443		317,881
Less: Accumulated depreciation and amortization		79,479		74,812		79,479		74,812
Nonregulated property, plant, and equipment, net		238,964		243,069		238,964		243,069
Construction work in progress:
Utility construction work in progress(b)		101,529		49,211		101,529		49,211
Nonregulated construction work in progress		4,219		1,392		4,219		1,392
Total property, plant, and equipment	$	1,971,100	$	1,878,774	$	1,971,128	$	1,878,802

(a)

An asset that will be retired in the near future and substantially in advance of its previously expected retirement date is subject to abandonment accounting. In the second quarter of 2021, the operator of Columbia received approval from MISO to retire Columbia Units 1 and 2. The co-owners intend to retire Unit 1 and Unit 2 by June 2026. Final timing and retirement dates are subject to change depending on operational, regulatory, and other factors. As of December 31, 2022, early retirement of Columbia was probable. "Plant anticipated to be retired early" in table above is the net book value of these generating units. Assets for Columbia Unit 1 and Unit 2 are currently included in rate base, and MGE continues to depreciate them on a straight-line basis using the composite depreciation rates approved by the PSCW that included retirement dates of 2029 for Unit 1. The PSCW approved in its 2023 electric rate case limited reopener to revise the depreciation schedule for Columbia Unit 2 to 2029 to align with Unit 1. See Footnote 9 for further details on MGE's rate proceedings. If it becomes probable that regulators will disallow full recovery or a return on the remaining net book value of a generating unit that is either abandoned or probable of being abandoned, an impairment loss would be required. An impairment loss would be recorded to the extent that the remaining net book value of the generating unit exceeds the present value of the amount expected to be recovered from ratepayers. No impairment was recorded as of December 31, 2022.

(b)

Includes Badger Hollow II and Paris solar projects. See Footnote 6 for further information on renewable projects.

MGE's utility plant is subject to the lien of its Indenture of Mortgage and Deed of Trust. See Footnote 14 for further discussion of the mortgage indenture and the entitlement of certain unsecured notes to be equally and ratably secured if MGE issues additional first mortgage bonds.

Leases - MGE Energy and MGE.

As part of its regular operations, MGE enters into various contracts related to IT equipment, substations, cell towers, land, wind easements, and other property in use for operations. A contract is or contains a lease if the contract conveys the right to control the use of identified property, plant, or equipment for a period of time in exchange for consideration. Determination as to whether an arrangement is or contains a lease is completed at inception. Leases with an initial term of 12 months or less are not recorded on the consolidated balance sheets; lease expense for these leases are recognized on a straight-line basis over the lease term. Leases with initial terms in excess of 12 months are recorded as operating or financing leases on the consolidated balance sheets.

Operating lease assets and operating lease liabilities are recognized based on the present value of the future minimum lease payments over the lease term at commencement date. For leases that do not provide an implicit rate, a collateralized incremental borrowing rate based on the information available at commencement date, including lease term, is used in determining the present value of future payments. The operating lease asset also includes any lease payments made and excludes lease incentives and initial direct costs incurred. Lease terms may include options to extend or terminate the lease when it is reasonably certain that the option will be exercised. Operating lease expense is recognized on a straight-line basis over the lease term. MGE has regulatory treatment and recognizes regulatory assets or liabilities for

timing differences between when net lease costs are recorded and when costs are recognized. As of December 31, 2022, MGE had no significant leases not yet commenced that would create significant future rights and obligations.

The following table shows lease expense for the years ended December 31:


(In thousands)	2022		2021		Income Statement Location
Finance lease expense:
Amortization of leased assets	$	1,633	$	1,609	Depreciation and amortization
Interest on lease liabilities		752		771	Interest expense, net
Operating lease expense		541		506	Other operations and maintenance
Total lease expense	$	2,926	$	2,886

The following table shows the lease assets and liabilities on the consolidated balance sheets as of December 31:


(In thousands)	2022		2021		Balance Sheet Location
Lease assets:
Finance lease assets	$	14,756	$	15,545	Property, plant, and equipment, net
Operating lease assets		7,786		7,961	Other deferred assets and other
Total lease assets	$	22,542	$	23,506
Lease liabilities:
Finance lease liabilities - current	$	1,039	$	1,050	Other current liabilities
Finance lease liabilities - long-term		17,108		17,322	Finance lease liabilities
Operating lease liabilities - current		136		161	Other current liabilities
Operating lease liabilities - long-term		7,915		7,965	Other deferred liabilities and other
Total lease liabilities	$	26,198	$	26,498

The following table shows other lease information for the years ended December 31:


(In thousands)	2022		2021
Cash paid for amounts included in the measurement of lease liabilities:
Finance leases - Financing cash flows	$	1,304	$	1,495
Finance leases - Operating cash flows		752		771
Operating leases - Operating cash flows		442		362
Lease assets obtained in exchange for lease liabilities:
Finance leases		1,094		1,026
Operating leases		126		2,178

The following table shows the weighted average remaining lease terms and discounts as of December 31:


Weighted-average remaining lease terms (in years):	2022			2021
Finance leases		38			38
Operating leases		34			35
Weighted-average discount rates:
Finance leases		4.34	%		4.30	%
Operating leases	3.07		%	3.07		%

The following table shows maturities of lease liabilities as of December 31, 2022:


(In thousands)	Finance			Operating
2023	$	1,782		$	372
2024		1,463			347
2025		1,203			294
2026		969			299
2027		884			304
Thereafter		38,913			11,830
Subtotal		45,214			13,446
Less: Present value discount		(27,067	)		(5,395	)
Lease liability		18,147			8,051
Less: current portion		(1,039	)		(136	)
Noncurrent lease liability	$	17,108		$	7,915

Joint Plant Ownership - MGE Energy and MGE.

MGE has undivided ownership interests in jointly owned facilities. Generation and operating expenses are primarily divided between the joint owners under the same method as ownership. MGE provides its own financing, and the respective portion of facilities and costs are included in the corresponding operating expenses (fuel for electric generation, purchased power, other operations and maintenance, etc.) in the consolidated statements of income.

The following table shows MGE's interest in utility plant in service, and the related accumulated depreciation reserves and other information related to MGE's jointly owned facilities:


(In thousands, except for percentages and MW)	Columbia(a)			Elm Road(b)			West Campus(c)			Forward Wind(d)			Two Creeks(e)			Badger Hollow I & II(f)
Ownership interest		19	%		8.33	%		55	%		12.8	%		33	%		33	%
Share of generation (MW)		211	MW		106	MW		157	MW		18	MW		50	MW		100	MW

For the year ended December 31,
Operating expense - 2022	$	26,141		$	18,613		$	(g)		$	662		$	1,032		$	787
Operating expense - 2021		33,284			18,478			(g)			669			953			140
Operating expense - 2020		27,127			17,259			(g)			664			118			—

As of December 31, 2022
Utility plant	$	—		$	202,118		$	115,137		$	34,117		$	67,890		$	74,941
Accumulated depreciation		—			(40,951)			(37,857)			(15,952)			(5,145)			(2,566)
Plant anticipated to be retired early, net		147,659			—			—			—			—			—
Construction work in progress		4,805			3,410			809			68			—			52,187

As of December 31, 2021
Utility plant	$	—		$	202,604		$	114,090		$	34,084		$	67,814		$	69,178
Accumulated depreciation		—			(39,279)			(34,907)			(14,945)			(2,932)			(227)
Plant anticipated to be retired early, net		158,983			—			—			—			—			—
Construction work in progress		2,388			898			493			21			—			19,748

(a)

MGE and the other co-owners announced plans to retire Columbia, a two unit coal-fired generation facility located in Portage, Wisconsin. The co-owners intend to retire Unit 1 and Unit 2 by June 2026. Final timing and retirement dates are subject to change depending on operational, regulatory, and other factors. As of December 31, 2022 and 2021, early retirement of Columbia was probable. See Footnote 4 for further information.

(b)

Two coal-fired generating units in Oak Creek, Wisconsin. In November 2021, MGE announced plans to end the use of coal as a primary fuel at the Elm Road Units and transition the plant to natural gas. By the end of 2030, MGE expects coal to be used only as a backup fuel at the Elm Road Units. This transition will help MGE meet its 2030 carbon reduction goals. By 2035, MGE expects that the Elm Road Units will be fully transitioned away from coal, which will eliminate coal as an internal generation source for MGE.

(c)

MGE Power West Campus and the UW jointly own the West Campus Cogeneration Facility (WCCF) located on the UW campus in Madison, Wisconsin. The UW owns a controlling interest in the chilled-water and steam plants, which are used to meet the

needs for air-conditioning and steam-heat capacity for the UW campus. MGE Power West Campus owns a controlling interest in the electric generation plant, which is leased and operated by MGE.

(d)

The Forward Wind Energy Center (Forward Wind) consists of 86 wind turbines located near Brownsville, Wisconsin.

(e)

The Two Creeks solar generation array is located in the Town of Two Creeks and the City of Two Rivers in Manitowoc and Kewaunee Counties, Wisconsin. Date of commercial operation of the solar array was November 2020.

(f)

The Badger Hollow I and II solar farm is located in southwestern Wisconsin in Iowa County, near the villages of Montfort and Cobb. Date of commercial operation of Badger Hollow I was November 2021. Construction of Badger Hollow II is expected to be completed in the second half of 2023.

(g)

Operating charges are allocated to the UW based on formulas contained in the operating agreement. Under the provisions of this arrangement, the UW is required to reimburse MGE for their allocated portion of fuel and operating expenses. For the years ended December 31, 2022, 2021, and 2020, the UW's allocated share of fuel and operating costs was $8.7 million, $6.2 million, and $5.2 million, respectively.

MGE currently has ongoing jointly-owned generation construction projects. Paris Solar-Battery Park is located in the Town of Paris in Kenosha County, Wisconsin. MGE's ownership interest is 10% and its share of generation is 31 MW. Red Barn Wind Farm is located in the Towns of Wingville and Clifton in Grant County, Wisconsin. MGE's ownership interest is 10% and its share of generation is 9.16 MW. As of December 31, 2022, $23.4 million and $0.4 million, respectively, (excluding AFUDC) related to Paris and Red Barn is reflected in "Construction work in progress" on the consolidated balance sheets. Construction of Paris is expected to be completed in 2023 and Red Barn early 2023.

Investments - MGE Energy and MGE.

Equity Securities, Equity Method Investments, and Other Investments.


	MGE Energy				MGE
(In thousands)	2022		2021		2022		2021
Equity securities	$	22,960	$	20,529	$	115	$	230
Equity method investments:
ATC and ATC Holdco		80,586		75,862		—		—
Other		39		39		—		—
Total equity method investments		80,625		75,901		—		—
Other investments		2,298		2,324		—		—
Total	$	105,883	$	98,754	$	115	$	230

Equity securities represent publicly traded securities and private equity investments in common stock of companies in various industries.

For the years ended December 31, 2022, 2021, and 2020, there were no liquidated investments for MGE. For the years ended December 31, 2022, 2021, and 2020, certain investments were liquidated for MGE Energy. As a result of these liquidations, the following was received:


(In thousands)	2022		2021		2020
Cash proceeds	$	924	$	1,684	$	622
Gain on sale		1,382		1,543		379

ATC and ATC Holdco.

ATC owns and operates electric transmission facilities primarily in Wisconsin. MGE received an interest in ATC when it, like other Wisconsin electric utilities, contributed its electric transmission facilities to ATC as required by Wisconsin law. That interest is presently held by MGE Transco, a subsidiary of MGE Energy. ATC Holdco was formed by several members of ATC, including MGE Energy, to pursue electric transmission development and investments outside of Wisconsin. The ownership interest in ATC Holdco is held by MGEE Transco, a subsidiary of MGE Energy.

As of December 31, 2022 and 2021, MGE Transco held a 3.6% ownership interest in ATC. As of December 31, 2022 and 2021, MGEE Transco held a 4.4% ownership interest in ATC Holdco.

MGE Transco and MGEE Transco have accounted for their investment in ATC and ATC Holdco, respectively, under the equity method of accounting. Equity earnings from investments are recorded as "Other income" on the consolidated statements of income of MGE Energy. For the years ended December 31, MGE Transco recorded the following:


(In thousands)	2022		2021		2020
Equity earnings from investment in ATC	$	9,025	$	9,774	$	10,167
Dividends received from ATC		7,090		7,832		8,633
Capital contributions to ATC		2,678		—		1,249

In January 2023, MGE Transco made a $0.4 million capital contribution to ATC.

ATC Holdco was formed in December 2016. ATC Holdco's transmission development activities have been suspended for the near term. In 2020, MGEE Transco recorded capital contributions of $0.3 million to ATC Holdco. In 2022 and 2021, MGEE Transco recorded no capital contributions to ATC Holdco.

ATC's summarized financial data is as follows:


(In thousands)
Income statement data for the year ended December 31,	2022			2021			2020
Operating revenues	$	751,158		$	754,838		$	758,117
Operating expenses		(381,528	)		(376,153	)		(372,463	)
Other income		1,171			1,144			1,922
Interest expense, net		(124,091	)		(115,089	)		(112,818	)
Earnings before members' income taxes	$	246,710		$	264,740		$	274,758

Balance sheet data as of December 31,	2022			2021
Current assets	$	89,606		$	89,747
Noncurrent assets		5,997,780			5,628,127
Total assets	$	6,087,386		$	5,717,874

Current liabilities	$	511,945		$	436,918
Long-term debt		2,612,980			2,513,009
Other noncurrent liabilities		485,795			421,997
Members' equity		2,476,666			2,345,950
Total members' equity and liabilities	$	6,087,386		$	5,717,874

MGE receives transmission and other related services from ATC. For the years ended December 31, 2022, 2021, and 2020, MGE recorded $31.4 million, $32.0 million, and $30.7 million, respectively, for transmission services received from ATC. MGE also provides a variety of operational, maintenance, and project management work for ATC, which is reimbursed by ATC. As of December 31, 2022 and 2021, MGE had a receivable due from ATC of $4.8 million and $7.0 million, respectively, related primarily to transmission interconnection at Badger Hollow and Paris solar generation sites. MGE will be reimbursed for these costs after the new generation assets are placed into service.

Regulatory Assets and Liabilities - MGE Energy and MGE.

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


(In thousands)	2022		2021
Regulatory Assets
Asset retirement obligation	$	14,721	$	13,081
Deferred fuel costs		12,067		3,292
Deferred bad debt expense		7,650		5,600
Debt related costs		7,580		8,173
Deferred pension and other postretirement costs		—		1,017
Derivatives		5,094		—
Leases		3,656		2,992
Tax recovery related to AFUDC equity		10,851		10,347
Unfunded pension and other postretirement liability		50,072		63,728
Other		1,750		782
Total Regulatory Assets	$	113,441	$	109,012

Regulatory Liabilities
Deferred pension and other postretirement costs	$	5,454	$	8,112
Elm Road		1,092		—
Income taxes		109,112		110,817
Non-ARO removal costs		31,664		29,694
Pension and other postretirement non-service costs		16,160		11,451
Purchased gas adjustment		4,857		1,448
Other		574		2,141
Total Regulatory Liabilities	$	168,913	$	163,663

MGE expects to recover its regulatory assets and return its regulatory liabilities through rates charged to customers based on PSCW decisions made during the ratemaking process or based on PSCW long-standing policies and guidelines. The adjustments to rates for these regulatory assets and liabilities will occur over the periods either specified by the PSCW or over the corresponding period related to the asset or liability. Management believes it is probable that MGE will continue to recover from customers the regulatory assets described above based on prior and current ratemaking treatment for such costs.

Asset Retirement Obligation

See Footnote 17 for a discussion of asset retirement obligations.

Deferred Fuel Costs/Savings
The fuel rules require Wisconsin utilities to defer electric fuel-related costs that fall outside a symmetrical cost tolerance band. Any over- or under-recovery of the actual costs is determined on an annual basis and is adjusted in future billings to electric retail customers. See Footnote 9.b. for further discussion.

Deferred bad debt expense

In March 2020, the PSCW issued an order authorizing deferral of expenditures incurred to ensure the provision of safe, reliable, and affordable access to utility services during the COVID-19 pandemic and late payment charges. Expenditures include items such as bad debt expense. Recovery of expenditures is expected to be addressed in future rate proceedings. While management believes that cost recovery is probable, the timing of collection from customers cannot be estimated at this time. Management will continue to assess the probability of recovery of deferred costs. As part of the 2021 and 2022/2023 settlement agreement, the PSCW approved MGE to defer any differential between bad debt expense reflected in rates and actual costs incurred in its next rate filing.

Debt Related Costs

This balance includes debt issuance costs of extinguished debt and other debt related expenses, including make-whole premiums paid on redemptions of long-term debt. The PSCW has allowed rate recovery on unamortized issuance costs for extinguished debt facilities. When the facility replacing the old facility is

deemed by the PSCW to be more favorable for the ratepayers, the PSCW will allow rate recovery of any unamortized issuance costs related to the old facility. These amounts are recovered over the term of the new facility.

Deferred Pension and Other Postretirement Costs

The current accounting treatment for Pension and Other Postretirement costs allows MGE to reflect any differential between pension and other postretirement costs reflected in rates and actual costs incurred in its next rate filing.

Derivatives

MGE has physical and financial contracts that are accounted for as derivatives. The amounts recorded for the net mark-to-market value of the commodity based contracts is offset with a corresponding regulatory asset or liability because these transactions are part of the PGA or fuel rules clause authorized by the PSCW. See Footnote 18 for further discussion.

Leases

As part of its regular operations, MGE enters into various contracts related to IT equipment, substations, cell towers, land, wind easements, and other property in use for operations. Leases with initial terms in excess of 12 months are recorded as operating or financing leases on the consolidated balance sheets. For ratemaking all leases are treated as operating leases. MGE has regulatory treatment and recognizes regulatory assets or liabilities for timing differences between when net lease costs are recovered and when costs are recognized. See Footnote 5 for further information.

Tax Recovery Related to AFUDC Equity

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

Unfunded Pension and Other Postretirement Liability

MGE is required to recognize the unfunded or funded status of defined benefit pension and other postretirement pension plans as a net liability or asset on the balance sheet with an offset to a regulatory asset or liability. The unfunded status represents future expenses that are expected to be recovered in rates. See Footnote 11 for further discussion.

Elm Road

Costs associated with Elm Road are estimated in MGE's rates and include costs for lease payments, management fees, community impact mitigation, and operating costs. Costs are collected in rates over a one to two-year period. The current accounting treatment for these costs allows MGE to reflect any differential between costs reflected in rates and actual costs incurred in its next rate filing.

Income Taxes

Excess deferred income taxes result from a decrease in tax rates subsequent to ratemaking settlements. The settlements were reached using tax rates that are higher than the currently applicable rates, and MGE is required to return these tax benefits to customers. The regulatory liability and deferred investment tax credit reflects the revenue requirement associated with the return of these tax benefits to customers.

Changes in income taxes are generally passed through in customer rates for the regulated utility. The one-time 2017 impact on timing differences related to income taxes passed through to customer rates of the 2017 Tax Act was recorded as a regulatory liability. The amount and timing of the cash impacts will depend on the period over which certain income tax benefits are provided to customers, which will be subject to review by the PSCW. A portion of the regulatory liability will be returned to customers based on a mandated timeframe dictated by applicable tax laws.

Non-ARO Removal Costs

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

Pension and Other Postretirement Non-Service Costs

These Pension and Other Postretirement non-service costs represents the non-service components of net periodic benefit cost capitalized in rates. The FASB issued authoritative guidance within the codification's Compensation-Retirement Benefits topic that only allows the service cost component of net periodic benefit cost to be eligible for capitalization within the consolidated balance sheets, all non-service costs are expensed. Under the current rate structure non-service cost is eligible for capitalization. The portion of net periodic benefit costs that are capitalized are being recovered as a component of depreciation expense. The non-service capitalized costs will be recovered in rates over the depreciable life of the asset for which net periodic benefit costs was applied. See Footnote 11 for further discussion.

Purchased Gas Adjustment

Transmission Costs

The current accounting treatment for transmission costs allows MGE to reflect any differential between transmission costs reflected in rates and actual costs incurred in its next rate filing.

Rate Matters - MGE Energy and MGE.

Rate Proceedings.


	Rate increase	Return on Common Equity	Common Equity Component of Regulatory Capital Structure	Effective Date
Approved 2021 settlement(a)
Electric	—%	9.8%	55.8%	1/1/2021
Gas	4.00%	9.8%	55.8%	1/1/2021
Approved 2022/2023 settlement(b)
Electric	8.81%	9.8%	55.6%	1/1/2022
Gas	2.15%	9.8%	55.6%	1/1/2022
Gas	0.96%	9.8%	55.6%	1/1/2023
Approved limited 2023 reopener(c)
Electric	9.01%	9.8%	55.6%	1/1/2023

(a)

The electric rate settlement included an increase in rate base but the associated rate increase was primarily offset by lower fuel and purchased power costs and a one-time $18.2 million return to customers of the portion of excess deferred taxes related to the 2017 Tax Act not restricted by IRS normalization rules. The gas rate increase covered infrastructure costs and technology improvements. The settlement agreement also included escrow accounting treatment for pension and other postretirement benefit costs, bad debt expense, and customer credit card fees. Escrow accounting treatment allows MGE to defer any difference between estimated costs in rates and actual costs incurred until a future rate filing. Any difference would be recorded as a regulatory asset or regulatory liability.

(b)

The electric and gas rate increases were driven by an increase in rate base including our investments in Badger Hollow I and a new customer information system. Also driving the requested electric increase were higher fuel and purchased power costs as well as the completion in 2021 of the one-time return of the electric excess deferred tax credit related to the 2017 Tax Act not restricted by IRS normalization rules. Included in the electric residential rate is a reduction in the customer charge.

(c)

The electric rate increase is driven by generation assets including our investments in Badger Hollow II (solar), Paris (solar and battery), Red Barn (wind), and West Riverside (natural gas). In addition, the reopener request includes an increase in fuel costs and the recovery of deferred 2021 fuel costs. The reopener also revises the depreciation

schedule for Columbia Unit 2 and shared equipment to 2029 to align with the depreciation schedule for Columbia Unit 1.

Sierra Club and Vote Solar have filed petitions with the Dane County Circuit Court seeking review of the PSCW decisions approving MGE's electric and gas 2022/2023 rate settlement and 2023 electric limited reopener. The Dane County Circuit Court affirmed the PSCW’s decision to approve the 2022/2023 rate settlement, and Sierra Club and Vote Solar have now appealed that decision to the Wisconsin Court of Appeals. The PSCW is named as the responding party; MGE is not named as a party. The petitions challenge the amount of the customer fixed charge that does not vary with usage. The requested relief is unclear. The revenue requirement approved by the PSCW in the settlement and limited reopener have not been challenged. The PSCW is expected to vigorously defend its approval of the rate case settlement and limited reopener. MGE has intervened in the proceedings to further defend the PSCW's decision.

A petition filed challenging the 2021 rate settlement was dismissed by the circuit court in December 2022.

Fuel Rules.

Fuel rules require Wisconsin utilities to defer electric fuel-related costs that fall outside a symmetrical cost tolerance band around the amount approved for a utility in its annual fuel proceedings. Any over- or under-recovery of the actual costs is determined in the following year and is then reflected in future billings to electric retail customers. The fuel rules bandwidth is set at plus or minus 1% in 2022 and increased to 2% in 2023.The electric fuel-related costs are subject to an excess revenues test. Excess revenues are defined as revenues in the year in question that provide MGE with a greater return on common equity than authorized by the PSCW in MGE's latest rate order. The recovery of under-collected electric fuel-related costs would be reduced by the amount that exceeds the excess revenue test. These costs are subject to the PSCW's annual review of fuel costs completed in the year following the deferral. The following table summarized deferred electric fuel-related savings and costs:


	Fuel Costs (in millions)	Refund or Recovery Period
2019 deferred fuel savings	$(1.5)(a)	January 2021 through December 2021
2020 deferred fuel savings	$(3.2)(a)	October 2021
2021 deferred fuel costs	$3.3(a)	January 2023 through December 2023(b)
2022 deferred fuel costs	$8.8	(c)

(a)

There was no change to the recovery (refund) in the fuel rules proceedings from the amount MGE deferred.

(b)

In August 2022, the PSCW issued a final decision in the 2021 fuel rules proceedings for MGE to include the recovery of these costs as part of the 2023 electric limited reopener, and the recovery of such costs was included in the reopener.

(c)

These costs will be subject to the PSCW's annual review of 2022 fuel costs, expected to be completed in 2023.

10.

Income Taxes.

MGE Energy and MGE Income Taxes.

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

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


	MGE Energy									MGE
(In thousands)	2022			2021			2020			2022			2021			2020
Current payable:
Federal	$	2,102		$	(2,589	)	$	4,179		$	934		$	(3,434	)	$	3,716
State		2,385			3,002			5,095			2,060			3,163			4,790
Net-deferred:
Federal		14,770			(1,473	)		6,181			14,397			(1,951	)		4,756
State		8,665			6,310			4,182			8,370			5,605			3,787
Amortized investment tax credits		(1,698	)		(1,135	)		(214	)		(1,698	)		(1,135	)		(214	)
Total income tax provision	$	26,224		$	4,115		$	19,423		$	24,063		$	2,248		$	16,835

The consolidated income tax provision differs from the amount computed by applying the statutory federal income tax rate to income before income taxes, as follows:


	MGE Energy												MGE
	2022				2021				2020				2022				2021				2020
Statutory federal income tax rate		21.0		%		21.0		%		21.0		%		21.0		%		21.0		%		21.0		%
State income taxes, net of federal benefit		6.2				6.2				6.3				6.2				6.2				6.3
Amortized investment tax credits		(0.7	)			(1.5	)			(0.2	)			(0.7	)			(1.5	)			(0.2	)
Credit for electricity from wind energy		(5.4	)			(6.0	)			(6.2	)			(5.7	)			(6.4	)			(6.8	)
AFUDC equity, net		(0.3	)			(0.9	)			(1.2	)			(0.3	)			(1.0	)			(1.4	)
Amortization of utility excess deferred tax(a)		(2.0	)			(14.8	)			(2.0	)			(2.1	)			(15.8	)			(2.2	)
Other, net, individually insignificant		0.3				(0.3	)			(0.3	)			0.2				(0.3	)			(0.3	)
Effective income tax rate		19.1		%		3.7		%		17.4		%		18.6		%		2.2		%		16.4		%

(a)

Included are impacts of the 2017 Tax Act for the regulated utility for excess deferred taxes recognized using a normalization method of accounting in recognition of IRS rules that restrict the rate at which the excess deferred taxes may be returned to utility customers. For the years ended December 31, 2022, 2021, and 2020, MGE recognized $4.1 million, $2.6 million, and $2.2 million, respectively. Included in the 2021 rate settlement was a one-time return to customers of the electric portion of excess deferred taxes related to the 2017 Tax Act not restricted by IRS normalization rules. For the year ended December 31, 2021, MGE recognized $13.2 million. Included in the 2022 and 2023 rate settlement was a net collection from customers of the gas portion of deficient deferred taxes related to the 2017 Tax Act not restricted by IRS normalization rules. For the year ended December 31, 2022, MGE recognized $1.3 million.

The significant components of deferred tax assets and liabilities that appear on the consolidated balance sheets as of December 31 are as follows:


	MGE Energy				MGE
(In thousands)	2022		2021		2022		2021
Deferred tax assets
Investment in ATC	$	20,098	$	20,868	$	—	$	—
Federal tax credits		46,282		39,161		46,282		39,161
Accrued expenses		10,642		11,053		10,644		11,047
Pension and other postretirement benefits		20,687		24,888		20,687		24,888
Deferred tax regulatory account		42,999		42,401		42,999		42,401
Derivatives		1,416		241		1,416		241
Leases		7,137		7,218		7,137		7,218
Other		17,438		17,390		17,490		17,442
Gross deferred income tax assets		166,699		163,220		146,655		142,398
Less valuation allowance		—		—		—		—
Net deferred income tax assets	$	166,699	$	163,220	$	146,655	$	142,398

Deferred tax liabilities
Property-related	$	295,872	$	274,613	$	295,872	$	274,613
Investment in ATC		52,840		52,731		—		—
Bond transactions		472		534		472		534
Pension and other postretirement benefits		35,590		34,781		35,590		34,781
Derivatives		1,416		241		1,416		241
Tax deductible prepayments		10,308		10,222		10,308		10,210
Leases		7,137		7,218		7,137		7,218
Other		15,254		14,029		15,118		13,686
Gross deferred income tax liabilities		418,889		394,369		365,913		341,283
Deferred income taxes, net	$	252,190	$	231,149	$	219,258	$	198,885

The components of federal and state tax benefit carryovers as of December 31, are as follows:


	MGE Energy						MGE
(In thousands)	2022			2021			2022			2021
Federal tax credits	$	46,282		$	39,161		$	46,282		$	39,161
State net operating losses		3			3			3			3
Valuation allowances for state net operating losses		(3	)		(3	)		(3	)		(3	)

Federal tax credit carryovers begin to expire in 2040 and state net operating loss carryforwards expire in 2023. Federal tax credits represent the deferred tax asset and net operating loss amounts represent the tax loss that is carried forward. The state valuation allowance reduces state carryforward losses to estimated realizable value due to the uncertainty of future income in various state tax jurisdictions.

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

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

A tabular reconciliation of unrecognized tax benefits and interest is as follows:


(In thousands)
Unrecognized Tax Benefits:	2022			2021			2020
Unrecognized tax benefits, January 1,	$	2,353		$	2,281		$	2,093
Additions based on tax positions related to the current year		731			714			796
Additions based on tax positions related to the prior years		—			—			—
Reductions based on tax positions related to the prior years		(599	)		(642	)		(608	)
Unrecognized tax benefits, December 31,	$	2,485		$	2,353		$	2,281

(In thousands)
Interest on Unrecognized Tax Benefits:	2022			2021			2020
Accrued interest on unrecognized tax benefits, January 1,	$	150		$	154		$	176
Reduction in interest expense on uncertain tax positions		(95	)		(98	)		(124	)
Interest expense on uncertain tax positions		134			94			102
Accrued interest on unrecognized tax benefits, December 31,	$	189		$	150		$	154

Unrecognized tax benefits are classified with "Other deferred liabilities" on the consolidated balance sheets. The interest component recoverable in rates is offset by a regulatory asset.

As of December 31, 2022, 2021, and 2020, MGE Energy and MGE have an unrecognized tax benefit primarily related to temporary tax differences associated with the change in income tax method of accounting for electric generation and electric and gas distribution repairs. As of December 31, 2022, 2021, and 2020, there were no unrecognized tax benefits relating to permanent differences and tax credits.

The unrecognized tax benefits as of December 31, 2022, are not expected to significantly increase or decrease within the next twelve months. In addition, statutes of limitations will expire for MGE Energy and MGE tax returns. The impact of the statutes of limitations expiring is not anticipated to be material. The following table shows tax years that remain subject to examination by major jurisdiction:


	Taxpayer	Open Years
	MGE Energy and consolidated subsidiaries in federal return	2019 through 2022
	MGE Energy Wisconsin combined reporting corporation return	2018 through 2022

11.

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

MGE maintains qualified and nonqualified pension plans, health care, and life insurance benefits, and defined contribution 401(k) benefit plans for its employees and retirees. MGE's costs for the 401(k) plans were $5.4 million, $5.1 million, and $4.7 million for the years ended December 31, 2022, 2021, and 2020, respectively. A measurement date of December 31 is utilized for all pension and postretirement benefit plans.

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

Benefit Obligations and Plan Assets.


(In thousands)	Pension Benefits						Other Postretirement Benefits
Change in Benefit Obligations:	2022			2021			2022			2021
Net benefit obligation as of January 1,	$	460,666		$	461,215		$	84,526		$	86,360
Service cost		5,064			5,730			1,293			1,448
Interest cost		11,161			9,109			1,940			1,549
Plan participants' contributions		—			—			986			992
Actuarial loss (gain)(a)		(120,166	)		3,871			(19,484	)		(685	)
Gross benefits paid		(21,437	)		(19,259	)		(5,725	)		(5,405	)
Less: federal subsidy on benefits paid(b)		—			—			292			267
Benefit obligation as of December 31,	$	335,288		$	460,666		$	63,828		$	84,526

Change in Plan Assets:
Fair value of plan assets as of January 1,	$	473,953		$	429,538		$	54,844		$	51,735
Actual return on plan assets		(84,562	)		61,487			(8,958	)		6,814
Employer contributions		2,217			2,187			720			708
Plan participants' contributions		—			—			986			992
Gross benefits paid		(21,437	)		(19,259	)		(5,725	)		(5,405	)
Fair value of plan assets at end of year		370,171			473,953			41,867			54,844
Funded Status as of December 31,	$	34,883		$	13,287		$	(21,961	)	$	(29,682	)

(a)

In 2022, higher discount rates were the primary driver of the actuarial gain.

(b)

In 2003, the Medicare Prescription Drug, Improvement and Modernization Act of 2003 was signed into law authorizing Medicare to provide prescription drug benefits to retirees. For both the years ended December 31, 2022 and 2021, the subsidy due to MGE was $0.3 million.

The accumulated benefit obligation for the defined benefit pension plans as of December 31, 2022 and 2021, was $319.6 million and $431.3 million, respectively.

The amounts recognized in the consolidated balance sheets to reflect the funded status of the plans as of December 31 are as follows:


	Pension Benefits						Other Postretirement Benefits
(In thousands)	2022			2021			2022			2021
Long-term asset	$	68,872		$	58,757		$	—		$	—
Current liability		(2,408	)		(2,342	)		—			—
Long-term liability		(31,581	)		(43,128	)		(21,961	)		(29,682	)
Net asset (liability)	$	34,883		$	13,287		$	(21,961	)	$	(29,682	)

The following table shows the amounts that have not yet been recognized in our net periodic benefit cost as of December 31 and are recorded as regulatory assets in the consolidated balance sheets:


	Pension Benefits					Other Postretirement Benefits
(In thousands)	2022		2021			2022			2021
Net actuarial loss (gain)	$	51,148	$	57,777		$	(1,085	)	$	6,256
Prior service benefit		—		(20	)		—			(297	)
Transition obligation		—		—			9			12
Total	$	51,148	$	57,757		$	(1,076	)	$	5,971

The projected benefit obligation and fair value of plan assets for pension plans with a projected benefit obligation in excess of plan assets as of December 31 are as follows:


(In thousands)	Pension Benefits
Projected Benefit Obligation in Excess of Plan Assets	2022		2021
Projected benefit obligation, end of year	$	33,989	$	45,470
Fair value of plan assets, end of year		—		—

The accumulated benefit obligation and fair value of plan assets with an accumulated benefit obligation in excess of plan assets as of December 31 are as follows:


(In thousands)	Pension Benefits				Other Postretirement Benefits
Accumulated Benefit Obligation in Excess of Plan Assets	2022		2021		2022		2021
Accumulated benefit obligation, end of year	$	33,211	$	43,831	$	63,828	$	84,526
Fair value of plan assets, end of year		—		—		41,867		54,844

Net Periodic Benefit Cost.


(In thousands)	Pension Benefits									Other Postretirement Benefits
Components of Net Periodic Benefit Cost:	2022(a)			2021(a)			2020(a)			2022(a)			2021(a)			2020(a)
Service cost	$	5,064		$	5,730		$	5,296		$	1,293		$	1,448		$	1,264
Interest cost		11,161			9,109			12,210			1,940			1,549			2,278
Expected return on assets		(31,391	)		(29,487	)		(27,229	)		(3,365	)		(3,277	)		(3,154	)
Amortization of:
Transition obligation		—			—			—			3			3			3
Prior service (credit) cost		(20	)		(124	)		(114	)		(297	)		(1,518	)		(2,669	)
Actuarial loss		2,416			6,646			5,357			145			493			217
Net periodic benefit cost (credit)	$	(12,770	)	$	(8,126	)	$	(4,480	)	$	(281	)	$	(1,302	)	$	(2,061	)

(a)

As approved by the PSCW, MGE is allowed to defer differences between actual employee benefit plan costs and costs reflected in current rates. The deferred costs may be recovered or refunded in MGE's next rate filing. For the years ended December 31, 2022, 2021, and 2020 MGE recovered approximately $1.0 million, $4.3 million, and $0.9 million, respectively, of pension and other postretirement costs. The recovery of these costs reduced the amount previously deferred and has not been reflected in the table above. See Footnote 8 for further information.

For the years ended December 31, 2022 and 2021, MGE deferred and recorded as a regulatory liability $1.5 million and $8.1 million, respectively, of savings from employee benefit plan costs. For the year ended December 31, 2022, MGE refunded in rates $4.2 million of savings from 2021 employee benefit plan costs. The deferred savings has not been reflected in the table above. See Footnote 8 for additional information.

The components of net periodic benefit cost, other than the service cost component, are recorded in "Other income, net" on the consolidated statements of income. The service cost component is recorded in "Other operations and maintenance" on the consolidated statements of income. MGE has regulatory treatment and recognizes regulatory assets or liabilities for timing differences between when net periodic benefit costs are recovered and when costs are recognized.

Plan Assumptions.

The weighted-average assumptions used to determine the benefit obligations were as follows for the years ended December 31:


	Pension Benefits						Other Postretirement Benefits
	2022			2021			2022			2021
Discount rate		5.47	%		2.94	%		5.45	%		2.85	%
Rate of compensation increase		3.21	%		3.19	%	N/A			N/A
Assumed health care cost trend rates:
Health care cost trend rate assumed for next year	N/A			N/A				7.00	%		5.75	%
Rate to which the cost trend rate is assumed to decline (the ultimate trend rate)	N/A			N/A				4.75	%		4.75	%
Year that the rate reaches the ultimate trend rate	N/A			N/A			2032			2027

MGE uses individual spot rates, instead of a weighted average of the yield curve spot rates, for measuring the service cost and interest cost components of net periodic benefit cost.

The weighted-average assumptions used to determine the net periodic cost were as follows for the years ended December 31:


	Pension Benefits									Other Postretirement Benefits
	2022			2021			2020			2022			2021			2020
Discount rate		2.94	%		2.70	%		3.42	%		2.85	%		2.52	%		3.30	%
Expected rate of return on plan assets		6.75	%		7.00	%		7.20	%		6.40	%		6.61	%		6.75	%
Rate of compensation increase		3.24	%		3.23	%		3.26	%	N/A			N/A			N/A

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

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

Investment Strategy.

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

The asset allocation for MGE's pension plans as of December 31, 2022 and 2021, and the target allocation for 2023, by asset category, follows:


	Target			Percentage of Plan Assets at Year End
	Allocation			2022			2021
Equity securities(a)		63.0	%		65.0	%		65.0	%
Fixed income securities		30.0	%		26.0	%		29.0	%
Real estate		7.0	%		9.0	%		6.0	%
Total		100.0	%		100.0	%		100.0	%

(a)

Target allocations for equity securities are broken out as follows: 45.5% United States equity and 17.5% non-United States equity.

The fair value of plan assets for the postretirement benefit plans is $41.9 million and $54.8 million as of December 31, 2022 and 2021, respectively. Of this amount, $36.3 million and $48.7 million as of December 31, 2022 and 2021, respectively, were held in the master pension trust and are allocable to postretirement health expenses. The target asset allocation and investment strategy for the portion of assets held in the master pension trust are the same as that explained for MGE's pension plans. The remainder of postretirement benefit assets are held either in an insurance continuance fund for the payment of retiree life benefits or health benefit trusts for payment of retiree health premiums. The asset allocation for the insurance continuance fund is determined by the life insurer. The target asset allocation for the health benefit trusts are established based on a similar investment strategy as assets held in the master pension trust, with consideration for liquidity needs in the health benefit trusts.

Concentrations of Credit Risk.

MGE evaluated its pension and other postretirement benefit plans' asset portfolios for the existence of significant concentrations of credit risk as of December 31, 2022. Types of concentrations that were

evaluated include, but are not limited to, investment concentrations in a single entity, type of industry, and foreign country. As of December 31, 2022, there were no significant concentrations (defined as greater than 10 percent of plan assets) of risk in MGE pension and postretirement benefit plan assets.

Fair Value Measurements of Plan Assets.

Pension and other postretirement benefit plan investments are recorded at fair value. See Footnote 19 for more information regarding the fair value hierarchy.

The following descriptions are the categories of underlying plan assets held within the pension and other postretirement benefit plans as of December 31, 2022:

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

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

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

Real Estate – Real estate funds are funds with a direct investment in pools of real estate properties. These funds are valued by investment managers on a periodic basis using pricing models that use independent appraisals. The fair value of real estate investments is determined using net asset value.

Insurance Continuance Fund (ICF) – The ICF is a supplemental retirement plan that includes assets that have been segregated and restricted to pay retiree term life insurance premiums.

Fixed Rate Fund – The Fixed Rate fund is supported by an underlying portfolio of fixed income securities, including public bonds, commercial mortgages, and private placement bonds. Public market data and GAAP reported market values are used when available to determine fair value.

All of the fair values of MGE's plan assets are measured using net asset value, except for cash and cash equivalents which are considered level 1 investments.

The fair values of MGE's plan assets by asset category as of December 31 are as follows:


(In thousands)	2022		2021
Cash and Cash Equivalents	$	1,715	$	1,428
Equity Securities:
U.S. Large Cap		121,884		162,060
U.S. Mid Cap		28,392		38,755
U.S. Small Cap		35,372		47,657
International Blend		75,843		87,781
Fixed Income Securities:
Short-Term Fund		3,807		5,222
High Yield Bond		17,895		25,190
Long Duration Bond		85,767		119,867
Real Estate		38,418		37,170
Insurance Continuance Fund		1,613		1,599
Fixed Rate Fund		1,332		2,068
Total	$	412,038	$	528,797

Expected Cash Flows.

MGE does not expect to need to make any required contributions to the qualified plans for 2023. The contributions for years after 2023 are not yet currently estimated. MGE has adopted the asset smoothing as permitted in accordance with the Pension Protection Act of 2006, including modifications made by WRERA.

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

In 2022, MGE made $7.3 million in employer contributions to its pension and postretirement plans.

Benefit Payments.

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


	Pension		Other Postretirement Benefits
(In thousands)	Pension Benefits		Gross Postretirement Benefits		Expected Medicare Part D Subsidy			Net Postretirement Benefits
2023	$	20,715	$	5,051	$	(332	)	$	4,719
2024		21,304		5,363		(365	)		4,998
2025		21,864		5,637		(400	)		5,237
2026		22,305		5,544		(447	)		5,097
2027		22,789		5,560		(483	)		5,077
2028 - 2032		117,798		27,199		(2,833	)		24,366

12.

Share-Based Compensation - MGE Energy and MGE.

In 2020, MGE Energy shareholders approved the 2021 Long-Term Incentive Plan (the 2021 Incentive Plan). It provides for the issuance of up to 500,000 shares of MGE Energy common stock in connection with awards made under the 2021 Incentive Plan. The 2021 Incentive Plan authorizes awards of restricted stock, restricted stock units, performance units, and dividend equivalents, or any combination of the foregoing for eligible employees and non-employee directors. The 2020 Performance Unit Plan (the 2020 Plan) was adopted in February 2020 for eligible employees. Plan participants may receive awards of performance units, restricted units, or both. Prior to the adoption of the 2020 plan, eligible employees could receive awards of performance units under the 2006 Performance Unit Plan. Under the 2013 Director Incentive Plan, eligible non-employee directors could receive awards of performance units. For the years ended December 31, 2022, 2021, and 2020, MGE recorded $1.3 million, $2.9 million, and $1.3 million, respectively, related to share-based compensation awards under the 2006 Performance Unit Plan, the 2020 Performance Unit Plan, the 2013 Director Incentive Plan, and the 2021 Incentive Plan in "Other operations and maintenance" on the consolidated statements of income.

2013 Director Incentive Plan and 2006 Performance Unit Plan - Liability Awards - Under MGE Energy's 2013 Director Incentive Plan and its 2006 Performance Unit Plan, non-employee directors and eligible employees, respectively, could receive performance units that entitled the holder to receive a cash payment equal to the value of a designated number of shares of MGE Energy's common stock, plus dividend equivalent payments thereon, at the end of the performance period set in the award. In accordance with the plans' provisions. These awards are subject to prescribed vesting schedules and must be settled in cash. Accordingly, no shares of common stock will be issued in connection with those plans.

On the grant date, the cost of the director or employee services received in exchange for a performance unit award is measured based on the current market value of MGE Energy common stock. The fair value of the awards is remeasured quarterly, including as of December 31, 2022, as required by applicable accounting standards. Changes in fair value as well as the original grant are recognized as compensation cost. Since this amount is remeasured throughout the vesting period, the compensation cost is subject to

variability. For nonretirement eligible employees under the 2006 Performance Unit Plan, stock-based compensation costs are accrued and recognized using the graded vesting method. Compensation cost for retirement eligible employees or employees that will become retirement eligible during the vesting schedule are recognized on an abridged horizon as retirement eligibility accelerates vesting.

Payouts under the 2013 Director Incentive Plan are subject to a three-year vesting schedule. Payouts under the 2006 Performance Unit Plan are subject to a five-year vesting schedule. The following activity occurred:


	2022		2021
	Director Incentive Plan	Performance Unit Plan	Director Incentive Plan	Performance Unit Plan
Nonvested awards January 1,	1,472	5,760	4,286	17,420
Granted	—	—	—	—
Vested	(1,472)	(3,756)	(2,814)	(11,660)
Nonvested awards December 31,	—	2,004	1,472	5,760

No cash settlements have occurred on the awards shown in the table above as cash payments are only made at the end of the period covered by the awards. In January 2022, cash payments of $1.8 million were distributed relating to awards that were granted under the plans in 2019, for the 2013 Director Incentive Plan, and in 2017, for the 2006 Performance Unit Plan.

Restricted Stock Units - Equity Awards - Payouts of restricted stock units under the 2021 Incentive Plan are based on the expiration of a three-year time-vesting period. Restricted stock units granted are to be paid out in shares of MGE Energy common stock and are accounted for as equity awards. The fair value of each restricted stock unit granted is based on the closing market price of one share of MGE Energy common stock on the grant date of the award. Compensation expense is recorded ratably over the performance period based on the fair value of the awards on the grant date. The following activity occurred:


	2022			2021
	Units	Weighted Average Grant Date Fair Value (per share)		Units	Weighted Average Grant Date Fair Value (per share)
Nonvested awards January 1,	13,126	$	65.83	—		N/A
Granted	15,931	$	72.46	16,267	$	65.83
Vested	—			—
Undistributed vested awards(a)	(1,687)	$	72.46	(3,141)	$	65.83
Nonvested awards December 31,	27,370	$	69.28	13,126	$	65.83

(a)

Represents restricted stock units that vested but were not distributed to retirement-eligible employees.

Restricted Stock Units - Liability Awards - Payouts of restricted stock units granted prior to 2021 are based on the expiration of a three-year time-vesting period and will be paid out in cash and accounted for as a liability award. Compensation expense is recorded ratably over the performance period based on the fair value of the awards at each reporting period. The following activity occurred:


	2022	2021
Nonvested awards January 1,	6,064	7,003
Granted	—	—
Vested	(6,064)	—
Undistributed vested awards(b)	—	(939)
Nonvested awards December 31,	—	6,064

(b)

Represents restricted stock units that vested but were not distributed to retirement-eligible employees.

Performance Units - Liability Awards - Performance units under the 2020 Plan entitle the holder to receive a cash payment equal to the value of a designated number of shares of MGE Energy's common stock, plus dividend-equivalent payments thereon. Performance units under the 2021 Incentive Plan can be paid out in shares of MGE Energy common stock, cash or a combination of cash and stock. MGE assumes it will make future payouts of its performance units granted in cash; therefore, these performance units are accounted

for as liability awards. Compensation expense for these performance units is recorded ratably over the performance period based on the fair value of the awards at each reporting period. The payout is based upon achievement of specified performance goals during a performance period set by the Compensation Committee of MGE Energy's Board of Directors. Awards are subject to vesting provisions providing for 100% vesting at the end of the performance period. Compensation cost for retirement eligible employees or employees that will become retirement eligible during the vesting schedule are recognized on an abridged horizon as retirement eligibility accelerates vesting.

The performance units contain market and performance conditions. The market condition is based on total shareowner return relative to an investor-owned utility peer group. The performance condition is based on achievement of targets specified in the award agreement (such as an earnings growth target). The fair value of each performance unit is based on the fair value of the underlying common stock on the grant date and the probability of satisfying the market and performance conditions contained in the award agreement during the three-year performance period. The actual payments upon vesting depends upon actual performance and may range from zero to 200% of the granted number of performance units. The following activity occurred:


		2022		2021
Nonvested awards January 1,		13,870		7,003
Granted		10,395		10,187
Vested		(6,064)		—
Undistributed vested awards(c)		(1,687)		(3,320)
Nonvested awards December 31,		16,514		13,870

Weighted average fair Value of each nonvested award	$	76.87	$	104.76
Weighted average estimated payout % based on performance criteria		109.2%		127.4%

(c)

Represents performance units that vested but were not distributed to retirement-eligible employees.

13.

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

Information regarding lines of credit and short-term borrowings is shown below:


(In thousands)	MGE Energy(a)							MGE
As of December 31,	2022			2021			2022				2021
Lines of credit(b)	$	150,000		$	150,000		$		100,000		$	100,000
Available capacity under line of credit	$	78,815		$	143,815		$		28,815		$	93,815
Short-term debt outstanding	$	70,500		$	5,500		$		70,500		$	5,500
Letters of credit issued inside credit facilities	$	685		$	685		$		685		$	685
Required ratio of consolidated debt to consolidated total capitalization - not to exceed a maximum		65.00	%(c)		65.00	%(c)			65.00	%(d)		65.00	%(d)
Weighted-average interest rate		4.32	%		0.15	%			4.32	%		0.15	%
Year Ended December 31,
Maximum short-term borrowings	$	70,500		$	64,000		$		70,500		$	64,000
Average short-term borrowings	$	20,177		$	28,583		$		20,177		$	28,583
Weighted-average interest rate		3.46	%		0.15	%			3.46	%		0.15	%

(a)

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

(b)

In November 2022, MGE Energy and MGE amended and restated their existing credit agreements, which extended their maturity dates to November 8, 2027. In January 2023, MGE amended one of its existing credit agreements to increase the available credit by an additional $30 million. As of December 31, 2022, MGE Energy and MGE had no borrowings outstanding under these credit facilities and were in compliance with the covenant requirements of the credit agreements.

(c)

A change in control constitutes a default under the agreement. Change in control events are defined as (i) a failure by MGE Energy to hold 100% of the outstanding voting equity interest in MGE or (ii) the acquisition of beneficial ownership of 30% or more of the outstanding voting stock of MGE Energy by one person or two or more persons acting in concert.

(d)

The ratio calculation excludes assets, liabilities, revenues, and expenses included in MGE's financial statements as the result of the consolidation of VIEs, such as MGE Power West Campus and MGE Power Elm Road. A change in control constitutes a default under the agreements. Change in control events are defined as (i) a failure by MGE Energy to hold 100% of the

outstanding voting equity interest in MGE or (ii) the acquisition of beneficial ownership of 30% or more of the outstanding voting stock of MGE Energy by one person or two or more persons acting in concert.

14.

Long-Term Debt - MGE Energy and MGE.

Long-Term Debt.


	December 31,
(In thousands)	2022			2021
First Mortgage Bonds:(a)
7.70%, 2028 Series	$	1,200		$	1,200
Tax Exempt Debt:
2.05%, 2023 Series, Industrial Development Revenue Bonds		19,300			19,300
Medium-Term Notes:(c)
6.12%, due 2028		20,000			20,000
7.12%, due 2032		25,000			25,000
6.247%, due 2037		25,000			25,000
Total Medium-Term Notes		70,000			70,000
Other Long-Term Debt:(d)
3.09%, due 2023(e)		30,000			30,000
3.29%, due 2026(e)		15,000			15,000
3.11%, due 2027(e)		30,000			30,000
2.94%, due 2029(e)		50,000			50,000
2.48%, due 2031(e)		60,000			60,000
5.43%, due 2032(b)(e)		25,000			—
5.68%, due 2033(f)		20,184			21,510
5.19%, due 2033(f)		13,237			14,133
2.63%, due 2033(e)		40,000			40,000
5.26%, due 2040(e)		15,000			15,000
5.04%, due 2040(g)		28,472			30,139
4.74%, due 2041(g)		18,167			19,167
4.38%, due 2042(e)		28,000			28,000
4.42%, due 2043(e)		20,000			20,000
4.47%, due 2048(e)		20,000			20,000
3.76%, due 2052(e)		40,000			40,000
4.19%, due 2048(e)		60,000			60,000
4.24%, due 2053(e)		20,000			20,000
4.34%, due 2058(e)		20,000			20,000
Total Other Long-Term Debt		553,060			532,949
Long-term debt due within one year		(54,314	)		(4,889	)
Unamortized discount and debt issuance costs		(4,000	)		(4,349	)
Total Long-Term Debt	$	585,246		$	614,211

(a)

MGE's utility plant is subject to the lien of its Indenture of Mortgage and Deed of Trust, under which its first mortgage bonds are issued. The Mortgage Indenture provides that dividends or any other distribution or purchase of MGE shares may not be made if the aggregate amount thereof since December 31, 1945, would exceed the earned surplus (retained earnings) accumulated subsequent to December 31, 1945. As of December 31, 2022, approximately $650.1 million was available for the payment of dividends under this covenant.

(b)

In November 2022, MGE entered into a private placement Note Purchase Agreement in which it committed to issue $25 million of new long-term debt (Series A), $15 million of new long-term debt (Series B), carrying an interest rate of 5.43% per annum over its 10-year life, and $35 million of new long-term debt (Series C), carrying an interest rate of 5.53% per annum over its 12-year life. Funding occurred on December 1, 2022, for Series A and will occur on February 28, 2023, for Series B and Series C. The proceeds of the debt financing will be used to assist with capital expenditures and other corporate obligations.

(c)

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

(d)

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

(e)

Issued by MGE. Under that Note Purchase Agreement: (i) note holders have the right to require MGE to repurchase their notes at par in the event of an acquisition of beneficial ownership of 30% or more of the outstanding voting stock of MGE Energy, (ii) MGE must maintain a ratio of its consolidated indebtedness to consolidated total capitalization not to exceed a maximum of 65%, and (iii) MGE cannot issue "Priority Debt" in an amount exceeding 20% of its consolidated assets. Priority

Debt is defined as any indebtedness of MGE secured by liens other than specified liens permitted by the Note Purchase Agreement and certain unsecured indebtedness of certain subsidiaries. As of December 31, 2022, MGE was in compliance with the covenant requirements.

(f)

Issued by MGE Power West Campus. The Note Purchase Agreements require MGE Power West Campus to maintain a projected debt service coverage ratio of not less than 1.25 to 1.00, and debt to total capitalization ratio of not more than 0.65 to 1.00. The notes are secured by a collateral assignment of lease payments that MGE is making to MGE Power West Campus for use of the WCCF pursuant to a long-term lease. As of December 31, 2022, MGE Power West Campus was in compliance with the covenant requirements.

(g)

Issued by MGE Power Elm Road. The Note Purchase Agreement requires MGE Power Elm Road to maintain a projected and actual debt service coverage ratio at the end of any calendar quarter of not less than 1.25 to 1.00 for the trailing 12-month period. The notes are secured by a collateral assignment of lease payments that MGE is making to MGE Power Elm Road for use of the Elm Road Units pursuant to long-term leases. As of December 31, 2022, MGE Power Elm Road was in compliance with the covenant requirements.

Long-Term Debt Maturities.

Below is MGE Energy's and MGE's aggregate maturities for all long-term debt for years following December 31, 2022.


(In thousands)	2023		2024		2025		2026		2027		Thereafter
Long-term debt maturities	$	54,314	$	5,146	$	5,285	$	20,433	$	35,588	$	522,794

MGE includes long-term debt held by MGE Power Elm Road and MGE Power West Campus in the consolidated financial statements (see Footnote 3 for further information regarding these VIEs).

15.

Common Equity.

Common Stock - MGE Energy and MGE.

MGE Energy sells shares of its common stock through its Direct Stock Purchase and Dividend Reinvestment Plan (the Stock Plan). Those shares may be newly issued shares or shares that are purchased in the open market by an independent agent for participants in the Stock Plan. Sales of newly issued shares under the Stock Plan are covered by a shelf registration statement that MGE Energy filed with the SEC. For the years ended December 31, 2022 and 2021, MGE Energy issued no new shares of common stock under the Stock Plan.

For the years ended December 31, 2022 and 2021, MGE Energy paid $57.5 million (or $1.59 per share) and $54.8 million (or $1.52 per share), respectively, in cash dividends on its common stock. Dividend payments by MGE to MGE Energy are subject to restrictions arising under a PSCW rate order and, to a lesser degree, MGE's first mortgage bonds. The PSCW order restricts any dividends, above the PSCW authorized amount that MGE may pay MGE Energy if MGE's common equity ratio, calculated in the manner used in the rate proceeding, is less than 55%. This restriction did not restrict MGE's payment of dividends in 2022. See Footnote 14 for further discussion of the mortgage indenture covenants regarding the payment of dividends. For the years ended December 31, 2022 and 2021, MGE paid $33.5 million and $5.0 million, respectively, in cash dividends to MGE Energy.

Dilutive Shares Calculation - MGE Energy.

As of December 31, 2022, 10,949 shares were included in the calculation of diluted earnings per share related to nonvested equity awards. See Footnote 12 for additional information on shared-based compensation awards.

16.

Commitments and Contingencies.

Environmental - MGE Energy and MGE.

Columbia

In February 2021, MGE and the other co-owners of Columbia announced plans to retire that facility. The co-owners intend to retire Unit 1 and Unit 2 by June 2026. Final timing and retirement dates are subject to change depending on operational, regulatory, and other factors. Effects of environmental compliance discussed below will depend upon the final retirement dates approved and compliance requirement dates.

Water Quality

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

Effluent Limitations Guidelines and Standards for Steam Electric Power Generating Point Source Category

In July 2021, the PSCW approved a Certificate of Authority (CA) application, filed by MGE and the other owners of Columbia. The CA application commits to close Columbia's wet pond system (as described in further detail in the CCR section below). By committing to close the wet pond system, Columbia will be in compliance with ELG requirements.

The Elm Road Units must satisfy the ELG rule's requirements no later than December 2023, as determined by the permitting authority. In December 2021, the PSCW approved a CA application for installation of additional wastewater treatment equipment to comply with the ELG rule. MGE's share of the costs to comply with the rule is estimated to be approximately $4 million. Construction began in March 2022 and is scheduled to be completed by the end of 2023.

Based on previous treatment of environmental compliance projects, management believes that any compliance costs will be recovered in future rates.

Cooling Water Intake Rules (Section 316(b))

WCCF, Blount, and Columbia are considered existing plants under this rule. WCCF employs a system that meets the Section 316(b) rule. Blount's WPDES permit assumes that the plant meets BTA standards for the duration of the permit, which expires in 2023. Before the next permit renewal, MGE is required to complete an entrainment study and recommend a BTA along with alternative technologies considered. MGE completed the entrainment study in 2021 and submitted the results to the WDNR.

The WDNR will make the final BTA determination and include any BTA requirements in Blount's next permit renewal, which is expected to be completed and effective in 2023. Management believes that the BTA determination at Blount will not be material for MGE.

Intakes at the Columbia plant are subject to this rule. Columbia's operator received a permit in 2019 requiring studies of intake structures to be submitted to the WDNR by November 2023 to help determine BTA. BTA improvements may not be required given that Columbia is scheduled to retire both units by June 2026. MGE will continue to work with Columbia's operator to evaluate all regulatory requirements applicable to the planned retirements. Management believes that the Section 316(b) rule will not have a material effect on its existing plants and that any compliance costs will be recovered in future rates based on previous treatment of environmental compliance projects.

Air Quality

Federal and state air quality regulations impose restrictions on various emissions, including emissions of particulate matter (PM), sulfur dioxide (SO2), nitrogen oxides (NOx), and other pollutants, and require permits for operation of emission sources. These permits have been obtained by MGE and must be renewed periodically. Current EPA initiatives under the Clean Air Act, including the Cross-State Air Pollution Rule (CSAPR) and National Ambient Air Quality Standards (NAAQS), have the potential to result in additional operating and capital expenditure costs for MGE.

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

WCCF, the Elm Road Units, Blount, and Columbia could be impacted by GHG reduction guidelines and approval criteria established under the Clean Air Act for the control of GHG emissions from fossil fuel-fired electric generating units (EGUs). The EPA is undertaking a new rulemaking under section 111(d) of the Clean Air Act to establish emission guidelines and limit GHG emissions from existing fossil fuel-fired EGUs. The EPA is also conducting a comprehensive review of the New Source Performance Standards (NSPS) and may set new emission standards for GHG emissions from new, modified, and/or reconstructed fossil fuel-fired power plants. The EPA anticipates issuing a proposed rule in spring 2023 and promulgating a final rule by summer 2024. MGE will continue to evaluate greenhouse gas rule developments, including any new EPA actions towards rule development, and any further court decisions on the EPA's authority to regulate greenhouse gases.

National Ambient Air Quality Standards (NAAQS) and Related Rules

The EPA's NAAQS regulations have been developed to set ambient levels of six pollutants to protect sensitive human populations (primary NAAQS) and the environment (secondary NAAQS) from the negative effects of exposure to these pollutants at higher levels. The Clean Air Act requires that the EPA periodically review, and adjust as necessary, the NAAQS for these six air pollutants. The EPA's NAAQS review can result in a lowering of the allowed ambient levels of a pollutant, a change in how the pollutant is monitored, and/or a change in which sources of that pollutant are regulated. States implement any necessary monitoring and measurement changes and recommend areas for attainment (meets the ambient requirements) or nonattainment (does not meet these standards). The EPA makes final attainment and nonattainment determinations. States must come up with a State Implementation Plan (SIP) to get nonattainment areas into attainment and maintain air quality in attainment areas. A company with facilities located in a nonattainment area will be most affected. Its facilities in nonattainment areas may be subject to additional data submission and emission measurement requirements during permitting renewals, its facilities may need to meet new emission limitations set by the SIP (which could result in significant capital expenditures), and it may have additional expenses and/or difficulties expanding existing facilities or building new facilities. The process, which starts with determining acceptable primary and/or secondary NAAQS and ends with executing SIPs can take years. Since the NAAQS regulations have the potential to affect both existing and new facilities, MGE continuously monitors changes to these rules to evaluate whether changes could impact its operations. In addition, the EPA has adopted interstate transport rules, such as CSAPR, to address contributions to NAAQS nonattainment from upwind sources in neighboring states. In the following paragraphs we discuss specific NAAQS and transport rule developments that may affect MGE.

Ozone NAAQS

The Elm Road Units are located in Milwaukee County, Wisconsin, a nonattainment area. In October 2022, the EPA reclassified Milwaukee County from "marginal" to "moderate" nonattainment under the 2015 ozone NAAQS. The Wisconsin Department of Natural Resources (WDNR) must develop a SIP for the area, and this reclassification will result in more stringent SIP requirements for both constructing new development and modifying or expanding existing plants in the area. The deadline for moderate classified areas to meet attainment standards is August 2024. MGE will continue to monitor the WDNR's SIP development and the extent to which the requirements will impact the Elm Road Units. At this time, the operator of the Elm Road Units does not expect that the 2015 Ozone NAAQS will have a material effect on its existing plants based on final designations.

Fine Particulate Matter (PM2.5) NAAQS

In January 2023, the EPA published a proposed rule to lower the average annual PM2.5 NAAQS from its current level. The EPA has also solicited comments on whether to lower the annual standard further than the proposed level, and whether or not to also lower the maximum 24-hour limit to be consistent with recommendations from its Clean Air Scientific Advisory Committee (CASAC). As the rule is currently proposed, the annual PM2.5 NAAQS and the 24-hour limit recommended by the CASAC is not expected to impact the counties where Columbia and the Elm Road Units are located. However, if the annual PM2.5 NAAQS is lowered further than the EPA's currently proposed value, the county where the Elm Road Units are located may be in nonattainment with the standard. A nonattainment designation would require the State of Wisconsin to develop a plan to get into attainment. However, we will not know the impact of this rule with any certainty until it is finalized, counties' attainment status is determined by the EPA, and the State of Wisconsin develops an attainment implementation plan. MGE will continue to follow the rule's developments.

Cross-State Air Pollution Rule

The EPA's CSAPR and its progeny are a suite of interstate air pollution transport rules designed to reduce ozone and fine PM2.5 ambient air levels in areas that the EPA has determined as being significantly impacted by pollution from upwind states. This is accomplished in the CSAPR through a reduction in SO2 and NOx from qualifying fossil-fuel fired power plants in upwind "contributing" states. NOx and SO2 contribute to fine particulate pollution and NOx contributes to ozone formation in downwind areas. Reductions are achieved through a cap-and-trade system. Individual plants can meet their caps through reducing emissions and/or buying allowances on the market.

In April 2022, the EPA published a proposed Federal Implementation Plan (FIP) to address state obligations under the Clean Air Act "good neighbor" provisions for the 2015 Ozone NAAQS. This proposed rule impacts 26 states, including Wisconsin, and is designed to both revise the current NOx CSAPR ozone season cap-and-trade obligations for fossil-fuel generated power plants and add NOx limitations for certain industries in specified states. For Wisconsin, the proposed rule includes revisions to the current obligations for fossil-fuel power generation as well as the new limitations for certain industries.

If finalized, the proposed rule would be effective beginning with the 2023 ozone season and start with emissions budgets that can be achieved with what the EPA has defined as immediately available measures, including consistently operating emissions controls already installed at power plants. In 2026, additional obligations would go into effect, including potential daily emissions limits and technology upgrades to coal-fired power plants without existing emission controls. Wisconsin would need to submit a SIP to meet its obligations or accept the EPA's proposed FIP.

MGE expects the rule, if finalized as written, to impact our fossil-fueled generation assets. However, we will not know the impact of this rule with any certainty until it is finalized. We will continue to monitor rule developments.

Clean Air Visibility Rule (CAVR)

will not need to do additional work to meet BART requirements. Wisconsin's 2021 SIP argues that Wisconsin will meet its current regional haze goals based on expected emissions reductions, which include Columbia unit retirements. Given that the Wisconsin SIP recognizes the Columbia unit retirements as part of its emission reduction plan, MGE does not anticipate further obligations with this rule at Columbia. MGE will continue to monitor legal developments and any future updates to this rule.

Solid Waste

Coal Combustion Residuals Rule

In July 2021, the PSCW approved a CA application filed by MGE and the other owners of Columbia to install technology required to cease bottom ash transport water discharges rather than extend the longevity of the ash ponds. The coal combustion residuals system that will replace the unlined surface impoundment is undergoing final testing. Construction is expected to be completed by the end of the first quarter of 2023. MGE's share of the costs of the project is expected to be approximately $4 million.

Review of the Elm Road Units has indicated that the costs to comply with the CCR rule are not expected to be significant.

Legal Matters - MGE Energy and MGE.

MGE is involved in various legal matters that are being defended and handled in the normal course of business. MGE maintains accruals for such costs that are probable of being incurred and subject to reasonable estimation. The accrued amount for these matters is not material to the financial statements. MGE does not expect the resolution of these matters to have a material adverse effect on its consolidated results of operations, financial condition, or cash flows.

Certain environmental groups have filed petitions against the PSCW regarding MGE's rate settlement and electric limited reopener. MGE has intervened in the petitions in cooperation with the PSCW. See Footnote 9.a. for more information regarding this matter.

Purchase Contracts - MGE Energy and MGE.

MGE Energy and MGE have entered into various commodity supply, transportation, and storage contracts to meet their obligations to deliver electricity and natural gas to customers. Management expects to recover these costs in future customer rates.

As of December 31, 2022, the future minimum commitments related to these purchase contracts were as follows:


(In thousands)	2023		2024		2025		2026		2027		Thereafter
Coal(a)	$	23,886	$	17,104	$	7,782	$	2,868	$	—	$	—
Natural gas
Transportation and storage(b)		25,446		25,446		25,446		14,736		1,892		10,549
Supply(c)		30,778		—		—		—		—		—
Purchase power(d)		5,513		5,623		5,735		5,850		5,967		266
Renewable energy(e)		25,024		2,025		2,040		2,056		2,072		26,592
Other		6,105		2,224		350		359		108		689
	$	116,752	$	52,422	$	41,353	$	25,869	$	10,039	$	38,096

(a)

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

(b)

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

(c)

These commitments include market-based pricing.

(d)

MGE has a purchase power agreement to help meet future electric supply requirements.

(e)

Operational commitments for solar and wind facilities.

Other Commitments.

MGE Energy holds investments in nonpublic venture capital funds. From time to time, these entities require additional capital infusions from their investors. MGE Energy has committed to contribute $8.0 million in capital for such infusions. The timing of these infusions is dependent on the needs of the investee and is therefore uncertain at this time.

In addition, MGE Energy has a three-year agreement with a venture debt fund expiring in December 2025. MGE Energy has committed to invest up to a total of $1.5 million into this fund. As of December 31, 2022, MGE Energy has $0.9 million remaining in commitments. The timing of infusions is dependent on the needs of the fund and is therefore uncertain at this time.

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


(In thousands)	2023		2024		2025		2026		2027		Thereafter
Other commitments	$	333	$	333	$	333	$	333	$	333	$	2,332

17.

Asset Retirement Obligations - MGE Energy and MGE.

MGE recorded an obligation for the fair value of its legal liability for asset retirement obligations (AROs) associated with removal of the West Campus Cogeneration Facility and the Elm Road Units, electric substations, combustion turbine generating units, wind generating facilities, and solar generating facilities, all of which are located on property not owned and would need to be removed upon the ultimate end of the associated leases. The significant conditional AROs identified by MGE included the costs of abandoning in place gas services and mains, the abatement and disposal of equipment and buildings contaminated with asbestos and PCBs, and the proper disposal and removal of tanks, batteries, and underground cable. Changes in management's assumptions regarding settlement dates, settlement methods, or assigned probabilities could have a material effect on the liabilities and the associated regulatory asset recorded as of December 31, 2022.

MGE also may have AROs relating to the removal of various assets, such as certain electric and gas distribution facilities. These facilities are generally located on property owned by third parties, on which MGE is permitted to operate by lease, permit, easement, license, or service agreement. The asset

retirement obligations associated with these facilities cannot be reasonably determined due to the indeterminate life of the related agreements.

The following table summarizes the change in AROs. Amounts include conditional AROs.


(In thousands)	2022			2021
Balance as of January 1,	$	46,580		$	31,196
Liabilities incurred(a)		1,947			8,589
Accretion expense		1,909			1,526
Liabilities settled		(317	)		(354	)
Revisions in estimated cash flows(b)		141			5,623
Balance as of December 31,	$	50,260		$	46,580

(a)

In 2021, MGE recorded an obligation of $4.9 million and $3.4 million, respectively, for the fair value of its legal liability for AROs associated with Badger Hollow I and other completed renewable projects. See Footnote 6 for additional information on Badger Hollow I.

(b)

In 2021, MGE revised the AROs associated with certain Columbia assets.

18.

Derivative and Hedging Instruments - MGE Energy and MGE.

Purpose.

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

Notional Amounts.

The gross notional volume of open derivatives is as follows:


	December 31, 2022			December 31, 2021
Commodity derivative contracts		353,600	MWh		278,000	MWh
Commodity derivative contracts		8,070,000	Dth		5,735,000	Dth
FTRs		1,945	MW		2,127	MW
PPA		—	MW		250	MW

Financial Statement Presentation.

MGE purchases and sells exchange-traded and over-the-counter options, swaps, and future contracts. These arrangements are primarily entered into to help stabilize the price risk associated with gas or power purchases. These transactions are employed by both MGE's gas and electric segments. Additionally, as a result of the firm transmission agreements that MGE holds on electricity transmission paths in the MISO market, MGE holds financial transmission rights (FTRs). An FTR is a financial instrument that entitles the holder to a stream of revenues or charges based on the differences in hourly day-ahead energy prices between two points on the transmission grid. The fair values of these instruments are offset with a corresponding regulatory asset/liability depending on whether they are in a net loss/gain position. Depending on the nature of the instrument, the gain or loss associated with

these transactions will be reflected as cost of gas sold, fuel for electric generation, or purchased power expense in the delivery month applicable to the instrument. As of December 31, 2022, the cost basis of exchange traded derivatives and FTRs exceeded their fair value by $5.1 million. As of December 31, 2021, the fair value of exchange traded derivatives and FTRs exceeded their cost basis by $2.8 million.

MGE was a party to a purchased power agreement that provided MGE with firm capacity and energy during a base term from June 1, 2012, through May 31, 2022. The agreement was accounted for as a derivative contract and was recognized at its fair value on the consolidated balance sheets. However, the derivative qualified for regulatory deferral and was recognized with a corresponding regulatory asset or liability depending on whether the fair value was in a loss or gain position. The actual cost was recognized in purchased power expense in the month of purchase.

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


(In thousands)	Derivative Assets		Derivative Liabilities		Balance Sheet Location
December 31, 2022
Commodity derivative contracts(a)	$	2,164	$	7,687	Other current liabilities
Commodity derivative contracts(a)		802		476	Other deferred liabilities and other
FTRs		103		—	Other current assets

December 31, 2021
Commodity derivative contracts(b)	$	2,959	$	811	Other current assets
Commodity derivative contracts(b)		420		38	Other deferred charges
FTRs		227		—	Other current assets
PPA	N/A			2,140	Other current liabilities

(a)

As of December 31, 2022, collateral of $5.2 million was posted against and netted with derivative liability positions on the consolidated balance sheets. The fair value of the derivative liability disclosed in this table has not been reduced for the collateral posted.

(b)

As of December 31, 2021, MGE received collateral of $1.3 million from counterparties under a master netting agreement for outstanding exchange traded derivative positions. The fair value of the derivative asset disclosed in this table has not been reduced for the collateral received.

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

Offsetting of Derivative Assets


(In thousands)	Gross Amounts		Gross Amounts Offset in Balance Sheets			Collateral Posted Against Derivative Positions			Net Amount Presented in Balance Sheets
December 31, 2022
Commodity derivative contracts	$	2,966	$	(2,966	)	$	—		$	—
FTRs		103		—			—		$	103

December 31, 2021
Commodity derivative contracts	$	3,379	$	(849	)	$	(1,254	)	$	1,276
FTRs		227		—			—			227

Offsetting of Derivative Liabilities


(In thousands)	Gross Amounts		Gross Amounts Offset in Balance Sheets			Collateral Posted Against Derivative Positions			Net Amount Presented in Balance Sheets
December 31, 2022
Commodity derivative contracts	$	8,163	$	(2,966	)	$	(5,197	)	$	—

December 31, 2021
Commodity derivative contracts	$	849	$	(849	)	$	—		$	—
PPA		2,140		—			—			2,140

The following tables summarize the unrealized and realized gains/losses related to the derivative instruments on the consolidated balance sheets and the consolidated statements of income.


	2022						2021
	Current and Long-Term Regulatory Asset (Liability)			Other Current Assets			Current and Long-Term Regulatory Asset (Liability)			Other Current Assets
(In thousands)
Balance as of January 1,	$	(617	)	$	770		$	13,989		$	1,162
Unrealized gain		(9,527	)		—			(23,173	)		—
Realized gain (loss) reclassified to a deferred account		1,472			(1,472	)		2,563			(2,563	)
Realized gain reclassified to income statement		13,766			3,449			6,004			2,171
Balance as of December 31,	$	5,094		$	2,747		$	(617	)	$	770


	Realized Losses (Gains)
	2022						2021
(In thousands)	Fuel for Electric Generation/ Purchased Power			Cost of Gas Sold			Fuel for Electric Generation/ Purchased Power			Cost of Gas Sold
Year Ended December 31:
Commodity derivative contracts	$	(14,806	)	$	(350	)	$	(3,948	)	$	(1,700	)
FTRs		583			—			(605	)		—
PPA		(2,642	)		—			(1,922	)		—

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

Certain counterparties extend MGE a credit limit. If MGE exceeds these limits, the counterparties may require collateral to be posted. As of December 31, 2022 and 2021, no counterparties were in a net liability position.

Nonperformance of counterparties to the non-exchange traded derivatives could expose MGE to credit loss. However, MGE enters into transactions only with companies that meet or exceed strict credit guidelines, and it monitors these counterparties on an ongoing basis to mitigate nonperformance risk in its portfolio. As of December 31, 2022, no counterparties had defaulted.

100

19.

Fair Value of Financial Instruments - MGE Energy and MGE.

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

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

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

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

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

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


	December 31, 2022				December 31, 2021
(In thousands)	Carrying Amount		Fair Value		Carrying Amount		Fair Value
Long-term debt(a)	$	643,560	$	571,374	$	623,449	$	729,914

(a)

Includes long-term debt due within one year. Excludes debt issuance costs and unamortized discount of $4.0 million and $4.3 million as of December 31, 2022 and 2021, respectively.

Recurring Fair Value Measurements.

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


	Fair Value as of December 31, 2022
(In thousands)	Total		Level 1		Level 2		Level 3
MGE Energy
Assets:
Derivatives, net(b)	$	3,069	$	1,353	$	—	$	1,716
Exchange-traded investments		1,516		1,516		—		—
Total Assets	$	4,585	$	2,869	$	—	$	1,716
Liabilities:
Derivatives, net(b)	$	8,163	$	5,581	$	—	$	2,582
Deferred compensation		4,743		—		4,743		—
Total Liabilities	$	12,906	$	5,581	$	4,743	$	2,582

MGE
Assets:
Derivatives, net(b)	$	3,069	$	1,353	$	—	$	1,716
Exchange-traded investments		115		115		—		—
Total Assets	$	3,184	$	1,468	$	—	$	1,716
Liabilities:
Derivatives, net(b)	$	8,163	$	5,581	$	—	$	2,582

101


Deferred compensation		4,743		—		4,743		—
Total Liabilities	$	12,906	$	5,581	$	4,743	$	2,582


	Fair Value as of December 31, 2021
(In thousands)	Total		Level 1		Level 2		Level 3
MGE Energy
Assets:
Derivatives, net(c)	$	3,606	$	1,170	$	—	$	2,436
Exchange-traded investments		1,296		1,296		—		—
Total Assets	$	4,902	$	2,466	$	—	$	2,436
Liabilities:
Derivatives, net(c)	$	2,989	$	731	$	—	$	2,258
Deferred compensation		3,653		—		3,653		—
Total Liabilities	$	6,642	$	731	$	3,653	$	2,258

MGE
Assets:
Derivatives, net(c)	$	3,606	$	1,170	$	—	$	2,436
Exchange-traded investments		230		230		—		—
Total Assets	$	3,836	$	1,400	$	—	$	2,436
Liabilities:
Derivatives, net(c)	$	2,989	$	731	$	—	$	2,258
Deferred compensation		3,653		—		3,653		—
Total Liabilities	$	6,642	$	731	$	3,653	$	2,258

(b)

(c)

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

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

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

The purchased power agreement, with a term ended May 2022, (see Footnote 18) was valued using an internal pricing model and therefore was classified as Level 3. The model projected future market energy prices and compared those prices to the projected power costs to be incurred under the contract. Inputs to the model required significant management judgment and estimation. Future energy prices were based on a forward power pricing curve using exchange-traded contracts in the electric futures market. A basis adjustment was applied to the market energy price to reflect the price

102

differential between the market price delivery point and the counterparty delivery point. The historical relationship between the delivery points was reviewed and a discount (below 100%) or premium (above 100%) was derived. This comparison was done for both peak times when demand was high and off peak times when demand was low. If the basis adjustment was lowered, the fair value measurement would decrease, and if the basis adjustment was increased, the fair value measurement would increase.

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

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


Significant Unobservable Inputs		2021
Basis adjustment:
On peak		94.1%
Off peak		92.4%
Counterparty fuel mix:
Internal generation - range		41%-66%
Internal generation - weighted average		56.6%
Purchased power - range		59%-34%
Purchased power - weighted average		43.4%

The following table summarizes the changes in Level 3 commodity derivative assets and liabilities measured at fair value on a recurring basis.


(In thousands)	2022			2021			2020
Balance as of January 1,	$	178		$	(14,055	)	$	(26,456	)
Realized and unrealized gains (losses):
Included in regulatory assets		(1,044	)		—			12,402
Included in regulatory liability		—			14,234			—
Included in other comprehensive income		—			—			—
Included in earnings		14,140			5,521			(6,439	)
Included in current assets		118			237			(87	)
Purchases		11,997			26,287			22,232
Sales		—			—			—
Issuances		—			—			—
Settlements		(26,255	)		(32,046	)		(15,707	)
Balance as of December 31,	$	(866	)	$	178		$	(14,055	)
Total gains (losses) included in earnings attributed to the change in unrealized gains (losses) related to assets and liabilities held as of December 31,(d)	$	—		$	—		$	—

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


(In thousands)
Year Ended December 31,	2022			2021			2020
Purchased power expense	$	14,497		$	6,192		$	(5,888	)
Cost of gas sold expense		(357	)		(671	)		(551	)
Total	$	14,140		$	5,521		$	(6,439	)

(d)

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

103

20.

Revenue - MGE Energy and MGE.

Revenues disaggregated by revenue source were as follows for the years ended December 31:


(In thousands)
Electric revenues	2022		2021		2020
Residential	$	161,300	$	151,646	$	146,431
Commercial		232,057		210,475		198,043
Industrial		13,303		12,529		11,514
Other-retail/municipal		37,323		35,169		32,915
Total retail		443,983		409,819		388,903
Sales to the market		19,385		9,499		4,015
Other revenues		1,799		968		774
Total electric revenues		465,167		420,286		393,692

Gas revenues
Residential		143,544		110,442		88,765
Commercial/Industrial		99,165		68,895		49,682
Total retail		242,709		179,337		138,447
Gas transportation		5,780		6,185		5,713
Other revenues		183		98		101
Total gas revenues		248,672		185,620		144,261

Non-regulated energy revenues		680		678		680
Total Operating Revenue	$	714,519	$	606,584	$	538,633

Performance Obligations

A performance obligation is a promise in a contract to transfer a distinct good or service to the customer and is the unit of account. A contract's transaction price is allocated to each distinct performance obligation and recognized as revenue when, or as, the performance obligation is satisfied. The majority of contracts have a single performance obligation.

Retail Revenue (Residential, Commercial, Industrial, and Other Retail/Municipal)

Providing electric and gas utility service to retail customers represents MGE's core business activity. Tariffs are approved by the PSCW through a rate order and provide MGE's customers with the standard terms and conditions, including pricing terms. The performance obligation to deliver electricity or gas is satisfied over time as the customer simultaneously receives and consumes the commodities provided by MGE. MGE recognizes revenues as the commodity is delivered to customers. Meters are read on a systematic basis throughout the month based on established meter-reading schedules and customers are subsequently billed for services received. At the end of the month, MGE accrues an estimate for unbilled commodities delivered to customers. The unbilled revenue estimate is based on daily system demand volumes, weather factors, estimated line losses, estimated customer usage by class, and applicable customer rates.

Utility Cost Recovery Mechanisms

MGE's tariff rates include a provision for fuel cost recovery. Over-collection of fuel-related costs that are outside the approved range will be recognized as a reduction of revenue. Under-collection of these costs will be recognized in "Purchased power" expense in the consolidated statements of income. The cumulative effects of these deferred amounts will be recorded in "Regulatory assets" or "Regulatory liabilities" on the consolidated balance sheets until they are reflected in future billings to customers. See Footnote 9.b. for further information.

MGE also has other cost recovery mechanisms. For example, any over-collection of the difference between actual costs incurred and the amount of costs collected from customers is recorded as a reduction of revenue in the period incurred.

Sales to the Market

Sales to the market include energy charges, capacity or demand charges, and ancillary charges represented by wholesale sales of electricity made to third parties who are not ultimate users of the electricity. Most of

104

these sales are spot market transactions on the markets operated by MISO. Each transaction is considered a performance obligation and revenue is recognized in the period in which energy charges, capacity or demand charges, and ancillary services are sold into MISO. MGE reports, on a net basis, transactions on the MISO markets in which it buys and sells power within the same hour to meet electric energy delivery requirements.

Transportation of Gas

MGE has contracts under which it provides gas transportation services to customers who have elected to purchase gas from a third party. MGE delivers this gas via pipelines within its service territory. Revenue is recognized as service is rendered or gas is delivered to customers. Tariffs are approved by the PSCW through a rate order and provide gas transportation customers with standard terms and conditions, including pricing terms.

21.

Noncontrolling Interest - MGE.

The noncontrolling interest on MGE's consolidated balance sheets was as follows:


	As of December 31,
(In thousands)	2022		2021
MGE Power Elm Road(a)	$	103,333	$	101,507
MGE Power West Campus(a)		44,830		47,080
Total Noncontrolling Interest	$	148,163	$	148,587

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


(In thousands)	2022		2021		2020
MGE Power Elm Road(a)	$	14,326	$	15,151	$	15,184
MGE Power West Campus(a)		7,250		7,240		7,209
Net Income Attributable to Noncontrolling Interest, Net of Tax	$	21,576	$	22,391	$	22,393

(a)

MGE Power Elm Road and MGE Power West Campus are not subsidiaries of MGE; however, they have been consolidated in the consolidated financial statements of MGE (see Footnote 3). MGE Power Elm Road and MGE Power West Campus are 100% owned by MGE Power, and MGE Power is 100% owned by MGE Energy. MGE Energy's proportionate share of the equity and net income (through its wholly owned subsidiary MGE Power) of MGE Power Elm Road and MGE Power West Campus is classified within the MGE consolidated financial statements as noncontrolling interest.

22.

Segment Information - MGE Energy and MGE.

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

The nonregulated energy operations are conducted through MGE Energy's subsidiaries: MGE Power, MGE Power Elm Road, and MGE Power West Campus. These subsidiaries own electric generating capacity that they lease to MGE to assist MGE. MGE Power Elm Road has an ownership interest in two coal-fired generating units in Oak Creek, Wisconsin, which are leased to MGE, and MGE Power West Campus owns a controlling interest in the electric generation plant of a natural gas-fired cogeneration facility on the UW campus. MGE Power West Campus's portion is also leased to MGE.

The transmission investment segment invests in ATC, a company that provides electric transmission services primarily in Wisconsin, and ATC Holdco, a company formed to pursue electric transmission development and investments outside of Wisconsin. These investments are held in MGE Transco and MGEE Transco, respectively. See Footnote 7 for further discussion.

The "All Others" segment includes: corporate, CWDC, MAGAEL, MGE State Energy Services, MGE Services, and North Mendota. These entities' operations consist of investing in companies and property which relate to the regulated operations, financing the regulated operations.

105

General corporate expenses include the cost of executive management, corporate accounting and finance, information technology, risk management, human resources and legal functions, and employee benefits that are allocated to electric and gas segments based on formulas prescribed by the PSCW. Identifiable assets are those used in MGE's operations in each segment.

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

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


(In thousands) MGE Energy	Electric			Gas			Non-Regulated Energy			Transmission Investment			All Others			Consolidation/ Elimination Entries			Consolidated Total
Year Ended December 31, 2022
Operating revenues	$	465,167		$	248,672		$	680		$	—		$	—		$	—		$	714,519
Interdepartmental revenues		(44	)		34,073			41,555			—			—			(75,584	)		—
Total operating revenues		465,123			282,745			42,235			—			—			(75,584	)		714,519
Depreciation and amortization		(62,897	)		(15,261	)		(7,391	)		—			—			—			(85,549	)
Operating income (loss)		77,672			26,261			34,683			—			(873	)		—			137,743
Interest (expense) income, net		(17,578	)		(4,787	)		(4,322	)		—			40			—			(26,647	)
Income tax (provision) benefit		(7,299	)		(8,492	)		(8,272	)		(2,490	)		329			—			(26,224	)
Equity in earnings of investments		—			—			—			9,136			—			—			9,136
Net income (loss)		65,187			18,215			22,090			6,647			(1,187	)		—			110,952

Year Ended December 31, 2021
Operating revenues	$	420,286		$	185,620		$	678		$	—		$	—		$	—		$	606,584
Interdepartmental revenues		556			22,728			40,866			—			—			(64,150	)		—
Total operating revenues		420,842			208,348			41,544			—			—			(64,150	)		606,584
Depreciation and amortization		(56,672	)		(12,852	)		(7,459	)		—			—			—			(76,983	)
Operating income (loss)		58,993			25,133			33,936			—			(768	)		—			117,294
Interest (expense) income, net		(15,261	)		(4,315	)		(4,577	)		—			41			—			(24,112	)
Income tax (provision) benefit		10,672			(4,922	)		(7,998	)		(2,486	)		619			—			(4,115	)
Equity in earnings of investments		—			—			—			9,339			(69	)		—			9,270
Net income (loss)		63,910			15,511			21,361			6,852			(1,873	)		—			105,761

Year Ended December 31, 2020
Operating revenues	$	393,692		$	144,261		$	680		$	—		$	—		$	—		$	538,633
Interdepartmental revenues		765			12,157			40,402			—			—			(53,324	)		—
Total operating revenues		394,457			156,418			41,082			—			—			(53,324	)		538,633
Depreciation and amortization		(54,658	)		(12,049	)		(7,481	)		—			—			—			(74,188	)
Operating income (loss)		57,847			19,674			33,460			(1	)		(983	)		—			109,997
Interest (expense) income, net		(14,446	)		(4,370	)		(4,826	)		—			121			—			(23,521	)
Income tax (provision) benefit		(4,230	)		(4,805	)		(7,800	)		(2,786	)		198			—			(19,423	)
Equity in earnings of investments		—			—			—			10,221			—			—			10,221
Net income (loss)		50,522			14,167			20,834			7,434			(539	)		—			92,418

106


(In thousands) MGE	Electric			Gas			Non-Regulated Energy			Consolidation/ Elimination Entries			Consolidated Total
Year Ended December 31, 2022
Operating revenues	$	465,167		$	248,672		$	680		$	—		$	714,519
Interdepartmental revenues		(44	)		34,073			41,555			(75,584	)		—
Total operating revenues		465,123			282,745			42,235			(75,584	)		714,519
Depreciation and amortization		(62,897	)		(15,261	)		(7,391	)		—			(85,549	)
Operating income		77,672			26,261			34,683			—			138,616
Interest expense, net		(17,578	)		(4,787	)		(4,322	)		—			(26,687	)
Income tax provision		(7,299	)		(8,492	)		(8,272	)		—			(24,063	)
Net income attributable to MGE		65,187			18,215			22,090			(21,576	)		83,916

Year Ended December 31, 2021
Operating revenues	$	420,286		$	185,620		$	678		$	—		$	606,584
Interdepartmental revenues		556			22,728			40,866			(64,150	)		—
Total operating revenues		420,842			208,348			41,544			(64,150	)		606,584
Depreciation and amortization		(56,672	)		(12,852	)		(7,459	)		—			(76,983	)
Operating income		58,993			25,133			33,936			—			118,062
Interest expense, net		(15,261	)		(4,315	)		(4,577	)		—			(24,153	)
Income tax (provision) benefit		10,672			(4,922	)		(7,998	)		—			(2,248	)
Net income attributable to MGE		63,910			15,511			21,361			(22,391	)		78,391

Year Ended December 31, 2020
Operating revenues	$	393,692		$	144,261		$	680		$	—		$	538,633
Interdepartmental revenues		765			12,157			40,402			(53,324	)		—
Total operating revenues		394,457			156,418			41,082			(53,324	)		538,633
Depreciation and amortization		(54,658	)		(12,049	)		(7,481	)		—			(74,188	)
Operating income		57,847			19,674			33,460			—			110,981
Interest expense, net		(14,446	)		(4,370	)		(4,826	)		—			(23,642	)
Income tax provision		(4,230	)		(4,805	)		(7,800	)		—			(16,835	)
Net income attributable to MGE		50,522			14,167			20,834			(22,393	)		63,130

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


	Utility				Consolidated
(In thousands) MGE Energy	Electric		Gas		Non-regulated Energy		Transmission Investment(a)		All Others		Consolidation/ Elimination Entries			Total
Assets:
December 31, 2022	$	1,626,373	$	530,733	$	247,841	$	80,642	$	467,112	$	(435,101	)	$	2,517,600
December 31, 2021		1,525,163		485,345		252,584		75,990		467,954		(435,130	)		2,371,906
December 31, 2020		1,421,302		444,702		254,298		74,480		495,483		(436,614	)		2,253,651
Capital Expenditures:
Year ended Dec. 31, 2022	$	141,273	$	27,656	$	6,101	$	—	$	—	$	—		$	175,030
Year ended Dec. 31, 2021		115,234		34,071		3,864		—		—		—			153,169
Year ended Dec. 31, 2020		162,210		36,906		4,023		—		—		—			203,139


	Utility				Consolidated
(In thousands) MGE	Electric		Gas		Non-regulated Energy		Consolidation/ Elimination Entries			Total
Assets:
December 31, 2022	$	1,626,373	$	530,733	$	247,791	$	(258	)	$	2,404,639
December 31, 2021		1,525,163		485,345		252,534		(267	)		2,262,775
December 31, 2020		1,421,302		444,702		254,248		(281	)		2,119,971
Capital Expenditures:
Year ended Dec. 31, 2022	$	141,273	$	27,656	$	6,101	$	—		$	175,030
Year ended Dec. 31, 2021		115,234		34,071		3,864		—			153,169
Year ended Dec. 31, 2020		162,210		36,906		4,023		—			203,139

(a)

The Transmission Investment segment represents MGE Energy's investment in equity method investees.

107

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

MGE Energy and MGE

None.

Item 9A. Controls and Procedures.

MGE Energy and MGE

Conclusion Regarding the Effectiveness of Disclosure Controls and Procedures

During the fourth quarter of 2022, each registrant's management, including the principal executive officer and principal financial officer, evaluated its disclosure controls and procedures related to the recording, processing, summarization, and reporting of information in its periodic reports that it files with the SEC. These disclosure controls and procedures have been designed to ensure that material information relating to that registrant, including its subsidiaries, is accumulated and made known to that registrant's management, including these officers, by other employees of that registrant and its subsidiaries as appropriate to allow timely decisions regarding required disclosure, and that this information is recorded, processed, summarized, evaluated, and reported, as applicable, within the time periods specified in the SEC's rules and forms. The evaluations take into account changes in the internal and external operating environments that may impact those controls and procedures. Due to the inherent limitations of control systems, not all misstatements may be detected. These inherent limitations include the realities that judgments in decision making can be faulty and breakdowns can occur because of simple error or mistake. Additionally, controls can be circumvented by the individual acts of some persons, by collusion of two or more people, or by management override of the control. Also, MGE Energy does not control or manage certain of its unconsolidated entities and thus, its access and ability to apply its procedures to those entities is more limited than is the case for its consolidated subsidiaries.

As of December 31, 2022, each registrant's principal executive officer and principal financial officer concluded that its disclosure controls and procedures were effective. Each registrant intends to strive continually to improve its disclosure controls and procedures to enhance the quality of its financial reporting.

Changes in Internal Control Over Financial Reporting

During the quarter ended December 31, 2022, there were no changes in either registrant's internal controls over financial reporting that materially affected, or are reasonably likely to affect materially, that registrant's internal control over financial reporting.

MGE Energy and MGE

Management of MGE Energy and MGE are required to assess and report on the effectiveness of its internal control over financial reporting as of December 31, 2022. As a result of that assessment, management determined that there were no material weaknesses as of December 31, 2022 and, therefore, concluded that MGE Energy and MGE's internal control over financial reporting was effective. Management's Report on Internal Control Over Financial Reporting is included in Item 8. Financial Statements and Supplementary Data of this Report.

Item 9B. Other Information.

MGE Energy

None.

Item 9C. Disclosure Regarding Foreign Jurisdictions that Prevent Inspections.

MGE Energy

None.

108

PART III.

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

MGE Energy

The information required by Item 10 relating to directors and nominees for election as directors at MGE Energy's annual meeting of shareholders is incorporated herein by reference to the information under the heading "ELECTION OF DIRECTORS" in MGE Energy's definitive proxy statement (2023 Proxy Statement) to be filed with the SEC before April 30, 2023. Information relating to compliance with Section 16(a) of the Securities Exchange Act of 1934 is incorporated herein by reference to the information under the heading "BENEFICIAL OWNERSHIP – Delinquent Section 16(a) Reports" in the 2023 Proxy Statement.

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

Code of Ethics

MGE Energy has adopted a Code of Ethics applicable to its directors and all of its employees, including its chief executive officer, chief financial officer, and principal accounting officer. The Code of Ethics is available on MGE Energy's website at www.mgeenergy.com. Information contained on MGE Energy's website shall not be deemed incorporated into, or to be a part of, this report.

Item 11. Executive Compensation.

See Item 12.

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

MGE Energy

The following table presents information regarding MGE Energy's equity compensation plans as of December 31, 2022:


	(a)	(b)	(c)
Plan category	Number of securities to be issued upon exercise of outstanding options, warrants, and rights	Weighted-average exercise price of outstanding options, warrants, and rights	Number of securities remaining available for future issuance under equity compensation plans (excluding securities reflected in column (a))
Equity compensation plans approved by shareholders	—	$—	447,220	(1)
Equity compensation plans not approved by shareholders	N/A	N/A	N/A
Total	—	$—	447,220

(1)

All of the available shares under the 2021 Long-term Incentive plan may be issued as awards in the form of restricted stock, restricted stock units, and performance units. Stock options are not authorized. As of December 31, 2022, there were restricted stock units and performance units outstanding under the 2021 Long-term Incentive Plan. Column (c) assumes the outstanding performance shares are settled in shares of common stock as opposed to cash.

The remainder of the required information is included in the 2023 Proxy Statement, which will be filed with the SEC before April 30, 2023, for Item 11 under the section "EXECUTIVE COMPENSATION," not including "Compensation Committee Report," and "Cumulative Five-Year Total Return Comparison Graph," and for Item 12 under the section "BENEFICIAL OWNERSHIP," which is incorporated herein by reference.

109

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

MGE Energy

The information required by Item 13 is incorporated by reference herein from the "BOARD OF DIRECTORS INFORMATION" section in the 2023 Proxy Statement, which will be filed with the SEC before April 30, 2023.

Item 14. Principal Accounting Fees and Services.

MGE Energy

The information required by Item 14 is incorporated herein by reference to the information under the heading "RATIFICATION OF PRICEWATERHOUSECOOPERS LLP AS OUR INDEPENDENT REGISTERED PUBLIC ACCOUNTING FIRM" in the 2023 Proxy Statement, which will be filed with the SEC before April 30, 2023.

MGE

Independent Registered Public Accounting Firm Fees Disclosure


	2022		2021
Audit fees(a)	$	1,072,643	$	1,124,568
Audit-related fees(b)		80,000		316,700
Tax fees(c)		43,118		35,478
All other fees(d)		4,500		607,800

(a)

Professional services rendered for the audits of the financial statements, review of the interim financial statements, opinion on the effectiveness of our internal control over financial reporting for MGE Energy, and services that generally only the independent auditor can reasonably provide, such as comfort letters, statutory audits, consents, and assistance with and review of documents filed with the SEC. Audit Fees for 2021 also include professional services rendered in connection with implementation of a new customer information system.

(b)

Audit-Related Fees for 2022 and 2021 include professional services rendered in connection with utility commission-mandated obligations. Fees in 2021 also include professional services rendered in connection with Enterprise Forward project implementation review that included review of security and internal controls. Enterprise Forward is a strategic information technology management project aimed at transforming MGE into a digital integrated utility and includes replacement of customer information system.

(c)

Tax fees for 2022 and 2021 include review of federal and state income tax returns.

(d)

Other Fees for 2021 include advisory services with respect to the Enterprise Forward project.

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

110

PART IV.

Item 15. Exhibits and Financial Statement Schedules.

(a) 1. Financial Statements.



MGE Energy
Consolidated Statements of Income for the years ended December 31, 2022, 2021, and 2020	57
Consolidated Statements of Cash Flows for the years ended December 31, 2022, 2021, and 2020	58
Consolidated Balance Sheets as of December 31, 2022 and 2021	59
Consolidated Statements of Common Equity as of December 31, 2022, 2021, and 2020	60
Notes to Consolidated Financial Statements	65

MGE
Consolidated Statements of Income for the years ended December 31, 2022, 2021, and 2020	61
Consolidated Statements of Cash Flows for the years ended December 31, 2022, 2021, and 2020	62
Consolidated Balance Sheets as of December 31, 2022 and 2021	63
Consolidated Statements of Equity as of December 31, 2022, 2021, and 2020	64
Notes to Consolidated Financial Statements	65

2. Financial Statement Schedules.



MGE Energy
Schedule I – Condensed Parent Company Financial Statements as of December 31, 2021 and 2020 and for the years ended December 31, 2022, 2021, and 2020.	115
Schedule II – Valuation and Qualifying Accounts for the years ended December 31, 2022, 2021, and 2020.	118

MGE
Schedule II – Valuation and Qualifying Accounts for the years ended December 31, 2022, 2021, and 2020.	118

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

3. All Exhibits Including Those Incorporated by Reference.

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

111


		Incorporated by Reference
Ex. No.	Exhibit Description	Form	File No.	Exhibit	Date Filed
3.1	Amended and Restated Articles of Incorporation of MGE Energy, Inc.	S-3 Registration Statement	333-197423	4.1	7/15/2014

3.2	Amended and Restated Bylaws of MGE Energy, Inc.	8-K	0-49965	3.2	3/24/2020

3.3	Restated Articles of Incorporation of Madison Gas and Electric Company as in effect at October 25, 2012.	8-K	0-1125	3.1	10/25/2012

3.4	Amended Bylaws of Madison Gas and Electric Company as in effect at August 16, 2002	10-K	0-1125	3.3	3/26/2003

4.1	Indenture of Mortgage and Deed of Trust between Madison Gas and Electric Company and U.S. Bank, N.A. (successor to First Wisconsin Trust Company), as Trustee	10-Q	0-49965	4.1	8/7/2018

4.2	Supplemental Indenture dated as of February 1, 1993 to aforementioned Indenture of Mortgage and Deed of Trust.	10-Q	0-49965	4.2	5/8/2018

4.3	Indenture between Madison Gas and Electric Company and The Bank of New York Mellon Trust Company, N.A. (as successor to Bank One, N.A.), as Trustee	10-K	0-1125	4B	3/29/2000

4.4	Description of Common Stock	10-K	0-49965	4.4	2/27/2020

10.1	Second Amended and Restated Credit Agreement dated as of November 8, 2022, among MGE Energy, Inc., the Lenders party thereto and JPMorgan Chase Bank, N.A., as Administrative Agent.	10-K	0-49965	10.1	2/22/2023

10.2	Second Amended and Restated Credit Agreement dated as of November 8, 2022, among Madison Gas and Electric Company, the Lenders party thereto and JPMorgan Chase Bank, N.A., as Administrative Agent.	10-K	0-1125	10.2	2/22/2023

10.3	First Amendment to second Amended and Restated Credit Agreement dated January 30, 2023, among Madison Gas and Electric Company, the lenders named therein and JPMorgan Chase Bank, N.A., as Administrative Agent.	8-K	0-1125	10.1	2/01/2023

10.4	Second Amended and Restated Credit Agreement dated as of November 8, 2022, among Madison Gas and Electric Company, the Lenders party thereto and U.S. Bank National Association, as Administrative Agent.	10-K	0-1125	10.4	2/22/2023

10.5	Joint Power Supply Agreement with Wisconsin Power and Light Company and Wisconsin Public Service Corporation.	10-Q	0-49965	10.4	5/8/2018

10.6	Joint Power Supply Agreement (Exclusive of Exhibits) with Wisconsin Power and Light Company and Wisconsin Public Service Corporation.	10-Q	0-49965	10.5	8/7/2018

10.7	Second Amended and Restated Agreement for Construction and Operation of Columbia Generating Plant.	10-K	0-49965	10.6	2/22/2019

10.8	West Campus Cogeneration Facility Joint Ownership Agreement, dated as of October 13, 2003, among MGE Power West Campus, LLC, The Board of Regents of the University of Wisconsin System, and the State of Wisconsin, as Joint Owners.	10-Q	0-1125	10.19	11/8/2005

10.9	West Campus Cogeneration Facility Operation and Maintenance Agreement, dated as of October 13, 2003, among Madison Gas and Electric Company, as Operator, and the Board of Regents of the University of Wisconsin System, as Joint Owner.	10-Q	0-1125	10.20	11/8/2005

10.10	West Campus Cogeneration Facility Lease Agreement, dated as of March 18, 2004, among MGE Power West Campus, LLC, as Lessor, and Madison Gas and Electric Company, as Lessee.	10-Q	0-1125	10.21	11/8/2005

10.11	West Campus Cogeneration Facility Ground Lease, dated as of July 15, 2002, among MGE Power LLC, as Lessee, and the Board of Regents of the University of Wisconsin System, as Lessor.	10-Q	0-1125	10.22	11/8/2005

10.12	West Campus Cogeneration Facility Amendment of Ground Lease, dated as of March 18, 2004, among MGE Power West Campus, LLC, as Lessee, and the Board of Regents of the University of Wisconsin System, as Lessor.	10-Q	0-1125	10.23	11/8/2005

10.13	West Campus Cogeneration Facility MGE Ground Sublease, dated as of March 18, 2004, among MGE Power West Campus, LLC, as Lessee, and Madison Gas and Electric Company, as Lessor.	10-Q	0-1125	10.24	11/8/2005

10.14	Elm Road Generating Station Common Facilities Operating and Maintenance Agreement, dated as of December 17, 2004, among Madison Gas and Electric Company, Wisconsin Electric Power Company, and Wisconsin Public Power Inc., as Lessee/Owner Parties, and Wisconsin Electric Power Company, as Operating Agent.	10-Q	0-1125	10.7	11/8/2005

10.15	Elm Road Generating Station New Common Facilities Ownership Agreement, dated as of December 17, 2004, among MGE Power Elm Road, LLC, Elm Road Generating Station Supercritical, LLC, and Wisconsin Public Power Inc., as Joint Owners.	10-Q	0-1125	10.8	11/8/2005

10.16	Elm Road Generating Station I Ownership Agreement, dated as of December 17, 2004, among MGE Power Elm Road, LLC, Elm Road Generating Station Supercritical, LLC, and Wisconsin Public Power Inc., as Joint Owners, Elm Road Services, LLC, as Project Manager, and W.E. Power LLC.	10-Q	0-1125	10.9	11/8/2005

10.17	Elm Road Generating Station I Facility Lease Agreement, dated as of November 4, 2005, among MGE Power Elm Road, LLC, as Lessor, and Madison Gas and Electric Company, as Lessee.	10-Q	0-1125	10.10	11/8/2005

112


10.18		Elm Road Generating Station I Operating and Maintenance Agreement, dated as of December 17, 2004, among Madison Gas and Electric Company, Wisconsin Electric Power Company, and Wisconsin Public Power Inc., as Lessee/ Owners, and Wisconsin Electric Power Company, as Operating Agent.	10-Q	0-1125	10.11	11/8/2005

10.19		Elm Road Generating Station I Easement and Indemnification Agreement, dated as of December 17, 2004, among MGE Power Elm Road, LLC and Wisconsin Public Power Inc., as Grantees, and Wisconsin Electric Power Company, as Grantor.	10-Q	0-1125	10.12	11/8/2005

10.20		Assignment and Assumption Agreement, dated as of November 4, 2005 between MGE Power Elm Road, LLC and Madison Gas and Electric Company relating to Elm Road Generating Station I Easement and Indemnification Agreement, dated as of December 17, 2004, among MGE Power Elm Road, LLC and Wisconsin Public Power Inc., as Grantees, and Wisconsin Electric Power Company, as Grantor.	10-K	0-1125	10.16	3/8/2006

10.21		Elm Road Generating Station II Ownership Agreement, dated as of December 17, 2004, among MGE Power Elm Road, LLC, Elm Road Generating Station Supercritical, LLC, and Wisconsin Public Power Inc., as Joint Owners, Elm Road Services, LLC, as Project Manager, and W.E. Power LLC.	10-Q	0-1125	10.13	11/8/2005

10.22		Elm Road Generating Station II Facility Lease Agreement, dated as of November 4, 2005, among MGE Power Elm Road, LLC, as Lessor, and Madison Gas and Electric Company, as Lessee.	10-Q	0-1125	10.14	11/8/2005

10.23		Elm Road Generating Station II Operating and Maintenance Agreement, dated as of December 17, 2004, among Madison Gas and Electric Company, Wisconsin Electric Power Company, and Wisconsin Public Power Inc., as Lessee/ Owners, and Wisconsin Electric Power Company, as Operating Agent.	10-Q	0-1125	10.15	11/8/2005

10.24		Elm Road Generating Station II Easement and Indemnification Agreement, dated as of December 17, 2004, among MGE Power Elm Road, LLC and Wisconsin Public Power Inc., as Grantees, and Wisconsin Electric Power Company, as Grantor.	10-Q	0-1125	10.16	11/8/2005

10.25		Substation and Transformer Shared Use Agreement and Easement Agreement, dated as of September 29, 2006, among Madison Gas and Electric Company and Northern Iowa Windpower II LLC as Joint Owners.	10-Q	0-1125	10.6	11/7/2006

10.26		Management and Administration Agreement, dated as of October 13, 2006, among Madison Gas and Electric Company as Owner and Midwest Renewable Energy Resources, LLC as Manager.	10-Q	0-1125	10.7	11/7/2006

10.27	*	Form of Severance Agreement.	10-K	0-49965	10.37	2/26/2009

10.28	*	Form of Amendment to Severance Agreement.	10-Q	0-49965	10.1	5/5/2016

10.29	*	Form of Severance Agreement for Officers hired on or after January 1, 2012.	10-Q	0-49965	10.2	5/5/2016

10.30	*	Form of Amended and Restated Deferred Compensation Agreement.	10-K	0-49965	10.39	2/26/2009

10.31	*	Amendment to Madison Gas and Electric Company Deferred Compensation Agreement	10-K	0-49965	10.31	2/22/2023

10.32	*	2023 Deferred Compensation Supplemental Executive Retirement Plan	10-K	0-49965	10.32	2/22/2023

10.33	*	Income Continuation Agreement - Keebler	10-K	0-49965	10.32	2/22/2018

10.34	*	Income Continuation Agreement - Hobbie	10-K	0-49965	10.34	2/22/2023

10.35	*	Income Continuation Agreement - Johnson	10-K	0-49965	10.35	2/22/2023

10.36	*	MGE Energy, Inc., 2006 Performance Unit Plan, as amended.	10-Q	0-49965	10.1	5/5/2017

10.37	*	Form of Performance Unit Award Agreement.	10-K	0-49965	10.42	2/26/2009

10.38	*	Form of Amendment to Performance Unit Award Agreement.	8-K	0-49965	10.1	4/21/2011

10.39	*	MGE Energy, Inc., 2013 Director Incentive Plan, as amended.	10-Q	0-49965	10.2	5/5/2017

10.40	*	Form of 2013 Director Incentive Plan Award Agreement.	10-K	0-49965	10.38	2/27/2014

10.41	*	MGE Energy, Inc., 2020 Performance Unit Plan	10-K	0-49965	10.40	2/27/2020

10.42	*	Form of 2020 Performance Unit Award Agreement	10-K	0-49965	10.41	2/27/2020

10.43	*	MGE Energy, Inc., 2021 Long-Term Incentive Plan	DEF 14A	0-49965	DEF 14A	3/31/2020

10.44	*	Form of Performance Unit Award Agreement for Employees pursuant to the MGE Energy Inc., 2021 Long-Term Incentive Plan	10-K	0-49965	10.43	2/24/2021

10.45	*	Form of Notice of Grant of Performance Unit Award Agreement for Employees pursuant to the MGE Energy Inc., 2021 Long-Term Incentive Plan	10-K	0-49965	10.44	2/24/2021

10.46	*	Form of Restricted Stock Award Agreement for Employees pursuant to the MGE Energy Inc., 2021 Long-Term Incentive Plan	10-K	0-49965	10.45	2/24/2021

10.47	*	Form of Restricted Stock Award Agreement for Directors pursuant to the MGE Energy Inc., 2021 Long-Term Incentive Plan	10-K	0-49965	10.46	2/24/2021

10.48	*	Form of Notice of Grant of Restricted Stock Award Agreement for Employees and Directors pursuant to the MGE Energy Inc., 2021 Long-Term Incentive Plan	10-K	0-49965	10.47	2/24/2021

113


10.49	*	Form of Restricted Stock Units Agreement for Employees pursuant to the MGE Energy Inc., 2021 Long-Term Incentive Plan	10-K	0-49965	10.48	2/24/2021

10.50	*	Form of Restricted Stock Units Agreement for Directors pursuant to the MGE Energy Inc., 2021 Long-Term Incentive Plan	10-K	0-49965	10.49	2/24/2021

10.51	*	Form of Notice of Grant of Restricted Stock Units Agreement for Employees and Directors pursuant to the MGE Energy Inc., 2021 Long-Term Incentive Plan	10-K	0-49965	10.50	2/24/2021

21	**	Subsidiaries of MGE Energy, Inc.	-	-	-	-

23.1	**	Consent of Independent Registered Public Accounting Firm - MGE Energy, Inc.	-	-	-	-

23.2	**	Consent of Independent Registered Public Accounting Firm - Madison Gas and Electric Company	-	-	-	-

31.1	**	Certifications Pursuant to Rule 13a-14(a) and 15d-14(a) of the Securities Exchange Act of 1934 filed by Jeffrey M. Keebler for MGE Energy, Inc.	-	-	-	-

31.2	**	Certifications Pursuant to Rule 13a-14(a) and 15d-14(a) of the Securities Exchange Act of 1934 filed by Jared J. Bushek for MGE Energy, Inc.	-	-	-	-

31.3	**	Certifications Pursuant to Rule 13a-14(a) and 15d-14(a) of the Securities Exchange Act of 1934 filed by Jeffrey M. Keebler for Madison Gas and Electric Company	-	-	-	-

31.4	**	Certifications Pursuant to Rule 13a-14(a) and 15d-14(a) of the Securities Exchange Act of 1934 filed by Jared J. Bushek for Madison Gas and Electric Company	-	-	-	-

32.1	***	Certifications Pursuant to Section 1350 of Chapter 63 of Title 18 United States Code (Sarbanes-Oxley Act of 2002) filed by Jeffrey M. Keebler for MGE Energy, Inc.	-	-	-	-

32.2	***	Certifications Pursuant to Section 1350 of Chapter 63 of Title 18 United States Code (Sarbanes-Oxley Act of 2002) filed by Jared J. Bushek for MGE Energy, Inc.	-	-	-	-

32.3	***	Certifications Pursuant to Section 1350 of Chapter 63 of Title 18 United States Code (Sarbanes-Oxley Act of 2002) filed by Jeffrey M. Keebler for Madison Gas and Electric Company	-	-	-	-

32.4	***	Certifications Pursuant to Section 1350 of Chapter 63 of Title 18 United States Code (Sarbanes-Oxley Act of 2002) filed by Jared J. Bushek for Madison Gas and Electric Company	-	-	-	-

101.INS	**	XBRL Instance	-	-	-	-
101.SCH	**	XBRL Taxonomy Extension Schema	-	-	-	-
101.CAL	**	XBRL Taxonomy Extension Calculation	-	-	-	-
101.DEF	**	XBRL Taxonomy Extension Definition	-	-	-	-
101.LAB	**	XBRL Taxonomy Extension Labels	-	-	-	-
101.PRE	**	XBRL Taxonomy Extension Presentation	-	-	-	-

*		Indicates a management contract or compensatory plan or arrangement.
**		Filed herewith.
***		Furnished herewith.

Item 16. Form 10-K Summary.

MGE Energy and MGE

None.

114

Schedule I

Condensed Parent Company Financial Statements

MGE Energy, Inc.

Statements of Income

(Parent Company Only)

(In thousands)


	For the Years Ended December 31,
	2022			2021			2020
Operating Expenses:
Other operations and maintenance	$	746		$	711		$	882
Total Operating Expenses		746			711			882
Operating Loss		(746	)		(711	)		(882	)
Equity in earnings of investments		112,180			107,883			92,922
Other income (loss), net		(855	)		(2,163	)		94
Interest income, net		2			5			78
Income before income taxes		110,581			105,014			92,212
Income tax provision		371			747			206
Net Income	$	110,952		$	105,761		$	92,418

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

MGE Energy, Inc.

Statements of Cash Flows

(Parent Company Only)

(In thousands)


	For the Years Ended December 31,
	2022			2021			2020
Net Cash Flows Provided by Operating Activities	$	58,253		$	27,535		$	27,631
Investing Activities:
Contributions to affiliates		(2,693	)		—			(32,157	)
Contributions to other investments		(2,357	)		(4,006	)		(3,809	)
Other		861			843			622
Cash Used for Investing Activities		(4,189	)		(3,163	)		(35,344	)
Financing Activities:
Issuance of common stock, net		—			—			79,635
Cash dividends paid on common stock		(57,500	)		(54,788	)		(51,729	)
Other		(187	)		—			—
Cash Provided by (Used for) Financing Activities		(57,687	)		(54,788	)		27,906
Change in cash, cash equivalents, and restricted cash		(3,623	)		(30,416	)		20,193
Cash, cash equivalents, and restricted cash at beginning of period		6,959			37,375			17,182
Cash, cash equivalents, and restricted cash at end of period	$	3,336		$	6,959		$	37,375

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

115

Schedule I

Condensed Parent Company Financial Statements (continued)

MGE Energy, Inc.

Balance Sheets

(Parent Company Only)

(In thousands)


	As of December 31,
ASSETS	2022		2021
Current Assets:
Cash and cash equivalents	$	3,336	$	6,959
Other current assets		1,978		1,681
Total Current Assets		5,314		8,640
Other deferred assets and other		294		244
Investments:
Investments in affiliates		1,091,103		1,036,347
Other investments		21,193		18,927
Total Investments		1,112,296		1,055,274
Total Assets	$	1,117,904	$	1,064,158

LIABILITIES AND SHAREHOLDERS' EQUITY
Current Liabilities:
Accounts payable to affiliates	$	530	$	548
Other current liabilities		2,017		2,516
Total Current Liabilities		2,547		3,064
Other Credits:
Deferred income taxes		32,624		32,014
Accounts payable to affiliates		1,059		1,589
Other deferred liabilities		—		23
Total Other Credits		33,683		33,626
Shareholders' Equity:
Common shareholders' equity		431,820		431,066
Retained earnings		649,854		596,402
Total Shareholders' Equity		1,081,674		1,027,468
Commitments and contingencies (see Footnote 3)
Total Liabilities and Shareholders' Equity	$	1,117,904	$	1,064,158

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

116

Schedule I

Condensed Parent Company Financial Statements (continued)

Notes to Condensed Financial Statements

(Parent Company Only)

Basis of Presentation.

MGE Energy is a holding company and conducts substantially all of its business operations through its subsidiaries. For Parent Company only presentation, investment in subsidiaries are accounted for using the equity method. These condensed Parent Company financial statements and related notes have been prepared in accordance with Rule 12-04, Schedule I of Regulation S-X. These statements should be read in conjunction with the financial statements and the notes in Item 8. Financial Statements and Supplementary Data of the Annual Report on Form 10-K for the year ended December 31, 2022.

Credit Agreements.

As of December 31, 2022, MGE Energy had access to an unsecured, committed credit facility with aggregate bank commitments of $50.0 million. As of December 31, 2022, no borrowings were outstanding under this facility. See Footnote 13 of the Notes to Consolidated Financial Statements in this Report for further information regarding MGE Energy's credit agreement.

Commitments and Contingencies.

See Footnote 16 of the Notes to Consolidated Financial Statements in this Report for information regarding commitments and contingencies.

Dividends from Affiliates.


	Dividends from Affiliates
(In thousands)	2022		2021		2020
MGE	$	33,500	$	5,000	$	—
MGE Power Elm Road		12,500		10,500		15,500
MGE Power West Campus		9,500		4,500		6,000
MGE Transco		4,621		5,464		5,864
MGEE Transco		—		—		350
Total	$	60,121	$	25,464	$	27,714

Dividend Restrictions

Dividend payments by MGE to MGE Energy are subject to restrictions arising under a PSCW rate order and, to a lesser degree, MGE's first mortgage bonds. The PSCW order restricts any dividends that MGE may pay MGE Energy if its common equity ratio, calculated in the manner used in the rate proceeding, is less than 55%. MGE's thirteen month rolling average common equity ratio as of December 31, 2022, is 60.5% as determined under the calculation used in the rate proceeding. This restriction did not impact MGE's payment of dividends in 2022. Cash dividends of $33.5 million and $5.0 million were paid by MGE to MGE Energy in 2022 and 2021, respectively. The rate proceeding calculation includes as indebtedness imputed amounts for MGE's outstanding purchase power capacity payments and other PSCW adjustments, but does not include the indebtedness associated with MGE Power Elm Road or MGE Power West Campus, which are consolidated into MGE's financial statements but are not direct obligations of MGE.

See Footnotes 13 and 14 of the Notes to Consolidated Financial Statements in this Report for more information on dividend restrictions appearing in credit agreements and long-term debt, respectively.

117

Schedule II

MGE Energy, Inc. and Madison Gas and Electric Company

Valuation and Qualifying Accounts


			Additions
	Balance at Beginning of Period		Charged to Costs and Expenses(b)		Charged to Other Accounts		Net Accounts Written Off(a)			Balance at End of Period
Year ended 2020:
Accumulated provision for uncollectibles	$	3,258,269		5,164,943		26,400		(1,373,047	)	$	7,076,565

Year ended 2021:
Accumulated provision for uncollectibles	$	7,076,565		3,402,468		32,400		(2,207,732	)	$	8,303,701

Year ended 2022:
Accumulated provision for uncollectibles	$	8,303,701		3,814,311		40,800		(3,785,972	)	$	8,372,840

(a)

Net of recovery of amounts previously written off.

(b)

For the years ended December 31, 2022, 2021, and 2020, MGE deferred $2.1 million, $1.8 million, and $3.8 million, respectively, of bad debt expense as a regulatory asset. See Footnote 8 of the Notes to Consolidated Financial Statements in this Report for further information.

118

Signatures - MGE Energy, Inc.

Pursuant to the requirements of Section 13 or 15(d) of the Securities Exchange Act of 1934, the registrant has duly caused this report to be signed on its behalf by the undersigned, hereunto duly authorized.


	MGE Energy, Inc.
	(Registrant)

Date: February 22, 2023	/s/ Jeffrey M. Keebler
	Chairman, President, and Chief Executive Officer

Pursuant to the requirements of the Securities Exchange Act of 1934, this report has been signed below by the following persons on behalf of the registrant and in the capacities indicated on February 22, 2023.


/s/ Jeffrey M. Keebler	Jeffrey M. Keebler Chairman, President, and Chief Executive Officer and Director (Principal Executive Officer)

/s/ Jared J. Bushek	Jared J. Bushek Vice President - Finance, Chief Information Officer and Treasurer (Chief Financial Officer)

/s/ Tamara J. Johnson	Tamara J. Johnson Vice President - Accounting and Controller (Chief Accounting Officer)
/s/ Marcia M. Anderson	Marcia M. Anderson, Director
/s/ James G. Berbee	James G. Berbee, Director
/s/ Mark D. Bugher	Mark D. Bugher, Director
/s/ Londa J. Dewey	Londa J. Dewey, Director
/s/ James L. Possin	James L. Possin, Director
/s/ Thomas R. Stolper	Thomas R. Stolper, Director
/s/ Gary J. Wolter	Gary J. Wolter, Director
/s/ Noble L. Wray	Noble L. Wray, Director

119

Signatures - Madison Gas and Electric Company


	Madison Gas and Electric Company
	(Registrant)

Date: February 22, 2023	/s/ Jeffrey M. Keebler
	Chairman, President, and Chief Executive Officer


/s/ Jeffrey M. Keebler	Jeffrey M. Keebler Chairman, President, and Chief Executive Officer and Director (Principal Executive Officer)

/s/ Jared J. Bushek	Jared J. Bushek Vice President - Finance, Chief Information Officer and Treasurer (Chief Financial Officer)

/s/ Tamara J. Johnson	Tamara J. Johnson Vice President - Accounting and Controller (Chief Accounting Officer)
/s/ Marcia M. Anderson	Marcia M. Anderson, Director
/s/ James G. Berbee	James G. Berbee, Director
/s/ Mark D. Bugher	Mark D. Bugher, Director
/s/ Londa J. Dewey	Londa J. Dewey, Director
/s/ James L. Possin	James L. Possin, Director
/s/ Thomas R. Stolper	Thomas R. Stolper, Director
/s/ Gary J. Wolter	Gary J. Wolter, Director
/s/ Noble L. Wray	Noble L. Wray, Director

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