10-Q

United States SECURITIES AND EXCHANGE COMMISSION Washington, D.C. 20549 FORM 10-Q ☒ Quarterly Report Pursuant to Section 13 or 15(d) of the Securities Exchange Act of 1934 For the quarterly period ended: March 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

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 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 check mark if the registrants have elected not to use the extended transition period for complying with any new or revised financial accounting 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 registrants are shell companies (as defined in Rule 12b-2 of the Exchange Act):

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

Securities registered pursuant to Section 12(b) of the Act:

Title of each class	Trading symbol(s)	Name of each exchange on which registered
Common Stock, $1 Par Value Per Share	MGEE	The NASDAQ Stock Market

Number of Shares Outstanding of Each Class of Common Stock as of April 30, 2022
MGE Energy, Inc.	Common stock, $1.00 par value, 36,163,370 shares outstanding.
Madison Gas and Electric Company	Common stock, $1.00 par value, 17,347,894 shares outstanding (all of which are owned beneficially and of record by MGE Energy, Inc.).

1

Table of Contents

PART I. FINANCIAL INFORMATION	3
Filing Format	3
Forward-Looking Statements	3
Where to Find More Information	3
Definitions, Abbreviations, and Acronyms Used in the Text and Notes of this Report	4
Item 1. Financial Statements.	6
MGE Energy, Inc.	6
Consolidated Statements of Income (unaudited)	6
Consolidated Statements of Cash Flows (unaudited)	7
Consolidated Balance Sheets (unaudited)	8
Consolidated Statements of Common Equity (unaudited)	9
Madison Gas and Electric Company	10
Consolidated Statements of Income (unaudited)	10
Consolidated Statements of Cash Flows (unaudited)	11
Consolidated Balance Sheets (unaudited)	12
Consolidated Statements of Equity (unaudited)	13
MGE Energy, Inc., and Madison Gas and Electric Company - Notes to Consolidated Financial Statements (unaudited)	14
1. Summary of Significant Accounting Policies.	14
2. New Accounting Standards.	15
3. Investment in ATC and ATC Holdco.	15
4. Taxes.	16
5. Pension and Other Postretirement Plans.	16
6. Equity and Financing Arrangements.	17
7. Share-Based Compensation.	17
8. Commitments and Contingencies.	18
9. Rate Matters.	21
10. Derivative and Hedging Instruments.	22
11. Fair Value of Financial Instruments.	25
12. Joint Plant Construction Project Ownership.	28
13. Revenue.	29
14. Segment Information.	30
Item 2. Management's Discussion and Analysis of Financial Condition and Results of Operations.	31
Item 3. Quantitative and Qualitative Disclosures About Market Risk.	44
Item 4. Controls and Procedures.	47
PART II. OTHER INFORMATION.	48
Item 1. Legal Proceedings.	48
Item 2. Unregistered Sales of Equity Securities and Use of Proceeds.	48
Item 3. Defaults Upon Senior Securities.	48
Item 4. Mine Safety Disclosures.	48
Item 5. Other Information.	48
Item 6. Exhibits.	49
Signatures - MGE Energy, Inc.	50
Signatures - Madison Gas and Electric Company	51

2

PART I. FINANCIAL INFORMATION.

Filing Format

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

Forward-Looking Statements

This report, and other documents filed by MGE Energy and MGE with the Securities and Exchange Commission (SEC) from time to time, contain forward-looking statements that reflect management's current assumptions and estimates regarding future performance and economic conditions—especially as they relate to economic conditions, future load growth, revenues, expenses, capital expenditures, financial resources, regulatory matters, and the scope and expense associated with future environmental regulation. These forward-looking statements are made pursuant to the provisions of the Private Securities Litigation Reform Act of 1995. Words such as "believe," "expect," "anticipate," "estimate," "could," "should," "intend," "will," and other similar words, 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 the registrants' 2021 Annual Report on Form 10-K: Item 1A. Risk Factors, Item 7. Management's Discussion and Analysis of Financial Condition and Results of Operations, as updated by Part I, Item 2. Management's Discussion and Analysis of Financial Condition and Results of Operations in this report, and Item 8. Financial Statements and Supplementary Data – Note 16, as updated by Part I, Item 1. Financial Statements – Note 8 in this report, and (b) other factors discussed herein and in other filings made by that registrant with the SEC.

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

Where to Find More Information

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.
 

3

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

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

MGE Energy and Subsidiaries:
CWDC	Central Wisconsin Development Corporation
MAGAEL	MAGAEL, LLC
MGE	Madison Gas and Electric Company
MGE Energy	MGE Energy, Inc.
MGE Power	MGE Power, LLC
MGE Power Elm Road	MGE Power Elm Road, LLC
MGE Power West Campus	MGE Power West Campus, LLC
MGE Services	MGE Services, LLC
MGE State Energy Services	MGE State Energy Services, LLC
MGE Transco	MGE Transco Investment, LLC
MGEE Transco	MGEE Transco, LLC
North Mendota	North Mendota Energy & Technology Park, LLC
Other Defined Terms:
2017 Tax Act	Tax Cut and Jobs Act of 2017
2021 Annual Report on Form 10-K	MGE Energy’s and MGE’s Annual Report of Form 10-K for the year ended December 31, 2021
2021 Plan	MGE Energy's 2021 Long-Term Incentive Plan
AFUDC	Allowance for Funds Used During Construction
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
Blount	Blount Station
BTA	Best technology available
CA	Certificate of Authority
CBP	United States Customs and Border Protection
CCR	Coal Combustion Residual
Columbia	Columbia Energy Center
COVID-19	Coronavirus Disease 2019
CSAPR	Cross-State Air Pollution Rule
Dth	Dekatherms, a quantity measure for natural gas
EGU	Electric generating unit
ELG	Effluent Limitations Guidelines
electric margin	Electric revenues less fuel for electric generation and purchased power costs, a non-GAAP measure
Elm Road Units	Elm Road Generating Station
EPA	United States Environmental Protection Agency
FERC	Federal Energy Regulatory Commission
FIP	Federal Implementation Plan
FTR	Financial Transmission Rights
GAAP	Generally Accepted Accounting Principles
gas margin	Gas revenues less cost of gas sold, a non-GAAP measure
GHG	Greenhouse gas
heating degree days (HDD)	Measure of the extent to which the average daily temperature is below 65 degrees Fahrenheit, which is considered an indicator of possible increased demand for energy to provide heating
IRS	Internal Revenue Service
kWh	Kilowatt-hour, a measure of electric energy produced
MISO	Midcontinent Independent System Operator (a regional transmission organization)
MW	Megawatt, a measure of electric energy generating capacity
MWh	Megawatt-hour, a measure of electric energy produced
NAAQS	National Ambient Air Quality Standards
NOx	Nitrogen oxide
PGA	Purchased Gas Adjustment clause, a regulatory mechanism used to reconcile natural gas costs recovered in rates to actual costs
PPA	Purchased Power Agreement

4

PSCW	Public Service Commission of Wisconsin
ROE	Return on equity
Saratoga	Saratoga Wind Farm
SCR	Selective Catalytic Reduction
SEC	Securities and Exchange Commission
SIP	State Implementation Plan
SO2	Sulfur dioxide
Stock Plan	Direct Stock Purchase and Dividend Reinvestment Plan of MGE Energy
Two Creeks	Two Creeks Solar Farm
WCCF	West Campus Cogeneration Facility
WDNR	Wisconsin Department of Natural Resources
WEPCO	Wisconsin Electric Power Company
West Riverside	West Riverside Energy Center in Beloit, Wisconsin
working capital	Current assets less current liabilities
WPL	Wisconsin Power and Light Company, a subsidiary of Alliant Energy Corporation
WRO	Withhold Release Order
XBRL	eXtensible Business Reporting Language

5

Item 1. Financial Statements.

MGE Energy, Inc.

Consolidated Statements of Income (unaudited)

(In thousands, except per share amounts)

	Three Months Ended
	March 31,
	2022			2021
Operating Revenues:
Electric revenues	$	110,127		$	100,645
Gas revenues		98,811			67,270
Total Operating Revenues		208,938			167,915
Operating Expenses:
Fuel for electric generation		13,485			13,171
Purchased power		12,543			9,355
Cost of gas sold		64,802			37,444
Other operations and maintenance		49,994			45,682
Depreciation and amortization		21,046			18,382
Other general taxes		5,205			4,827
Total Operating Expenses		167,075			128,861
Operating Income		41,863			39,054
Other income, net		6,972			2,078
Interest expense, net		(6,571	)		(5,740	)
Income before income taxes		42,264			35,392
Income tax provision		(7,844	)		(459	)
Net Income	$	34,420		$	34,933
Earnings Per Share of Common Stock
Basic	$	0.95		$	0.97
Diluted	$	0.95		$	0.97
Dividends per share of common stock	$	0.388		$	0.370
Weighted Average Shares Outstanding
Basic		36,163			36,163
Diluted		36,171			36,165

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

6

MGE Energy, Inc.

Consolidated Statements of Cash Flows (unaudited)

(In thousands)

	Three Months Ended
	March 31,
	2022			2021
Operating Activities:
Net income	$	34,420		$	34,933
Items not affecting cash:
Depreciation and amortization		21,046			18,382
Deferred income taxes		5,606			(796	)
Provision for doubtful receivables		441			388
Employee benefit plan cost (credit)		(1,678	)		1,461
Equity earnings in investments		(2,504	)		(2,444	)
Other items		(486	)		(277	)
Changes in working capital items:
Decrease (increase) in current assets		12,332			(2,851	)
Decrease in current liabilities		(7,115	)		(4,213	)
Dividends from investments		2,001			1,967
Cash contributions to pension and other postretirement plans		(1,660	)		(1,552	)
Other noncurrent items, net		(304	)		(1,115	)
Cash Provided by Operating Activities		62,099			43,883
Investing Activities:
Capital expenditures		(30,778	)		(34,746	)
Capital contributions to investments		(1,546	)		(670	)
Other		155			(419	)
Cash Used for Investing Activities		(32,169	)		(35,835	)
Financing Activities:
Cash dividends paid on common stock		(14,013	)		(13,380	)
Repayments of long-term debt		(1,211	)		(1,182	)
(Repayments of) proceeds from short-term debt		(5,500	)		1,500
Other		(492	)		(523	)
Cash Used for Financing Activities		(21,216	)		(13,585	)
Change in cash, cash equivalents, and restricted cash		8,714			(5,537	)
Cash, cash equivalents, and restricted cash at beginning of period		18,835			47,039
Cash, cash equivalents, and restricted cash at end of period	$	27,549		$	41,502
Supplemental disclosures of cash flow information:
Significant noncash investing activities:
Accrued capital expenditures	$	6,735		$	8,843

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

7

MGE Energy, Inc.

Consolidated Balance Sheets (unaudited)

(In thousands)

	March 31,		December 31,
ASSETS	2022		2021
Current Assets:
Cash and cash equivalents	$	26,374	$	17,438
Accounts receivable, less reserves of $8,952 and $6,940, respectively		50,167		46,205
Other accounts receivable, less reserves of $1,213 and $1,364, respectively		15,244		16,094
Unbilled revenues		30,839		34,812
Materials and supplies, at average cost		30,951		29,863
Fuel for electric generation, at average cost		6,331		6,429
Stored natural gas, at average cost		5,580		15,668
Prepaid taxes		15,487		20,214
Regulatory assets - current		2,205		1,465
Other current assets		11,255		11,183
Total Current Assets		194,433		199,371
Other long-term receivables		691		1,155
Regulatory assets		108,271		107,547
Pension benefit asset		62,806		58,757
Other deferred assets and other		26,697		27,548
Property, Plant, and Equipment:
Property, plant, and equipment, net		1,843,122		1,828,171
Construction work in progress		40,156		50,603
Total Property, Plant, and Equipment		1,883,278		1,878,774
Investments		101,365		98,754
Total Assets	$	2,377,541	$	2,371,906
LIABILITIES AND CAPITALIZATION
Current Liabilities:
Long-term debt due within one year	$	4,920	$	4,889
Short-term debt		—		5,500
Accounts payable		44,690		64,149
Accrued interest and taxes		9,265		10,385
Accrued payroll related items		9,296		12,951
Regulatory liabilities - current		24,557		9,365
Derivative liabilities		130		2,140
Other current liabilities		5,246		8,468
Total Current Liabilities		98,104		117,847
Other Credits:
Deferred income taxes		233,146		231,149
Investment tax credit - deferred		48,773		44,836
Regulatory liabilities		155,096		154,298
Accrued pension and other postretirement benefits		72,881		73,085
Finance lease liabilities		16,920		17,322
Other deferred liabilities and other		91,363		91,690
Total Other Credits		618,179		612,380
Capitalization:
Common shareholders' equity		1,048,153		1,027,468
Long-term debt		613,105		614,211
Total Capitalization		1,661,258		1,641,679
Commitments and contingencies (see Footnote 8)
Total Liabilities and Capitalization	$	2,377,541	$	2,371,906

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

8

MGE Energy, Inc.

Consolidated Statements of Common Equity (unaudited)

(In thousands, except per share amounts)

										Accumulated
					Additional					Other
	Common Stock				Paid-in		Retained			Comprehensive
	Shares		Value		Capital		Earnings			Income/(Loss)		Total
Three Months Ended March 31, 2021
Beginning Balance		36,163	$	36,163	$	394,408	$	545,429		$	—	$	976,000
Net income								34,933					34,933
Common stock dividends declared    ($0.370 per share)								(13,380	)				(13,380	)
Equity-based compensation plans and other						158							158
Ending Balance - March 31, 2021		36,163	$	36,163	$	394,566	$	566,982		$	—	$	997,711
Three Months Ended March 31, 2022
Beginning Balance		36,163	$	36,163	$	394,903	$	596,402		$	—	$	1,027,468
Net income								34,420					34,420
Common stock dividends declared    ($0.388 per share)								(14,013	)				(14,013	)
Equity-based compensation plans and other						278							278
Ending Balance - March 31, 2022		36,163	$	36,163	$	395,181	$	616,809		$	—	$	1,048,153

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

9

Madison Gas and Electric Company

Consolidated Statements of Income (unaudited)

(In thousands)

	Three Months Ended
	March 31,
	2022			2021
Operating Revenues:
Electric revenues	$	110,127		$	100,645
Gas revenues		98,811			67,270
Total Operating Revenues		208,938			167,915
Operating Expenses:
Fuel for electric generation		13,485			13,171
Purchased power		12,543			9,355
Cost of gas sold		64,802			37,444
Other operations and maintenance		49,746			45,538
Depreciation and amortization		21,046			18,382
Other general taxes		5,205			4,827
Total Operating Expenses		166,827			128,717
Operating Income		42,111			39,198
Other income (expense), net		3,519			(104	)
Interest expense, net		(6,577	)		(5,753	)
Income before income taxes		39,053			33,341
Income tax (provision) benefit		(7,000	)		433
Net Income	$	32,053		$	33,774
Less: Net Income Attributable to Noncontrolling Interest, net of tax		(4,756	)		(5,501	)
Net Income Attributable to MGE	$	27,297		$	28,273

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

10

Madison Gas and Electric Company

Consolidated Statements of Cash Flows (unaudited)

(In thousands)

	Three Months Ended
	March 31,
	2022			2021
Operating Activities:
Net income	$	32,053		$	33,774
Items not affecting cash:
Depreciation and amortization		21,046			18,382
Deferred income taxes		5,230			(1,766	)
Provision for doubtful receivables		441			388
Employee benefit plan cost (credit)		(1,678	)		1,461
Other items		587			(252	)
Changes in working capital items:
Decrease (increase) in current assets		11,810			(3,037	)
Decrease in current liabilities		(4,648	)		(4,037	)
Cash contributions to pension and other postretirement plans		(1,660	)		(1,552	)
Other noncurrent items, net		(500	)		(1,380	)
Cash Provided by Operating Activities		62,681			41,981
Investing Activities:
Capital expenditures		(30,778	)		(34,746	)
Other		(164	)		(462	)
Cash Used for Investing Activities		(30,942	)		(35,208	)
Financing Activities:
Cash dividends paid to parent by MGE		(5,000	)		—
Distributions to parent from noncontrolling interest		(9,000	)		(5,000	)
Repayments of long-term debt		(1,211	)		(1,182	)
(Repayments of) proceeds from short-term debt		(5,500	)		1,500
Other		(492	)		(523	)
Cash Used for Financing Activities		(21,203	)		(5,205	)
Change in cash, cash equivalents, and restricted cash		10,536			1,568
Cash, cash equivalents, and restricted cash at beginning of period		7,798			6,404
Cash, cash equivalents, and restricted cash at end of period	$	18,334		$	7,972
Supplemental disclosures of cash flow information:
Significant noncash investing activities:
Accrued capital expenditures	$	6,735		$	8,843

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

11

Madison Gas and Electric Company

Consolidated Balance Sheets (unaudited)

(In thousands)

	March 31,		December 31,
ASSETS	2022		2021
Current Assets:
Cash and cash equivalents	$	17,159	$	6,401
Accounts receivable, less reserves of $8,952 and $6,940, respectively		50,167		46,205
Affiliate receivables		530		558
Other accounts receivable, less reserves of $1,213 and $1,364, respectively		15,242		16,092
Unbilled revenues		30,839		34,812
Materials and supplies, at average cost		30,951		29,863
Fuel for electric generation, at average cost		6,331		6,429
Stored natural gas, at average cost		5,580		15,668
Prepaid taxes		15,193		19,379
Regulatory assets - current		2,205		1,465
Other current assets		11,152		11,071
Total Current Assets		185,349		187,943
Affiliate receivable long-term		1,456		1,589
Regulatory assets		108,271		107,547
Pension benefit asset		62,806		58,757
Other deferred assets and other		26,806		27,907
Property, Plant, and Equipment:
Property, plant, and equipment, net		1,843,150		1,828,199
Construction work in progress		40,156		50,603
Total Property, Plant, and Equipment		1,883,306		1,878,802
Investments		177		230
Total Assets	$	2,268,171	$	2,262,775
LIABILITIES AND CAPITALIZATION
Current Liabilities:
Long-term debt due within one year	$	4,920	$	4,889
Short-term debt		—		5,500
Accounts payable		44,672		64,130
Accrued interest and taxes		9,417		10,649
Accrued payroll related items		9,296		12,951
Regulatory liabilities - current		24,557		9,365
Derivative liabilities		130		2,140
Other current liabilities		5,324		5,968
Total Current Liabilities		98,316		115,592
Other Credits:
Deferred income taxes		200,507		198,885
Investment tax credit - deferred		48,773		44,836
Regulatory liabilities		155,096		154,298
Accrued pension and other postretirement benefits		72,881		73,085
Finance lease liabilities		16,920		17,322
Other deferred liabilities and other		92,126		92,152
Total Other Credits		586,303		580,578
Capitalization:
Common shareholder's equity		826,104		803,807
Noncontrolling interest		144,343		148,587
Total Equity		970,447		952,394
Long-term debt		613,105		614,211
Total Capitalization		1,583,552		1,566,605
Commitments and contingencies (see Footnote 8)
Total Liabilities and Capitalization	$	2,268,171	$	2,262,775

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

12

Madison Gas and Electric Company

Consolidated Statements of Equity (unaudited)

(In thousands)

										Accumulated
					Additional					Other		Non-
	Common Stock				Paid-in		Retained			Comprehensive		Controlling
	Shares		Value		Capital		Earnings			Income/(Loss)		Interest			Total
Three Months Ended March 31, 2021
Beginning balance		17,348	$	17,348	$	252,917	$	460,151		$	—	$	141,196		$	871,612
Net income								28,273					5,501			33,774
Distributions to parent from    noncontrolling interest													(5,000	)		(5,000	)
Ending Balance - March 31, 2021		17,348	$	17,348	$	252,917	$	488,424		$	—	$	141,697		$	900,386
Three Months Ended March 31, 2022
Beginning balance		17,348	$	17,348	$	252,917	$	533,542		$	—	$	148,587		$	952,394
Net income								27,297					4,756			32,053
Cash dividends paid to parent by MGE								(5,000	)							(5,000	)
Distributions to parent from    noncontrolling interest													(9,000	)		(9,000	)
Ending Balance - March 31, 2022		17,348	$	17,348	$	252,917	$	555,839		$	—	$	144,343		$	970,447

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

13

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

Notes to Consolidated Financial Statements (unaudited)

March 31, 2022

1.Summary of Significant Accounting Policies – MGE Energy and MGE.

a.Basis of Presentation.

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

MGE Power Elm Road and MGE Power West Campus own electric generating assets and lease those assets to MGE. Both entities are variable interest entities under applicable authoritative accounting guidance. MGE is considered the primary beneficiary of these entities as a result of contractual agreements. As a result, MGE has consolidated MGE Power Elm Road and MGE Power West Campus. See Footnote 3 of Notes to Consolidated Financial Statements under Item 8, Financial Statements and Supplementary Data, of MGE Energy's and MGE's 2021 Annual Report on Form 10-K (the 2021 Annual Report on Form 10-K).

The accompanying consolidated financial statements as of March 31, 2022, and during the three months ended March 31, 2022, are unaudited but include all adjustments that MGE Energy and MGE management consider necessary for a fair statement of their respective financial statements. All adjustments are of a normal, recurring nature except as otherwise disclosed. The year-end consolidated balance sheet information was derived from the audited balance sheet appearing in the 2021 Annual Report on Form 10-K but does not include all disclosures required by accounting principles generally accepted in the United States of America. These notes should be read in conjunction with the financial statements and the notes on pages 61 through 115 of the 2021 Annual Report on Form 10-K.

b.Cash, Cash Equivalents, and Restricted Cash.

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

	MGE Energy				MGE
	March 31,		December 31,		March 31,		December 31,
(In thousands)	2022		2021		2022		2021
Cash and cash equivalents	$	26,374	$	17,438	$	17,159	$	6,401
Restricted cash		641		847		641		847
Receivable - margin account		534		550		534		550
Cash, cash equivalents, and restricted cash	$	27,549	$	18,835	$	18,334	$	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.

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c.Property, Plant, and Equipment.

Columbia.

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 by the end of 2023 and Unit 2 by the end of 2024. Final timing and retirement dates are subject to change depending on operational, regulatory, and other factors. As of March 31, 2022, early retirement of Columbia was probable.

The net book value of our ownership share of this generating unit was $156.7 million as of March 31, 2022. This amount was classified as plant to be retired within "Property, plant, and equipment, net" on the consolidated balance sheets. 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 and 2038 for Unit 2. MGE is currently seeking approval from the PSCW in its 2023 electric 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 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. No impairment was recorded as of March 31, 2022.

2.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 their consolidated results of operations, financial condition, or cash flows.

3.Investment in ATC and ATC Holdco - MGE Energy and MGE.

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

MGE Transco and MGEE Transco have accounted for their investments 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. MGE Transco recorded the following amounts related to its investment in ATC:

	Three Months Ended
	March 31,
(In thousands)	2022		2021
Equity earnings from investment in ATC	$	2,478	$	2,420
Dividends received from ATC		2,001		1,967
Capital contributions to ATC		1,243		—

ATC Holdco was formed in December 2016. ATC Holdco's transmission development activities have been suspended for the near term.

In April 2022, MGE Transco made a $0.5 million capital contribution to ATC.

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ATC's summarized financial data is as follows:

	Three Months Ended
	March 31,
(In thousands)	2022			2021
Operating revenues	$	190,999		$	188,694
Operating expenses		(95,491	)		(95,104	)
Other income, net		404			378
Interest expense, net		(28,440	)		(28,871	)
Earnings before members' income taxes	$	67,472		$	65,097

MGE receives transmission and other related services from ATC. During the three months ended March 31, 2022 and 2021, MGE recorded $7.9 million and $8.0 million, respectively, for transmission services. MGE also provides a variety of operational, maintenance, and project management work for ATC, which is reimbursed by ATC. As of March 31, 2022, and December 31, 2021, MGE had a receivable due from ATC of $8.1 million and $7.0 million, respectively. The receivable is primarily related to Badger Hollow I and II. MGE is reimbursed for these costs after the new generation assets are placed into service.

4.Taxes - MGE Energy and MGE.

Effective Tax Rate.

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
Three Months Ended March 31,	2022				2021				2022				2021
Statutory federal income tax rate		21.0		%		21.0		%		21.0		%		21.0		%
State income taxes, net of federal benefit		6.3				6.3				6.3				6.3
Amortized investment tax credits		(0.7	)			(1.6	)			(0.8	)			(1.8	)
Credit for electricity from wind energy		(5.4	)			(7.1	)			(6.0	)			(7.8	)
AFUDC equity, net		(0.5	)			(0.6	)			(0.5	)			(0.6	)
Amortization of utility excess deferred tax - tax reform(a)		(1.9	)			(16.7	)			(1.8	)			(18.3	)
Other, net, individually insignificant		(0.2	)			—				(0.3	)			(0.1	)
Effective income tax rate		18.6		%		1.3		%		17.9		%		(1.3	)	%

(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 three months ended March 31, 2022 and 2021, MGE recognized $1.0 million and $0.7 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 three months ended March 31, 2021, MGE recognized $3.3 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 three months ended March 31, 2022, MGE recognized $0.3 million.

5.Pension and Other Postretirement Plans - 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.

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.

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The following table presents the components of net periodic benefit costs recognized.

	Three Months Ended
	March 31,
(In thousands)	2022			2021
Pension Benefits
Components of net periodic benefit cost:
Service cost	$	1,337		$	1,422
Interest cost		2,796			2,272
Expected return on assets		(7,851	)		(7,375	)
Amortization of:
Prior service credit		(5	)		(31	)
Actuarial loss		724			1,580
Net periodic benefit (credit) cost	$	(2,999	)	$	(2,132	)
Postretirement Benefits
Components of net periodic benefit cost:
Service cost	$	333		$	351
Interest cost		491			384
Expected return on assets		(843	)		(817	)
Amortization of:
Transition obligation		1			1
Prior service credit		(74	)		(380	)
Actuarial loss		48			109
Net periodic benefit (credit) cost	$	(44	)	$	(352	)

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. During the three months ended March 31, 2022 and 2021, MGE recovered $0.3 million and $3.4 million of pension and other postretirement costs, respectively. The recovery of these costs reduced the amount previously deferred and has not been reflected in the table above.

During the three months ended March 31, 2022, MGE returned $1.0 million of savings from 2021 employee benefit plan costs. The deferred savings has not been reflected in the table above.

6.Equity and Financing Arrangements.

a.Common Stock - MGE Energy.

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. All sales under the Stock Plan are covered by a shelf registration statement that MGE Energy filed with the SEC. During the three months ended March 31, 2022 and 2021, MGE Energy issued no new shares of common stock under the Stock Plan.

b.Dilutive Shares Calculation - MGE Energy.

As of March 31, 2022, 7,492 shares were included in the calculation of diluted earnings per share related to nonvested equity awards. See Footnote 7 for additional information on share-based compensation awards.

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

During the three months ended March 31, 2022 and 2021, MGE recorded $0.4 million and $0.7 million, respectively, in compensation expense 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 Long-Term Incentive Plan (2021 Plan).

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In January 2022, cash payments of $1.8 million were distributed related to awards that were granted in 2019, for the 2013 Director Incentive Plan, and in 2017, for the 2006 Performance Unit Plan.

In February 2022, MGE issued 10,395 performance units and 15,931 restricted stock units under the 2021 Plan to eligible employees and non-employee directors.

MGE recognizes stock-based compensation expense 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. The performance units can be paid out in either cash, shares of common stock or a combination of cash and stock and are classified as a liability award. The restricted stock units will be paid out in shares of common stock, and therefore are classified as equity awards.

8.Commitments and Contingencies.

a.Environmental - MGE Energy and MGE.

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 by the end of 2023 and Unit 2 by the end of 2024. Final timing and retirement dates are subject to change depending on operational, regulatory, and other factors. Effects of environmental compliance requirements discussed below will depend upon the final retirement dates approved and compliance requirement dates.

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 operations are conducted, the costs of operations, as well as capital and operating expenditures. Several of these environmental rules are subject to legal challenges, reconsideration and/or other uncertainties. Regulatory initiatives, proposed rules, and court challenges to adopted rules could have a material effect on capital expenditures and operating costs. Management believes compliance costs will be recovered in future rates based on previous treatment of environmental compliance projects.

These initiatives, proposed rules, and court challenges include:

•The EPA's 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.

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 estimated costs to comply with the rule is estimated to be approximately $4 million. Construction began in March 2022.

•The EPA's cooling water intake rules require cooling water intake structures at electric power plants to meet best technology available (BTA) standards to reduce the mortality from entrainment (drawing aquatic life into a plant's cooling system) and impingement (trapping aquatic life on screens).

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

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make the final BTA determination and include any BTA requirements in Blount's next permit renewal, which is expected to be completed by the end of 2022 and effective in 2023. Management believes that the BTA determination at Blount will not be material for MGE.

Columbia's river intakes are subject to this rule. BTA improvements may not be required given that the owners are planning to retire both units by the end of 2024. MGE will continue to work with Columbia's operator to evaluate all regulatory requirements applicable to the planned retirements. MGE does not expect this rule to have a material effect on its existing plants.

•Greenhouse Gas (GHG) reduction guidelines and approval criteria established under the Clean Air Act for states to use in developing plans to control GHG emissions from fossil fuel-fired electric generating units (EGUs), including existing and proposed regulations governing existing, new or modified fossil-fuel generating units.

In October 2021, as part of the Biden administration's Unified Agenda, the EPA announced their intention to introduce a new set of emission guidelines for states to follow in submitting state plans to establish and implement standards of performance for greenhouse gas emissions from existing fossil fuel-fired EGUs. In late 2021, the US Supreme Court agreed to hear arguments regarding the extent of EPA's authority to regulate greenhouse gases from electric generation units under the Clean Air Act. MGE will continue to evaluate greenhouse gas rule developments, including any further Supreme Court decisions on the EPA's authority to regulate greenhouse gases.

•The EPA's rule to regulate ambient levels of ozone through the 2015 Ozone National Ambient Air Quality Standards (NAAQS).

The Elm Road Units are located in Milwaukee County, Wisconsin, a nonattainment area. The Wisconsin Department of Natural Resources (WDNR) must develop a State Implementation Plan (SIP) for the area, which will likely result in more stringent requirements for both constructing new development and modifying or expanding existing plants in the area. 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, MGE does not expect that the 2015 Ozone NAAQS will have a material effect on its existing plants based on final designations.

•Rules regulating nitrogen oxide (NOx) and sulfur dioxide (SO2) emissions, including the Cross State Air Pollution Rule (CSAPR) and Clean Air Visibility Rule.

The EPA's CSAPR and its progeny are a suite of interstate air pollution transport rules designed to reduce ozone and fine particulate (PM2.5) 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 generally 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.

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Wisconsin would need to submit a State Implementation Plan (SIP) to meet its obligations or accept the EPA's proposed FIP.

MGE is currently evaluating the proposed rule to determine potential impacts to our business. 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.

MGE has met its current CSAPR obligations through a combination of reduced emissions through pollution control (e.g., SCR installation at Columbia), and owned, received, and purchased allowances. MGE expects to meet ongoing CSAPR obligations for the foreseeable future.

•The EPA's Coal Combustion Residuals Rule (CCR), which 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. Columbia requested an extension to initiate closure by October 2022. The EPA has not formally approved the extension. The Columbia owners anticipate that the EPA will approve the extension request. However, we will not know the outcome of the extension request with any certainty until the EPA makes a final decision on this request. In the interim, the EPA determined that the extension demonstration is complete and confirmed that the deadline to cease placement of CCR and non-CCR wastewaters in the primary pond is tolled pending a final decision.

Review of the Elm Road Units has indicated that the costs to comply with the CCR rule are not expected to be significant. 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. Pending the EPA’s final approval of closure plans at Columbia, MGE's share of the estimated costs of the project will be approximately $4 million. Construction is expected to be completed by the end of 2022.

b.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 accrues for 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 filed petitions against the PSCW regarding MGE's two most recent rate settlements. MGE has intervened in the petitions in cooperation with the PSCW. See Footnote 9.a. for more information regarding this matter.

c.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. The following table shows future commitments related to purchase contracts as of March 31, 2022:

(In thousands)	2022		2023		2024		2025		2026		Thereafter
Coal(a)	$	17,825	$	14,023	$	8,299	$	2,862	$	—	$	—

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

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9.Rate Matters - MGE Energy and MGE.

a.Rate Proceedings.

In April 2022, MGE filed with the PSCW a proposed electric limited 2023 rate case reopener. The limited reopener proposes a 4.38% increase for electric rates in 2023. 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 a reduction in fuel costs, which MGE has partially offset with 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. PSCW approval of the 2023 limited reopener is pending. A final order is expected before the end of the year.

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 for gas rates in 2022. 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. As part of the settlement agreement, for 2023, the PSCW approved a 0.96% increase in gas rates and to address a potential electric rate change through a limited rate case reopener. The return on common stock equity for 2022 and 2023 is 9.8% based on a capital structure consisting of 55.6% common equity.

In December 2020, the PSCW approved a settlement agreement for MGE's 2021 rate case. The settlement agreement provided for a zero percent increase for electric rates and an approximately 4% increase for gas rates in 2021. 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. As part of the settlement, the fuel rules bandwidth was set at plus or minus 1% for 2021. When compared to the 2020 rate case, the settlement included lower forecasted electric sales for 2021 to reflect changes to customer usage during the COVID-19 pandemic. 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. The return on common stock equity for 2021 was 9.8% based on a capital structure of 55.8% common equity in 2021.

Sierra Club and Vote Solar have filed petitions with the Dane County Circuit Court seeking review of the PSCW decision approving MGE's two most recent rate settlements (2021 and 2022/2023). The PSCW is named as the responding party; MGE is not named as a party. The petitions challenge the process the PSCW used to approve the portion of the settlements relating to electric rates and the electric customer fixed charge that does not vary with usage. The requested relief is unclear. The revenue requirement approved by the PSCW in the settlements have not been challenged. The PSCW is expected to vigorously defend its approval of the rate case settlements. MGE has intervened in the proceedings to further defend the PSCW's decision.

b.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%. Under fuel rules, MGE defers costs, less any excess revenues, if its actual electric fuel costs exceed 101% of the electric fuel costs allowed in its latest rate order. Excess revenues are defined as revenues in the year in question that provide MGE with a greater return on common equity than authorized by the PSCW in MGE's latest rate order. Conversely, MGE is required to defer the benefit of lower costs if actual electric

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fuel costs were less than 99% of the electric fuel costs allowed in that order. These costs are subject to the PSCW's annual review of fuel costs completed in the year following the deferral.

The PSCW issued a final decision in the 2019 fuel rules proceedings regarding $1.5 million of deferred savings giving MGE the option either to use the $1.5 million as part of the settlement to MGE's 2021 rate case or to refund the balance to customers in October 2020. MGE elected to include the savings as part of the 2021 rate change settlement as described above, reducing electric retail rates as opposed to a one-time credit back to retail customers. There was no change to the refund in the fuel rules proceedings from the amount MGE deferred in the previous year.

In September 2021, the PSCW issued a final decision in the 2020 fuel rules proceedings for MGE to refund $3.2 million of additional fuel savings realized during 2020 plus accrued interest to its retail electric customers over a one-month period in October 2021. There was no change to the refund in the fuel rules proceedings from the amount MGE deferred in the previous year.

MGE has under recovered fuel costs in 2021. As of December 31, 2021, MGE had deferred $3.3 million of 2021 fuel costs. These costs will be subject to the PSCW's annual review of 2021 fuel costs, expected to be completed in 2022. MGE has proposed to include these costs as part of the 2023 electric limited reopener.

As of March 31, 2022, MGE had no deferred 2022 fuel savings or costs.

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

a.Purpose.

As part of its regular operations, MGE enters into contracts, including options, swaps, futures, forwards, and other contractual commitments, to manage its exposure to commodity prices. To the extent that these contracts are derivatives, MGE assesses whether or not the normal purchases or normal sales exclusion applies. For contracts to which this exclusion cannot be applied, 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.

b.Notional Amounts.

The gross notional volume of open derivatives is as follows:

	March 31, 2022			December 31, 2021
Commodity derivative contracts		369,960	MWh		278,000	MWh
Commodity derivative contracts		3,260,000	Dth		5,735,000	Dth
FTRs		858	MW		2,127	MW
PPA		100	MW		250	MW

c.Financial Statement Presentation.

MGE purchases and sells exchange-traded and over-the-counter options, swaps, and future contracts. These arrangements are primarily entered into to help stabilize the price risk associated with gas or power purchases. These transactions are employed by both MGE's gas and electric segments. Additionally, as a result of the firm transmission agreements that MGE holds on electricity transmission paths in the MISO market, MGE holds 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

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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 March 31, 2022, and December 31, 2021, the fair value of exchange traded derivatives and FTRs exceeded their cost basis by $9.8 million and $2.8 million, respectively.

MGE is a party to a purchased power agreement that provides MGE with firm capacity and energy during a base term from June 1, 2012, through May 31, 2022. The agreement is accounted for as a derivative contract and is recognized at its fair value on the consolidated balance sheets. However, the derivative qualifies for regulatory deferral and is recognized with a corresponding regulatory asset or liability depending on whether the fair value is in a loss or gain position. The fair value of the contract as of March 31, 2022, and December 31, 2021, reflected a loss position of $0.1 million and $2.1 million, respectively. The actual cost will be recognized in purchased power expense in the month of purchase.

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

	Derivative		Derivative
(In thousands)	Assets		Liabilities		Balance Sheet Location
March 31, 2022
Commodity derivative contracts(a)	$	9,518	$	325	Other current assets
Commodity derivative contracts(a)		626		32	Other deferred charges
FTRs(a)		—		16	Derivative liability (current)
PPA	N/A			130	Derivative liability (current)
December 31, 2021
Commodity derivative contracts(a)	$	2,959	$	811	Other current assets
Commodity derivative contracts(a)		420		38	Other deferred charges
FTRs		227		—	Other current assets
PPA	N/A			2,140	Derivative liability (current)

(a)As of March 31, 2022 and December 31, 2021, MGE received collateral of $6.9 million and $1.3 million, respectively, 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
March 31, 2022
Commodity derivative contracts	$	10,144	$	(357	)	$	(6,911	)	$	2,876
December 31, 2021
Commodity derivative contracts	$	3,379	$	(849	)	$	(1,254	)	$	1,276
FTRs		227		—			—			227

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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
March 31, 2022
Commodity derivative contracts	$	357	$	(357	)	$	—		$	—
FTRs		16		—			(16	)		—
PPA		130		—			—			130
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
(In thousands)	Current and Long-Term Regulatory Asset (Liability)			Other Current Assets			Current and Long-Term Regulatory Asset (Liability)			Other Current Assets
Three Months Ended March 31:
Balance as of January 1,	$	(617	)	$	770		$	13,989		$	1,162
Unrealized gain		(11,333	)		—			(3,588	)		—
Realized gain (loss) reclassified to a deferred account		1,279			(1,279	)		(50	)		50
Realized gain (loss) reclassified to income statement		1,030			776			708			(1,039	)
Balance as of March 31,	$	(9,641	)	$	267		$	11,059		$	173

	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
Three Months Ended March 31:
Commodity derivative contracts	$	(312	)	$	(881	)	$	(195	)	$	1,022
FTRs		3			—			(256	)		—
PPA		(616	)		—			(240	)		—

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.

The PPA has a provision that may require MGE to post collateral if MGE's debt rating falls below investment grade (i.e., below BBB-). The amount of collateral that it may be required to post varies from $20.0 million to $40.0 million, depending on MGE's nominated capacity amount. As of March 31, 2022, no collateral was required to be, or had been, posted. Certain counterparties extend MGE a credit limit. If MGE exceeds these limits, the counterparties may require collateral to be posted. As of March 31, 2022 and December 31, 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 March 31, 2022, no counterparties had defaulted.

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

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

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

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

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

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

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:

	March 31, 2022				December 31, 2021
(In thousands)	Carrying Amount		Fair Value		Carrying Amount		Fair Value
Long-term debt(a)		622,238		643,259		623,449		729,914

(a)Includes long-term debt due within one year. Excludes debt issuance costs and unamortized discount of $4.2 million and $4.3 million as of March 31, 2022, and December 31, 2021, respectively.

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b.Recurring Fair Value Measurements.

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

	Fair Value as of March 31, 2022
(In thousands)	Total		Level 1		Level 2		Level 3
MGE Energy
Assets:
Derivatives, net(b)	$	10,144	$	3,183	$	—	$	6,961
Exchange-traded investments		1,443		1,443		—		—
Total Assets	$	11,587	$	4,626	$	—	$	6,961
Liabilities:
Derivatives, net(b)	$	503	$	321	$	—	$	182
Deferred compensation		3,613		—		3,613		—
Total Liabilities	$	4,116	$	321	$	3,613	$	182
MGE
Assets:
Derivatives, net(b)	$	10,144	$	3,183	$	—	$	6,961
Exchange-traded investments		177		177		—		—
Total Assets	$	10,321	$	3,360	$	—	$	6,961
Liabilities:
Derivatives, net(b)	$	503	$	321	$	—	$	182
Deferred compensation		3,613		—		3,613		—
Total Liabilities	$	4,116	$	321	$	3,613	$	182

	Fair Value as of December 31, 2021
(In thousands)	Total		Level 1		Level 2		Level 3
MGE Energy
Assets:
Derivatives, net(b)	$	3,606	$	1,170	$	—	$	2,436
Exchange-traded investments		1,296		1,296		—		—
Total Assets	$	4,902	$	2,466	$	—	$	2,436
Liabilities:
Derivatives, net(b)	$	2,989	$	731	$	—	$	2,258
Deferred compensation		3,653		—		3,653		—
Total Liabilities	$	6,642	$	731	$	3,653	$	2,258
MGE
Assets:
Derivatives, net(b)	$	3,606	$	1,170	$	—	$	2,436
Exchange-traded investments		230		230		—		—
Total Assets	$	3,836	$	1,400	$	—	$	2,436
Liabilities:
Derivatives, net(b)	$	2,989	$	731	$	—	$	2,258
Deferred compensation		3,653		—		3,653		—
Total Liabilities	$	6,642	$	731	$	3,653	$	2,258

(b)As of March 31, 2022 and December 31, 2021 MGE received collateral of $6.9 million and $1.3 million, respectively, 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.

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

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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 (see Footnote 10) was valued using an internal pricing model and therefore is classified as Level 3. The model projects future market energy prices and compares those prices to the projected power costs to be incurred under the contract. Inputs to the model require significant management judgment and estimation. Future energy prices are based on a forward power pricing curve using exchange-traded contracts in the electric futures market. A basis adjustment is applied to the market energy price to reflect the price differential between the market price delivery point and the counterparty delivery point. The historical relationship between the delivery points is reviewed and a discount (below 100%) or premium (above 100%) is derived. This comparison is done for both peak times when demand is high and off-peak times when demand is low. If the basis adjustment is lowered, the fair value measurement will decrease, and if the basis adjustment is increased, the fair value measurement will increase.

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

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

	Model Input
	March 31,	December 31,
Significant Unobservable Inputs	2022	2021
Basis adjustment:
On peak	92.1%	94.1%
Off peak	90.0%	92.4%
Counterparty fuel mix:
Internal generation - range	41%-66%	41%-66%
Internal generation - weighted average	49.5%	56.6%
Purchased power - range	59%-34%	59%-34%
Purchased power - weighted average	50.5%	43.4%

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The following table summarizes the changes in Level 3 commodity derivative assets and liabilities measured at fair value on a recurring basis.

	Three Months Ended
	March 31,
(In thousands)	2022		2021
Beginning balance	$	178	$	(14,055)
Realized and unrealized gains (losses):
Included in regulatory assets		—		2,688
Included in regulatory liability		6,600		—
Included in other comprehensive income		—		—
Included in earnings		855		307
Included in current assets		73		355
Purchases		7,026		5,884
Sales		—		—
Issuances		—		—
Settlements		(7,953)		(6,546)
Balance as of March 31,	$	6,779	$	(11,367)
Total gains (losses) included in earnings attributed to    the change in unrealized gains (losses) related to    assets and liabilities held as of March 31,(c)	$	—	$	—

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(c).

	Three Months Ended
	March 31,
(In thousands)	2022		2021
Purchased power expense	$	973	$	702
Cost of gas sold expense		(118)		(395)
Total	$	855	$	307

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

12.Joint Plant Construction Project Ownership - MGE Energy and MGE

MGE currently has ongoing jointly-owned solar generation construction projects, as shown in the following table. Incurred costs are reflected in "Construction work in progress" on the consolidated balance sheets.

	Ownership	Share of	Share of	Costs incurred as of March 31,	Estimated Date of Commercial
Project	Interest	Generation	Estimated Costs(a)	2022(a)	Operation
Red Barn(b)	10%	9.16 MW	$18 million	$0.6 million	December 2022
Badger Hollow II(c)	33%	50 MW	$65 million	$23.8 million(d)	First Half of 2023

(a)Excluding AFUDC.

(b)The Red Barn Wind Farm is located in the Towns of Wingville and Clifton in Grant County, Wisconsin.

(c)The Badger Hollow II solar farm is located in southwestern Wisconsin in Iowa County, near the villages of Montfort and Cobb.

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

MGE received specific approval to recover 100% AFUDC on Badger Hollow II. During the three months ended March 31, 2022 and 2021, MGE recognized $0.4 million and $0.1 million, respectively, after tax, in AFUDC for Badger Hollow II.

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13.Revenue - MGE Energy and MGE.

Revenues disaggregated by revenue source were as follows:

	Three Months Ended
(In thousands)	March 31,
Electric revenues	2022		2021
Residential	$	40,474	$	36,694
Commercial		54,449		47,883
Industrial		3,147		3,001
Other-retail/municipal		8,829		8,170
Total retail		106,899		95,748
Sales to the market		2,882		4,639
Other		308		222
Total electric revenues		110,089		100,609
Gas revenues
Residential		56,683		39,758
Commercial/Industrial		40,251		25,507
Total retail		96,934		65,265
Gas transportation		1,876		2,002
Other		1		3
Total gas revenues		98,811		67,270
Non-regulated energy revenues		38		36
Total Operating Revenue	$	208,938	$	167,915

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. The PSCW allows Wisconsin utilities to defer electric fuel-related costs, less excess revenues, that fall outside a symmetrical cost tolerance band. Any over- or under-recovery of the actual costs in a given year 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 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.

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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 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.

14.Segment Information - MGE Energy and MGE.

MGE Energy operates in the following business segments: electric utility, gas utility, nonregulated energy, transmission investment, and all other. See the 2021 Annual Report on Form 10-K for additional discussion of each of these segments.

(In thousands) MGE Energy	Electric		Gas		Non-Regulated Energy		Transmission Investment		All Others			Consolidation/ Elimination			Consolidated Total
Three Months Ended March 31, 2022
Operating revenues	$	110,089	$	98,811	$	38	$	—	$	—		$	—		$	208,938
Interdepartmental revenues		118		6,121		10,315		—		—			(16,554	)		—
Total operating revenues		110,207		104,932		10,353		—		—			(16,554	)		208,938
Equity in earnings of investments		—		—		—		2,504		—			—			2,504
Net income		14,617		12,084		5,352		1,822		545			—			34,420
Three Months Ended March 31, 2021
Operating revenues	$	100,609	$	67,270	$	36	$	—	$	—		$	—		$	167,915
Interdepartmental revenues		273		4,811		10,173		—		—			(15,257	)		—
Total operating revenues		100,882		72,081		10,209		—		—			(15,257	)		167,915
Equity in earnings of investments		—		—		—		2,444		—			—			2,444
Net income (loss)		18,024		10,556		5,194		1,778		(619	)		—			34,933

(In thousands) MGE	Electric		Gas		Non-Regulated Energy		Consolidation/ Elimination			Consolidated Total
Three Months Ended March 31, 2022
Operating revenues	$	110,089	$	98,811	$	38	$	—		$	208,938
Interdepartmental revenues		118		6,121		10,315		(16,554	)		—
Total operating revenues		110,207		104,932		10,353		(16,554	)		208,938
Net income attributable to MGE		14,617		12,084		5,352		(4,756	)		27,297
Three Months Ended March 31, 2021
Operating revenues	$	100,609	$	67,270	$	36	$	—		$	167,915
Interdepartmental revenues		273		4,811		10,173		(15,257	)		—
Total operating revenues		100,882		72,081		10,209		(15,257	)		167,915
Net income attributable to MGE		18,024		10,556		5,194		(5,501	)		28,273

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

General

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

•Regulated electric utility operations, conducted through MGE,

•Regulated gas utility operations, conducted through MGE,

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

•Transmission investments, representing our equity investment in ATC and 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 159,000 customers in Dane County, Wisconsin, including the city of Madison, and purchases and distributes natural gas to approximately 169,000 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.

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 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 as well as the parent company 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,

•Governmental efforts to address the COVID-19 pandemic, including restrictions on activity, increased

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employee health and welfare costs, and precautions for dealing with members of the public, and

•Other factors listed in "Item 1A. Risk Factors" in our 2021 Annual Report on Form 10-K.

During the three months ended March 31, 2022, MGE Energy's earnings were $34.4 million or $0.95 per share compared to $34.9 million or $0.97 per share during the same period in the prior year. MGE's earnings during the three months ended March 31, 2022, were $27.3 million compared to $28.3 million during the same period in the prior year.

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

	Three Months Ended
(In millions)	March 31,
Business Segment:	2022		2021
Electric Utility	$	14.6	$	18.0
Gas Utility		12.1		10.5
Nonregulated Energy		5.4		5.2
Transmission Investments		1.8		1.8
All Other		0.5		(0.6)
Net Income	$	34.4	$	34.9

Our net income during the three months ended March 31, 2022, compared to the same periods in the prior year primarily reflects the effects of the following factors:

Electric Utility

An increase in electric investments contributed to earnings for 2022. Timing of 2021 depreciation and other operations and maintenance costs contributed to higher earnings in the first quarter of 2021. Depreciation and operations and maintenance costs increased during the remainder of 2021 after significant capital projects were completed. The new customer information system went live in September 2021 and Badger Hollow I was completed in November 2021. MGE received approval to recover 100% AFUDC during construction of these projects.

Gas Utility

An increase in gas investments contributed to increased earnings for 2022. Higher gas retail sales resulting from colder weather in the first quarter of 2022 contributed to higher earnings for the three months ended March 31, 2022. Heating degree days (a measure for determining the impact of weather during the heating season) increased by approximately 4% in the first quarter 2022 compared to the same period in the prior year.

The following developments affected the first three months of 2022:

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 the settlement agreement for 2023, the PSCW approved a 0.96% increase in gas rates and to address a potential electric rate change 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 March 31, 2022(a)	Estimated Date of Commercial Operation
Red Barn	10%	9.16MW	$18 million	$0.6 million	December 2022
Badger Hollow II	33%	50 MW	$65 million	$23.8 million(b)(c)	First Half of 2023

(a)Excluding AFUDC.

(b)MGE received specific approval to recover 100% AFUDC on Badger Hollow II. After tax, MGE recognized $0.9 million of AFUDC equity through March 31, 2022, on Badger Hollow II, 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.

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In the near term, 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. These costs will be subject to the PSCW's annual review of 2021 fuel costs, expected to be completed during 2022. MGE has proposed to include these costs as part of the 2023 electric limited reopener.

2023 Electric Limited Rate Case Reopener: In April 2022, MGE filed with the PSCW a proposed electric limited rate case reopener. The limited rate case reopener proposes a 4.38% increase to electric rates for 2023. See "Other Matters" below for additional information on the 2023 electric limited 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 5.1% and 5.0% of our net income during the three months ended March 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: MGE has outlined initiatives to achieve our new target.

•Transitioning away from coal. Columbia: In February 2021, MGE, along with the other plant co-owners, announced plans to retire the two-unit coal-fired Columbia generating plant near Portage, Wisconsin. MGE currently owns 19% of the facility. The co-owners intend to retire Unit 1 by the end of 2023 and Unit 2 by the end of 2024. 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: 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. MGE is a minority owner of Elm Road, owning 8.33%. The approximately 1,230 MW coal-fired plant is co-owned by WEC Energy Group, whose subsidiary serves as operator, and by WPPI Energy, Inc. 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. 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. In addition to current projects under construction, MGE is seeking to acquire a joint interest in several renewable generation projects as described below.

Project	Source	Ownership Interest	Share of Generation/ Battery Storage	Share of Estimated Costs(c)(d)	Estimated Date of Commercial Operation
Paris(a)	Solar/Battery	10%	20MW/11MW	$43 million	2023
Darien(b)	Solar/Battery	10%	25MW/7.5MW	$45 million	2023
Koshkonong(b)	Solar/Battery	10%	30MW/16.5MW	$65 million	2024(e)

(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

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(d)Requested, in the case of projects pending PSCW approval, or received, in the case of Paris, approval to recover 100% AFUDC.

(e)Construction of the project is expected to be completed in phases ranging from May 2024 through December 2024.

•Natural gas as a fuel source. West Riverside: In 2016, MGE entered into an agreement with WPL under which MGE may acquire up to 50 MW of capacity in a gas-fired generating plant constructed by WPL at its West Riverside Energy Center in Beloit, Wisconsin, during the five-year period following the in-service date of the plant. The plant was placed in service in May 2020. In January 2022, MGE, along with joint applicants, filed an application with the PSCW requesting approval for a sale and purchase of ownership interests in West Riverside. If approved, MGE's share of West Riverside will be 25 MW at a purchase price of approximately $25 million. The closing and actual transfer of ownership is expected to occur in March 2023. MGE also retains the option to purchase an additional 25 MW of capacity from West Riverside until May 2025. MGE currently expects to exercise this option in a future period.

Solar Procurement Disruptions – 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. Additionally, in March 2022, the U.S. Department of Commerce announced a solar tariff investigation on solar panels from four Southeast Asian countries. This investigation could result in additional tariffs on solar panels. 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. Any delays or increase in costs will be filed with the PSCW.

COVID-19 Update – MGE Energy continues to provide safe and reliable service to our customers despite the challenges presented by the Coronavirus Disease 2019 (COVID-19) pandemic. We have operated continuously throughout the pandemic and suffered no material disruptions in service or employment. We continue to monitor potential disruptions or constraints in materials and supplies from key suppliers and as well as macroeconomic trends, such as inflation. We could experience increased costs and delays in our ability to perform certain maintenance and capital project activities. We cannot estimate with any degree of certainty the actual impact of COVID-19 and associated governmental regulations may have on future results of operations, financial position, and liquidity. See Item 1A. "Risk Factors" "Pandemic virus or diseases, including COVID-19, could have a material adverse effect on our business, financial condition and liquidity" in our 2021 Annual Report on Form 10-K for a description of risk.

The following discussion is based on the business segments as discussed in Footnote 14 of the Notes to Consolidated Financial Statements in this Report.

Results of Operations

Results of operations include financial information prepared in accordance with GAAP and electric and gas margins, both which are non-GAAP measures. Electric margin (electric revenues less fuel for electric generation and purchased power costs) and gas margin (gas revenues less cost of gas sold) are non-GAAP measures because they exclude items used in the calculation of the most comparable GAAP measure, operating income. These exclusions consist of nonregulated operating revenues, other operations and maintenance expense, depreciation and amortization expense, and other general taxes expense. Thus, electric and gas margin are not measures determined in accordance with GAAP.

Management believes that electric and gas margins provide a meaningful basis for evaluating and managing utility operations since fuel for electric generation, purchased power costs, and cost of gas sold are passed through without mark-up to customers in current rates. As a result, management uses electric and gas margins internally when assessing the operating performance of our segments. The presentation of utility electric and gas margins herein is intended to provide supplemental information for investors regarding operating performance. These electric and gas margins may not be comparable to how other entities calculate utility electric and gas margin or similar measures. Furthermore, these measures are not intended to replace operating income as determined in accordance with GAAP as an indicator of operating performance.

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Three Months Ended March 31, 2022 and 2021

The following table provides a calculation of electric and gas margins (both non-GAAP measures), along with a reconciliation to the most comparable GAAP measure, operating income:

	Three Months Ended March 31,
(In millions)	2022		2021		$ Change
Electric revenues	$	110.1	$	100.6	$	9.5
Fuel for electric generation		(13.5)		(13.2)		(0.3)
Purchased power		(12.5)		(9.4)		(3.1)
Total Electric Margins (non-GAAP)		84.1		78.0		6.1
Gas revenues		98.8		67.3		31.5
Cost of gas sold		(64.8)		(37.4)		(27.4)
Total Gas Margins (non-GAAP)		34.0		29.9		4.1
Other operating revenues		—		0.1		(0.1)
Other operations and maintenance		(50.0)		(45.7)		(4.3)
Depreciation and amortization		(21.0)		(18.4)		(2.6)
Other general taxes		(5.2)		(4.8)		(0.4)
Operating Income	$	41.9	$	39.1	$	2.8

Operating income during the three months ended March 31, 2022, compared to the same period in the prior year, primarily reflects the effects of the following factors:

•Electric revenues and fuel costs

oA $9.5 million increase in electric revenues primarily driven by higher electric retail rates to recover higher fuel and purchased power costs and other items described in the "Other Matters" section below.

oA $0.3 million increase in fuel for electric generation reflecting higher market costs offset by lower internal generation.

oA $3.1 million increase in purchased power driven by higher market purchases as a result of lower internal generation.

•Gas revenues and cost of gas sold

oA $31.5 million increase in gas revenue driven by higher cost of gas, which is recovered on a pass-through basis in revenues and increase in retail gas deliveries related to favorable weather conditions in the current year.

oA $27.4 million increase in cost of gas sold driven by higher cost per therm of gas. Average cost per therm increased approximately 56%. An increase in volume of approximately 11% also contributed to the increase in cost.

•A $4.3 million increase in other operations and maintenance. See "Consolidated operations and maintenance expenses" section below for a description of the factors contributing to the decrease.

•A $2.6 million increase in depreciation and amortization expense. See "Consolidated depreciation expense" section below for a description of the factors contributing to the increase.

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Electric sales and revenues

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

	Revenues					Sales (kWh)
	Three Months Ended March 31,					Three Months Ended March 31,
(In thousands)	2022		2021		% Change	2022	2021	% Change
Residential	$	40,474	$	36,694	10.3%	221,884	219,770	1.0%
Commercial		54,449		47,883	13.7%	426,529	414,337	2.9%
Industrial		3,147		3,001	4.9%	39,261	39,005	0.7%
Other-retail/municipal		8,829		8,170	8.1%	80,610	76,356	5.6%
Total retail		106,899		95,748	11.6%	768,284	749,468	2.5%
Sales to the market		2,882		4,639	(37.9)%	51,152	95,872	(46.6)%
Other		308		222	38.7%	—	—	—%
Total	$	110,089	$	100,609	9.4%	819,436	845,340	(3.1)%

Electric margin, a non-GAAP measure, increased $6.1 million during the three months ended March 31, 2022, compared to the same period in 2021, due to the following:

(In millions)
Rate changes	$	11.3
Customer fixed and demand charges		0.6
Increase in commercial, industrial and other-retail/municipal volume		0.6
Increase in residential volume		0.2
Other		0.2
Increased fuel costs		(4.8	)
Revenue subject to refund, net		(2.0	)
Total	$	6.1

•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 the three months ended March 31, 2022, were $11.3 million higher than those charged during the same period in the prior year.

•Fuel costs. Fuel costs increased during the three months ended March 31, 2022, primarily as a result of higher costs to generate electricity in the market and higher customer demand.

•Revenue subject to refund. For cost recovery mechanisms, any over-collection of revenues resulting from the amount of 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 margin impact in the year the costs are refunded.

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Gas deliveries and revenues

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

	Revenues					Therms Delivered
(In thousands, except HDD and average	Three Months Ended March 31,					Three Months Ended March 31,
rate per therm of retail customer)	2022		2021		% Change	2022	2021	% Change
Residential	$	56,683	$	39,758	42.6%	55,661	50,305	10.6%
Commercial/Industrial		40,251		25,507	57.8%	47,892	42,254	13.3%
Total retail		96,934		65,265	48.5%	103,553	92,559	11.9%
Gas transportation		1,876		2,002	(6.3)%	26,067	23,308	11.8%
Other		1		3	(66.7)%	—	—	—%
Total	$	98,811	$	67,270	46.9%	129,620	115,867	11.9%
Heating degree days (normal 3,529)						3,718	3,593	3.5%
Average rate per therm of retail customer	$	0.936	$	0.705	32.8%

Gas margin, a non-GAAP measure, increased $4.1 million during the three months ended March 31, 2022, compared to the same period in 2021, due to the following:

(In millions)
Increase in volume	$	1.9
Rate changes		1.7
Other		0.5
Total	$	4.1

•Volume. For 2022, retail gas deliveries increased 11.9% compared to the same period in the prior year primarily related to favorable weather conditions in the current year.

•Rate changes. In December 2021, the PSCW authorized MGE to increase 2022 rates for retail gas customers by approximately 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. Payments for natural gas increased driving higher rates during the three months ended March 31, 2022.

Consolidated operations and maintenance expenses

During the three months ended March 31, 2022, operations and maintenance expenses increased $4.3 million, compared to the same period in the prior year. The following contributed to the net change:

(In millions)
Increased administrative and general costs	$	2.3
Increased electric production expenses		1.1
Increased customer accounts costs		1.0
Increased other expenses		0.1
Decreased electric distribution expenses		(0.2	)
Total	$	4.3

•Increase in administration and general costs are primarily related to increase in pension and OPEB service costs.

•Increased electric production expenses are primarily related to increased maintenance costs for Saratoga, Two Creeks, and Badger Hollow I.

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

Consolidated depreciation expense

Electric depreciation expense increased $2.0 million and gas depreciation expense increased $0.7 million during the three months ended March 31, 2022, compared to the same period in the prior year. MGE placed in service Badger Hollow I 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 increasing depreciation costs for both electric and gas in 2022.

Electric and gas other income

Electric and gas other income increased $2.3 million and $1.3 million, respectively, during the three months ended March 31, 2022, compared to the same period in the prior year, 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. During the three months ended March 31, 2022 and 2021, net income at the nonregulated energy operations segment was $5.4 million and $5.2 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 the three months ended March 31, 2022 and 2021, other income at the transmission investment segment primarily reflects ATC's operations and was $2.5 million and $2.4 million, respectively. See Footnote 3 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 4 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. They are not owned by MGE. 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:

	Three Months Ended
	March 31,
(In millions)	2022		2021
MGE Power Elm Road	$	3.0	$	3.7
MGE Power West Campus		1.8		1.8

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Contractual Obligations and Commercial Commitments - MGE Energy and MGE

There were no material changes, other than from the normal course of business, to MGE Energy's and MGE's contractual obligations (representing cash obligations that are considered to be firm commitments) and commercial commitments (representing commitments triggered by future events) during the three months ended March 31, 2022, except as noted below. Further discussion of the contractual obligations and commercial commitments is included in Footnote 16 of the Notes to Consolidated Financial Statements and "Contractual Obligations and Commercial Commitments for MGE Energy and MGE" under "Management's Discussion and Analysis of Financial Condition and Results of Operations" in the 2021 Annual Report on Form 10-K.

Purchase Contracts – MGE Energy and MGE

See item c. within Footnote 8 of Notes to Consolidated Financial Statements in this Report for a description of commitments as of March 31, 2022, that MGE Energy and MGE have entered with respect to various commodity supply and transportation contracts to meet their obligations to deliver electricity and natural gas to customers.

Liquidity and Capital Resources

Subject to the duration and severity of the COVID-19 pandemic, 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 both long-term debt financing, short-term debt financing, and if needed, could issue new shares through our Direct Stock Purchase and Dividend Reinvestment Plan. See "Credit Facilities" under Part II, Item 7, Management's Discussion and Analysis of Financial Condition and Results of Operations – Liquidity and Capital Resources in the 2021 Annual Report on Form 10-K for information regarding MGE Energy's and MGE's credit facilities.

Cash Flows

The following summarizes cash flows for MGE Energy and MGE during the three months ended March 31, 2022 and 2021:

	MGE Energy				MGE
(In thousands)	2022		2021		2022		2021
Cash provided by (used for):
Operating activities	$	62,099	$	43,883	$	62,681	$	41,981
Investing activities		(32,169)		(35,835)		(30,942)		(35,208)
Financing activities		(21,216)		(13,585)		(21,203)		(5,205)

Cash Provided by Operating Activities

MGE Energy

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

Cash provided by operating activities during the three months ended March 31, 2022, was $62.1 million, an increase of $18.2 million when compared to the same period in the prior year.

MGE Energy's net income decreased $0.5 million during the three months ended March 31, 2022, when compared to the same period in the prior year.

MGE Energy's federal and state taxes paid increased $1.0 million during the three months ended March 31, 2022, when compared to the prior year.

Working capital accounts (excluding prepaid and accrued taxes) resulted in $0.2 million in cash provided by operating activities during the three months ended March 31, 2022. Actual purchased gas costs were $5.9 million

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lower than the amount collected in rates. MGE Energy paid a $2.5 million contribution to the MGE Foundation in 2022. In addition, working capital accounts were impacted by decreased inventories and decreased unbilled revenues, partially offset by increased accounts receivable and decreased accounts payable.

Working capital accounts (excluding prepaid and accrued taxes) resulted in $11.4 million in cash used for operating activities during the three months ended March 31, 2021. Actual purchased gas costs were $13.0 million higher than the amount collected in rates primarily due to the extreme cold weather experienced in the U.S. in February 2021. These costs were deferred as a regulatory asset and will be recovered in a future period. In addition, working capital accounts were impacted by increased accounts receivable and decreased other current liabilities, partially offset by decreased gas inventories and decreased unbilled revenues.

Hosted software asset expenditures during the three months ended March 31, 2022, were $0.1 million. This amount represents a decrease of $1.2 million of cash used when compared to the prior year.

MGE

Cash provided by operating activities during the three months ended March 31, 2022, was $62.7 million, an increase of $20.7 million when compared to the same period in the prior year.

Net income decreased $1.7 million during the three months ended March 31, 2022, when compared to the same period in the prior year.

MGE's federal and state taxes paid increased $1.0 million during the three months ended March 31, 2022, when compared to the prior year.

Working capital accounts (excluding prepaid and accrued taxes) resulted in $2.8 million in cash provided by operating activities during the three months ended March 31, 2022. Actual purchased gas costs were $5.9 million lower than the amount collected in rates. In addition, working capital accounts were impacted by decreased inventories and decreased unbilled revenues, partially offset by increased accounts receivable and decreased accounts payable.

Working capital accounts (excluding prepaid and accrued taxes) resulted in $11.3 million in cash used for operating activities during the three months ended March 31, 2021. Actual purchased gas costs were $13.0 million higher than the amount collected in rates primarily due to the extreme cold weather experienced in the U.S. in February 2021. These costs were deferred as a regulatory asset and will be recovered in a future period. In addition, working capital accounts were impacted by increased accounts receivable and decreased other current liabilities, partially offset by decreased gas inventories and decreased unbilled revenues.

Hosted software asset expenditures during the three months ended March 31, 2022, were $0.1 million. This amount represents a decrease of $1.2 million of cash used when compared to the prior year.

Capital Requirements and Investing Activities

MGE Energy

MGE Energy's cash used for investing activities decreased $3.7 million during the three months ended March 31, 2022, when compared to the same period in the prior year.

Capital expenditures during the three months ended March 31, 2022, were $30.8 million. This amount represents a decrease of $4.0 million from the expenditures made in the same period in the prior year. This decrease primarily reflects the reduction of utility expenditures.

MGE

MGE's cash used for investing activities decreased $4.3 million during the three months ended March 31, 2022, when compared to the same period in the prior year.

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Capital expenditures during the three months ended March 31, 2022, were $30.8 million. This amount represents a decrease of $4.0 million from the expenditures made in the same period in the prior year. This decrease primarily reflects the reduction of utility expenditures.

MGE Energy's and MGE's Capital Requirements

MGE Energy's and MGE's liquidity are primarily affected by their capital expenditure requirements. During the three months ended March 31, 2022, capital expenditures for MGE Energy and MGE totaled $30.8 million, which included $30.2 million of utility capital expenditures.

MGE does not currently expect any material changes resulting from the COVID-19 pandemic and associated governmental regulations to its construction plans as presented in the 2022 through 2025 capital expenditure forecast included under Part II, Item 7. Management's Discussion and Analysis of Financial Condition and Results of Operations – Liquidity and Capital Resources in the 2021 Annual Report on Form 10-K.

Cash Used for Financing Activities

MGE Energy

Cash used for MGE Energy's financing activities was $21.2 million during the three months ended March 31, 2022, compared to $13.6 million for the same period in the prior year.

During the three months ended March 31, 2022, dividends paid were $14.0 million compared to $13.4 million in the prior year. The increase reflected a higher dividend rate per share ($0.388 vs. $0.370).

During the three months ended March 31, 2022, net short-term debt repayments were $5.5 million, compared to $1.5 million of net short-term debt borrowings in the prior year.

MGE

During the three months ended March 31, 2022, cash used for MGE's financing activities was $21.2 million, compared to $5.2 million for the same period in the prior year.

Cash dividends to parent (MGE Energy) were $5.0 million during the three months ended March 31, 2022. There were no cash dividends to parent in the prior year.

Distributions to parent from noncontrolling interest, which represent distributions from MGE Power Elm Road and MGE Power West Campus to MGE Energy, were $9.0 million during the three months ended March 31, 2022, compared to $5.0 million in the prior year.

During the three months ended March 31, 2022, net short-term debt repayments were $5.5 million, compared to $1.5 million of net short-term debt borrowings in the prior year.

Capitalization Ratios

MGE Energy's capitalization ratios were as follows:

	MGE Energy
	March 31, 2022	December 31, 2021
Common shareholders' equity	62.9%	62.2%
Long-term debt(a)	37.1%	37.5%
Short-term debt	—%	0.3%

(a)Includes the current portion of long-term debt.

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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.

Environmental Matters

The following discussion is limited to updates or developments in environmental matters that occurred during the three months ended March 31, 2022. Further discussion of environmental matters is included in the 2021 Annual Report on Form 10-K and Footnote 8.a. of Notes to Consolidated Financial Statements in this Report.

Rules regulating nitrogen oxide (NOx) and sulfur dioxide (SO2) emissions, including the Cross State Air Pollution Rule (CSAPR) and Clean Air Visibility Rule

The EPA's CSAPR and its progeny are a suite of interstate air pollution transport rules designed to reduce ozone and fine particulate (PM2.5) 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 emission reductions 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 State Implementation Plan (SIP) to meet its obligations or accept the EPA's proposed FIP.

MGE is currently evaluating the proposed rule to determine potential impacts to our business. MGE expects the rule, if finalized as written, to impact our fossil-fueled generation assets. However, MGE will not know the impacts of this rule with any certainty until the rule is finalized. We will continue to monitor rule developments.

MGE has met its current CSAPR obligations through a combination of reduced emissions through pollution control (e.g., SCR installation at Columbia), and owned, received, and purchased allowances. MGE expects to meet ongoing CSAPR obligations for the foreseeable future.

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 to electric rates and a 2.15% increase to gas rates for 2022. The electric and gas rate increases are driven by an increase in rate base including our investments in Badger Hollow I and a new customer information system. Also driving the electric increase are 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

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Tax Act not restricted by IRS normalization rules. Included in the electric residential rate is a reduction in the customer charge. As part of the settlement agreement for 2023, the PSCW approved a 0.96% increase in gas rates and to address a potential electric rate change through a limited rate case reopener.

In April 2022, MGE filed a limited reopener with a proposed a 4.38% increase to electric rates for 2023. 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 a reduction in fuel costs, which MGE has partially offset with 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. PSCW approval of the limited reopener is pending. A final order is expected before the end of the year.

Details related to MGE's 2022/2023 approved settlement agreement and pending electric limited reopener:

(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)(d)	$	1,159,155	$	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 - 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.

(d)Pending approval by the PSCW.

ATC

2013 FERC Complaint - In 2013, several parties filed a complaint with the FERC seeking to reduce the base return on equity (ROE) used by MISO transmission owners, including ATC. The complaint provided for a statutory refund period of November 2013 through February 2015. The complaint asserted that the MISO ROE should not exceed 9.15%, that the equity components of hypothetical capital structures should be restricted to 50%, and that the relevant incentive ROE adders should be discontinued. At the time, MISO's base ROE was 12.38% and ATC's base ROE was 12.2%. On September 28, 2016, FERC issued an order, for the period November 2013 through February 2015, reducing ATC's base ROE to 10.32%. In November 2019, FERC issued an order to further reduce ATC's base ROE to 9.88%. In May 2020, the FERC issued an order further refining the methodology for setting the ROE that electric utilities are authorized to earn. This increased the ROE from 9.88% to 10.02%. This base ROE is effective for the 2013 FERC complaint period and for all periods following September 2016.

2015 FERC Complaint - In February 2015, several parties filed a complaint with the FERC seeking to reduce the base ROE used by MISO transmission owners, including ATC, to 8.67%. The complaint provided for a statutory refund period of February 2015 through May 2016 with a refund effective date retroactive to the complaint filing date. In June 2016, an administrative law judge issued an initial decision for the complaint that would reduce the transmission owner's base ROE to 9.7%. In November 2019, FERC issued an order dismissing the complaint with the determination that the ROE was reasonable. As a result of this order and the methodology FERC used to determine the applicable ROE in the 2013 FERC complaint, several parties have requested a rehearing by FERC. If FERC denies these requests, the complainants are likely to file an appeal with the appellate court. Any downward change to ATC's ROE could result in lower equity earnings and distributions from ATC in the future.

As of December 31, 2018, our share of the estimated refund recorded was $2.5 million, including interest. Following the November 2019 FERC order, our share of ATC's earnings reflects a pre-tax adjustment of $2.0

43

million, including interest, related to the 2013 complaint refund period and from September 28, 2016 through December 31, 2019. As a result of the May 2020 FERC order, our share of ATC's earnings reflects a $0.6 million reduction of our reserve. Additionally, our share of ATC's earnings reflects the derecognition of a possible refund related to the 2015 complaint as ATC considers such a refund to be no longer considered probable due to FERC's November 2019 dismissal of that complaint. However, due to pending requests for rehearing, a loss related to the 2015 complaint remains possible. Our share of the estimated refund for the 2015 complaint is approximately $2.3 million. As of December 31, 2020, our share of the estimated refund amount reflected a net increase in ATC's earnings with a pre-tax adjustment of $0.6 million, inclusive of interest.

We derived approximately 5.1% and 5.0% of our net income during the three months ended March 31, 2022 and 2021, respectively, from our investment in ATC.

Adoption of Accounting Principles and Recently Issued Accounting Pronouncements

See Footnote 2 of Notes to Consolidated Financial Statements in this Report for discussion of new accounting pronouncements.

Item 3. Quantitative and Qualitative Disclosures About Market Risk.

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

Commodity Price Risk

MGE has commodity price risk exposure with respect to the price of natural gas, electricity, coal, emission credits, and oil. MGE's electric operations burn natural gas in several of its peaking power plants and, in many cases, the cost of purchased power is tied to the cost of natural gas. MGE employs established policies and procedures to reduce the market risks associated with changing commodity prices. MGE's commodity risks are 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. Under the electric fuel rules, MGE would defer the benefit of lower costs if the actual electric fuel costs fall outside the lower end of the range and is required to defer costs, less any excess revenues, if the actual electric fuel costs exceed the upper end of the range. Excess revenues are defined as revenues in the year in question that provide MGE with a greater return on common equity than authorized by the PSCW in MGE's latest rate order. The range is defined by the PSCW and has been modified throughout the years based on market conditions and other relevant factors. MGE is subject to a plus or minus 1% range. MGE assumes the risks and benefits of variances that are within the cost tolerance band. For 2022, $82.7 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.

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

44

also holds financial transmission rights (FTRs), which are used to hedge the risk of increased transmission congestion charges. As of March 31, 2022, the fair value of exchange traded derivatives and FTRs exceeded their cost basis by $9.8 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.

MGE has also entered into a purchased power agreement that provides MGE with firm capacity and energy that began on June 1, 2012, and ends on May 31, 2022 (the "base term"). The agreement is considered a derivative contract and is recognized at its fair value on the consolidated balance sheets. However, the derivative qualifies for regulatory deferral and is recognized with a corresponding regulatory asset or liability depending on whether the fair value is in a loss or gain position. The fair value of the contract as of March 31, 2022, reflected a loss position of $0.1 million.

Interest Rate Risk

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

Equity Price Risk - Pension-Related Assets

MGE currently funds its liabilities related to employee benefits through trust funds. These funds, which include investments in debt and equity securities, are managed by various third-party investment managers. Changes in the market value of these investments can have an impact on the future expenses related to these liabilities. The value of employee benefit plan assets has declined by approximately 7% during the three months ended March 31, 2022.

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 March 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, 2021, 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

45

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.

46

Item 4. Controls and Procedures.

During the first 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 March 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.

During the quarter ended March 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.

47

PART II. OTHER INFORMATION.

Item 1. Legal Proceedings.

MGE Energy and MGE

MGE Energy and its subsidiaries, including MGE, from time to time are involved in various legal proceedings that are handled and defended in the ordinary course of business. See Footnote 8.a. and 8.b. of Notes to Consolidated Financial Statements in this Report for more information.

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

Issuer Purchases of Equity Securities

Period	Total Number of Shares Purchased		Average Price Paid per Share		Total Number of Shares Purchased as Part of Publicly Announced Plans or Programs(a)	Maximum number (or Approximate Dollar Value) of Shares That May Yet Be Purchased Under the Plans or Programs(a)
January 1-31, 2022		7,264	$	79.44	—	—
February 1-28, 2022		7,020		74.05	—	—
March 1-31, 2022		39,234		76.76	—	—
Total		53,518	$	76.77	—	—

(a)Under the MGE Energy, Inc. Direct Stock Purchase and Dividend Reinvestment Plan (Stock Plan), common stock shares deliverable to plan participants may be either newly issued shares or shares purchased on the open market, as determined from time to time by MGE Energy. During 2022, MGE Energy's transfer agent used open market purchases to provide shares to meet obligations to participants in the Stock Plan. The shares are purchased on the open market through the transfer agent's securities broker-dealer and then are reissued under the Stock Plan as needed to meet share delivery requirements. The volume and timing of share repurchases in the open market depends upon the level of dividend reinvestment and optional share purchases being made from time to time by plan participants. As a result, there is no specified maximum number of shares to be repurchased and no specified termination date for the repurchases. All shares issued through the Stock Plan, whether newly issued or open market purchases, are sold pursuant to a registration statement that was filed with the SEC and is currently effective.

Item 3. Defaults Upon Senior Securities.

None.

Item 4. Mine Safety Disclosures.

Not applicable to MGE Energy and MGE.

Item 5. Other Information.

None.

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Item 6. Exhibits.

Ex. No.		Exhibit Description
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
104.1		Included in the cover page, formatted in Inline XBRL
*		Filed herewith.
**		Furnished herewith.

49

Signatures - MGE Energy, Inc.

Pursuant to the requirements of the Securities Exchange Act of 1934, the registrant has duly caused this report to be signed on its behalf by the undersigned hereunto duly authorized.

	MGE ENERGY, INC.
Date: May 5, 2022	/s/ Jeffrey M. Keebler
	Jeffrey M. Keebler Chairman, President and Chief Executive Officer (Duly Authorized Officer)
Date: May 5, 2022	/s/ Jared J. Bushek
	Jared J. Bushek Vice President - Finance, Chief Information Officer and Treasurer (Chief Financial Officer)
Date: May 5, 2022	/s/ Tamara J. Johnson
	Tamara J. Johnson Vice President - Accounting and Controller (Chief Accounting Officer)

50

Signatures – Madison Gas and Electric Company

Pursuant to the requirements of the Securities Exchange Act of 1934, the registrant has duly caused this report to be signed on its behalf by the undersigned hereunto duly authorized.

	MADISON GAS AND ELECTRIC
Date: May 5, 2022	/s/ Jeffrey M. Keebler
	Jeffrey M. Keebler Chairman, President and Chief Executive Officer (Duly Authorized Officer)
Date: May 5, 2022	/s/ Jared J. Bushek
	Jared J. Bushek Vice President - Finance, Chief Information Officer and Treasurer (Chief Financial Officer)
Date: May 5, 2022	/s/ Tamara J. Johnson
	Tamara J. Johnson Vice President - Accounting and Controller (Chief Accounting Officer)

51

EX-31.1

EXHIBIT 31.1

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

I, Jeffrey M. Keebler, certify that:

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

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

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

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

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

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

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

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

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

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

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

/s/ Jeffrey M. Keebler

Jeffrey M. Keebler

Chairman, President and Chief Executive Officer

Date: May 5, 2022

1

EX-31.2

EXHIBIT 31.2

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

I, Jared J. Bushek, certify that:

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

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

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

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

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

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

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

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

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

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

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

/s/ Jared J. Bushek

Jared J. Bushek

Vice President - Finance, Chief Information Officer and Treasurer

Date: May 5, 2022

1

EX-31.3

EXHIBIT 31.3

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

I, Jeffrey M. Keebler, certify that:

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

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

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

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

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

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

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

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

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

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

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

/s/ Jeffrey M. Keebler

Jeffrey M. Keebler

Chairman, President and Chief Executive Officer

Date: May 5, 2022

1

EX-31.4

EXHIBIT 31.4

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

I, Jared J. Bushek, certify that:

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

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

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

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

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

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

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

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

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

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

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

/s/ Jared J. Bushek

Jared J. Bushek

Vice President - Finance, Chief Information Officer and Treasurer

Date: May 5, 2022

1

EX-32.1

EXHIBIT 32.1

Certification Pursuant to 18 U.S.C. Section 1350,

as Adopted Pursuant to Section 906 of the Sarbanes-Oxley Act of 2002

In connection with the quarterly report on Form 10-Q of MGE Energy, Inc. (the "Company"), for the period ended March 31, 2022, as filed with the Securities and Exchange Commission on the date hereof ("the Report"), I, Jeffrey M. Keebler, Chief Executive Officer of the Company, certify, pursuant to 18 U.S.C. Section 1350, as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002, that:

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

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

/s/ Jeffrey M. Keebler

Jeffrey M. Keebler

Chairman, President and Chief Executive Officer

Date: May 5, 2022

1

EX-32.2

EXHIBIT 32.2

Certification Pursuant to 18 U.S.C. Section 1350,

as Adopted Pursuant to Section 906 of the Sarbanes-Oxley Act of 2002

In connection with the quarterly report on Form 10-Q of MGE Energy, Inc. (the "Company"), for the period ended March 31, 2022, as filed with the Securities and Exchange Commission on the date hereof ("the Report"), I, Jared J. Bushek, Chief Financial Officer of the Company, certify, pursuant to 18 U.S.C. Section 1350, as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002, that:

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

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

/s/ Jared J. Bushek

Jared J. Bushek

Vice President - Finance, Chief Information Officer and Treasurer

Date: May 5, 2022

1

EX-32.3

EXHIBIT 32.3

Certification Pursuant to 18 U.S.C. Section 1350,

as Adopted Pursuant to Section 906 of the Sarbanes-Oxley Act of 2002

In connection with the quarterly report on Form 10-Q of Madison Gas and Electric Company (the "Company"), for the period ended March 31, 2022, as filed with the Securities and Exchange Commission on the date hereof ("the Report"), I, Jeffrey M. Keebler, Chief Executive Officer of the Company, certify, pursuant to 18 U.S.C. Section 1350, as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002, that:

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

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

/s/ Jeffrey M. Keebler

Jeffrey M. Keebler

Chairman, President and Chief Executive Officer

Date: May 5, 2022

1

EX-32.4

EXHIBIT 32.4

Certification Pursuant to 18 U.S.C. Section 1350,

as Adopted Pursuant to Section 906 of the Sarbanes-Oxley Act of 2002

In connection with the quarterly report on Form 10-Q of Madison Gas and Electric Company (the "Company"), for the period ended March 31, 2022, as filed with the Securities and Exchange Commission on the date hereof ("the Report"), I, Jared J. Bushek, Chief Financial Officer of the Company, certify, pursuant to 18 U.S.C. Section 1350, as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002, that:

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

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

/s/ Jared J. Bushek

Jared J. Bushek

Vice President - Finance, Chief Information Officer and Treasurer

Date: May 5, 2022

1

XML

Document and Entity Information - shares	3 Months Ended
	Mar. 31, 2022	Apr. 30, 2022
Document And Entity Information [Line Items]
Entity Registrant Name	MGE Energy, Inc.
Entity Central Index Key	0001161728
Document Type	10-Q
Document Period End Date	Mar. 31, 2022
Amendment Flag	false
Trading Symbol	MGEE
Document Fiscal Year Focus	2022
Document Fiscal Period Focus	Q1
Current Fiscal Year End Date	--12-31
Entity Current Reporting Status	Yes
Entity Filer Category	Large Accelerated Filer
Entity Common Stock, Shares Outstanding		36,163,370
Entity Emerging Growth Company	false
Entity Small Business	false
Entity Shell Company	false
Security Exchange Name	NASDAQ
Security 12(b) Title	Common Stock, $1 Par Value Per Share
Entity Tax Identification Number	39-2040501
Entity File Number	000-49965
Entity Incorporation, State or Country Code	WI
Entity Address, Address Line One	133 South Blair Street
Entity Address, City or Town	Madison
Entity Address, State or Province	WI
Entity Address, Postal Zip Code	53788
City Area Code	608
Local Phone Number	252-7000
Document Transition Report	false
Entity Interactive Data Current	Yes
Document Quarterly Report	true
MGE [Member]
Document And Entity Information [Line Items]
Entity Registrant Name	Madison Gas and Electric Company
Entity Central Index Key	0000061339
Entity Current Reporting Status	Yes
Entity Filer Category	Non-accelerated Filer
Entity Common Stock, Shares Outstanding		17,347,894
Entity Emerging Growth Company	false
Entity Small Business	false
Entity Shell Company	false
Entity Tax Identification Number	39-0444025
Entity File Number	000-1125
Entity Incorporation, State or Country Code	WI
Entity Address, Address Line One	133 South Blair Street
Entity Address, City or Town	Madison
Entity Address, State or Province	WI
Entity Address, Postal Zip Code	53788
City Area Code	608
Local Phone Number	252-7000
Document Transition Report	false
Entity Interactive Data Current	Yes
Document Quarterly Report	true

XML

Consolidated Statements of Income (Unaudited) - USD ($) shares in Thousands, $ in Thousands	3 Months Ended
	Mar. 31, 2022	Mar. 31, 2021
Operating Revenues:
Electric revenues	$ 110,127	$ 100,645
Gas revenue	98,811	67,270
Total Operating Revenues	208,938	167,915
Operating Expenses:
Fuel for electric generation	13,485	13,171
Purchased power	12,543	9,355
Cost of gas sold	64,802	37,444
Other operations and maintenance	49,994	45,682
Depreciation and amortization	21,046	18,382
Other general taxes	5,205	4,827
Total Operating Expenses	167,075	128,861
Operating Income	41,863	39,054
Other (expense) income, net	6,972	2,078
Interest expense, net	(6,571)	(5,740)
Income before income taxes	42,264	35,392
Income tax (provision) benefit	(7,844)	(459)
Net Income Including Noncontrolling Interest	34,420	34,933
Net Income	$ 34,420	$ 34,933
Earnings per share of Common Stock - Basic	$ 0.95	$ 0.97
Earnings per share of Common Stock - Diluted	0.95	0.97
Dividends per share of common stock	$ 0.388	$ 0.370
Weighted Average Number of Shares Outstanding, Basic	36,163	36,163
Weighted Average Shares Outstanding - Diluted	36,171	36,165
MGE [Member]
Operating Revenues:
Electric revenues	$ 110,127	$ 100,645
Gas revenue	98,811	67,270
Total Operating Revenues	208,938	167,915
Operating Expenses:
Fuel for electric generation	13,485	13,171
Purchased power	12,543	9,355
Cost of gas sold	64,802	37,444
Other operations and maintenance	49,746	45,538
Depreciation and amortization	21,046	18,382
Other general taxes	5,205	4,827
Total Operating Expenses	166,827	128,717
Operating Income	42,111	39,198
Other (expense) income, net	3,519	(104)
Interest expense, net	(6,577)	(5,753)
Income before income taxes	39,053	33,341
Income tax (provision) benefit	(7,000)	433
Net Income Including Noncontrolling Interest	32,053	33,774
Less Net Income Attributable to Noncontrolling Interest, net of tax	(4,756)	(5,501)
Net Income	$ 27,297	$ 28,273

XML

Consolidated Statements of Cash Flows (Unaudited) - USD ($) $ in Thousands	3 Months Ended
	Mar. 31, 2022	Mar. 31, 2021
Operating Activities:
Net Income	$ 34,420	$ 34,933
Items not affecting cash:
Depreciation and amortization	21,046	18,382
Deferred income taxes	5,606	(796)
Provision for doubtful receivables	441	388
Employee benefit plan cost (credit)	(1,678)	1,461
Equity earnings in investments	(2,504)	(2,444)
Other items	(486)	(277)
Changes in working capital items:
Decrease (increase) in current assets	12,332	(2,851)
Decrease in current liabilities	(7,115)	(4,213)
Dividends from investment	2,001	1,967
Cash contributions to pension and other postretirement plans	(1,660)	(1,552)
Other noncurrent items, net	(304)	(1,115)
Cash Provided by Operating Activities	62,099	43,883
Investing Activities:
Capital expenditures	(30,778)	(34,746)
Capital contributions to investments	(1,546)	(670)
Other	155	(419)
Cash Used for Investing Activities	(32,169)	(35,835)
Financing Activities:
Cash dividends paid on common stock	(14,013)	(13,380)
Repayments of long-term debt	(1,211)	(1,182)
(Repayments of) proceeds from short-term debt	(5,500)	1,500
Other	(492)	(523)
Cash Used for Financing Activities	(21,216)	(13,585)
Change in cash, cash equivalents, and restricted cash	8,714	(5,537)
Cash, cash equivalents, and restricted cash at beginning of period	18,835	47,039
Cash, cash equivalents, and restricted cash at end of period	27,549	41,502
Significant noncash investing activities:
Accrued capital expenditures	6,735	8,843
MGE [Member]
Operating Activities:
Net Income	32,053	33,774
Items not affecting cash:
Depreciation and amortization	21,046	18,382
Deferred income taxes	5,230	(1,766)
Provision for doubtful receivables	441	388
Employee benefit plan cost (credit)	(1,678)	1,461
Other items	587	(252)
Changes in working capital items:
Decrease (increase) in current assets	11,810	(3,037)
Decrease in current liabilities	(4,648)	(4,037)
Cash contributions to pension and other postretirement plans	(1,660)	(1,552)
Other noncurrent items, net	(500)	(1,380)
Cash Provided by Operating Activities	62,681	41,981
Investing Activities:
Capital expenditures	(30,778)	(34,746)
Other	(164)	(462)
Cash Used for Investing Activities	(30,942)	(35,208)
Financing Activities:
Cash dividends paid to parent by MGE	(5,000)	0
Distributions to parent from noncontrolling interest	(9,000)	(5,000)
Repayments of long-term debt	(1,211)	(1,182)
(Repayments of) proceeds from short-term debt	(5,500)	1,500
Other	(492)	(523)
Cash Used for Financing Activities	(21,203)	(5,205)
Change in cash, cash equivalents, and restricted cash	10,536	1,568
Cash, cash equivalents, and restricted cash at beginning of period	7,798	6,404
Cash, cash equivalents, and restricted cash at end of period	18,334	7,972
Significant noncash investing activities:
Accrued capital expenditures	$ 6,735	$ 8,843

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Consolidated Balance Sheets (Unaudited) - USD ($) $ in Thousands	Mar. 31, 2022	Dec. 31, 2021
Current Assets:
Cash and cash equivalents	$ 26,374	$ 17,438
Accounts receivable, less reserves	50,167	46,205
Other accounts receivables, less reserves	15,244	16,094
Unbilled revenues	30,839	34,812
Materials and supplies, at average cost	30,951	29,863
Fuel for electric generation, at average cost	6,331	6,429
Stored natural gas, at average cost	5,580	15,668
Prepaid taxes	15,487	20,214
Regulatory assets - current	2,205	1,465
Other current assets	11,255	11,183
Total Current Assets	194,433	199,371
Other long-term receivables	691	1,155
Regulatory assets	108,271	107,547
Pension benefit asset	62,806	58,757
Other deferred assets and other	26,697	27,548
Property, Plant, and Equipment:
Property, plant, and equipment, net	1,843,122	1,828,171
Construction work in progress	40,156	50,603
Total Property, Plant, and Equipment	1,883,278	1,878,774
Investments	101,365	98,754
Total Assets	2,377,541	2,371,906
Current Liabilities:
Long-term debt due within one year	4,920	4,889
Short-term debt	0	5,500
Accounts payable	44,690	64,149
Accrued interest and taxes	9,265	10,385
Accrued payroll related items	9,296	12,951
Regulatory liabilities - current	24,557	9,365
Derivative liabilities	130	2,140
Other current liabilities	5,246	8,468
Total Current Liabilities	98,104	117,847
Other Credits:
Deferred income taxes	233,146	231,149
Investment tax credit - deferred	48,773	44,836
Regulatory liabilities	155,096	154,298
Accrued pension and other postretirement benefits	72,881	73,085
Finance lease liabilities	16,920	17,322
Other deferred liabilities and other	91,363	91,690
Total Other Credits	618,179	612,380
Capitalization:
Common shareholders equity	1,048,153	1,027,468
Long-term debt	613,105	614,211
Total Capitalization	1,661,258	1,641,679
Commitments and contingencies (see Footnote 8)
Total Liabilities and Capitalization	2,377,541	2,371,906
MGE [Member]
Current Assets:
Cash and cash equivalents	17,159	6,401
Accounts receivable, less reserves	50,167	46,205
Affiliate receivables	530	558
Other accounts receivables, less reserves	15,242	16,092
Unbilled revenues	30,839	34,812
Materials and supplies, at average cost	30,951	29,863
Fuel for electric generation, at average cost	6,331	6,429
Stored natural gas, at average cost	5,580	15,668
Prepaid taxes	15,193	19,379
Regulatory assets - current	2,205	1,465
Other current assets	11,152	11,071
Total Current Assets	185,349	187,943
Affiliate receivable long-term	1,456	1,589
Regulatory assets	108,271	107,547
Pension benefit asset	62,806	58,757
Other deferred assets and other	26,806	27,907
Property, Plant, and Equipment:
Property, plant, and equipment, net	1,843,150	1,828,199
Construction work in progress	40,156	50,603
Total Property, Plant, and Equipment	1,883,306	1,878,802
Investments	177	230
Total Assets	2,268,171	2,262,775
Current Liabilities:
Long-term debt due within one year	4,920	4,889
Short-term debt	0	5,500
Accounts payable	44,672	64,130
Accrued interest and taxes	9,417	10,649
Accrued payroll related items	9,296	12,951
Regulatory liabilities - current	24,557	9,365
Derivative liabilities	130	2,140
Other current liabilities	5,324	5,968
Total Current Liabilities	98,316	115,592
Other Credits:
Deferred income taxes	200,507	198,885
Investment tax credit - deferred	48,773	44,836
Regulatory liabilities	155,096	154,298
Accrued pension and other postretirement benefits	72,881	73,085
Finance lease liabilities	16,920	17,322
Other deferred liabilities and other	92,126	92,152
Total Other Credits	586,303	580,578
Capitalization:
Common shareholders equity	826,104	803,807
Noncontrolling interest	144,343	148,587
Total Equity	970,447	952,394
Long-term debt	613,105	614,211
Total Capitalization	1,583,552	1,566,605
Commitments and contingencies (see Footnote 8)
Total Liabilities and Capitalization	$ 2,268,171	$ 2,262,775

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Consolidated Balance Sheets (Unaudited) (Parentheticals) - USD ($) $ in Thousands	Mar. 31, 2022	Dec. 31, 2021
Receivables, Net
Reserve for uncollectible accounts receivable	$ 8,952	$ 6,940
Reserve for uncollectible other accounts receivable	1,213	1,364
MGE [Member]
Receivables, Net
Reserve for uncollectible accounts receivable	8,952	6,940
Reserve for uncollectible other accounts receivable	$ 1,213	$ 1,364

XML

MGE Energy Inc Consolidated Statements of Common Equity (Unaudited) - USD ($) shares in Thousands, $ in Thousands	Total	Common Stock [Member]	Additional Paid-in Capital [Member]	Retained Earnings [Member]	AOCI Attributable to Parent [Member]
Beginning balance, shares at Dec. 31, 2020		36,163
Beginning balance, value at Dec. 31, 2020	$ 976,000	$ 36,163	$ 394,408	$ 545,429	$ 0
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Net Income	34,933			34,933
Common stock dividends declared	(13,380)			(13,380)
Equity-based compensation plans and other	158		158
Ending balance, shares at Mar. 31, 2021		36,163
Ending balance, value at Mar. 31, 2021	997,711	$ 36,163	394,566	566,982	0
Beginning balance, shares at Dec. 31, 2021		36,163
Beginning balance, value at Dec. 31, 2021	1,027,468	$ 36,163	394,903	596,402	0
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Net Income	34,420			34,420
Common stock dividends declared	(14,013)			(14,013)
Equity-based compensation plans and other	278		278
Ending balance, shares at Mar. 31, 2022		36,163
Ending balance, value at Mar. 31, 2022	$ 1,048,153	$ 36,163	$ 395,181	$ 616,809	$ 0

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Consolidated Statements of Common Equity (Unaudited) (Parentheticals) - $ / shares	3 Months Ended
	Mar. 31, 2022	Mar. 31, 2021
Dividends per share of common stock	$ 0.388	$ 0.370

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Madison Gas and Electric Company Consolidated Statements of Common Equity (Unaudited) - USD ($) shares in Thousands, $ in Thousands	Total	MGE [Member]	Common Stock [Member]	Common Stock [Member] MGE [Member]	Additional Paid-in Capital [Member] MGE [Member]	Retained Earnings [Member] MGE [Member]	Accumulated Other Comprehensive Income/(Loss) [Member] MGE [Member]	Noncontrolling Interest [Member] MGE [Member]
Beginning balance, shares at Dec. 31, 2020			36,163	17,348
Beginning balance, value at Dec. 31, 2020		$ 871,612		$ 17,348	$ 252,917	$ 460,151	$ 0	$ 141,196
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Net Income	$ 34,933	33,774				28,273		5,501
Cash dividends paid to parent by MGE		0
Distributions to parent from noncontrolling interest		(5,000)						(5,000)
Ending balance, shares at Mar. 31, 2021			36,163	17,348
Ending balance, value at Mar. 31, 2021		900,386		$ 17,348	252,917	488,424	0	141,697
Beginning balance, shares at Dec. 31, 2021			36,163	17,348
Beginning balance, value at Dec. 31, 2021		952,394		$ 17,348	252,917	533,542	0	148,587
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Net Income	$ 34,420	32,053				27,297		4,756
Cash dividends paid to parent by MGE		(5,000)				(5,000)
Distributions to parent from noncontrolling interest		(9,000)						(9,000)
Ending balance, shares at Mar. 31, 2022			36,163	17,348
Ending balance, value at Mar. 31, 2022		$ 970,447		$ 17,348	$ 252,917	$ 555,839	$ 0	$ 144,343

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Summary of Significant Accounting Policies

3 Months Ended

Mar. 31, 2022

Organization, Consolidation and Presentation of Financial Statements [Abstract]

Summary of Significant Accounting Principles

1.Summary of Significant Accounting Policies – MGE Energy and MGE.

a.Basis of Presentation.

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

MGE Power Elm Road and MGE Power West Campus own electric generating assets and lease those assets to MGE. Both entities are variable interest entities under applicable authoritative accounting guidance. MGE is considered the primary beneficiary of these entities as a result of contractual agreements. As a result, MGE has consolidated MGE Power Elm Road and MGE Power West Campus. See Footnote 3 of Notes to Consolidated Financial Statements under Item 8, Financial Statements and Supplementary Data, of MGE Energy's and MGE's 2021 Annual Report on Form 10-K (the 2021 Annual Report on Form 10-K).

The accompanying consolidated financial statements as of March 31, 2022, and during the three months ended March 31, 2022, are unaudited but include all adjustments that MGE Energy and MGE management consider necessary for a fair statement of their respective financial statements. All adjustments are of a normal, recurring nature except as otherwise disclosed. The year-end consolidated balance sheet information was derived from the audited balance sheet appearing in the 2021 Annual Report on Form 10-K but does not include all disclosures required by accounting principles generally accepted in the United States of America. These notes should be read in conjunction with the financial statements and the notes on pages 61 through 115 of the 2021 Annual Report on Form 10-K.

b.Cash, Cash Equivalents, and Restricted Cash.

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

	MGE Energy				MGE
	March 31,		December 31,		March 31,		December 31,
(In thousands)	2022		2021		2022		2021
Cash and cash equivalents	$	26,374	$	17,438	$	17,159	$	6,401
Restricted cash		641		847		641		847
Receivable - margin account		534		550		534		550
Cash, cash equivalents, and restricted cash	$	27,549	$	18,835	$	18,334	$	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.

c.Property, Plant, and Equipment.

Columbia.

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 by the end of 2023 and Unit 2 by the end of 2024. Final timing and retirement dates are subject to change depending on operational, regulatory, and other factors. As of March 31, 2022, early retirement of Columbia was probable.

The net book value of our ownership share of this generating unit was $156.7 million as of March 31, 2022. This amount was classified as plant to be retired within "Property, plant, and equipment, net" on the consolidated balance sheets. 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 and 2038 for Unit 2. MGE is currently seeking approval from the PSCW in its 2023 electric 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 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. No impairment was recorded as of March 31, 2022.

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New Accounting Standards

3 Months Ended

Mar. 31, 2022

Accounting Standards Update and Change in Accounting Principle [Abstract]

New Accounting Pronouncements

2.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 their consolidated results of operations, financial condition, or cash flows.

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Investment in ATC and ATC Holdco

3 Months Ended

Mar. 31, 2022

Equity Method Investments and Joint Ventures [Abstract]

Investment in ATC and ATC Holdco

3.Investment in ATC and ATC Holdco - MGE Energy and MGE.

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

MGE Transco and MGEE Transco have accounted for their investments 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. MGE Transco recorded the following amounts related to its investment in ATC:

	Three Months Ended
	March 31,
(In thousands)	2022		2021
Equity earnings from investment in ATC	$	2,478	$	2,420
Dividends received from ATC		2,001		1,967
Capital contributions to ATC		1,243		—

ATC Holdco was formed in December 2016. ATC Holdco's transmission development activities have been suspended for the near term.

In April 2022, MGE Transco made a $0.5 million capital contribution to ATC.

ATC's summarized financial data is as follows:

	Three Months Ended
	March 31,
(In thousands)	2022			2021
Operating revenues	$	190,999		$	188,694
Operating expenses		(95,491	)		(95,104	)
Other income, net		404			378
Interest expense, net		(28,440	)		(28,871	)
Earnings before members' income taxes	$	67,472		$	65,097

MGE receives transmission and other related services from ATC. During the three months ended March 31, 2022 and 2021, MGE recorded $7.9 million and $8.0 million, respectively, for transmission services. MGE also provides a variety of operational, maintenance, and project management work for ATC, which is reimbursed by ATC. As of March 31, 2022, and December 31, 2021, MGE had a receivable due from ATC of $8.1 million and $7.0 million, respectively. The receivable is primarily related to Badger Hollow I and II. MGE is reimbursed for these costs after the new generation assets are placed into service.

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Taxes

3 Months Ended

Mar. 31, 2022

Income Tax Disclosure [Abstract]

Taxes

4.Taxes - MGE Energy and MGE.

Effective Tax Rate.

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
Three Months Ended March 31,	2022				2021				2022				2021
Statutory federal income tax rate		21.0		%		21.0		%		21.0		%		21.0		%
State income taxes, net of federal benefit		6.3				6.3				6.3				6.3
Amortized investment tax credits		(0.7	)			(1.6	)			(0.8	)			(1.8	)
Credit for electricity from wind energy		(5.4	)			(7.1	)			(6.0	)			(7.8	)
AFUDC equity, net		(0.5	)			(0.6	)			(0.5	)			(0.6	)
Amortization of utility excess deferred tax - tax reform(a)		(1.9	)			(16.7	)			(1.8	)			(18.3	)
Other, net, individually insignificant		(0.2	)			—				(0.3	)			(0.1	)
Effective income tax rate		18.6		%		1.3		%		17.9		%		(1.3	)	%

(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 three months ended March 31, 2022 and 2021, MGE recognized $1.0 million and $0.7 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 three months ended March 31, 2021, MGE recognized $3.3 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 three months ended March 31, 2022, MGE recognized $0.3 million.

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Pension and Other Postretirement Plans

3 Months Ended

Mar. 31, 2022

Retirement Benefits [Abstract]

Pension and Other Postretirement Plans

5.Pension and Other Postretirement Plans - 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.

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.

The following table presents the components of net periodic benefit costs recognized.

	Three Months Ended
	March 31,
(In thousands)	2022			2021
Pension Benefits
Components of net periodic benefit cost:
Service cost	$	1,337		$	1,422
Interest cost		2,796			2,272
Expected return on assets		(7,851	)		(7,375	)
Amortization of:
Prior service credit		(5	)		(31	)
Actuarial loss		724			1,580
Net periodic benefit (credit) cost	$	(2,999	)	$	(2,132	)
Postretirement Benefits
Components of net periodic benefit cost:
Service cost	$	333		$	351
Interest cost		491			384
Expected return on assets		(843	)		(817	)
Amortization of:
Transition obligation		1			1
Prior service credit		(74	)		(380	)
Actuarial loss		48			109
Net periodic benefit (credit) cost	$	(44	)	$	(352	)

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. During the three months ended March 31, 2022 and 2021, MGE recovered $0.3 million and $3.4 million of pension and other postretirement costs, respectively. The recovery of these costs reduced the amount previously deferred and has not been reflected in the table above.

During the three months ended March 31, 2022, MGE returned $1.0 million of savings from 2021 employee benefit plan costs. The deferred savings has not been reflected in the table above.

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Equity and Financing Arrangements

3 Months Ended

Mar. 31, 2022

Equity and Financing Arrangements Disclosure [Abstract]

Equity and Financing Arrangements

6.Equity and Financing Arrangements.

a.Common Stock - MGE Energy.

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. All sales under the Stock Plan are covered by a shelf registration statement that MGE Energy filed with the SEC. During the three months ended March 31, 2022 and 2021, MGE Energy issued no new shares of common stock under the Stock Plan.

b.Dilutive Shares Calculation - MGE Energy.

As of March 31, 2022, 7,492 shares were included in the calculation of diluted earnings per share related to nonvested equity awards. See Footnote 7 for additional information on share-based compensation awards.

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Share-Based Compensation

3 Months Ended

Mar. 31, 2022

Share-based Payment Arrangement [Abstract]

Share-Based Compensation

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

During the three months ended March 31, 2022 and 2021, MGE recorded $0.4 million and $0.7 million, respectively, in compensation expense 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 Long-Term Incentive Plan (2021 Plan).

In January 2022, cash payments of $1.8 million were distributed related to awards that were granted in 2019, for the 2013 Director Incentive Plan, and in 2017, for the 2006 Performance Unit Plan.

In February 2022, MGE issued 10,395 performance units and 15,931 restricted stock units under the 2021 Plan to eligible employees and non-employee directors.

MGE recognizes stock-based compensation expense 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. The performance units can be paid out in either cash, shares of common stock or a combination of cash and stock and are classified as a liability award. The restricted stock units will be paid out in shares of common stock, and therefore are classified as equity awards.

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Commitments and Contingencies

3 Months Ended

Mar. 31, 2022

Commitments and Contingencies Disclosure [Abstract]

Commitments and Contingencies

8.Commitments and Contingencies.

a.Environmental - MGE Energy and MGE.

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 by the end of 2023 and Unit 2 by the end of 2024. Final timing and retirement dates are subject to change depending on operational, regulatory, and other factors. Effects of environmental compliance requirements discussed below will depend upon the final retirement dates approved and compliance requirement dates.

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 operations are conducted, the costs of operations, as well as capital and operating expenditures. Several of these environmental rules are subject to legal challenges, reconsideration and/or other uncertainties. Regulatory initiatives, proposed rules, and court challenges to adopted rules could have a material effect on capital expenditures and operating costs. Management believes compliance costs will be recovered in future rates based on previous treatment of environmental compliance projects.

These initiatives, proposed rules, and court challenges include:

•The EPA's 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.

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 estimated costs to comply with the rule is estimated to be approximately $4 million. Construction began in March 2022.

•The EPA's cooling water intake rules require cooling water intake structures at electric power plants to meet best technology available (BTA) standards to reduce the mortality from entrainment (drawing aquatic life into a plant's cooling system) and impingement (trapping aquatic life on screens).

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 by the end of 2022 and effective in 2023. Management believes that the BTA determination at Blount will not be material for MGE.

Columbia's river intakes are subject to this rule. BTA improvements may not be required given that the owners are planning to retire both units by the end of 2024. MGE will continue to work with Columbia's operator to evaluate all regulatory requirements applicable to the planned retirements. MGE does not expect this rule to have a material effect on its existing plants.

•Greenhouse Gas (GHG) reduction guidelines and approval criteria established under the Clean Air Act for states to use in developing plans to control GHG emissions from fossil fuel-fired electric generating units (EGUs), including existing and proposed regulations governing existing, new or modified fossil-fuel generating units.

In October 2021, as part of the Biden administration's Unified Agenda, the EPA announced their intention to introduce a new set of emission guidelines for states to follow in submitting state plans to establish and implement standards of performance for greenhouse gas emissions from existing fossil fuel-fired EGUs. In late 2021, the US Supreme Court agreed to hear arguments regarding the extent of EPA's authority to regulate greenhouse gases from electric generation units under the Clean Air Act. MGE will continue to evaluate greenhouse gas rule developments, including any further Supreme Court decisions on the EPA's authority to regulate greenhouse gases.

•The EPA's rule to regulate ambient levels of ozone through the 2015 Ozone National Ambient Air Quality Standards (NAAQS).

The Elm Road Units are located in Milwaukee County, Wisconsin, a nonattainment area. The Wisconsin Department of Natural Resources (WDNR) must develop a State Implementation Plan (SIP) for the area, which will likely result in more stringent requirements for both constructing new development and modifying or expanding existing plants in the area. 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, MGE does not expect that the 2015 Ozone NAAQS will have a material effect on its existing plants based on final designations.

•Rules regulating nitrogen oxide (NOx) and sulfur dioxide (SO2) emissions, including the Cross State Air Pollution Rule (CSAPR) and Clean Air Visibility Rule.

The EPA's CSAPR and its progeny are a suite of interstate air pollution transport rules designed to reduce ozone and fine particulate (PM2.5) 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 generally 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 State Implementation Plan (SIP) to meet its obligations or accept the EPA's proposed FIP.

MGE is currently evaluating the proposed rule to determine potential impacts to our business. 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.

MGE has met its current CSAPR obligations through a combination of reduced emissions through pollution control (e.g., SCR installation at Columbia), and owned, received, and purchased allowances. MGE expects to meet ongoing CSAPR obligations for the foreseeable future.

•The EPA's Coal Combustion Residuals Rule (CCR), which 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. Columbia requested an extension to initiate closure by October 2022. The EPA has not formally approved the extension. The Columbia owners anticipate that the EPA will approve the extension request. However, we will not know the outcome of the extension request with any certainty until the EPA makes a final decision on this request. In the interim, the EPA determined that the extension demonstration is complete and confirmed that the deadline to cease placement of CCR and non-CCR wastewaters in the primary pond is tolled pending a final decision.

Review of the Elm Road Units has indicated that the costs to comply with the CCR rule are not expected to be significant. 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. Pending the EPA’s final approval of closure plans at Columbia, MGE's share of the estimated costs of the project will be approximately $4 million. Construction is expected to be completed by the end of 2022.

b.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 accrues for 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 filed petitions against the PSCW regarding MGE's two most recent rate settlements. MGE has intervened in the petitions in cooperation with the PSCW. See Footnote 9.a. for more information regarding this matter.

c.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. The following table shows future commitments related to purchase contracts as of March 31, 2022:

(In thousands)	2022		2023		2024		2025		2026		Thereafter
Coal(a)	$	17,825	$	14,023	$	8,299	$	2,862	$	—	$	—

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

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Rate Matters

3 Months Ended

Mar. 31, 2022

Regulated Operations [Abstract]

Rate Matters

9.Rate Matters - MGE Energy and MGE.

a.Rate Proceedings.

In April 2022, MGE filed with the PSCW a proposed electric limited 2023 rate case reopener. The limited reopener proposes a 4.38% increase for electric rates in 2023. 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 a reduction in fuel costs, which MGE has partially offset with 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. PSCW approval of the 2023 limited reopener is pending. A final order is expected before the end of the year.

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 for gas rates in 2022. 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. As part of the settlement agreement, for 2023, the PSCW approved a 0.96% increase in gas rates and to address a potential electric rate change through a limited rate case reopener. The return on common stock equity for 2022 and 2023 is 9.8% based on a capital structure consisting of 55.6% common equity.

In December 2020, the PSCW approved a settlement agreement for MGE's 2021 rate case. The settlement agreement provided for a zero percent increase for electric rates and an approximately 4% increase for gas rates in 2021. 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. As part of the settlement, the fuel rules bandwidth was set at plus or minus 1% for 2021. When compared to the 2020 rate case, the settlement included lower forecasted electric sales for 2021 to reflect changes to customer usage during the COVID-19 pandemic. 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. The return on common stock equity for 2021 was 9.8% based on a capital structure of 55.8% common equity in 2021.

Sierra Club and Vote Solar have filed petitions with the Dane County Circuit Court seeking review of the PSCW decision approving MGE's two most recent rate settlements (2021 and 2022/2023). The PSCW is named as the responding party; MGE is not named as a party. The petitions challenge the process the PSCW used to approve the portion of the settlements relating to electric rates and the electric customer fixed charge that does not vary with usage. The requested relief is unclear. The revenue requirement approved by the PSCW in the settlements have not been challenged. The PSCW is expected to vigorously defend its approval of the rate case settlements. MGE has intervened in the proceedings to further defend the PSCW's decision.

b.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%. Under fuel rules, MGE defers costs, less any excess revenues, if its actual electric fuel costs exceed 101% of the electric fuel costs allowed in its latest rate order. Excess revenues are defined as revenues in the year in question that provide MGE with a greater return on common equity than authorized by the PSCW in MGE's latest rate order. Conversely, MGE is required to defer the benefit of lower costs if actual electric

fuel costs were less than 99% of the electric fuel costs allowed in that order. These costs are subject to the PSCW's annual review of fuel costs completed in the year following the deferral.

The PSCW issued a final decision in the 2019 fuel rules proceedings regarding $1.5 million of deferred savings giving MGE the option either to use the $1.5 million as part of the settlement to MGE's 2021 rate case or to refund the balance to customers in October 2020. MGE elected to include the savings as part of the 2021 rate change settlement as described above, reducing electric retail rates as opposed to a one-time credit back to retail customers. There was no change to the refund in the fuel rules proceedings from the amount MGE deferred in the previous year.

In September 2021, the PSCW issued a final decision in the 2020 fuel rules proceedings for MGE to refund $3.2 million of additional fuel savings realized during 2020 plus accrued interest to its retail electric customers over a one-month period in October 2021. There was no change to the refund in the fuel rules proceedings from the amount MGE deferred in the previous year.

MGE has under recovered fuel costs in 2021. As of December 31, 2021, MGE had deferred $3.3 million of 2021 fuel costs. These costs will be subject to the PSCW's annual review of 2021 fuel costs, expected to be completed in 2022. MGE has proposed to include these costs as part of the 2023 electric limited reopener.

As of March 31, 2022, MGE had no deferred 2022 fuel savings or costs.

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Derivative and Hedging Instruments

3 Months Ended

Mar. 31, 2022

Derivative Instruments and Hedging Activities Disclosure [Abstract]

Derivative and Hedging Instruments

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

a.Purpose.

As part of its regular operations, MGE enters into contracts, including options, swaps, futures, forwards, and other contractual commitments, to manage its exposure to commodity prices. To the extent that these contracts are derivatives, MGE assesses whether or not the normal purchases or normal sales exclusion applies. For contracts to which this exclusion cannot be applied, 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.

b.Notional Amounts.

The gross notional volume of open derivatives is as follows:

	March 31, 2022			December 31, 2021
Commodity derivative contracts		369,960	MWh		278,000	MWh
Commodity derivative contracts		3,260,000	Dth		5,735,000	Dth
FTRs		858	MW		2,127	MW
PPA		100	MW		250	MW

c.Financial Statement Presentation.

MGE purchases and sells exchange-traded and over-the-counter options, swaps, and future contracts. These arrangements are primarily entered into to help stabilize the price risk associated with gas or power purchases. These transactions are employed by both MGE's gas and electric segments. Additionally, as a result of the firm transmission agreements that MGE holds on electricity transmission paths in the MISO market, MGE holds 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 March 31, 2022, and December 31, 2021, the fair value of exchange traded derivatives and FTRs exceeded their cost basis by $9.8 million and $2.8 million, respectively.

MGE is a party to a purchased power agreement that provides MGE with firm capacity and energy during a base term from June 1, 2012, through May 31, 2022. The agreement is accounted for as a derivative contract and is recognized at its fair value on the consolidated balance sheets. However, the derivative qualifies for regulatory deferral and is recognized with a corresponding regulatory asset or liability depending on whether the fair value is in a loss or gain position. The fair value of the contract as of March 31, 2022, and December 31, 2021, reflected a loss position of $0.1 million and $2.1 million, respectively. The actual cost will be recognized in purchased power expense in the month of purchase.

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

	Derivative		Derivative
(In thousands)	Assets		Liabilities		Balance Sheet Location
March 31, 2022
Commodity derivative contracts(a)	$	9,518	$	325	Other current assets
Commodity derivative contracts(a)		626		32	Other deferred charges
FTRs(a)		—		16	Derivative liability (current)
PPA	N/A			130	Derivative liability (current)
December 31, 2021
Commodity derivative contracts(a)	$	2,959	$	811	Other current assets
Commodity derivative contracts(a)		420		38	Other deferred charges
FTRs		227		—	Other current assets
PPA	N/A			2,140	Derivative liability (current)

(a)As of March 31, 2022 and December 31, 2021, MGE received collateral of $6.9 million and $1.3 million, respectively, 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
March 31, 2022
Commodity derivative contracts	$	10,144	$	(357	)	$	(6,911	)	$	2,876
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
March 31, 2022
Commodity derivative contracts	$	357	$	(357	)	$	—		$	—
FTRs		16		—			(16	)		—
PPA		130		—			—			130
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
(In thousands)	Current and Long-Term Regulatory Asset (Liability)			Other Current Assets			Current and Long-Term Regulatory Asset (Liability)			Other Current Assets
Three Months Ended March 31:
Balance as of January 1,	$	(617	)	$	770		$	13,989		$	1,162
Unrealized gain		(11,333	)		—			(3,588	)		—
Realized gain (loss) reclassified to a deferred account		1,279			(1,279	)		(50	)		50
Realized gain (loss) reclassified to income statement		1,030			776			708			(1,039	)
Balance as of March 31,	$	(9,641	)	$	267		$	11,059		$	173

	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
Three Months Ended March 31:
Commodity derivative contracts	$	(312	)	$	(881	)	$	(195	)	$	1,022
FTRs		3			—			(256	)		—
PPA		(616	)		—			(240	)		—

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.

The PPA has a provision that may require MGE to post collateral if MGE's debt rating falls below investment grade (i.e., below BBB-). The amount of collateral that it may be required to post varies from $20.0 million to $40.0 million, depending on MGE's nominated capacity amount. As of March 31, 2022, no collateral was required to be, or had been, posted. Certain counterparties extend MGE a credit limit. If MGE exceeds these limits, the counterparties may require collateral to be posted. As of March 31, 2022 and December 31, 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 March 31, 2022, no counterparties had defaulted.

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Fair Value of Financial Instruments

3 Months Ended

Mar. 31, 2022

Fair Value Disclosures [Abstract]

Fair Value of Financial Instruments

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

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

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

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

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

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

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:

	March 31, 2022				December 31, 2021
(In thousands)	Carrying Amount		Fair Value		Carrying Amount		Fair Value
Long-term debt(a)		622,238		643,259		623,449		729,914

(a)Includes long-term debt due within one year. Excludes debt issuance costs and unamortized discount of $4.2 million and $4.3 million as of March 31, 2022, and December 31, 2021, respectively.

b.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 March 31, 2022
(In thousands)	Total		Level 1		Level 2		Level 3
MGE Energy
Assets:
Derivatives, net(b)	$	10,144	$	3,183	$	—	$	6,961
Exchange-traded investments		1,443		1,443		—		—
Total Assets	$	11,587	$	4,626	$	—	$	6,961
Liabilities:
Derivatives, net(b)	$	503	$	321	$	—	$	182
Deferred compensation		3,613		—		3,613		—
Total Liabilities	$	4,116	$	321	$	3,613	$	182
MGE
Assets:
Derivatives, net(b)	$	10,144	$	3,183	$	—	$	6,961
Exchange-traded investments		177		177		—		—
Total Assets	$	10,321	$	3,360	$	—	$	6,961
Liabilities:
Derivatives, net(b)	$	503	$	321	$	—	$	182
Deferred compensation		3,613		—		3,613		—
Total Liabilities	$	4,116	$	321	$	3,613	$	182

	Fair Value as of December 31, 2021
(In thousands)	Total		Level 1		Level 2		Level 3
MGE Energy
Assets:
Derivatives, net(b)	$	3,606	$	1,170	$	—	$	2,436
Exchange-traded investments		1,296		1,296		—		—
Total Assets	$	4,902	$	2,466	$	—	$	2,436
Liabilities:
Derivatives, net(b)	$	2,989	$	731	$	—	$	2,258
Deferred compensation		3,653		—		3,653		—
Total Liabilities	$	6,642	$	731	$	3,653	$	2,258
MGE
Assets:
Derivatives, net(b)	$	3,606	$	1,170	$	—	$	2,436
Exchange-traded investments		230		230		—		—
Total Assets	$	3,836	$	1,400	$	—	$	2,436
Liabilities:
Derivatives, net(b)	$	2,989	$	731	$	—	$	2,258
Deferred compensation		3,653		—		3,653		—
Total Liabilities	$	6,642	$	731	$	3,653	$	2,258

(b)As of March 31, 2022 and December 31, 2021 MGE received collateral of $6.9 million and $1.3 million, respectively, 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.

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 (see Footnote 10) was valued using an internal pricing model and therefore is classified as Level 3. The model projects future market energy prices and compares those prices to the projected power costs to be incurred under the contract. Inputs to the model require significant management judgment and estimation. Future energy prices are based on a forward power pricing curve using exchange-traded contracts in the electric futures market. A basis adjustment is applied to the market energy price to reflect the price differential between the market price delivery point and the counterparty delivery point. The historical relationship between the delivery points is reviewed and a discount (below 100%) or premium (above 100%) is derived. This comparison is done for both peak times when demand is high and off-peak times when demand is low. If the basis adjustment is lowered, the fair value measurement will decrease, and if the basis adjustment is increased, the fair value measurement will increase.

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

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

	Model Input
	March 31,	December 31,
Significant Unobservable Inputs	2022	2021
Basis adjustment:
On peak	92.1%	94.1%
Off peak	90.0%	92.4%
Counterparty fuel mix:
Internal generation - range	41%-66%	41%-66%
Internal generation - weighted average	49.5%	56.6%
Purchased power - range	59%-34%	59%-34%
Purchased power - weighted average	50.5%	43.4%

The following table summarizes the changes in Level 3 commodity derivative assets and liabilities measured at fair value on a recurring basis.

	Three Months Ended
	March 31,
(In thousands)	2022		2021
Beginning balance	$	178	$	(14,055)
Realized and unrealized gains (losses):
Included in regulatory assets		—		2,688
Included in regulatory liability		6,600		—
Included in other comprehensive income		—		—
Included in earnings		855		307
Included in current assets		73		355
Purchases		7,026		5,884
Sales		—		—
Issuances		—		—
Settlements		(7,953)		(6,546)
Balance as of March 31,	$	6,779	$	(11,367)
Total gains (losses) included in earnings attributed to    the change in unrealized gains (losses) related to    assets and liabilities held as of March 31,(c)	$	—	$	—

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(c).

	Three Months Ended
	March 31,
(In thousands)	2022		2021
Purchased power expense	$	973	$	702
Cost of gas sold expense		(118)		(395)
Total	$	855	$	307

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

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Joint Plant Ownership

3 Months Ended

Mar. 31, 2022

Public Utilities, Property, Plant and Equipment [Abstract]

Jointly Owned Electric Utility Plant

12.Joint Plant Construction Project Ownership - MGE Energy and MGE

MGE currently has ongoing jointly-owned solar generation construction projects, as shown in the following table. Incurred costs are reflected in "Construction work in progress" on the consolidated balance sheets.

	Ownership	Share of	Share of	Costs incurred as of March 31,	Estimated Date of Commercial
Project	Interest	Generation	Estimated Costs(a)	2022(a)	Operation
Red Barn(b)	10%	9.16 MW	$18 million	$0.6 million	December 2022
Badger Hollow II(c)	33%	50 MW	$65 million	$23.8 million(d)	First Half of 2023

(a)Excluding AFUDC.

(b)The Red Barn Wind Farm is located in the Towns of Wingville and Clifton in Grant County, Wisconsin.

(c)The Badger Hollow II solar farm is located in southwestern Wisconsin in Iowa County, near the villages of Montfort and Cobb.

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

MGE received specific approval to recover 100% AFUDC on Badger Hollow II. During the three months ended March 31, 2022 and 2021, MGE recognized $0.4 million and $0.1 million, respectively, after tax, in AFUDC for Badger Hollow II.

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Revenue

3 Months Ended

Mar. 31, 2022

Revenue from Contract with Customer [Abstract]

Revenue from Contract with Customer

13.Revenue - MGE Energy and MGE.

Revenues disaggregated by revenue source were as follows:

	Three Months Ended
(In thousands)	March 31,
Electric revenues	2022		2021
Residential	$	40,474	$	36,694
Commercial		54,449		47,883
Industrial		3,147		3,001
Other-retail/municipal		8,829		8,170
Total retail		106,899		95,748
Sales to the market		2,882		4,639
Other		308		222
Total electric revenues		110,089		100,609
Gas revenues
Residential		56,683		39,758
Commercial/Industrial		40,251		25,507
Total retail		96,934		65,265
Gas transportation		1,876		2,002
Other		1		3
Total gas revenues		98,811		67,270
Non-regulated energy revenues		38		36
Total Operating Revenue	$	208,938	$	167,915

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. The PSCW allows Wisconsin utilities to defer electric fuel-related costs, less excess revenues, that fall outside a symmetrical cost tolerance band. Any over- or under-recovery of the actual costs in a given year 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 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 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.

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Segment Information

3 Months Ended

Mar. 31, 2022

Segment Reporting [Abstract]

Segment Information

14.Segment Information - MGE Energy and MGE.

MGE Energy operates in the following business segments: electric utility, gas utility, nonregulated energy, transmission investment, and all other. See the 2021 Annual Report on Form 10-K for additional discussion of each of these segments.

(In thousands) MGE Energy	Electric		Gas		Non-Regulated Energy		Transmission Investment		All Others			Consolidation/ Elimination			Consolidated Total
Three Months Ended March 31, 2022
Operating revenues	$	110,089	$	98,811	$	38	$	—	$	—		$	—		$	208,938
Interdepartmental revenues		118		6,121		10,315		—		—			(16,554	)		—
Total operating revenues		110,207		104,932		10,353		—		—			(16,554	)		208,938
Equity in earnings of investments		—		—		—		2,504		—			—			2,504
Net income		14,617		12,084		5,352		1,822		545			—			34,420
Three Months Ended March 31, 2021
Operating revenues	$	100,609	$	67,270	$	36	$	—	$	—		$	—		$	167,915
Interdepartmental revenues		273		4,811		10,173		—		—			(15,257	)		—
Total operating revenues		100,882		72,081		10,209		—		—			(15,257	)		167,915
Equity in earnings of investments		—		—		—		2,444		—			—			2,444
Net income (loss)		18,024		10,556		5,194		1,778		(619	)		—			34,933

(In thousands) MGE	Electric		Gas		Non-Regulated Energy		Consolidation/ Elimination			Consolidated Total
Three Months Ended March 31, 2022
Operating revenues	$	110,089	$	98,811	$	38	$	—		$	208,938
Interdepartmental revenues		118		6,121		10,315		(16,554	)		—
Total operating revenues		110,207		104,932		10,353		(16,554	)		208,938
Net income attributable to MGE		14,617		12,084		5,352		(4,756	)		27,297
Three Months Ended March 31, 2021
Operating revenues	$	100,609	$	67,270	$	36	$	—		$	167,915
Interdepartmental revenues		273		4,811		10,173		(15,257	)		—
Total operating revenues		100,882		72,081		10,209		(15,257	)		167,915
Net income attributable to MGE		18,024		10,556		5,194		(5,501	)		28,273

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Significant Accounting Policies (Policies)

3 Months Ended

Mar. 31, 2022

Accounting Policies [Abstract]

Variable Interest Entities

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

Cash and Cash Equivalents

Cash Equivalents

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

Restricted Cash

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

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.

New Accounting Pronouncement Disclosure

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

Investments - ATC and ATC Holdco

MGE Transco and MGEE Transco have accounted for their investments in ATC and ATC Holdco, respectively, under the equity method of accounting.

Pension and Other Postretirement Benefit Plan Assets

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.

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.

Common Stock

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. All sales under the Stock Plan are covered by a shelf registration statement that MGE Energy filed with the SEC.

Wisconsin 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%. Under fuel rules, MGE defers costs, less any excess revenues, if its actual electric fuel costs exceed 101% of the electric fuel costs allowed in its latest rate order. Excess revenues are defined as revenues in the year in question that provide MGE with a greater return on common equity than authorized by the PSCW in MGE's latest rate order. Conversely, MGE is required to defer the benefit of lower costs if actual electric

fuel costs were less than 99% of the electric fuel costs allowed in that order. These costs are subject to the PSCW's annual review of fuel costs completed in the year following the deferral.

Derivative Hedging

As part of its regular operations, MGE enters into contracts, including options, swaps, futures, forwards, and other contractual commitments, to manage its exposure to commodity prices. To the extent that these contracts are derivatives, MGE assesses whether or not the normal purchases or normal sales exclusion applies. For contracts to which this exclusion cannot be applied, 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.

Derivative Netting

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

Recurring Fair Value Measurements

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

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

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

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

a.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.

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 (see Footnote 10) was valued using an internal pricing model and therefore is classified as Level 3. The model projects future market energy prices and compares those prices to the projected power costs to be incurred under the contract. Inputs to the model require significant management judgment and estimation. Future energy prices are based on a forward power pricing curve using exchange-traded contracts in the electric futures market. A basis adjustment is applied to the market energy price to reflect the price differential between the market price delivery point and the counterparty delivery point. The historical relationship between the delivery points is reviewed and a discount (below 100%) or premium (above 100%) is derived. This comparison is done for both peak times when demand is high and off-peak times when demand is low. If the basis adjustment is lowered, the fair value measurement will decrease, and if the basis adjustment is increased, the fair value measurement will increase.

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

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

	Model Input
	March 31,	December 31,
Significant Unobservable Inputs	2022	2021
Basis adjustment:
On peak	92.1%	94.1%
Off peak	90.0%	92.4%
Counterparty fuel mix:
Internal generation - range	41%-66%	41%-66%
Internal generation - weighted average	49.5%	56.6%
Purchased power - range	59%-34%	59%-34%
Purchased power - weighted average	50.5%	43.4%

Revenue Recognition

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. The PSCW allows Wisconsin utilities to defer electric fuel-related costs, less excess revenues, that fall outside a symmetrical cost tolerance band. Any over- or under-recovery of the actual costs in a given year 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 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 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.

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Summary of Significant Accounting Principles (Tables)

3 Months Ended

Mar. 31, 2022

Cash, Cash Equivalents, And Restricted Cash [Abstract]

Cash, Cash Equivalents, and Restricted Cash

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

	MGE Energy				MGE
	March 31,		December 31,		March 31,		December 31,
(In thousands)	2022		2021		2022		2021
Cash and cash equivalents	$	26,374	$	17,438	$	17,159	$	6,401
Restricted cash		641		847		641		847
Receivable - margin account		534		550		534		550
Cash, cash equivalents, and restricted cash	$	27,549	$	18,835	$	18,334	$	7,798

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Investment in ATC and ATC Holdco (Tables)

3 Months Ended

Mar. 31, 2022

Equity Method Investments and Joint Ventures [Abstract]

Equity Method Investments Financial Data

MGE Transco and MGEE Transco have accounted for their investments 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. MGE Transco recorded the following amounts related to its investment in ATC:

	Three Months Ended
	March 31,
(In thousands)	2022		2021
Equity earnings from investment in ATC	$	2,478	$	2,420
Dividends received from ATC		2,001		1,967
Capital contributions to ATC		1,243		—

ATC's summarized financial data is as follows:

	Three Months Ended
	March 31,
(In thousands)	2022			2021
Operating revenues	$	190,999		$	188,694
Operating expenses		(95,491	)		(95,104	)
Other income, net		404			378
Interest expense, net		(28,440	)		(28,871	)
Earnings before members' income taxes	$	67,472		$	65,097

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Taxes (Tables)

3 Months Ended

Mar. 31, 2022

Income Tax Disclosure [Abstract]

Effective Tax Rate Reconciliation

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
Three Months Ended March 31,	2022				2021				2022				2021
Statutory federal income tax rate		21.0		%		21.0		%		21.0		%		21.0		%
State income taxes, net of federal benefit		6.3				6.3				6.3				6.3
Amortized investment tax credits		(0.7	)			(1.6	)			(0.8	)			(1.8	)
Credit for electricity from wind energy		(5.4	)			(7.1	)			(6.0	)			(7.8	)
AFUDC equity, net		(0.5	)			(0.6	)			(0.5	)			(0.6	)
Amortization of utility excess deferred tax - tax reform(a)		(1.9	)			(16.7	)			(1.8	)			(18.3	)
Other, net, individually insignificant		(0.2	)			—				(0.3	)			(0.1	)
Effective income tax rate		18.6		%		1.3		%		17.9		%		(1.3	)	%

(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 three months ended March 31, 2022 and 2021, MGE recognized $1.0 million and $0.7 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 three months ended March 31, 2021, MGE recognized $3.3 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 three months ended March 31, 2022, MGE recognized $0.3 million.

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Pension and Other Postretirement Plans (Tables)

3 Months Ended

Mar. 31, 2022

Retirement Benefits [Abstract]

Schedule of Net Periodic Benefit Costs

The following table presents the components of net periodic benefit costs recognized.

	Three Months Ended
	March 31,
(In thousands)	2022			2021
Pension Benefits
Components of net periodic benefit cost:
Service cost	$	1,337		$	1,422
Interest cost		2,796			2,272
Expected return on assets		(7,851	)		(7,375	)
Amortization of:
Prior service credit		(5	)		(31	)
Actuarial loss		724			1,580
Net periodic benefit (credit) cost	$	(2,999	)	$	(2,132	)
Postretirement Benefits
Components of net periodic benefit cost:
Service cost	$	333		$	351
Interest cost		491			384
Expected return on assets		(843	)		(817	)
Amortization of:
Transition obligation		1			1
Prior service credit		(74	)		(380	)
Actuarial loss		48			109
Net periodic benefit (credit) cost	$	(44	)	$	(352	)

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Commitments and Contingencies (Tables)

3 Months Ended

Mar. 31, 2022

Commitments and Contingencies Disclosure [Abstract]

Contractual Obligation, Fiscal Year Maturity Schedule

The following table shows future commitments related to purchase contracts as of March 31, 2022:

(In thousands)	2022		2023		2024		2025		2026		Thereafter
Coal(a)	$	17,825	$	14,023	$	8,299	$	2,862	$	—	$	—

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

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Derivative and Hedging Instruments (Tables)

3 Months Ended

Mar. 31, 2022

Derivative Instruments and Hedging Activities Disclosure [Abstract]

Gross Notional Volume of Open Derivatives

The gross notional volume of open derivatives is as follows:

	March 31, 2022			December 31, 2021
Commodity derivative contracts		369,960	MWh		278,000	MWh
Commodity derivative contracts		3,260,000	Dth		5,735,000	Dth
FTRs		858	MW		2,127	MW
PPA		100	MW		250	MW

Fair Value of Derivative Instruments on the Balance Sheet

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

	Derivative		Derivative
(In thousands)	Assets		Liabilities		Balance Sheet Location
March 31, 2022
Commodity derivative contracts(a)	$	9,518	$	325	Other current assets
Commodity derivative contracts(a)		626		32	Other deferred charges
FTRs(a)		—		16	Derivative liability (current)
PPA	N/A			130	Derivative liability (current)
December 31, 2021
Commodity derivative contracts(a)	$	2,959	$	811	Other current assets
Commodity derivative contracts(a)		420		38	Other deferred charges
FTRs		227		—	Other current assets
PPA	N/A			2,140	Derivative liability (current)

(a)As of March 31, 2022 and December 31, 2021, MGE received collateral of $6.9 million and $1.3 million, respectively, 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.

Offsetting Assets

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

Offsetting of Derivative Assets

(In thousands)	Gross Amounts		Gross Amounts Offset in Balance Sheets			Collateral Posted Against Derivative Positions			Net Amount Presented in Balance Sheets
March 31, 2022
Commodity derivative contracts	$	10,144	$	(357	)	$	(6,911	)	$	2,876
December 31, 2021
Commodity derivative contracts	$	3,379	$	(849	)	$	(1,254	)	$	1,276
FTRs		227		—			—			227

Offsetting Liabilities

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
March 31, 2022
Commodity derivative contracts	$	357	$	(357	)	$	—		$	—
FTRs		16		—			(16	)		—
PPA		130		—			—			130
December 31, 2021
Commodity derivative contracts	$	849	$	(849	)	$	—		$	—
PPA		2,140		—			—			2,140

Derivative Gains and Losses in Balance Sheet

The following tables summarize the unrealized and realized gains/losses related to the derivative instruments on the consolidated balance sheets and the consolidated statements of income.

	2022						2021
(In thousands)	Current and Long-Term Regulatory Asset (Liability)			Other Current Assets			Current and Long-Term Regulatory Asset (Liability)			Other Current Assets
Three Months Ended March 31:
Balance as of January 1,	$	(617	)	$	770		$	13,989		$	1,162
Unrealized gain		(11,333	)		—			(3,588	)		—
Realized gain (loss) reclassified to a deferred account		1,279			(1,279	)		(50	)		50
Realized gain (loss) reclassified to income statement		1,030			776			708			(1,039	)
Balance as of March 31,	$	(9,641	)	$	267		$	11,059		$	173

Derivative Gains and Losses in Income Statement

	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
Three Months Ended March 31:
Commodity derivative contracts	$	(312	)	$	(881	)	$	(195	)	$	1,022
FTRs		3			—			(256	)		—
PPA		(616	)		—			(240	)		—

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Fair Value of Financial Instruments (Tables)

3 Months Ended

Mar. 31, 2022

Fair Value Disclosures [Abstract]

Estimated Fair Market Value of Financial Instruments

The estimated fair market value of financial instruments are as follows:

	March 31, 2022				December 31, 2021
(In thousands)	Carrying Amount		Fair Value		Carrying Amount		Fair Value
Long-term debt(a)		622,238		643,259		623,449		729,914

(a)Includes long-term debt due within one year. Excludes debt issuance costs and unamortized discount of $4.2 million and $4.3 million as of March 31, 2022, and December 31, 2021, respectively.

Assets and Liabilities Measured at Fair Value on a Recurring Basis

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

	Fair Value as of March 31, 2022
(In thousands)	Total		Level 1		Level 2		Level 3
MGE Energy
Assets:
Derivatives, net(b)	$	10,144	$	3,183	$	—	$	6,961
Exchange-traded investments		1,443		1,443		—		—
Total Assets	$	11,587	$	4,626	$	—	$	6,961
Liabilities:
Derivatives, net(b)	$	503	$	321	$	—	$	182
Deferred compensation		3,613		—		3,613		—
Total Liabilities	$	4,116	$	321	$	3,613	$	182
MGE
Assets:
Derivatives, net(b)	$	10,144	$	3,183	$	—	$	6,961
Exchange-traded investments		177		177		—		—
Total Assets	$	10,321	$	3,360	$	—	$	6,961
Liabilities:
Derivatives, net(b)	$	503	$	321	$	—	$	182
Deferred compensation		3,613		—		3,613		—
Total Liabilities	$	4,116	$	321	$	3,613	$	182

	Fair Value as of December 31, 2021
(In thousands)	Total		Level 1		Level 2		Level 3
MGE Energy
Assets:
Derivatives, net(b)	$	3,606	$	1,170	$	—	$	2,436
Exchange-traded investments		1,296		1,296		—		—
Total Assets	$	4,902	$	2,466	$	—	$	2,436
Liabilities:
Derivatives, net(b)	$	2,989	$	731	$	—	$	2,258
Deferred compensation		3,653		—		3,653		—
Total Liabilities	$	6,642	$	731	$	3,653	$	2,258
MGE
Assets:
Derivatives, net(b)	$	3,606	$	1,170	$	—	$	2,436
Exchange-traded investments		230		230		—		—
Total Assets	$	3,836	$	1,400	$	—	$	2,436
Liabilities:
Derivatives, net(b)	$	2,989	$	731	$	—	$	2,258
Deferred compensation		3,653		—		3,653		—
Total Liabilities	$	6,642	$	731	$	3,653	$	2,258

(b)As of March 31, 2022 and December 31, 2021 MGE received collateral of $6.9 million and $1.3 million, respectively, 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.

Significant Unobservable Inputs

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

	Model Input
	March 31,	December 31,
Significant Unobservable Inputs	2022	2021
Basis adjustment:
On peak	92.1%	94.1%
Off peak	90.0%	92.4%
Counterparty fuel mix:
Internal generation - range	41%-66%	41%-66%
Internal generation - weighted average	49.5%	56.6%
Purchased power - range	59%-34%	59%-34%
Purchased power - weighted average	50.5%	43.4%

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

The following table summarizes the changes in Level 3 commodity derivative assets and liabilities measured at fair value on a recurring basis.

	Three Months Ended
	March 31,
(In thousands)	2022		2021
Beginning balance	$	178	$	(14,055)
Realized and unrealized gains (losses):
Included in regulatory assets		—		2,688
Included in regulatory liability		6,600		—
Included in other comprehensive income		—		—
Included in earnings		855		307
Included in current assets		73		355
Purchases		7,026		5,884
Sales		—		—
Issuances		—		—
Settlements		(7,953)		(6,546)
Balance as of March 31,	$	6,779	$	(11,367)
Total gains (losses) included in earnings attributed to    the change in unrealized gains (losses) related to    assets and liabilities held as of March 31,(c)	$	—	$	—

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

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

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

	Three Months Ended
	March 31,
(In thousands)	2022		2021
Purchased power expense	$	973	$	702
Cost of gas sold expense		(118)		(395)
Total	$	855	$	307

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

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Joint Plant (Tables)

3 Months Ended

Mar. 31, 2022

Public Utilities, Property, Plant and Equipment [Abstract]

Schedule of Jointly Owned Utility Plants

MGE currently has ongoing jointly-owned solar generation construction projects, as shown in the following table. Incurred costs are reflected in "Construction work in progress" on the consolidated balance sheets.

	Ownership	Share of	Share of	Costs incurred as of March 31,	Estimated Date of Commercial
Project	Interest	Generation	Estimated Costs(a)	2022(a)	Operation
Red Barn(b)	10%	9.16 MW	$18 million	$0.6 million	December 2022
Badger Hollow II(c)	33%	50 MW	$65 million	$23.8 million(d)	First Half of 2023

(a)Excluding AFUDC.

(b)The Red Barn Wind Farm is located in the Towns of Wingville and Clifton in Grant County, Wisconsin.

(c)The Badger Hollow II solar farm is located in southwestern Wisconsin in Iowa County, near the villages of Montfort and Cobb.

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

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Revenue (Tables)

3 Months Ended

Mar. 31, 2022

Revenue from Contract with Customer [Abstract]

Disaggregation of Revenue

Revenues disaggregated by revenue source were as follows:

	Three Months Ended
(In thousands)	March 31,
Electric revenues	2022		2021
Residential	$	40,474	$	36,694
Commercial		54,449		47,883
Industrial		3,147		3,001
Other-retail/municipal		8,829		8,170
Total retail		106,899		95,748
Sales to the market		2,882		4,639
Other		308		222
Total electric revenues		110,089		100,609
Gas revenues
Residential		56,683		39,758
Commercial/Industrial		40,251		25,507
Total retail		96,934		65,265
Gas transportation		1,876		2,002
Other		1		3
Total gas revenues		98,811		67,270
Non-regulated energy revenues		38		36
Total Operating Revenue	$	208,938	$	167,915

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Segment Information (Tables)

3 Months Ended

Mar. 31, 2022

Segment Reporting [Abstract]

Segment Information

(In thousands) MGE Energy	Electric		Gas		Non-Regulated Energy		Transmission Investment		All Others			Consolidation/ Elimination			Consolidated Total
Three Months Ended March 31, 2022
Operating revenues	$	110,089	$	98,811	$	38	$	—	$	—		$	—		$	208,938
Interdepartmental revenues		118		6,121		10,315		—		—			(16,554	)		—
Total operating revenues		110,207		104,932		10,353		—		—			(16,554	)		208,938
Equity in earnings of investments		—		—		—		2,504		—			—			2,504
Net income		14,617		12,084		5,352		1,822		545			—			34,420
Three Months Ended March 31, 2021
Operating revenues	$	100,609	$	67,270	$	36	$	—	$	—		$	—		$	167,915
Interdepartmental revenues		273		4,811		10,173		—		—			(15,257	)		—
Total operating revenues		100,882		72,081		10,209		—		—			(15,257	)		167,915
Equity in earnings of investments		—		—		—		2,444		—			—			2,444
Net income (loss)		18,024		10,556		5,194		1,778		(619	)		—			34,933

(In thousands) MGE	Electric		Gas		Non-Regulated Energy		Consolidation/ Elimination			Consolidated Total
Three Months Ended March 31, 2022
Operating revenues	$	110,089	$	98,811	$	38	$	—		$	208,938
Interdepartmental revenues		118		6,121		10,315		(16,554	)		—
Total operating revenues		110,207		104,932		10,353		(16,554	)		208,938
Net income attributable to MGE		14,617		12,084		5,352		(4,756	)		27,297
Three Months Ended March 31, 2021
Operating revenues	$	100,609	$	67,270	$	36	$	—		$	167,915
Interdepartmental revenues		273		4,811		10,173		(15,257	)		—
Total operating revenues		100,882		72,081		10,209		(15,257	)		167,915
Net income attributable to MGE		18,024		10,556		5,194		(5,501	)		28,273

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Summary of Significant Accounting Principles (Details-1) - USD ($) $ in Thousands	Mar. 31, 2022	Dec. 31, 2021	Mar. 31, 2021	Dec. 31, 2020
Cash Cash Equivalents And Restricted Cash [Line Items]
Cash and cash equivalents	$ 26,374	$ 17,438
Restricted cash	641	847
Receivable - margin account	534	550
Cash, cash equivalents, and restricted cash	27,549	18,835	$ 41,502	$ 47,039
MGE [Member]
Cash Cash Equivalents And Restricted Cash [Line Items]
Cash and cash equivalents	17,159	6,401
Restricted cash	641	847
Receivable - margin account	534	550
Cash, cash equivalents, and restricted cash	$ 18,334	$ 7,798	$ 7,972	$ 6,404

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Summary of Significant Accounting Principles (Details-2) - Columbia Units [Member] $ in Millions	3 Months Ended
	Mar. 31, 2022 USD ($)
Jointly Owned Utility Plant Interests [Line Items]
Net book value of property, plant, and equipment	$ 156.7
Impairment of Long-Lived Assets
Impairment of long-lived assets	$ 0.0

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Investment in ATC and ATC Holdco (Details-1) - USD ($) $ in Thousands	1 Months Ended	3 Months Ended
	Apr. 30, 2022	Mar. 31, 2022	Mar. 31, 2021
Schedule of Equity Method Investments [Line Items]
Equity earnings from investment		$ 2,504	$ 2,444
Dividends from investment		2,001	1,967
Capital contributions to investments		1,546	670
MGE Transco [Member] | ATC [Member]
Schedule of Equity Method Investments [Line Items]
Equity earnings from investment		2,478	2,420
Dividends from investment		2,001	1,967
Capital contributions to investments		$ 1,243	$ 0
MGE Transco [Member] | ATC [Member] | Subsequent Event [Member]
Schedule of Equity Method Investments [Line Items]
Capital contributions to investments	$ 500

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Investment in ATC and ATC Holdco (Details-2) - ATC [Member] - USD ($) $ in Thousands	3 Months Ended
	Mar. 31, 2022	Mar. 31, 2021
Schedule of Equity Method Investments [Line Items]
Operating revenues	$ 190,999	$ 188,694
Operating expenses	(95,491)	(95,104)
Other income, net	404	378
Interest expense, net	(28,440)	(28,871)
Earnings before members' income taxes	$ 67,472	$ 65,097

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Investment in ATC and ATC Holdco (Details-3) - ATC [Member] - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2022	Mar. 31, 2021	Dec. 31, 2021
Related Party Transaction [Line Items]
Related party expenses	$ 7.9	$ 8.0
Due from related parties	$ 8.1		$ 7.0

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Taxes (Details) - USD ($) $ in Millions		3 Months Ended
		Mar. 31, 2022	Mar. 31, 2021
Effective Income Tax Rate Reconciliation, Percent [Abstract]
Statutory federal income tax rate		21.00%	21.00%
State income taxes, net of federal benefit		6.30%	6.30%
Amortized investment tax credits		(0.70%)	(1.60%)
Credit for electricity from wind energy		(5.40%)	(7.10%)
AFUDC equity, net		(0.50%)	(0.60%)
Amortization of utility excess deferred tax - tax reform	[1]	(1.90%)	(16.70%)
Other, net, individually significant		(0.20%)	0.00%
Effective income tax rate		18.60%	1.30%
Excess Deferred Taxes, Tax Cuts And Jobs Act [Member]
Effects Of The Tax Cuts And Jobs Act [Abstract]
Excess deferred tax - Income statement effect		$ 1.0	$ 0.7
Return of unprotected excess deferred taxes			$ 3.3
Deficient Deferred Taxes, Tax Cuts And Jobs Act [Member]
Effects Of The Tax Cuts And Jobs Act [Abstract]
Collection of unprotected deficient deferred taxes		$ 0.3
MGE [Member]
Effective Income Tax Rate Reconciliation, Percent [Abstract]
Statutory federal income tax rate		21.00%	21.00%
State income taxes, net of federal benefit		6.30%	6.30%
Amortized investment tax credits		(0.80%)	(1.80%)
Credit for electricity from wind energy		(6.00%)	(7.80%)
AFUDC equity, net		(0.50%)	(0.60%)
Amortization of utility excess deferred tax - tax reform	[1]	(1.80%)	(18.30%)
Other, net, individually significant		(0.30%)	(0.10%)
Effective income tax rate		17.90%	(1.30%)

[1] 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 three months ended March 31, 2022 and 2021, MGE recognized $1.0 million and $0.7 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 three months ended March 31, 2021, MGE recognized $3.3 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 three months ended March 31, 2022, MGE recognized $0.3 million.

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Pension and Other Postretirement Plans (Details) - USD ($) $ in Thousands	3 Months Ended
	Mar. 31, 2022	Mar. 31, 2021
Defined Benefit Plan Deferred Pension And Other Postretirement Benefit Plan Costs Recovered [Abstract]
Deferred (recognized) pension and OPEB costs	$ (300)	$ (3,400)
Returned Savings From Prior Year Employee Benefit Costs	1,000
Pension Benefits [Member]
Components of net periodic benefit cost:
Service cost	1,337	1,422
Interest cost	2,796	2,272
Expected return on assets	(7,851)	(7,375)
Amortization of:
Prior service credit	(5)	(31)
Actuarial loss	724	1,580
Net periodic benefit (credit) cost	(2,999)	(2,132)
Postretirement Benefits [Member]
Components of net periodic benefit cost:
Service cost	333	351
Interest cost	491	384
Expected return on assets	(843)	(817)
Amortization of:
Transition obligation	1	1
Prior service credit	(74)	(380)
Actuarial loss	48	109
Net periodic benefit (credit) cost	$ (44)	$ (352)

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Equity and Financing Arrangements (Details) - shares	3 Months Ended
	Mar. 31, 2022	Mar. 31, 2021
Common Stock [Abstract]
Common stock issued during period under the stock plan	0	0
Dilutive Shares Calculation [Abstract]
Shares included in diluted earnings per share	7,492

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Share Based Compensation (Details) - USD ($) $ in Millions		1 Months Ended	3 Months Ended
	Feb. 18, 2022	Jan. 31, 2022	Mar. 31, 2022	Mar. 31, 2021
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Compensation expense (benefit)			$ 0.4	$ 0.7
2021 Long Term Incentive Plan [Member] | Performance Shares [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Grants in Period	10,395
2021 Long Term Incentive Plan [Member] | Restricted Units [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Grants in Period	15,931
2006 Performance Unit Plan and 2013 Director Incentive Plan [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Cash payments distributed related to awards previously granted and now payable		$ 1.8

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Commitments and Contingencies (Details-1) $ in Millions	Mar. 31, 2022 USD ($)
Columbia Units [Member]
Public Utilities, General Disclosures [Line Items]
Projected Costs For Environmental Regulation	$ 4
Elm Road Units [Member]
Public Utilities, General Disclosures [Line Items]
Projected Costs For Environmental Regulation	$ 4

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Commitments and Contingencies (Details-2) - Coal [Member] $ in Thousands	Mar. 31, 2022 USD ($)	[1]
Operating expense purchase contracts [Abstract]
Purchase obligation, 2022	$ 17,825
Purchase obligation, 2023	14,023
Purchase obligation, 2024	8,299
Purchase obligation, 2025	2,862
Purchase obligation, 2026	0
Purchase obligation, Thereafter	$ 0

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

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Rate Matters (Details) - USD ($) $ in Thousands	1 Months Ended	3 Months Ended	12 Months Ended
	Oct. 31, 2021	Mar. 31, 2022	Dec. 31, 2023	Dec. 31, 2021	Dec. 31, 2019
Fuel Rules [Abstract]
Deferred fuel rules monitored costs		$ 0		$ (3,300)	$ 1,500
PSCW [Member] | MGE [Member]
Rate Proceedings [Abstract]
Authorized return on equity, percentage		9.80%		9.80%
Approved equity capital structure, percentage		55.60%		55.80%
Fuel Rules [Abstract]
Fuel rules, bandwidth		1.00%		1.00%
Fuel rules, electric fuel deferred costs upper threshold		101.00%
Fuel rules, electric fuel deferred costs lower threshold		99.00%
PSCW [Member] | MGE [Member] | Fuel Rules Refund, 2020 [Member]
Fuel Rules [Abstract]
Return of electric fuel credit, total	$ 3,200
PSCW [Member] | Rate Matters For Future Periods [Member] | MGE [Member]
Rate Proceedings [Abstract]
Authorized return on equity, percentage			9.80%
Approved equity capital structure, percentage			55.60%
Electric Rate Proceeding [Member] | PSCW [Member] | MGE [Member]
Rate Proceedings [Abstract]
Authorized rate increase (decrease), percentage		8.81%		0.00%
Effects Of The Tax Cuts And Jobs Act [Abstract]
Return of unprotected excess deferred taxes				$ 18,200
Electric Rate Proceeding [Member] | PSCW [Member] | Rate Matters For Future Periods [Member] | MGE [Member]
Rate Proceedings [Abstract]
Proposed rate increase (decrease), percentage			4.38%
Gas Rate Proceeding [Member] | PSCW [Member] | MGE [Member]
Rate Proceedings [Abstract]
Authorized rate increase (decrease), percentage		2.15%		4.00%
Gas Rate Proceeding [Member] | PSCW [Member] | Rate Matters For Future Periods [Member] | MGE [Member]
Rate Proceedings [Abstract]
Authorized rate increase (decrease), percentage			0.96%

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Derivative and Hedging Instruments (Details-1) $ in Thousands		3 Months Ended	12 Months Ended
		Mar. 31, 2022 USD ($) Dth1 MWh MW	Dec. 31, 2021 USD ($) Dth1 MWh MW	Mar. 31, 2021 USD ($)	Dec. 31, 2020 USD ($)
Derivative fair values [Abstract]
Collateral posted against derivative positions		$ 6,900	$ 1,300
Other Current Assets [Member]
Derivative fair values [Abstract]
Derivative, Fair Value, Net		267	770	$ 173	$ 1,162
Commodity Contracts And Financial Transimission Rights [Member]
Derivative fair values [Abstract]
Derivative, Fair Value, Net		$ 9,800	$ 2,800
Commodity Contract [Member]
Gross Notional Volume of Open Derivatives [Abstract]
Notional amount, energy measures (in MWh) | MWh		369,960	278,000
Notional amount, decatherm measure (in Dth) | Dth1		3,260,000	5,735,000
Derivative fair values [Abstract]
Derivative Asset, Fair Value, Gross Asset		$ 10,144	$ 3,379
Derivative Liability, Fair Value, Gross Liability		357	849
Collateral posted against derivative positions		6,911	1,254
Commodity Contract [Member] | Other Current Assets [Member]
Derivative fair values [Abstract]
Derivative Asset, Fair Value, Gross Asset	[1]	9,518	2,959
Derivative Liability, Fair Value, Gross Liability	[1]	325	811
Commodity Contract [Member] | Other Deferred Charges [Member]
Derivative fair values [Abstract]
Derivative Asset, Fair Value, Gross Asset	[1]	626	420
Derivative Liability, Fair Value, Gross Liability	[1]	32	38
Commodity Contract [Member] | Cash Flow Hedging [Member]
Derivative fair values [Abstract]
Collateral posted against derivative positions		$ 6,900	$ 1,300
Energy Related Commodity Contract [Member] | Cash Flow Hedging [Member]
Derivatives, Fair Value [Line Items]
Maximum term of derivative hedging contract		4 years
Financial Transmission Rights [Member]
Gross Notional Volume of Open Derivatives [Abstract]
Notional amount, power measure (in MW) | MW		858	2,127
Derivative fair values [Abstract]
Derivative Asset, Fair Value, Gross Asset			$ 227
Derivative Liability, Fair Value, Gross Liability		$ 16
Collateral posted against derivative positions			0
Financial Transmission Rights [Member] | Other Current Assets [Member]
Derivative fair values [Abstract]
Derivative Asset, Fair Value, Gross Asset			227
Derivative Liability, Fair Value, Gross Liability			$ 0
Financial Transmission Rights [Member] | Derivative Liability (Current) [Member]
Derivative fair values [Abstract]
Derivative Asset, Fair Value, Gross Asset	[1]	0
Derivative Liability, Fair Value, Gross Liability	[1]	$ 16
PPA [Member]
Gross Notional Volume of Open Derivatives [Abstract]
Notional amount, power measure (in MW) | MW		100	250
Derivative fair values [Abstract]
Derivative, Fair Value, Net		$ (100)	$ (2,100)
Derivative Liability, Fair Value, Gross Liability		130	2,140
PPA [Member] | Derivative Liability (Current) [Member]
Derivative fair values [Abstract]
Derivative Liability, Fair Value, Gross Liability		$ 130	$ 2,140

[1] As of March 31, 2022 and December 31, 2021, MGE received collateral of $6.9 million and $1.3 million, respectively, 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.

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Derivative and Hedging Instruments (Details-2) - USD ($) $ in Thousands	Mar. 31, 2022	Dec. 31, 2021
Offsetting Assets [Line Items]
Collateral posted against derivative positions	$ (6,900)	$ (1,300)
Commodity Contract [Member]
Offsetting Assets [Line Items]
Gross amounts	10,144	3,379
Gross amounts offset in balance sheet	(357)	(849)
Collateral posted against derivative positions	(6,911)	(1,254)
Net amount presented in balance sheet	$ 2,876	1,276
Financial Transmission Rights [Member]
Offsetting Assets [Line Items]
Gross amounts		227
Gross amounts offset in balance sheet		0
Collateral posted against derivative positions		0
Net amount presented in balance sheet		$ 227

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Derivative and Hedging Instruments (Details-3) - USD ($) $ in Thousands	Mar. 31, 2022	Dec. 31, 2021
Commodity Contract [Member]
Offsetting Liabilities [Line Items]
Gross amounts	$ 357	$ 849
Gross amounts offset in balance sheet	(357)	(849)
Collateral posted against derivative positions	0	0
Net amount presented in balance sheet	0	0
Financial Transmission Rights [Member]
Offsetting Liabilities [Line Items]
Gross amounts	16
Gross amounts offset in balance sheet	0
Collateral posted against derivative positions	(16)
Net amount presented in balance sheet	0
Purchased Power Agreement [Member]
Offsetting Liabilities [Line Items]
Gross amounts	130	2,140
Gross amounts offset in balance sheet	0	0
Collateral posted against derivative positions	0	0
Net amount presented in balance sheet	$ 130	$ 2,140

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Derivative and Hedging Instruments (Details-4) - USD ($) $ in Thousands	3 Months Ended
	Mar. 31, 2022	Mar. 31, 2021
Current and Long-Term Regulatory Asset (Liability) [Member]
Change In Derivative Fair Value [Roll Forward]
Beginning balance,	$ (617)	$ 13,989
Unrealized gain	(11,333)	(3,588)
Realized (loss) gain reclassified to a deferred account	1,279	(50)
Realized (loss) gain reclassified to income statement	1,030	708
Ending balance,	(9,641)	11,059
Other Current Assets [Member]
Change In Derivative Fair Value [Roll Forward]
Beginning balance,	770	1,162
Unrealized gain	0	0
Realized (loss) gain reclassified to a deferred account	(1,279)	50
Realized (loss) gain reclassified to income statement	776	(1,039)
Ending balance,	$ 267	$ 173

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Derivative and Hedging Instruments (Details-5) $ in Thousands	3 Months Ended
	Mar. 31, 2022 USD ($) Counterparty	Mar. 31, 2021 USD ($)	Dec. 31, 2021 USD ($)
Counterparties in net liability position or default [Abstract]
Derivative, net liability position of counterparties	$ 0		$ 0
Number of counterparties in default | Counterparty	0
Commodity Contract [Member] | Fuel For Electric Generation Purchased Power [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Realized losses (gains) on income statement	$ (312)	$ (195)
Commodity Contract [Member] | Cost Of Gas Sold Expense [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Realized losses (gains) on income statement	(881)	1,022
Financial Transmission Rights [Member] | Fuel For Electric Generation Purchased Power [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Realized losses (gains) on income statement	3	(256)
Financial Transmission Rights [Member] | Cost Of Gas Sold Expense [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Realized losses (gains) on income statement	0	0
Purchased Power Agreement [Member]
Derivative collateral required to be posted for PPA [Abstract]
Minimum collateral that may be required to be posted	20,000
Maximum collateral that may be required to be posted	40,000
Collateral Already Posted, Aggregate Fair Value	0
Purchased Power Agreement [Member] | Fuel For Electric Generation Purchased Power [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Realized losses (gains) on income statement	(616)	(240)
Purchased Power Agreement [Member] | Cost Of Gas Sold Expense [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Realized losses (gains) on income statement	$ 0	$ 0

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Fair Value of Financial Instruments (Details-1) - USD ($) $ in Thousands		Mar. 31, 2022	Dec. 31, 2021
Liabilities:
Unamortized discount and debt issuance costs, net		$ 4,200	$ 4,300
Carrying Amount [Member]
Liabilities:
Long-term debt	[1]	622,238	623,449
Fair Value [Member]
Liabilities:
Long-term debt	[1]	$ 643,259	$ 729,914

[1] Includes long-term debt due within one year. Excludes debt issuance costs and unamortized discount of $4.2 million and $4.3 million as of March 31, 2022, and December 31, 2021, respectively.

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Fair Value of Financial Instruments (Details-2) - USD ($) $ in Thousands		Mar. 31, 2022	Dec. 31, 2021
Assets:
Collateral posted against derivative positions		$ 6,900	$ 1,300
Recurring [Member]
Assets:
Derivative assets, net	[1]	10,144	3,606
Exchange-traded investments		1,443	1,296
Total Assets		11,587	4,902
Liabilities:
Derivative liabilities, net	[1]	503	2,989
Deferred compensation		3,613	3,653
Total liabilities		4,116	6,642
Recurring [Member] | Level 1 [Member]
Assets:
Derivative assets, net	[1]	3,183	1,170
Exchange-traded investments		1,443	1,296
Total Assets		4,626	2,466
Liabilities:
Derivative liabilities, net	[1]	321	731
Deferred compensation		0	0
Total liabilities		321	731
Recurring [Member] | Level 2 [Member]
Assets:
Derivative assets, net	[1]	0	0
Exchange-traded investments		0	0
Total Assets		0	0
Liabilities:
Derivative liabilities, net	[1]	0	0
Deferred compensation		3,613	3,653
Total liabilities		3,613	3,653
Recurring [Member] | Level 3 [Member]
Assets:
Derivative assets, net	[1]	6,961	2,436
Exchange-traded investments		0	0
Total Assets		6,961	2,436
Liabilities:
Derivative liabilities, net	[1]	182	2,258
Deferred compensation		0	0
Total liabilities		182	2,258
MGE [Member] | Recurring [Member]
Assets:
Derivative assets, net	[1]	10,144	3,606
Exchange-traded investments		177	230
Total Assets		10,321	3,836
Liabilities:
Derivative liabilities, net	[1]	503	2,989
Deferred compensation		3,613	3,653
Total liabilities		4,116	6,642
MGE [Member] | Recurring [Member] | Level 1 [Member]
Assets:
Derivative assets, net	[1]	3,183	1,170
Exchange-traded investments		177	230
Total Assets		3,360	1,400
Liabilities:
Derivative liabilities, net	[1]	321	731
Deferred compensation		0	0
Total liabilities		321	731
MGE [Member] | Recurring [Member] | Level 2 [Member]
Assets:
Derivative assets, net	[1]	0	0
Exchange-traded investments		0	0
Total Assets		0	0
Liabilities:
Derivative liabilities, net	[1]	0	0
Deferred compensation		3,613	3,653
Total liabilities		3,613	3,653
MGE [Member] | Recurring [Member] | Level 3 [Member]
Assets:
Derivative assets, net	[1]	6,961	2,436
Exchange-traded investments		0	0
Total Assets		6,961	2,436
Liabilities:
Derivative liabilities, net	[1]	182	2,258
Deferred compensation		0	0
Total liabilities		$ 182	$ 2,258

[1] As of March 31, 2022 and December 31, 2021 MGE received collateral of $6.9 million and $1.3 million, respectively, 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.

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Fair Value of Financial Instruments (Details-3)	3 Months Ended	12 Months Ended
	Mar. 31, 2022	Dec. 31, 2021
Basis adjustment:
Basis adjustment - on peak	92.10%	94.10%
Basis adjustment - off peak	90.00%	92.40%
US Treasury Bills [Member]
Deferred compensation plan [Abstract]
Investment interest calculation, investment maturity period (26 weeks)	182 days
Investment interest calculation, monthly compounding rate	1.00%
Investment interest calculation, minimum annual rate compounded monthly	7.00%
Minimum [Member]
Counterparty fuel mix:
Internal generation	41.00%	41.00%
Purchased power	34.00%	34.00%
Maximum [Member]
Counterparty fuel mix:
Internal generation	66.00%	66.00%
Purchased power	59.00%	59.00%
Weighted Average [Member]
Counterparty fuel mix:
Internal generation	49.50%	56.60%
Purchased power	50.50%	43.40%

XML

Fair Value of Financial Instruments (Details-4) - USD ($) $ in Thousands		3 Months Ended
		Mar. 31, 2022	Mar. 31, 2021
Fair Value, Net Derivative Asset (Liability) Measured on Recurring Basis, Unobservable Input Reconciliation [Roll Forward]
Beginning balance,		$ 178	$ (14,055)
Realized and unrealized gains (losses):
Included in regulatory assets		0	2,688
Included in regulatory liability		6,600	0
Included in other comprehensive income		0	0
Included in earnings	[1]	855	307
Included in current assets		73	355
Purchases		7,026	5,884
Sales		0	0
Issuances		0	0
Settlements		(7,953)	(6,546)
Ending balance,		$ 6,779	$ (11,367)

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

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Fair Value of Financial Instruments (Details-5) - USD ($) $ in Thousands		3 Months Ended
		Mar. 31, 2022	Mar. 31, 2021
Fair Value Disclosures [Abstract]
Total gains (losses) included in earnings attributed to the change in unrealized gains (losses) related to assets and liabilities	[1]	$ 0	$ 0
Fair Value, Net Derivative Asset (Liability) Measured on Recurring Basis, Unobservable Input Reconciliation [Line Items]
Included in earnings	[1]	855	307
Purchased Power Expense [Member]
Fair Value, Net Derivative Asset (Liability) Measured on Recurring Basis, Unobservable Input Reconciliation [Line Items]
Included in earnings		973	702
Cost Of Gas Sold Expense [Member]
Fair Value, Net Derivative Asset (Liability) Measured on Recurring Basis, Unobservable Input Reconciliation [Line Items]
Included in earnings		$ (118)	$ (395)

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

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Joint Plant Ownership (Details) $ in Millions		3 Months Ended
		Mar. 31, 2022 USD ($) MW	Mar. 31, 2021 USD ($)
Red Barn Units [Member]
Jointly Owned Utility Plant Interests [Line Items]
Projected Solar Farm Project Costs	[1],[2]	$ 18.0
Public Utilities, Property, Plant and Equipment, Construction Work in Progress	[1],[2]	$ 0.6
Red Barn Units [Member] | MGE [Member]
Jointly Owned Utility Plant Interests [Line Items]
Jointly owned utility plant, ownership interest	[2]	10.00%
Jointly owned utility plant, plant capacity (in MW) | MW	[2]	9.16
Badger Hollow II Units [Member]
Jointly Owned Utility Plant Interests [Line Items]
Projected Solar Farm Project Costs	[1],[3]	$ 65.0
Public Utilities, Property, Plant and Equipment, Construction Work in Progress	[1],[3],[4]	23.8
Allowance for Funds Used During Construction
AFUDC		$ 0.4	$ 0.1
Badger Hollow II Units [Member] | Public Service Commission of Wisconsin [Member]
Allowance for Funds Used During Construction
Authorized AFUDC rate - Signficiant projects (100%)		100.00%
Badger Hollow II Units [Member] | MGE [Member]
Jointly Owned Utility Plant Interests [Line Items]
Jointly owned utility plant, ownership interest	[3]	33.00%
Jointly owned utility plant, plant capacity (in MW) | MW	[3]	50

[1] Excluding AFUDC.

[2] The Red Barn Wind Farm is located in the Towns of Wingville and Clifton in Grant County, Wisconsin.

[3] The Badger Hollow II solar farm is located in southwestern Wisconsin in Iowa County, near the villages of Montfort and Cobb.

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

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Revenue (Details-1) - USD ($) $ in Thousands	3 Months Ended
	Mar. 31, 2022	Mar. 31, 2021
Total Operating Revenue [Member]
Disaggregation of Revenue [Line Items]
Revenues recognized from contracts with customers	$ 208,938	$ 167,915
Electric [Member]
Disaggregation of Revenue [Line Items]
Revenues recognized from contracts with customers	110,089	100,609
Electric [Member] | Residential [Member]
Disaggregation of Revenue [Line Items]
Revenues recognized from contracts with customers	40,474	36,694
Electric [Member] | Commercial [Member]
Disaggregation of Revenue [Line Items]
Revenues recognized from contracts with customers	54,449	47,883
Electric [Member] | Industrial [Member]
Disaggregation of Revenue [Line Items]
Revenues recognized from contracts with customers	3,147	3,001
Electric [Member] | Other-retail/municipal
Disaggregation of Revenue [Line Items]
Revenues recognized from contracts with customers	8,829	8,170
Electric [Member] | Total Retail [Member]
Disaggregation of Revenue [Line Items]
Revenues recognized from contracts with customers	106,899	95,748
Electric [Member] | Sales To The Market [Member]
Disaggregation of Revenue [Line Items]
Revenues recognized from contracts with customers	2,882	4,639
Electric [Member] | Other [Member]
Disaggregation of Revenue [Line Items]
Revenues recognized from contracts with customers	308	222
Gas [Member]
Disaggregation of Revenue [Line Items]
Revenues recognized from contracts with customers	98,811	67,270
Gas [Member] | Residential [Member]
Disaggregation of Revenue [Line Items]
Revenues recognized from contracts with customers	56,683	39,758
Gas [Member] | Commercial/Industrial [Member]
Disaggregation of Revenue [Line Items]
Revenues recognized from contracts with customers	40,251	25,507
Gas [Member] | Total Retail [Member]
Disaggregation of Revenue [Line Items]
Revenues recognized from contracts with customers	96,934	65,265
Gas [Member] | Gas Transportation [Member]
Disaggregation of Revenue [Line Items]
Revenues recognized from contracts with customers	1,876	2,002
Gas [Member] | Other [Member]
Disaggregation of Revenue [Line Items]
Revenues recognized from contracts with customers	1	3
Non Regulated Energy [Member]
Disaggregation of Revenue [Line Items]
Revenues recognized from contracts with customers	$ 38	$ 36

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Segment Information (Details) - USD ($) $ in Thousands	3 Months Ended
	Mar. 31, 2022	Mar. 31, 2021
Segment Reporting Information [Line Items]
Operating revenues	$ 208,938	$ 167,915
Equity in earnings of investment	2,504	2,444
Net Income	34,420	34,933
Electric [Member]
Segment Reporting Information [Line Items]
Operating revenues	110,089	100,609
Gas [Member]
Segment Reporting Information [Line Items]
Operating revenues	98,811	67,270
Non Regulated Energy [Member]
Segment Reporting Information [Line Items]
Operating revenues	38	36
Transmission Investment [Member]
Segment Reporting Information [Line Items]
Operating revenues	0	0
All Others [Member]
Segment Reporting Information [Line Items]
Operating revenues	0	0
Operating Segments [Member]
Segment Reporting Information [Line Items]
Operating revenues	208,938	167,915
Equity in earnings of investment	2,504	2,444
Operating Segments [Member] | Electric [Member]
Segment Reporting Information [Line Items]
Operating revenues	110,207	100,882
Equity in earnings of investment	0	0
Net Income	14,617	18,024
Operating Segments [Member] | Gas [Member]
Segment Reporting Information [Line Items]
Operating revenues	104,932	72,081
Equity in earnings of investment	0	0
Net Income	12,084	10,556
Operating Segments [Member] | Non Regulated Energy [Member]
Segment Reporting Information [Line Items]
Operating revenues	10,353	10,209
Equity in earnings of investment	0	0
Net Income	5,352	5,194
Operating Segments [Member] | Transmission Investment [Member]
Segment Reporting Information [Line Items]
Operating revenues	0	0
Equity in earnings of investment	2,504	2,444
Net Income	1,822	1,778
Operating Segments [Member] | All Others [Member]
Segment Reporting Information [Line Items]
Operating revenues	0	0
Equity in earnings of investment	0	0
Net Income	545	(619)
Consolidation Elimination Entries [Member]
Segment Reporting Information [Line Items]
Operating revenues	(16,554)	(15,257)
Equity in earnings of investment	0	0
Net Income	0	0
Consolidation Elimination Entries [Member] | Electric [Member]
Segment Reporting Information [Line Items]
Operating revenues	118	273
Consolidation Elimination Entries [Member] | Gas [Member]
Segment Reporting Information [Line Items]
Operating revenues	6,121	4,811
Consolidation Elimination Entries [Member] | Non Regulated Energy [Member]
Segment Reporting Information [Line Items]
Operating revenues	10,315	10,173
Consolidation Elimination Entries [Member] | Transmission Investment [Member]
Segment Reporting Information [Line Items]
Operating revenues	0	0
Consolidation Elimination Entries [Member] | All Others [Member]
Segment Reporting Information [Line Items]
Operating revenues	0	0
MGE [Member]
Segment Reporting Information [Line Items]
Operating revenues	208,938	167,915
Net Income	27,297	28,273
MGE [Member] | Electric [Member]
Segment Reporting Information [Line Items]
Operating revenues	110,089	100,609
MGE [Member] | Gas [Member]
Segment Reporting Information [Line Items]
Operating revenues	98,811	67,270
MGE [Member] | Non Regulated Energy [Member]
Segment Reporting Information [Line Items]
Operating revenues	38	36
MGE [Member] | Operating Segments [Member]
Segment Reporting Information [Line Items]
Operating revenues	208,938	167,915
Net Income	27,297	28,273
MGE [Member] | Operating Segments [Member] | Electric [Member]
Segment Reporting Information [Line Items]
Operating revenues	110,207	100,882
Net Income	14,617	18,024
MGE [Member] | Operating Segments [Member] | Gas [Member]
Segment Reporting Information [Line Items]
Operating revenues	104,932	72,081
Net Income	12,084	10,556
MGE [Member] | Operating Segments [Member] | Non Regulated Energy [Member]
Segment Reporting Information [Line Items]
Operating revenues	10,353	10,209
Net Income	5,352	5,194
MGE [Member] | Consolidation Elimination Entries [Member]
Segment Reporting Information [Line Items]
Operating revenues	(16,554)	(15,257)
Net Income	(4,756)	(5,501)
MGE [Member] | Consolidation Elimination Entries [Member] | Electric [Member]
Segment Reporting Information [Line Items]
Operating revenues	118	273
MGE [Member] | Consolidation Elimination Entries [Member] | Gas [Member]
Segment Reporting Information [Line Items]
Operating revenues	6,121	4,811
MGE [Member] | Consolidation Elimination Entries [Member] | Non Regulated Energy [Member]
Segment Reporting Information [Line Items]
Operating revenues	$ 10,315	$ 10,173