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, 2021 ☐ 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 and posted pursuant to Rule 405 of Regulation S-T (§232.405 of this chapter) during the preceding 12 months (or for such shorter period that the registrants were required to submit 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, 2021
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 Format3

Forward-Looking Statements3

Where to Find More Information3

Definitions, Abbreviations, and Acronyms Used in the Text and Notes of this Report4

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 Company10

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 Company14

Notes to Consolidated Financial Statements (unaudited)14

Item 2. Management's Discussion and Analysis of Financial Condition and Results of Operations.30

Item 3. Quantitative and Qualitative Disclosures About Market Risk.44

Item 4. Controls and Procedures.46

PART II. OTHER INFORMATION.47

Item 1. Legal Proceedings.47

Item 2. Unregistered Sales of Equity Securities and Use of Proceeds.47

Item 4. Mine Safety Disclosures.48

Item 5. Other Information.48

Item 6. Exhibits.48

Signatures - MGE Energy, Inc.49

Signatures - Madison Gas and Electric Company50

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 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' 2020 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 assume 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

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

3

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

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

MGE Energy and Subsidiaries:

CWDCCentral Wisconsin Development Corporation

MAGAELMAGAEL, LLC

MGEMadison Gas and Electric Company

MGE EnergyMGE Energy, Inc.

MGE PowerMGE Power, LLC

MGE Power Elm RoadMGE Power Elm Road, LLC

MGE Power West CampusMGE Power West Campus, LLC

MGE ServicesMGE Services, LLC

MGE State Energy ServicesMGE State Energy Services, LLC

MGE TranscoMGE Transco Investment, LLC

MGEE TranscoMGEE Transco, LLC

North MendotaNorth Mendota Energy & Technology Park, LLC

Other Defined Terms:

2017 Tax ActTax Cut and Jobs Act of 2017

2021 PlanMGE Energy's 2021 Long-Term Incentive Plan

ACEAffordable Clean Energy

AFUDCAllowance for Funds Used During Construction

ATCAmerican Transmission Company LLC

ATC HoldcoATC Holdco, LLC

Badger Hollow IBadger Hollow I Solar Farm

Badger Hollow IIBadger Hollow II Solar Farm

BlountBlount Station

CACertificate of Authority

CAVRClean Air Visibility Rule

CCRCoal Combustion Residual

codificationFinancial Accounting Standards Board Accounting Standards Codification

ColumbiaColumbia Energy Center

COVID-19Coronavirus Disease 2019

CSAPRCross-State Air Pollution Rule

DthDekatherms, a quantity measure for natural gas

electric marginElectric revenues less fuel for electric generation and purchase power costs, a non-GAAP measure

Elm Road UnitsElm Road Generating Station

EPAUnited States Environmental Protection Agency

FERCFederal Energy Regulatory Commission

FTRFinancial Transmission Rights

GAAPGenerally Accepted Accounting Principles

gas marginGas revenues less cost of gas sold, a non-GAAP measure

GHGGreenhouse 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

IRSInternal Revenue Service

kWhKilowatt-hour, a measure of electric energy produced

MISOMidcontinent Independent System Operator (a regional transmission organization)

MWMegawatt, a measure of electric energy generating capacity

MWhMegawatt-hour, a measure of electric energy produced

NAAQSNational Ambient Air Quality Standards

4

NO_xNitrogen Oxide

PGAPurchased Gas Adjustment clause, a regulatory mechanism used to reconcile natural gas costs recovered in rates to actual costs

PPAPurchased Power Agreement

PSCWPublic Service Commission of Wisconsin

RiversideRiverside Energy Center

ROEReturn on Equity

SCRSelective Catalytic Reduction

SECSecurities and Exchange Commission

SO₂Sulfur Dioxide

Stock PlanDirect Stock Purchase and Dividend Reinvestment Plan of MGE Energy

WCCFWest Campus Cogeneration Facility

working capitalCurrent assets less current liabilities

WPLWisconsin Power and Light Company, a subsidiary of Alliant Energy Corporation

XBRLeXtensible 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,
			2021		2020
	Operating Revenues:
	Electric revenues	$	100,645	$	93,028
	Gas revenues		67,270		56,845
	Total Operating Revenues		167,915		149,873
	Operating Expenses:
	Fuel for electric generation		13,171		9,706
	Purchased power		9,355		10,486
	Cost of gas sold		37,444		30,798
	Other operations and maintenance		45,682		44,369
	Depreciation and amortization		18,382		18,167
	Other general taxes		4,827		4,907
	Total Operating Expenses		128,861		118,433
	Operating Income		39,054		31,440
	Other income, net		2,078		5,671
	Interest expense, net		(5,740)		(6,061)
	Income before income taxes		35,392		31,050
	Income tax provision		(459)		(5,013)
	Net Income	$	34,933	$	26,037
	Earnings Per Share of Common Stock
	Basic	$	0.97	$	0.75
	Diluted	$	0.97	$	0.75
	Dividends per share of common stock	$	0.370	$	0.353
	Weighted Average Shares Outstanding
	Basic		36,163		34,668
	Diluted		36,165		34,668
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,
		2021		2020
Operating Activities:
Net income	$	34,933	$	26,037
Items not affecting cash:
Depreciation and amortization		18,382		18,167
Deferred income taxes		(796)		1,433
Provision for doubtful receivables		388		734
Employee benefit plan cost (credit)		1,461		(940)
Equity earnings in investments		(2,444)		(2,266)
Other items		(277)		(1,974)
Changes in working capital items:
(Increase) decrease in current assets		(2,851)		14,089
Decrease in current liabilities		(4,213)		(2,738)
Dividends from investments		1,967		2,700
Cash contributions to pension and other postretirement plans		(1,552)		(1,470)
Other noncurrent items, net		(1,115)		47
Cash Provided by Operating Activities		43,883		53,819
Investing Activities:
Capital expenditures		(34,746)		(46,758)
Capital contributions to investments		(670)		(1,643)
Other		(419)		(398)
Cash Used for Investing Activities		(35,835)		(48,799)
Financing Activities:
Cash dividends paid on common stock		(13,380)		(12,221)
Repayments of long-term debt		(1,182)		(1,155)
Net proceeds from short-term debt		1,500		3,000
Other		(523)		(664)
Cash Used for Financing Activities		(13,585)		(11,040)
Change in cash, cash equivalents, and restricted cash		(5,537)		(6,020)
Cash, cash equivalents, and restricted cash at beginning of period		47,039		25,814
Cash, cash equivalents, and restricted cash at end of period	$	41,502	$	19,794
Supplemental disclosures of cash flow information:
Significant noncash investing activities:
Accrued capital expenditures	$	8,843	$	8,129
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		2021		2020
Current Assets:
Cash and cash equivalents	$	40,239	$	44,738
Accounts receivable, less reserves of $6,382 and $5,787, respectively		43,172		41,384
Other accounts receivable, less reserves of $1,307 and $1,290, respectively		9,702		7,300
Unbilled revenues		25,148		27,511
Materials and supplies, at average cost		32,222		32,513
Fuel for electric generation, at average cost		4,885		6,356
Stored natural gas, at average cost		1,578		8,396
Prepaid taxes		11,210		15,179
Regulatory assets - current		24,313		14,748
Other current assets		9,042		11,394
Total Current Assets		201,511		209,519
Other long-term receivables		1,486		1,435
Regulatory assets		139,667		142,504
Pension benefit asset		17,848		13,873
Other deferred assets and other		22,564		22,259
Property, Plant, and Equipment:
Property, plant, and equipment, net		1,633,908		1,630,286
Construction work in progress		157,970		139,099
Total Property, Plant, and Equipment		1,791,878		1,769,385
Investments		95,283		94,676
Total Assets	$	2,270,237	$	2,253,651
LIABILITIES AND CAPITALIZATION
Current Liabilities:
Long-term debt due within one year	$	4,800	$	4,771
Short-term debt		54,000		52,500
Accounts payable		53,840		54,642
Accrued interest and taxes		7,540		8,539
Accrued payroll related items		10,019		12,635
Regulatory liabilities - current		37,035		41,664
Derivative liabilities		9,790		10,160
Other current liabilities		6,774		6,015
Total Current Liabilities		183,798		190,926
Other Credits:
Deferred income taxes		236,903		231,471
Investment tax credit - deferred		21,588		21,821
Regulatory liabilities		143,365		142,239
Accrued pension and other postretirement benefits		77,941		78,168
Derivative liabilities		1,800		3,980
Finance lease liabilities		17,623		17,532
Other deferred liabilities and other		71,297		72,211
Total Other Credits		570,517		567,422
Capitalization:
Common shareholders' equity		997,711		976,000
Long-term debt		518,211		519,303
Total Capitalization		1,515,922		1,495,303
Commitments and contingencies (see Footnote 8)
Total Liabilities and Capitalization	$	2,270,237	$	2,253,651
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, 2020
Beginning Balance	34,668	$	34,668	$	316,268	$	504,740	$	-	$	855,676
Net income							26,037				26,037
Common stock dividends declared
($0.353 per share)							(12,221)				(12,221)
Ending Balance - March 31, 2020	34,668	$	34,668	$	316,268	$	518,556	$	-	$	869,492
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
($0.3700 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
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,
			2021		2020
	Operating Revenues:
	Electric revenues	$	100,645	$	93,028
	Gas revenues		67,270		56,845
	Total Operating Revenues		167,915		149,873
	Operating Expenses:
	Fuel for electric generation		13,171		9,706
	Purchased power		9,355		10,486
	Cost of gas sold		37,444		30,798
	Other operations and maintenance		45,538		44,150
	Depreciation and amortization		18,382		18,167
	Other general taxes		4,827		4,907
	Total Operating Expenses		128,717		118,214
	Operating Income		39,198		31,659
	Other (expense) income, net		(104)		3,380
	Interest expense, net		(5,753)		(6,111)
	Income before income taxes		33,341		28,928
	Income tax benefit (provision)		433		(4,371)
	Net Income	$	33,774	$	24,557
	Less Net Income Attributable to Noncontrolling Interest, net of tax		(5,501)		(5,493)
	Net Income Attributable to MGE	$	28,273	$	19,064
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,
		2021		2020
Operating Activities:
Net income	$	33,774	$	24,557
Items not affecting cash:
Depreciation and amortization		18,382		18,167
Deferred income taxes		(1,766)		976
Provision for doubtful receivables		388		734
Employee benefit plan cost (credit)		1,461		(940)
Other items		(252)		(1,721)
Changes in working capital items:
(Increase) decrease in current assets		(3,037)		12,953
(Decrease) increase in current liabilities		(4,037)		290
Cash contributions to pension and other postretirement plans		(1,552)		(1,470)
Other noncurrent items, net		(1,380)		(428)
Cash Provided by Operating Activities		41,981		53,118
Investing Activities:
Capital expenditures		(34,746)		(46,758)
Other		(462)		(406)
Cash Used for Investing Activities		(35,208)		(47,164)
Financing Activities:
Distributions to parent from noncontrolling interest		(5,000)		(7,000)
Repayments of long-term debt		(1,182)		(1,155)
Net proceeds from short-term debt		1,500		3,000
Other		(523)		(664)
Cash Used for Financing Activities		(5,205)		(5,819)
Change in cash, cash equivalents, and restricted cash		1,568		135
Cash, cash equivalents, and restricted cash at beginning of period		6,404		5,529
Cash, cash equivalents, and restricted cash at end of period	$	7,972	$	5,664
Supplemental disclosures of cash flow information:
Significant noncash investing activities:
Accrued capital expenditures	$	8,843	$	8,129
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		2021		2020
Current Assets:
Cash and cash equivalents	$	6,709	$	4,103
Accounts receivable, less reserves of $6,382 and $5,787, respectively		43,172		41,384
Affiliate receivables		530		532
Other accounts receivable, less reserves of $1,307 and $1,290, respectively		9,698		7,295
Unbilled revenues		25,148		27,511
Materials and supplies, at average cost		32,222		32,513
Fuel for electric generation, at average cost		4,885		6,356
Stored natural gas, at average cost		1,578		8,396
Prepaid taxes		11,102		14,848
Regulatory assets - current		24,313		14,748
Other current assets		8,940		11,326
Total Current Assets		168,297		169,012
Affiliate receivable long-term		1,986		2,118
Regulatory assets		139,667		142,504
Pension benefit asset		17,848		13,873
Other deferred assets and other		22,877		22,448
Property, Plant, and Equipment:
Property, plant, and equipment, net		1,633,936		1,630,314
Construction work in progress		157,970		139,099
Total Property, Plant, and Equipment		1,791,906		1,769,413
Investments		433		603
Total Assets	$	2,143,014	$	2,119,971
LIABILITIES AND CAPITALIZATION
Current Liabilities:
Long-term debt due within one year	$	4,800	$	4,771
Short-term debt		54,000		52,500
Accounts payable		53,808		54,576
Accrued interest and taxes		9,574		10,405
Accrued payroll related items		10,019		12,635
Regulatory liabilities - current		37,035		41,664
Derivative liabilities		9,790		10,160
Other current liabilities		6,776		6,042
Total Current Liabilities		185,802		192,753
Other Credits:
Deferred income taxes		204,853		200,390
Investment tax credit - deferred		21,588		21,821
Regulatory liabilities		143,365		142,239
Accrued pension and other postretirement benefits		77,941		78,168
Derivative liabilities		1,800		3,980
Finance lease liabilities		17,623		17,532
Other deferred liabilities and other		71,445		72,173
Total Other Credits		538,615		536,303
Capitalization:
Common shareholder's equity		758,689		730,416
Noncontrolling interest		141,697		141,196
Total Equity		900,386		871,612
Long-term debt		518,211		519,303
Total Capitalization		1,418,597		1,390,915
Commitments and contingencies (see Footnote 8)
Total Liabilities and Capitalization	$	2,143,014	$	2,119,971
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, 2020
Beginning balance	17,348	$	17,348	$	222,917	$	397,021	$	-	$	140,303	$	777,589
Net income							19,064				5,493		24,557
Distributions to parent from
noncontrolling interest											(7,000)		(7,000)
Ending Balance - March 31, 2020	17,348	$	17,348	$	222,917	$	416,085	$	-	$	138,796	$	795,146
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
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, 2021

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 2020 Annual Report on Form 10-K (the 2020 Annual Report on Form 10-K).

The accompanying consolidated financial statements as of March 31, 2021, and during the three months ended, are unaudited but include all adjustments that MGE Energy and MGE management consider necessary for a fair statement of their respective financial statements. All adjustments are of a normal, recurring nature except as otherwise disclosed. The year-end consolidated balance sheet information was derived from the audited balance sheet appearing in the 2020 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 62 through 115 of the 2020 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)		2021		2020		2021		2020
Cash and cash equivalents	$	40,239	$	44,738	$	6,709	$	4,103
Restricted cash		467		644		467		644
Receivable - margin account		796		1,657		796		1,657
Cash, cash equivalents, and restricted cash	$	41,502	$	47,039	$	7,972	$	6,404

Cash Equivalents

All highly liquid investments purchased with an original maturity of three months or less 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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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 the 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)		2021		2020
Equity earnings from investment in ATC	$	2,420	$	2,266
Dividends from ATC		1,967		2,391
Capital contributions to ATC		-		178

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

ATC's summarized financial data is as follows:

		Three Months Ended
		March 31,
(In thousands)		2021		2020
Operating revenues	$	188,694	$	186,801
Operating expenses		(95,104)		(95,211)
Other income, net		378		375
Interest expense, net		(28,871)		(28,888)
Earnings before members' income taxes	$	65,097	$	63,077

MGE receives transmission and other related services from ATC. During the three months ended March 31, 2021 and 2020, MGE recorded $8.0 million and $7.7 million, respectively, for transmission services received from ATC. MGE also provides a variety of operational, maintenance, and project management work for ATC, which is reimbursed by ATC. As of March 31, 2021, and December 31, 2020, MGE had a receivable due from ATC of $3.0 and $2.6 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:

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	MGE Energy				MGE
Three Months Ended March 31,	2021		2020		2021		2020
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	(1.6)		(0.1)		(1.8)		(0.1)
Credit for electricity from wind energy	(7.1)		(6.9)		(7.8)		(7.5)
AFUDC equity, net	(0.6)		(1.6)		(0.6)		(1.7)
Amortization of utility excess deferred tax - tax reform(a)	(16.7)		(2.6)		(18.3)		(2.8)
Other, net, individually insignificant	-		-		(0.1)		(0.1)
Effective income tax rate	1.3	%	16.1	%	(1.3)	%	15.1	%

(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, 2021 and 2020, MGE recognized $0.7 million. 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.

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)		2021		2020
Pension Benefits
Components of net periodic benefit cost:
Service cost	$	1,422	$	1,316
Interest cost		2,272		3,023
Expected return on assets		(7,375)		(6,811)
Amortization of:
Prior service credit		(31)		(31)
Actuarial loss		1,580		1,286
Net periodic benefit (credit) cost	$	(2,132)	$	(1,217)
Postretirement Benefits
Components of net periodic benefit cost:
Service cost	$	351	$	311
Interest cost		384		573
Expected return on assets		(817)		(790)
Amortization of:
Transition obligation		1		1
Prior service credit		(380)		(667)
Actuarial loss		109		70
Net periodic benefit (credit) cost	$	(352)	$	(502)

As approved by the PSCW, MGE is allowed to defer differences between actual employee benefit plan costs and costs reflected in current rates. The deferred costs may be recovered or refunded in MGE's next rate filing. For the three months ended March 31, 2021 and 2020, MGE recovered approximately $3.4 million and $0.4 million, respectively, of pension and other postretirement costs, which reduced the amount previously deferred and has not been reflected in the table above.

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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, 2021 and 2020, MGE Energy issued no new shares of common stock under the Stock Plan.

b.Dilutive Shares Calculation - MGE Energy.

As of March 31, 2021, 1,543 shares were included in the calculation of diluted earnings per share related to nonvested equity awards. See Footnote 7 for additional information on shared-based compensation awards.

7.

Share-Based Compensation - MGE Energy and MGE.

During the three months ended March 31, 2021 and 2020, MGE recorded $0.7 million in compensation expense and $0.6 million in compensation benefit, respectively, related to share-based compensation awards under the 2006 Performance Unit Plan, the 2020 Performance Unit Plan, the 2013 Director Incentive Plan, and the 2021 Long-Term Incentive Plan (2021 Plan).

In January 2021, cash payments of $1.9 million were distributed related to awards that were granted under the plans in 2018, for the 2013 Director Incentive Plan, and in 2016, for the 2006 Performance Unit Plan.

In February 2021, MGE issued 10,187 performance units and 16,267 restricted stock units under the 2021 Plan to eligible employees and non-employee directors.

The performance units can be paid out in either cash, shares of common stock or a combination of cash and stock and are accounted for as a liability award. The restricted stock units will be paid out in shares of common stock, and therefore accounted for 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 for Units 1 and 2 are subject to PSCW and regional regulatory reviews, including identification and approval of energy and capacity resources to replace Columbia. 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

17

electric power plants which focus on the reduction of metals and other pollutants in wastewater from new and existing power plants. The standards were finalized in August 2020.

In February 2021, MGE and the other owners of Columbia filed a Certificate of Authority (CA) application with the PSCW. The CA application commits to close Columbia's wet pond system to comply with the Coal Combustions Residuals (CCR) Rule 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 rule's requirements no later than December 31, 2023, as determined by the permitting authority. The operator of the Elm Road Units has been evaluating the rule impacts and has conducted an analysis of compliance obligations, pollution prevention technologies, and their associated costs. In February 2021, MGE and its co-owner filed a CA application with the PSCW. If approved, MGE's share of the estimated costs to comply with the rule is estimated to be approximately $4 million. Subject to approval from the PSCW, construction is expected to begin in 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 Wisconsin Pollution Discharge Elimination System permit assumes that the plant meets BTA for the duration of the permit, which expires in 2023. However, MGE must conduct studies of its Blount plant by the end of 2021 to help regulators determine BTA.

Columbia's river intakes are subject to this rule. BTA improvements may not be required given that Columbia could be fully retired before the issuance of the next permit, which is expected to be issued in 2023 or later. 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 January 2021, the U.S. Court of Appeals for the District of Columbia Circuit (D.C. Circuit) vacated and remanded to the EPA the Affordable Clean Energy Rule (ACE Rule) and the repeal of the predecessor Clean Power Plan Rule (CPP Rule), both of which regulated greenhouse gas emissions from existing electric generation units pursuant to Section 111(d) of the Clean Air Act. As a result of these legal proceedings, neither the CPP nor ACE rules are currently in effect. MGE will continue to evaluate the rule development and monitor ongoing and potential legal proceedings.

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

In May 2018, the EPA issued a final rule that designated the northeast portion of Milwaukee County as being in nonattainment with Ozone NAAQS. The Elm Road Units are located in Milwaukee County, outside the designated nonattainment area. In August 2018, several environmental groups, the City of Chicago, and the State of Illinois filed federal lawsuits challenging several of the EPA's attainment designation decisions, including the partial Milwaukee County designation as being too narrow and not sufficiently protective. In July 2020, the U.S. District Court of the District of Columbia remanded the partial Milwaukee County attainment designation back to the EPA for further explanation. MGE is monitoring

18

the outcome of the EPA's remand analysis and how it may affect the Elm Road Units in Milwaukee County. 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 (NO_x) and sulfur dioxide (SO₂) emissions, including the Cross State Air Pollution Rule (CSAPR) and Clean Air Visibility Rule (CAVR).

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. In September 2019, the D.C. Circuit remanded the rule to the EPA holding that the rule improperly provided only a partial remedy for addressing interstate transport of pollutants from upwind to downwind states. In March 2021, the EPA addressed the remand by finalizing its revised CSAPR Update Rule. The revised rule does not require further emission reductions from Wisconsin stationary sources beyond those under the original CSAPR. MGE has met its current CSAPR obligations through a combination of reduced emissions through pollution control (e.g., SCR installation at Columbia), as well as owned, received, and purchased allowances. MGE expects to meet ongoing CSAPR obligations for the foreseeable future. MGE will continue to monitor legal developments and any future updates to this rule.

•The EPA's Coal Combustion Residuals Rule (CCR), which regulates coal ash from burning coal for the purpose of generating electricity as a solid waste 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. In August 2020, the EPA revised the CCR rule to require 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 comply by October 2022. The EPA will address the remaining issues on remand in a subsequent action.

Review of the Elm Road Units has indicated that the costs to comply with this rule are not expected to be significant. Columbia's operator has completed a review of its system and has developed a compliance plan. In February 2021, a CA application was filed with the PSCW for approval to install technology required to cease bottom ash transport water discharges rather than extend the longevity of the ash ponds. If approved, MGE's share of the estimated costs of the project would 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.

In January 2021, certain environmental groups filed a petition against the PSCW regarding MGE's 2021 rate settlement. MGE has intervened in the petition in cooperation with the PSCW. See Footnote 9.a. for more information regarding this matter.

9.

Rate Matters - MGE Energy and MGE.

a.Rate Proceedings.

In May 2021, MGE filed an application with the PSCW requesting a 5.9% increase to electric rates and a

19

3.0% increase to gas rates for 2022. The proposed electric and gas rate increases are primarily 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 is the completion in 2020 of the one-time return of the electric excess deferred tax credit related to the 2017 Tax Act not restricted by IRS normalization rules. In its application, MGE is proposing to address potential 2023 rate changes through an electric limited rate case re-opener and a 1.65% increase in gas rates. The proposed return on common stock equity for 2022 is 9.8% based on a proposed capital structure consisting of 55.6% common equity in 2022. PSCW approval of the application is pending. A final order is expected before the end of the year.

In December 2020, the PSCW approved a settlement agreement for MGE's 2021 rate case. The settlement agreement provides for a zero percent increase for electric rates and an approximately 4% increase for gas rates in 2021. The electric rate settlement includes an increase in rate base but the associated rate increase is primarily offset by lower fuel and purchase 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 is 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 covers infrastructure costs and technology improvements. The settlement agreement also includes 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 its next rate filing. Any difference would be recorded as a regulatory asset or regulatory liability. The return on common stock equity for 2021 is 9.8% based on a capital structure of 55.8% common equity in 2021.

On January 27, 2021, Sierra Club and Vote Solar filed a petition with the Dane County Circuit Court seeking review of the PSCW decision approving the rate settlement in MGE's 2021 rate case. The PSCW is named as the responding party; MGE is not named as a party. The petition challenges the process the PSCW used to approve the portion of the settlement 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 settlement has not been challenged. The PSCW is expected to vigorously defend its approval of the rate case settlement. MGE has intervened in the proceedings to further defend the PSCW’s decision.

In December 2018, the PSCW approved a settlement agreement between MGE and intervening parties in the then pending rate case. The settlement decreased electric rates by 2.24%, or $9.2 million, in 2019. The decrease in electric rates reflected the ongoing impacts of the 2017 Tax Act. Lower fuel costs and an increase in rate base from renewable generation assets further impacted the rate change. In 2020, electric rates decreased a further 0.84%, or $3.4 million, as approved by the PSCW in December 2019 in MGE's 2020 Fuel Cost Plan, which reflected lower fuel costs. The settlement agreement increased gas rates by 1.06%, or $1.7 million, in 2019 and 1.46%, or $2.4 million, in 2020. The gas increase covered infrastructure costs. It also reflected the impacts of the 2017 Tax Act. The return on common stock equity for 2019 and 2020 was 9.8% based on a capital structure consisting of 56.6% common equity in 2019 and 56.1% common equity in 2020.

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% in 2021. 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. In 2020 the fuel rules bandwidth was set at plus or minus 2%. These costs are subject to the PSCW's annual review of fuel costs completed in the year following the deferral.

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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.

As of December 31, 2020, MGE had deferred $3.2 million of 2020 fuel-related savings. These costs will be subject to the PSCW's annual review of 2020 fuel costs, which is expected to be completed in 2021. In March 2021, as part of the 2020 fuel costs application filed with the PSCW, MGE seeks to return the 2020 fuel-related savings to customers in 2022 as part of the 2022 rate case.

As of March 31, 2021, MGE had deferred $0.5 million of 2021 fuel savings. These costs will be subject to the PSCW's annual review of 2021 fuel costs, which is expected to be completed in 2022.

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, 2021		December 31, 2020
Commodity derivative contracts	277,400	MWh	259,080	MWh
Commodity derivative contracts	2,190,000	Dth	6,030,000	Dth
FTRs	1,152	MW	2,869	MW
PPA	700	MW	850	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, 2021, and December 31,

21

2020, the fair value of exchange traded derivatives and FTRs exceeded their cost basis by $0.5 million and $0.2 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 also allows MGE an option to extend the contract after the base term. The agreement is accounted for as a derivative contract and is recognized at its fair value on the consolidated balance 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, 2021, and December 31, 2020, reflected a loss position of $11.6 million and $14.1 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, 2021
Commodity derivative contracts(a)	$	653	$	174	Other current assets
Commodity derivative contracts(a)		30		16	Other deferred charges
FTRs		38		-	Other current assets
PPA		N/A		9,790	Derivative liability (current)
PPA		N/A		1,800	Derivative liability (long-term)
December 31, 2020
Commodity derivative contracts(a)	$	617	$	593	Other current assets
Commodity derivative contracts(a)		189		39	Other deferred charges
FTRs		-		23	Other current liabilities
PPA		N/A		10,160	Derivative liability (current)
PPA		N/A		3,980	Derivative liability (long-term)

(a) No collateral was posted against derivative positions as of March 31, 2021, and December 31, 2020.

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, 2021
Commodity derivative contracts	$	683	$	(190)	$	-	$	493
FTRs		38		-		-		38
December 31, 2020
Commodity derivative contracts	$	806	$	(632)	$	-	$	174

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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, 2021
Commodity derivative contracts	$	190	$	(190)	$	-	$	-
PPA		11,590		-		-		11,590
December 31, 2020
Commodity derivative contracts	$	632	$	(632)	$	-	$	-
FTRs		23		-		-		23
PPA		14,140		-		-		14,140

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.

		2021				2020
(In thousands)		Current and Long-Term Regulatory Asset		Other Current Assets		Current and Long-Term Regulatory Asset		Other Current Assets
Three Months Ended March 31:
Balance at January 1,	$	13,989	$	1,162	$	26,875	$	1,100
Unrealized gain		(3,588)		-		(689)		-
Realized (loss) gain reclassified to a deferred account		(50)		50		(1,063)		1,063
Realized gain (loss) reclassified to income statement		708		(1,039)		204		(1,733)
Balance at March 31,	$	11,059	$	173	$	25,327	$	430

		Realized losses (gains)
		2021				2020
(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	$	(195)	$	1,022	$	680	$	1,607
FTRs		(256)		-		(65)		-
PPA		(240)		-		(693)		-

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, 2021, 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, 2021, and December 31, 2020, 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, 2021, no counterparties had defaulted.

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

23

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, 2021				December 31, 2020
(In thousands)		Carrying Amount		Fair Value		Carrying Amount		Fair Value
MGE Energy
Assets:
Cash and cash equivalents	$	40,239	$	40,239	$	44,738	$	44,738
Liabilities:
Short-term debt - commercial paper		54,000		54,000		52,500		52,500
Long-term debt(a)		527,038		590,748		528,220		639,271
MGE
Assets:
Cash and cash equivalents	$	6,709	$	6,709	$	4,103	$	4,103
Liabilities:
Short-term debt - commercial paper		54,000		54,000		52,500		52,500
Long-term debt(a)		527,038		590,748		528,220		639,271

(a) Includes long-term debt due within one year. Excludes debt issuance costs and unamortized discount of $4.0 million and $4.1 million as of March 31, 2021, and December 31, 2020, 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, 2021
(In thousands)		Total		Level 1		Level 2		Level 3
MGE Energy
Assets:
Derivatives, net(b)	$	721	$	423	$	-	$	298
Exchange-traded investments		1,474		1,474		-		-
Total Assets	$	2,195	$	1,897	$	-	$	298
Liabilities:
Derivatives, net(b)	$	11,780	$	115	$	-	$	11,665
Deferred compensation		3,581		-		3,581		-
Total Liabilities	$	15,361	$	115	$	3,581	$	11,665
MGE
Assets:
Derivatives, net(b)	$	721	$	423	$	-	$	298
Exchange-traded investments		431		431		-		-
Total Assets	$	1,152	$	854	$	-	$	298
Liabilities:
Derivatives, net(b)	$	11,780	$	115	$	-	$	11,665
Deferred compensation		3,581		-		3,581		-
Total Liabilities	$	15,361	$	115	$	3,581	$	11,665

		Fair Value as of December 31, 2020
(In thousands)		Total		Level 1		Level 2		Level 3
MGE Energy
Assets:
Derivatives, net(b)	$	806	$	436	$	-	$	370
Exchange-traded investments		1,750		1,750		-		-
Total Assets	$	2,556	$	2,186	$	-	$	370
Liabilities:
Derivatives, net(b)	$	14,795	$	370	$	-	$	14,425
Deferred compensation		3,509		-		3,509		-
Total Liabilities	$	18,304	$	370	$	3,509	$	14,425
MGE
Assets:
Derivatives, net(b)	$	806	$	436	$	-	$	370
Exchange-traded investments		603		603		-		-
Total Assets	$	1,409	$	1,039	$	-	$	370
Liabilities:
Derivatives, net(b)	$	14,795	$	370	$	-	$	14,425
Deferred compensation		3,509		-		3,509		-
Total Liabilities	$	18,304	$	370	$	3,509	$	14,425

(b) These amounts are shown gross. No collateral was posted against derivative positions with counterparties as of March 31, 2021, or December 31, 2020.

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

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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
Significant Unobservable Inputs	March 31, 2021		December 31, 2020
Basis adjustment:
On peak	94.4	%	94.2	%
Off peak	95.0	%	94.5	%
Counterparty fuel mix:
Internal generation - range	41.0% - 66.0	%	46.0% - 65.0	%
Internal generation - weighted average	56.9	%	56.5	%
Purchased power - range	59.0% - 34.0	%	54.0% - 35.0	%
Purchased power - weighted average	43.1	%	43.5	%

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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)		2021		2020
Beginning balance	$	(14,055)	$	(26,456)
Realized and unrealized gains (losses):
Included in regulatory assets		2,688		810
Included in other comprehensive income		-		-
Included in earnings		307		(1,453)
Included in current assets		355		247
Purchases		5,884		5,015
Sales		-		-
Issuances		-		-
Settlements		(6,546)		(3,810)
Balance as of March 31,	$	(11,367)	$	(25,647)
Total gains (losses) included in earnings attributed to the change in unrealized gains (losses) related to assets and liabilities held at 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)		2021		2020
Purchased power expense	$	702	$	(1,184)
Cost of gas sold expense		(395)		(269)
Total	$	307	$	(1,453)

(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 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		Date of Commercial
Project	Interest		Generation		Estimated Costs		March 31, 2021(a)		Operation
Badger Hollow I(b)	33	%	50	MW	$65	million	$56.4	million	Q3 2021(c)
Badger Hollow II(b)	33	%	50	MW	$65	million	$5.3	million	December 2022(c)

(a)Excluding AFUDC.

(b)The Badger Hollow I and Badger Hollow II solar farms are located in southwestern Wisconsin in Iowa County, near the villages of Montfort and Cobb.

(c)Estimated date of commercial operation.

MGE received specific approval to recover 100% AFUDC on each of these projects. During the three months ended March 31, 2021 and 2020, MGE recognized $1.1 million and $0.4 million, respectively, after tax, in AFUDC for Badger Hollow I and 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		2021		2020
Residential	$	36,694	$	33,428
Commercial		47,883		47,634
Industrial		3,001		2,800
Other-retail/municipal		8,170		8,204
Total retail		95,748		92,066
Sales to the market		4,639		482
Other revenues		222		442
Total electric revenues	$	100,609	$	92,990
Gas revenues
Residential		39,758		33,487
Commercial/Industrial		25,507		21,471
Total retail		65,265		54,958
Gas transportation		2,002		1,794
Other revenues		3		93
Total gas revenues	$	67,270	$	56,845
Non-regulated energy revenues		36		38
Total Operating Revenue	$	167,915	$	149,873

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 2020 Annual Report on Form 10-K for additional discussion of each of these segments.

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

(In thousands) MGE Energy		Electric		Gas		Nonregulated Energy		Transmission Investment		All Others		Consolidation/ Elimination		Consolidated Total
Three Months Ended March 31, 2021
Operating revenues from external customers	$	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
Three Months Ended March 31, 2020
Operating revenues from external customers	$	92,990	$	56,845	$	38	$	-	$	-	$	-	$	149,873
Interdepartmental revenues		191		3,451		10,056		-		-		(13,698)		-
Total operating revenues		93,181		60,296		10,094		-		-		(13,698)		149,873
Equity in earnings of investments		-		-		-		2,286		-		-		2,286
Net income (loss)		11,463		8,034		5,060		1,663		(183)		-		26,037

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

(In thousands) MGE		Electric		Gas		Nonregulated Energy		Consolidation/ Elimination		Consolidated Total
Three Months Ended March 31, 2021
Operating revenues from external customers	$	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
Three Months Ended March 31, 2020
Operating revenues from external customers	$	92,990	$	56,845	$	38	$	-	$	149,873
Interdepartmental revenues		191		3,451		10,056		(13,698)		-
Total operating revenues		93,181		60,296		10,094		(13,698)		149,873
Net income attributable to MGE		11,463		8,034		5,060		(5,493)		19,064

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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 157,000 customers in Dane County, Wisconsin, including the city of Madison, and purchases and distributes natural gas to approximately 166,000 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. 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 announcement of the retirement of Columbia 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 standing consistent with financial strength in MGE as well as the parent company in order to accomplish these goals.

We 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 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 2020 Annual Report on Form 10-K.

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For the three months ended March 31, 2021, MGE Energy's earnings were $34.9 million or $0.97 per share compared to $26.0 million or $0.75 per share for the same period in the prior year. MGE's earnings for the three months ended March 31, 2021, were $28.3 million compared to $19.1 million for 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:		2021		2020
Electric Utility	$	18.0	$	11.5
Gas Utility		10.5		8.0
Nonregulated Energy		5.2		5.1
Transmission Investments		1.8		1.6
All Other		(0.6)		(0.2)
Net Income	$	34.9	$	26.0

Our net income during the three months ended March 31, 2021, compared to the same period in the prior year primarily reflects the effects of the following factors:

Electric Utility

An increase in electric investments included in rate base contributed to increased earnings for 2021. Timing of 2021 depreciation and other operations and maintenance costs also contributed to higher earnings in the first quarter of 2021. Depreciation and operations and maintenance costs are expected to increase during the remainder of 2021 after significant capital projects are completed. Badger Hollow I and a new customer information system are expected to be completed in the third quarter of 2021. Ongoing remote work arrangements and colder temperatures contributed to higher electric residential sales, which increased by approximately 9% for the three months ended March 31, 2021, compared to the same period in the prior year. However, electric commercial retail sales dropped approximately 4% in the first quarter 2021 compared to the same period in the prior year.

Gas Utility

An increase in gas investments included in rate base contributed to increased earnings for 2021. Higher gas retail sales resulting from colder weather in the first quarter of 2021 contributing to higher earnings in that period. Heating degree days (a measure for determining the impact of weather during the heating season) increased by approximately 11% in the first quarter 2021 compared to the same period in the prior year.

The following developments affected the first three months of 2021:

2021 Rate Settlement Agreement: In December 2020, the PSCW approved a settlement agreement for MGE's 2021 rate case. The settlement agreement provides for a zero percent increase for electric rates and an approximately 4% increase for gas rates in 2021. The electric rate settlement includes an increase in rate base but the associated rate increase is primarily offset by lower fuel and purchase 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 includes lower forecasted electric sales for 2021 to reflect changes to customer usage during the COVID-19 pandemic. The gas rate increase covers infrastructure costs and technology improvements. The settlement agreement also includes 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 its next rate case filing. Any difference would be recorded as a regulatory asset or regulatory liability.

Utility Solar: Large solar generation projects are under construction, as shown in the following table. Incurred costs are reflected in "Construction work in progress" on the consolidated balance sheets. MGE has received specific approval to recover 100% AFUDC on Badger Hollow I and II. After tax, MGE recognized $2.9 million and $0.2 million of AFUDC equity on Badger Hollow I and II, respectively, during construction.

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Project	Ownership Interest	Share of Generation	Share of Estimated Costs	Costs Incurred as of March 31, 2021(a)	Estimated Date of Commercial Operation
Badger Hollow I	33%	50 MW	$65 million	$56.4 million	Q3 2021
Badger Hollow II	33%	50 MW	$65 million	$5.3 million	December 2022
O'Brien	100%	20 MW	$32 million	$11.9 million	Mid-2021

(a)Excluding AFUDC.

Deferred Fuel Costs – Subject to Refund: As of March 31, 2021, MGE had deferred $0.5 million of 2021 fuel savings. These costs will be subject to the PSCW's annual review of 2021 fuel costs, expected to be completed during 2022.

Tax Reform: Pursuant to the 2017 Tax Act, deferred income tax balances as of December 31, 2017, were remeasured to reflect the decrease in the corporate tax rate. The approved rate settlement agreement for 2021 includes approximately $5.3 million of the benefit in base rates that is being returned to customers using a normalization method of accounting. IRS normalization rules limit the rate at which MGE can return the benefits to customers. The settlement agreement also includes $18.2 million of the benefit not subject to normalization restrictions in electric base rates. The collection of the remaining portion not subject to normalization restrictions related to gas will be addressed by the PSCW in a future rate case.

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

2022/2023 Rate Case Filing: In May 2021, MGE filed an application with the PSCW for the 2022/2023 rate case. MGE is requesting a 5.9% increase to electric rates and a 3.0% increase to gas rates for 2022. MGE is proposing to address potential 2023 rate changes through an electric limited rate case re-opener and a 1.65% increase in gas rates. See "Other Matters" below for additional information on the 2022/2023 rate case application.

2020 Annual Fuel Proceeding: As of December 31, 2020, MGE had deferred $3.2 million of 2020 fuel-related savings. These costs will be subject to the PSCW's annual review of 2020 fuel costs, which is expected to be completed in 2021. In March 2021, as part of the 2020 fuel costs application with the PSCW, MGE seeks to return the 2020 fuel-related savings to customers in 2022 as part of the 2022 rate case.

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 5.0% and 6.5% of our net income during the three months ended March 31, 2021 and 2020, 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. At present, it is unclear how the changes in the presidential, congressional, and EPA administrations may affect existing, pending or new legislative or rulemaking proposals or regulatory initiatives. Such legislation and rulemaking 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.

EPA's Affordable Clean Energy (ACE) Rule: In January 2021, the U.S. Court of Appeals for the District of Columbia Circuit (D.C. Circuit) vacated and remanded to the EPA the ACE Rule and the repeal of the predecessor Clean Power Plan Rule, both of which regulated greenhouse gas emissions from existing electric generation units pursuant to Section 111(d) of the Clean Air Act. As a result of these legal proceedings, neither the CPP nor ACE rules are currently in effect. MGE is still evaluating this D.C. Circuit decision for what impacts it may have to MGE operations. MGE will continue to evaluate the rule development and monitor ongoing and potential legal proceedings.

Columbia: In February 2021, MGE, along with the 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

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2 are subject to PSCW and regional regulatory reviews, including identification and approval of energy and capacity resources to replace Columbia. 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.

Future Generation – Renewable Energy: MGE is seeking approval from the PSCW to acquire a joint interest in the following renewable generation projects as shown in the following table. There is no certainty that these projects will be approved by the PSCW.

Project	Source	Ownership Interest	Share of Generation	Share of Estimated Costs	Estimated Date of Commercial Operation
Darien	Solar/Battery	10%	25MW/7.5MW	$45 million	December 31, 2023
Paris	Solar/Battery	10%	20MW/11MW	$43 million	May 31, 2023
Red Barn	Wind	10%	9.16 MW	$17 million	December 31, 2022
Koshkonong	Solar/Battery	10%	30MW/16.5MW	$65 million	2024(a)

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

Future Generation - 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 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. MGE has not yet determined whether it will exercise its option in the Riverside plant. A determination will be made based on a variety of factors during the option period. If MGE acquires 50 MW of capacity, the estimated cost would be approximately $50 million.

Financing Plans: MGE expects to issue up to $100 million of new long-term debt during 2021 to finance authorized utility capital expenditures, including the construction of the Badger Hollow I and II and O'Brien solar farm projects, and other general corporate purposes.

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 discuss various COVID-19-related events and their effects below:

 Governmental and Regulatory Actions. State and local governments issued orders and regulations to restrict or manage business and individual activity. These orders and regulations continue to evolve in response to changing health metrics and safety health guidance. Additionally, the PSCW ordered changes to the tariff provisions on March 24, 2020, in response to the COVID-19 pandemic. All restrictions were lifted by November 1, 2020.

 Liquidity: We remain focused on maintaining strong credit quality. Subject to the duration and severity of the COVID-19 pandemic, we believe we have adequate liquidity on hand to support future operations and capital expenditures over the next twelve months. As of March 31, 2021, MGE Energy and MGE had $40.2 million and $6.7 million, respectively, in cash and cash equivalents and had available borrowing capacity under revolving credit facilities as noted below.

Borrower		Aggregate Bank Commitments		Outstanding Commercial Paper		Letters of Credit Issued Inside Credit Facilities		Outstanding Borrowings		Available Capacity	Expiration Date
(Dollars in millions)
MGE Energy	$	50.0	$	-	$	-	$	-	$	50.0	February 7, 2024
MGE	$	100.0	$	54.0	$	0.7	$	-	$	45.3	February 7, 2024

The credit agreements require the borrower to maintain a ratio of consolidated debt to consolidated total

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capitalization not to exceed a maximum of 65%. In the case of MGE, the ratio calculation excludes assets, liabilities, revenues, and expenses included in MGE's financial statements as a result of the consolidation of VIEs, such as MGE Power Elm Road and MGE Power West Campus. The ratio of consolidated debt to consolidated total capitalization for each of MGE Energy and MGE, as calculated under the credit agreements' covenant, was 36.6% and 39.2%, respectively, as of March 31, 2021, and 37.1% and 40.0%, respectively, as of December 31, 2020. See "Item 7. Management’s Discussion and Analysis of Financial Condition and Results of Operations – Liquidity and Capital Resources – Credit Facilities" in the 2020 Annual Report on Form 10-K for more information about our credit facilities.

 Customer Impacts: Governmental regulations limiting community activity began impacting customer sales in late March 2020. While the total expected impact of COVID-19 on future sales is currently unknown, MGE has experienced higher electric residential sales and lower electric commercial and industrial sales since the outset of the pandemic. As these regulations become less restrictive, we expect sales to be less impacted.

 Capital Expenditures & Operations: MGE does not currently expect any material changes to its construction expenditures plans disclosed in "Liquidity and Capital Resources" in the 2020 Annual Report on Form 10-K resulting from COVID-19. To date, MGE Energy has experienced no material disruptions in utility operations. Our administrative personnel have been working largely remotely, and our field operations have not been materially affected.

We cannot reasonably 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 2020 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 purchase 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, purchase 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.

Three Months Ended March 31, 2021 and 2020

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:

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		Three Months Ended March 31,
(In millions)		2021		2020		$ Change
Electric revenues	$	100.6	$	93.0	$	7.6
Fuel for electric generation		(13.2)		(9.7)		(3.5)
Purchased power		(9.4)		(10.5)		1.1
Total Electric Margins		78.0		72.8		5.2
Gas revenues		67.3		56.8		10.5
Cost of gas sold		(37.4)		(30.8)		(6.6)
Total Gas Margins		29.9		26.0		3.9
Other operating revenues		0.1		0.1		-
Other operations and maintenance		(45.7)		(44.4)		(1.3)
Depreciation and amortization		(18.4)		(18.2)		(0.2)
Other general taxes		(4.8)		(4.9)		0.1
Operating Income	$	39.1	$	31.4	$	7.7

Operating income during the three months ended March 31, 2021, compared to the same period in the prior year primarily reflects the effects of the following factors:

 Electric revenues and fuel costs

o Electric revenues increased $7.6 million primarily due to 2020 electric revenues that reflected a reduction in revenues to account for an over-collection of costs in customer rates. See revenue subject to refund discussed in the "Electric Margin" section below.

o A $3.5 million increase in fuel for electric generation reflecting higher internal generation and market costs.

o A $1.1 million decrease in purchased power costs driven by lower market purchases as a result of higher internal generation.

 Gas revenues and cost of gas sold

o A $10.5 million increase in gas revenue driven by higher customer demand resulting from colder weather in the first quarter of 2021 and higher cost of gas, which is recovered on a pass-through basis in revenues.

o A $6.6 million increase in cost of gas sold driven by higher cost per therm of gas. Average cost per therm increased approximately 13%. An increase in volume of approximately 8% also contributed to the increase in cost.

 A $1.3 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 $0.2 million increase in depreciation and amortization expense.

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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)
(In thousands)		Three Months Ended March 31,				Three Months Ended March 31,
		2021		2020	% Change	2021	2020	% Change
Residential	$	36,694	$	33,428	9.8 %	219,770	202,581	8.5 %
Commercial		47,883		47,634	0.5 %	414,337	430,118	(3.7)%
Industrial		3,001		2,800	7.2 %	39,005	40,418	(3.5)%
Other-retail/municipal		8,170		8,204	(0.4)%	76,356	81,045	(5.8)%
Total retail		95,748		92,066	4.0 %	749,468	754,162	(0.6)%
Sales to the market		4,639		482	n.m.%	95,872	23,946	n.m.%
Other revenues		222		442	(49.8)%	-	-	- %
Total	$	100,609	$	92,990	8.2 %	845,340	778,108	8.6 %

n.m. not meaningful

Electric margin, a non-GAAP measure, increased $5.2 million during the three months ended March 31, 2021, compared to the same period in 2020, due to the following:

(In millions)
Revenue subject to refund, net	$	3.3
Increase in residential volume		1.8
Decreased fuel costs		1.7
Rate changes		0.7
Customer fixed and demand charges		(1.3)
Decrease in commercial, industrial and other volume		(0.8)
Other		(0.2)
Total	$	5.2

 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.

 Residential volume. During the three months ended March 31, 2021, there was an 8.5% increase in residential sales driven by the COVID-19 pandemic and associated governmental regulations and restrictions on activity. As businesses shifted their workforce to a remote work environment, residential sales increased.

 Fuel costs. Fuel costs decreased during the three months ended March 31, 2021, primarily as a result of lower costs to generate and purchase electricity in the market and lower customer demand.

 Rate changes. MGE's PSCW approved 2020 Fuel Cost Plan resulted in a fuel credit that decreased rates 0.84% in 2020. Rates charged to retail customers during the three months ended March 31, 2021, were $0.7 million higher than those charged during the same period in the prior year as a result of the fuel credit from 2020 ending.

 Customer fixed and demand charges. During the three months ended March 31, 2021, fixed and demand charges decreased $1.3 million primarily attributable to the decrease in demand charges for commercial customers. The COVID-19 pandemic and associated governmental regulations and restrictions on activity impacted commercial business operations leading to reduced sales.

 Commercial, industrial, and other retail volume. During the three months ended March 31, 2021, there was a 3.7% reduction in commercial sales compared to the same period in the prior year driven by impacts from the COVID-19 pandemic and associated governmental regulations and restrictions on activity.

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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 rate per therm of retail customer)		Three Months Ended March 31,				Three Months Ended March 31,
		2021		2020	% Change	2021	2020	% Change
Residential	$	39,758	$	33,487	18.7 %	50,305	46,802	7.5 %
Commercial/Industrial		25,507		21,471	18.8 %	42,254	39,700	6.4 %
Total retail		65,265		54,958	18.8 %	92,559	86,502	7.0 %
Gas transportation		2,002		1,794	11.6 %	23,308	22,519	3.5 %
Other revenues		3		93	(96.8)%	-	-	- %
Total	$	67,270	$	56,845	18.3 %	115,867	109,021	6.3 %
Heating degree days (normal 3,531)						3,593	3,225	11.4 %
Average rate per therm of
retail customer	$	0.705	$	0.635	11.0 %

Gas margin, a non-GAAP measure, increased $3.9 million during the three months ended March 31, 2021, compared to the same period in 2020, due to the following:

(In millions)
Rate changes	$	2.9
Increase in volume		0.9
Other		0.3
Revenue subject to refund, net		(0.2)
Total	$	3.9

 Rate changes. In December 2020, the PSCW authorized MGE to increase 2021 rates for retail gas customers by approximately 4.0%.

 Volume. For 2021, retail gas deliveries increased 7% compared to the same period in the prior year primarily related to favorable weather conditions in the current year.

 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.

Consolidated operations and maintenance expenses

During the three months ended March 31, 2021, operations and maintenance expenses increased $1.3 million, compared to the same period in the prior year. The following contributed to the net change:

(In millions)
Increased transmission costs	$	1.1
Increased electric production expenses		0.6
Increased electric distribution expenses		0.3
Decreased administrative and general costs		(0.6)
Decreased other costs		(0.1)
Total	$	1.3

 Increased transmission costs are related to higher transmission rates in 2021 compared to rates in 2020. Transmission rates in 2020 reflected adjustments from a lower return on equity, ordered in FERC proceedings, for prior year rates.

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Consolidated depreciation expense

Electric depreciation expense increased $0.2 million and gas depreciation expense was flat during the three months ended March 31, 2021, compared to the same period in the prior year.

Electric and gas other income

Electric and gas other income decreased $2.4 million and $1.1 million, respectively, during the three months ended March 31, 2021, compared to the same period in the prior year, primarily related to the collection 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, 2021 and 2020, net income at the nonregulated energy operations segment was $5.2 million and $5.1 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 which typically have long development and investment lead times before becoming operational. ATC Holdco's future transmission development activities have been suspended for the near term. During the three months ended March 31, 2021 and 2020, other income at the transmission investment segment was $2.4 million and $2.3 million, respectively. In May 2020, the FERC issued an opinion further refining the methodology for setting the ROE that electric utilities are authorized to earn. 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 2021, the effective electric tax rate decreased 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)		2021		2020
MGE Power Elm Road	$	3.7	$	3.7
MGE Power West Campus		1.8		1.8

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, 2021. Further discussion of the contractual obligations and commercial commitments is included in

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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 2020 Annual Report on Form 10-K.

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 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 2020 Annual Report on Form 10-K and "Liquidity" under "COVID-19 Update" above 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, 2021 and 2020:

		MGE Energy				MGE
(In thousands)		2021		2020		2021		2020
Cash provided by (used for):
Operating activities	$	43,883	$	53,819	$	41,981	$	53,118
Investing activities		(35,835)		(48,799)		(35,208)		(47,164)
Financing activities		(13,585)		(11,040)		(5,205)		(5,819)

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, 2021, was $43.9 million, a decrease of $9.9 million when compared to the same period in the prior year.

MGE Energy's net income increased $8.9 million during the three months ended March 31, 2021, when compared to the same period in the prior year.

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 purchase 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.

Working capital accounts (excluding prepaid and accrued taxes) resulted in $4.9 million in cash provided by operating activities during the three months ended March 31, 2020, primarily due to decreased gas inventories, decreased unbilled revenues, and increased accounts payable, partially offset by decreased other current liabilities.

Hosted software asset expenditures during the three months ended March 31, 2021 were $1.3 million. This amount represents an increase of $0.9 million of cash used when compared to the prior year.

MGE

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Cash provided by operating activities during the three months ended March 31, 2021, was $42.0 million, a decrease of $11.1 million when compared to the same period in the prior year.

Net income increased $9.2 million during the three months ended March 31, 2021, when compared to the same period in the prior year.

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 purchase 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.

Working capital accounts (excluding prepaid and accrued taxes) resulted in $7.1 million in cash provided by operating activities during the three months ended March 31, 2020, primarily due to decreased gas inventories, decreased unbilled revenues, and increased accounts payable, partially offset by increased other current liabilities.

Hosted software asset expenditures during the three months ended March 31, 2021 were $1.3 million. This amount represents an increase of $0.9 million of cash used when compared to the prior year.

Cash Used for Investing Activities

MGE Energy

MGE Energy's cash used for investing activities decreased $13.0 million during the three months ended March 31, 2021, when compared to the same period in the prior year.

Capital expenditures during the three months ended March 31, 2021, were $34.7 million. This amount represents a decrease of $12.0 million from the expenditures made in the same period in the prior year. This decrease primarily reflects the reduction of expenditures on the construction of Badger Hollow I due to timing of expenditures.

Capital contributions to ATC and other investments decreased $1.0 million during the three months ended March 31, 2021, when compared to the same period in the prior year.

MGE

MGE's cash used for investing activities decreased $12.0 million during the three months ended March 31, 2021, when compared to the same period in the prior year.

Capital expenditures during the three months ended March 31, 2021, were $34.7 million. This amount represents a decrease of $12.0 million from the expenditures made in the same period in the prior year. This decrease primarily reflects the reduction of expenditures on the construction of Badger Hollow I due to timing of expenditures.

Cash Used for Financing Activities

MGE Energy

Cash used for MGE Energy's financing activities was $13.6 million for the three months ended March 31, 2021, compared to $11.0 million of cash used for MGE Energy's financing activities for the same period in the prior year.

For the three months ended March 31, 2021, dividends paid were $13.4 million compared to $12.2 million in the prior year. This increase was a result of a higher dividend per share ($0.370 vs. $0.353) and greater number of outstanding shares as a result of the May 2020 issuance of common shares.

During the three months ended March 31, 2021, net short-term debt borrowings were $1.5 million compared to

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$3.0 million of net short-term debt borrowings for the three months ended March 31, 2020.

MGE

During the three months ended March 31, 2021, cash used for MGE's financing activities was $5.2 million compared to $5.8 million of cash used for MGE's financing activities for the same period 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 $5.0 million and $7.0 million for the three months ended March 31, 2021 and 2020, respectively.

During the three months ended March 31, 2021, net short-term debt borrowings were $1.5 million compared to $3.0 million of net short-term debt borrowings for the three months ended March 31, 2020.

Capitalization Ratios

MGE Energy's capitalization ratios were as follows:

	MGE Energy
	March 31,2021	December 31, 2020
Common shareholders' equity	63.4%	62.9%
Long-term debt(a)	33.2%	33.7%
Short-term debt	3.4%	3.4%

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

MGE Energy's and MGE's Capital Requirements

MGE Energy's and MGE's liquidity are primarily affected by their capital expenditure requirements. During the three months ended March 31, 2021, capital expenditures for MGE Energy and MGE totaled $34.7 million, which included $34.2 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 2021-2023 capital expenditure forecast included under Item 7. Management's Discussion and Analysis of Financial Condition and Results of Operations – Liquidity and Capital Resources in the 2020 Annual Report on Form 10-K.

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 borrowings are subject to default or prepayment as a result of a downgrading of credit ratings, although a downgrading of MGE's credit ratings could increase fees and interest charges under both MGE Energy's and MGE's credit agreements.

Environmental Matters

There were no material updates or developments in environmental matters that occurred during the three months ended March 31, 2021. Further discussion of environmental matters is included in the 2020 Annual Report on Form 10-K and Footnote 8.a. of Notes to Consolidated Financial Statements in this Report.

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Other Matters

Rate Matters

In May 2021, MGE filed an application with the PSCW requesting a 5.9% increase to electric rates and a 3.0% increase to gas rates for 2022. The proposed electric and gas rate increases are primarily 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 is the completion in 2020 of the one-time return of the electric excess deferred tax credit related to the 2017 Tax Act not restricted by IRS normalization rules. In its application, MGE is proposing to address potential 2023 rate changes through an electric limited rate case re-opener and a 1.65% increase in gas rates. PSCW approval of the application is pending. A final order is expected before the end of the year.

Details related to MGE's 2022/2023 proposed rate case:

(Dollars in thousands)	Proposed Average Rate Base(a)	Proposed Return on Common Equity(b)	Proposed Common Equity Component of Regulatory Capital Structure
Electric (2022 Test Period)	1,048,440	9.8%	55.63%
Gas (2022 Test Period)	300,797	9.8%	55.63%

(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)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.

Proposed electric (2023 Test Period) average rate base will be subject to a limited reopener expected to be filed in 2022 and proposed gas (2023 Test Period) average rate base is $317.6 million. MGE has proposed to maintain 2022 levels for return on common stock equity and capital structure for electric and gas rates in 2023.

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 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

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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 5.0% and 6.5% of our net income during the three months ended March 31, 2021 and 2020, 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.

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Item 3. Quantitative and Qualitative Disclosures About Market Risk.

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

Commodity Price Risk

MGE has commodity price risk exposure with respect to the price of natural gas, electricity, coal, emission credits, and oil. MGE'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. Beginning in 2021, MGE is subject to a plus or minus 1% range. Prior to 2021, the range was set at 2%. MGE assumes the risks and benefits of variances that are within the cost tolerance band. For 2021, $64.1 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 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 also holds financial transmission rights (FTRs), which are used to hedge the risk of increased transmission congestion charges. As of March 31, 2021, the fair value of exchange traded derivatives and FTRs exceeded their cost basis by $0.5 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 also allows MGE an option to extend the contract after the base term. The agreement is considered a derivative contract and is recognized at its fair value on the consolidated balance 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, 2021, reflected a loss position of $11.6 million.

44

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 increased by approximately 3% during the three months ended March 31, 2021.

Credit Risk - Counterparty

Credit risk is the loss that may result from counterparty nonperformance. MGE is exposed to credit risk primarily through its merchant energy business. MGE uses credit policies to manage credit risk, which include an established credit approval process, counterparty limits, credit mitigation measures such as collateral or prepayment arrangements, and using netting agreements.

Due to the possibility of extreme volatility in the prices of energy commodities and derivatives, the market value of contractual positions with individual counterparties could exceed established credit limits or collateral provided by those counterparties. If such a counterparty were then to fail to perform its obligations under its contract (for example, fail to deliver the electricity MGE originally contracted for), MGE could sustain a loss that could have a material impact on its financial results.

Additionally, if a counterparty were to default and MGE were to liquidate all contracts with that entity, MGE's credit loss could include: the loss in value of mark-to-market contracts, the amount owed for settled transactions, and additional payments to settle unrealized losses. As of March 31, 2021, 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, 2020, no one customer constituted more than 10% of total operating revenues for MGE Energy and MGE. Credit risk for electric and gas is managed by MGE's credit and collection policies, which are consistent with state regulatory requirements.

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

45

Item 4. Controls and Procedures.

During the first quarter of 2021, 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, 2021, 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, 2021, 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.

46

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, 2021	8,504	$	66.93	-	-
February 1-28, 2021	9,790		65.37	-	-
March 1-31, 2021	43,813		71.53	-	-
Total	62,107	$	69.93	-	-

(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 2021, 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.

47

Item 4. Mine Safety Disclosures.

Not applicable to MGE Energy and MGE.

Item 5. Other Information.

Not applicable to MGE Energy and MGE.

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.

48

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 6, 2021	/s/ Jeffrey M. Keebler
	Jeffrey M. Keebler Chairman, President and Chief Executive Officer (Duly Authorized Officer)
Date: May 6, 2021	/s/ Jared J. Bushek
	Jared J. Bushek Vice President - Finance, Chief Information Officer and Treasurer (Chief Financial Officer)
Date: May 6, 2021	/s/ Tamara J. Johnson
	Tamara J. Johnson Vice President - Accounting and Controller (Chief Accounting Officer)

49

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 6, 2021	/s/ Jeffrey M. Keebler
	Jeffrey M. Keebler Chairman, President and Chief Executive Officer (Duly Authorized Officer)
Date: May 6, 2021	/s/ Jared J. Bushek
	Jared J. Bushek Vice President - Finance, Chief Information Officer and Treasurer (Chief Financial Officer)
Date: May 6, 2021	/s/ Tamara J. Johnson
	Tamara J. Johnson Vice President - Accounting and Controller (Chief Accounting Officer)

50

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) Ev aluated 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 6, 2021

EX-31

1

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) Ev aluated 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 6, 2021

EX-31

1

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 6, 2021

EX-31

1

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 6, 2021

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, 2021, 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, pursuan t 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 6, 2021

EX-32

1

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, 2021, 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 6, 2021

EX-32

1

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, 2021, 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 6, 2021

EX-32

1

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, 2021, 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 6, 2021

XML

Document and Entity Information - shares	3 Months Ended
	Mar. 31, 2021	Apr. 30, 2021
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, 2021
Amendment Flag	false
Trading Symbol	MGEE
Document Fiscal Year Focus	2021
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 Country Code	WI
Entity Address Address Line 1	133 South Blair Street
EntityAddressCityOrTown	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 Country Code	WI
Entity Address Address Line 1	133 South Blair Street
EntityAddressCityOrTown	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, 2021	Mar. 31, 2020
Operating Revenues:
Electric revenues	$ 100,645	$ 93,028
Gas revenue	67,270	56,845
Total Operating Revenues	167,915	149,873
Operating Expenses:
Fuel for electric generation	13,171	9,706
Purchased power	9,355	10,486
Cost of gas sold	37,444	30,798
Other operations and maintenance	45,682	44,369
Depreciation and amortization	18,382	18,167
Other general taxes	4,827	4,907
Total Operating Expenses	128,861	118,433
Operating Income	39,054	31,440
Other (expense) income, net	2,078	5,671
Interest expense, net	(5,740)	(6,061)
Income before income taxes	35,392	31,050
Income tax benefit (provision)	(459)	(5,013)
Net Income Including Noncontrolling Interest	34,933	26,037
Net Income	$ 34,933	$ 26,037
Earnings per share of Common Stock - Basic	$ 0.97	$ 0.75
Earnings per share of Common Stock - Diluted	0.97	0.75
Dividends per share of common stock	$ 0.370	$ 0.353
Weighted Average Number Of Shares Outstanding Basic	36,163	34,668
Weighted Average Shares Outstanding - Diluted	36,165	34,668
MGE [Member]
Operating Revenues:
Electric revenues	$ 100,645	$ 93,028
Gas revenue	67,270	56,845
Total Operating Revenues	167,915	149,873
Operating Expenses:
Fuel for electric generation	13,171	9,706
Purchased power	9,355	10,486
Cost of gas sold	37,444	30,798
Other operations and maintenance	45,538	44,150
Depreciation and amortization	18,382	18,167
Other general taxes	4,827	4,907
Total Operating Expenses	128,717	118,214
Operating Income	39,198	31,659
Other (expense) income, net	(104)	3,380
Interest expense, net	(5,753)	(6,111)
Income before income taxes	33,341	28,928
Income tax benefit (provision)	433	(4,371)
Net Income Including Noncontrolling Interest	33,774	24,557
Less Net Income Attributable to Noncontrolling Interest, net of tax	(5,501)	(5,493)
Net Income	$ 28,273	$ 19,064

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Consolidated Statements of Cash Flows (Unaudited) - USD ($)	3 Months Ended
	Mar. 31, 2021	Mar. 31, 2020
Operating Activities:
Net Income	$ 34,933,000	$ 26,037,000
Items not affecting cash:
Depreciation and amortization	18,382,000	18,167,000
Deferred income taxes	(796,000)	1,433,000
Provision for doubtful receivables	388,000	734,000
Employee benefit plan cost (credit)	1,461,000	(940,000)
Equity earnings in investments	(2,444,000)	(2,266,000)
Other items	(277,000)	(1,974,000)
Changes in working capital items:
(Increase) decrease in current assets	(2,851,000)	14,089,000
(Decrease) increase in current liabilities	(4,213,000)	(2,738,000)
Dividends from investments	1,967,000	2,700,000
Cash contributions to pension and other postretirement plans	(1,552,000)	(1,470,000)
Other noncurrent items, net	(1,115,000)	47,000
Cash Provided by Operating Activities	43,883,000	53,819,000
Investing Activities:
Capital expenditures	(34,746,000)	(46,758,000)
Capital contributions to investments	(670,000)	(1,643,000)
Other	(419,000)	(398,000)
Cash Used for Investing Activities	(35,835,000)	(48,799,000)
Financing Activities:
Cash dividends paid on common stock	(13,380,000)	(12,221,000)
Repayments of long-term debt	(1,182,000)	(1,155,000)
Net proceeds from short-term debt	1,500,000	3,000,000
Other	(523,000)	(664,000)
Cash Used for Financing Activities	(13,585,000)	(11,040,000)
Change in cash, cash equivalents, and restricted cash	(5,537,000)	(6,020,000)
Cash, cash equivalents, and restricted cash at beginning of period	47,039,000	25,814,000
Cash, cash equivalents, and restricted cash at end of period	41,502,000	19,794,000
Significant noncash investing activities:
Accrued capital expenditures	8,843,000	8,129,000
MGE [Member]
Operating Activities:
Net Income	33,774,000	24,557,000
Items not affecting cash:
Depreciation and amortization	18,382,000	18,167,000
Deferred income taxes	(1,766,000)	976,000
Provision for doubtful receivables	388,000	734,000
Employee benefit plan cost (credit)	1,461,000	(940,000)
Other items	(252,000)	(1,721,000)
Changes in working capital items:
(Increase) decrease in current assets	(3,037,000)	12,953,000
(Decrease) increase in current liabilities	(4,037,000)	290,000
Cash contributions to pension and other postretirement plans	(1,552,000)	(1,470,000)
Other noncurrent items, net	(1,380,000)	(428,000)
Cash Provided by Operating Activities	41,981,000	53,118,000
Investing Activities:
Capital expenditures	(34,746,000)	(46,758,000)
Other	(462,000)	(406,000)
Cash Used for Investing Activities	(35,208,000)	(47,164,000)
Financing Activities:
Distributions to parent from noncontrolling interest	(5,000,000)	(7,000,000)
Repayments of long-term debt	(1,182,000)	(1,155,000)
Net proceeds from short-term debt	1,500,000	3,000,000
Other	(523,000)	(664,000)
Cash Used for Financing Activities	(5,205,000)	(5,819,000)
Change in cash, cash equivalents, and restricted cash	1,568,000	135,000
Cash, cash equivalents, and restricted cash at beginning of period	6,404,000	5,529,000
Cash, cash equivalents, and restricted cash at end of period	7,972,000	5,664,000
Significant noncash investing activities:
Accrued capital expenditures	$ 8,843,000	$ 8,129,000

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Consolidated Balance Sheets (Unaudited) - USD ($)	Mar. 31, 2021	Dec. 31, 2020
Current Assets:
Cash and cash equivalents	$ 40,239,000	$ 44,738,000
Accounts receivable, less reserves	43,172,000	41,384,000
Other accounts receivables, less reserves	9,702,000	7,300,000
Unbilled revenues	25,148,000	27,511,000
Materials and supplies, at average cost	32,222,000	32,513,000
Fuel for electric generation, at average cost	4,885,000	6,356,000
Stored natural gas, at average cost	1,578,000	8,396,000
Prepaid taxes	11,210,000	15,179,000
Regulatory assets - current	24,313,000	14,748,000
Other current assets	9,042,000	11,394,000
Total Current Assets	201,511,000	209,519,000
Other long-term receivables	1,486,000	1,435,000
Regulatory assets	139,667,000	142,504,000
Pension benefit asset	17,848,000	13,873,000
Other deferred assets and other	22,564,000	22,259,000
Property, Plant, and Equipment:
Property, plant, and equipment, net	1,633,908,000	1,630,286,000
Construction work in progress	157,970,000	139,099,000
Total Property, Plant, and Equipment	1,791,878,000	1,769,385,000
Investments	95,283,000	94,676,000
Total Assets	2,270,237,000	2,253,651,000
Current Liabilities:
Long-term debt due within one year	4,800,000	4,771,000
Short-term debt	54,000,000	52,500,000
Accounts payable	53,840,000	54,642,000
Accrued interest and taxes	7,540,000	8,539,000
Accrued payroll related items	10,019,000	12,635,000
Regulatory liabilities - current	37,035,000	41,664,000
Derivative liabilities	9,790,000	10,160,000
Other current liabilities	6,774,000	6,015,000
Total Current Liabilities	183,798,000	190,926,000
Other Credits:
Deferred income taxes	236,903,000	231,471,000
Investment tax credit - deferred	21,588,000	21,821,000
Regulatory liabilities	143,365,000	142,239,000
Accrued pension and other postretirement benefits	77,941,000	78,168,000
Derivative liabilities	1,800,000	3,980,000
Finance lease liabilities	17,623,000	17,532,000
Other deferred liabilities and other	71,297,000	72,211,000
Total Other Credits	570,517,000	567,422,000
Capitalization:
Common shareholders equity	997,711,000	976,000,000
Long-term debt	518,211,000	519,303,000
Total Capitalization	1,515,922,000	1,495,303,000
Commitments and contingencies (see Footnote 8)
Total Liabilities and Capitalization	2,270,237,000	2,253,651,000
MGE [Member]
Current Assets:
Cash and cash equivalents	6,709,000	4,103,000
Accounts receivable, less reserves	43,172,000	41,384,000
Affiliate receivables	530,000	532,000
Other accounts receivables, less reserves	9,698,000	7,295,000
Unbilled revenues	25,148,000	27,511,000
Materials and supplies, at average cost	32,222,000	32,513,000
Fuel for electric generation, at average cost	4,885,000	6,356,000
Stored natural gas, at average cost	1,578,000	8,396,000
Prepaid taxes	11,102,000	14,848,000
Regulatory assets - current	24,313,000	14,748,000
Other current assets	8,940,000	11,326,000
Total Current Assets	168,297,000	169,012,000
Affiliate receivable long-term	1,986,000	2,118,000
Regulatory assets	139,667,000	142,504,000
Pension benefit asset	17,848,000	13,873,000
Other deferred assets and other	22,877,000	22,448,000
Property, Plant, and Equipment:
Property, plant, and equipment, net	1,633,936,000	1,630,314,000
Construction work in progress	157,970,000	139,099,000
Total Property, Plant, and Equipment	1,791,906,000	1,769,413,000
Investments	433,000	603,000
Total Assets	2,143,014,000	2,119,971,000
Current Liabilities:
Long-term debt due within one year	4,800,000	4,771,000
Short-term debt	54,000,000	52,500,000
Accounts payable	53,808,000	54,576,000
Accrued interest and taxes	9,574,000	10,405,000
Accrued payroll related items	10,019,000	12,635,000
Regulatory liabilities - current	37,035,000	41,664,000
Derivative liabilities	9,790,000	10,160,000
Other current liabilities	6,776,000	6,042,000
Total Current Liabilities	185,802,000	192,753,000
Other Credits:
Deferred income taxes	204,853,000	200,390,000
Investment tax credit - deferred	21,588,000	21,821,000
Regulatory liabilities	143,365,000	142,239,000
Accrued pension and other postretirement benefits	77,941,000	78,168,000
Derivative liabilities	1,800,000	3,980,000
Finance lease liabilities	17,623,000	17,532,000
Other deferred liabilities and other	71,445,000	72,173,000
Total Other Credits	538,615,000	536,303,000
Capitalization:
Common shareholders equity	758,689,000	730,416,000
Noncontrolling interest	141,697,000	141,196,000
Total Equity	900,386,000	871,612,000
Long-term debt	518,211,000	519,303,000
Total Capitalization	1,418,597,000	1,390,915,000
Commitments and contingencies (see Footnote 8)
Total Liabilities and Capitalization	$ 2,143,014,000	$ 2,119,971,000

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Consolidated Balance Sheets (Unaudited) (Parentheticals) - USD ($) $ in Thousands	Mar. 31, 2021	Dec. 31, 2020
Receivables, Net
Reserve for uncollectible accounts receivable	$ 6,382	$ 5,787
Reserve for uncollectible other accounts receivable	1,307	1,290
MGE [Member]
Receivables, Net
Reserve for uncollectible accounts receivable	6,382	5,787
Reserve for uncollectible other accounts receivable	$ 1,307	$ 1,290

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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]	Accumulated Other Comprehensive Income/(Loss) [Member]
Beginning balance, shares at Dec. 31, 2019		34,668
Beginning balance, value at Dec. 31, 2019	$ 855,676	$ 34,668	$ 316,268	$ 504,740	$ 0
Increase (Decrease) In Stockholders' Equity [Roll Forward]
Net Income	26,037			26,037
Common stock dividends declared	(12,221)			(12,221)
Ending balance, shares at Mar. 31, 2020		34,668
Ending balance, value at Mar. 31, 2020	869,492	$ 34,668	316,268	518,556	0
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

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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]	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, 2019			34,668	17,348
Beginning balance, value at Dec. 31, 2019		$ 777,589		$ 17,348		$ 222,917	$ 397,021	$ 0	$ 140,303
Increase (Decrease) In Stockholders' Equity [Roll Forward]
Net Income	$ 26,037	24,557					19,064		5,493
Distributions to parent from noncontrolling interest		(7,000)							(7,000)
Ending balance, shares at Mar. 31, 2020			34,668	17,348
Ending balance, value at Mar. 31, 2020		795,146		$ 17,348		222,917	416,085	0	138,796
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
Distributions to parent from noncontrolling interest		(5,000)							(5,000)
Equity-based compensation plans and other	$ 158				$ 158
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

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Consolidated Statements of Common Equity (Unaudited) (Parentheticals) - $ / shares	3 Months Ended
	Mar. 31, 2021	Mar. 31, 2020
Consolidated Statements of Common Equity
Dividends per share of common stock	$ 0.370	$ 0.353

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Summary of Significant Accounting Principles

3 Months Ended

Mar. 31, 2021

Organization, Consolidation and Presentation of Financial Statements [Abstract]

Summary of Significant Accounting Policies

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 2020 Annual Report on Form 10-K (the 2020 Annual Report on Form 10-K).

The accompanying consolidated financial statements as of March 31, 2021, and during the three months ended, are unaudited but include all adjustments that MGE Energy and MGE management consider necessary for a fair statement of their respective financial statements. All adjustments are of a normal, recurring nature except as otherwise disclosed. The year-end consolidated balance sheet information was derived from the audited balance sheet appearing in the 2020 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 62 through 115 of the 2020 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)		2021		2020		2021		2020
Cash and cash equivalents	$	40,239	$	44,738	$	6,709	$	4,103
Restricted cash		467		644		467		644
Receivable - margin account		796		1,657		796		1,657
Cash, cash equivalents, and restricted cash	$	41,502	$	47,039	$	7,972	$	6,404

Cash Equivalents

All highly liquid investments purchased with an original maturity of three months or less 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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Adoption of Accounting Principles and Recently Issued Accounting Pronouncements

3 Months Ended

Mar. 31, 2021

New Accounting Pronouncements and Changes in Accounting Principles [Abstract]

New Accounting Pronouncements

New Accounting Standards - MGE Energy and MGE.

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

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Investment in ATC and ATC Holdco

3 Months Ended

Mar. 31, 2021

Equity Method Investments and Joint Ventures [Abstract]

Investment in ATC and ATC Holdco

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)		2021		2020
Equity earnings from investment in ATC	$	2,420	$	2,266
Dividends from ATC		1,967		2,391
Capital contributions to ATC		-		178

ATC Holdco was formed in December 2016. ATC Holdco's future transmission development activities have been suspended for the near term.ATC's summarized financial data is as follows:

		Three Months Ended
		March 31,
(In thousands)		2021		2020
Operating revenues	$	188,694	$	186,801
Operating expenses		(95,104)		(95,211)
Other income, net		378		375
Interest expense, net		(28,871)		(28,888)
Earnings before members' income taxes	$	65,097	$	63,077

MGE receives transmission and other related services from ATC. During the three months ended March 31, 2021 and 2020, MGE recorded $8.0 million and $7.7 million, respectively, for transmission services received from ATC. MGE also provides a variety of operational, maintenance, and project management work for ATC, which is reimbursed by ATC. As of March 31, 2021, and December 31, 2020, MGE had a receivable due from ATC of $3.0 and $2.6 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, 2021

Income Tax Disclosure [Abstract]

Taxes

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,	2021		2020		2021		2020
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	(1.6)		(0.1)		(1.8)		(0.1)
Credit for electricity from wind energy	(7.1)		(6.9)		(7.8)		(7.5)
AFUDC equity, net	(0.6)		(1.6)		(0.6)		(1.7)
Amortization of utility excess deferred tax - tax reform(a)	(16.7)		(2.6)		(18.3)		(2.8)
Other, net, individually insignificant	-		-		(0.1)		(0.1)
Effective income tax rate	1.3	%	16.1	%	(1.3)	%	15.1	%

(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, 2021 and 2020, MGE recognized $0.7 million. 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.

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Pension and Other Postretirement Plans

3 Months Ended

Mar. 31, 2021

Compensation and Retirement Disclosure [Abstract]

Pension and Other Postretirement Plans

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)		2021		2020
Pension Benefits
Components of net periodic benefit cost:
Service cost	$	1,422	$	1,316
Interest cost		2,272		3,023
Expected return on assets		(7,375)		(6,811)
Amortization of:
Prior service credit		(31)		(31)
Actuarial loss		1,580		1,286
Net periodic benefit (credit) cost	$	(2,132)	$	(1,217)
Postretirement Benefits
Components of net periodic benefit cost:
Service cost	$	351	$	311
Interest cost		384		573
Expected return on assets		(817)		(790)
Amortization of:
Transition obligation		1		1
Prior service credit		(380)		(667)
Actuarial loss		109		70
Net periodic benefit (credit) cost	$	(352)	$	(502)

As approved by the PSCW, MGE is allowed to defer differences between actual employee benefit plan costs and costs reflected in current rates. The deferred costs may be recovered or refunded in MGE's next rate filing. For the three months ended March 31, 2021 and 2020, MGE recovered approximately $3.4 million and $0.4 million, respectively, of pension and other postretirement costs, which reduced the amount previously deferred and has not been reflected in the table above.

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Equity and Financing Arrangements

3 Months Ended

Mar. 31, 2021

Equity and Financing Arrangements Disclosure [Abstract]

Equity and Financing Arrangements

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, 2021 and 2020, MGE Energy issued no new shares of common stock under the Stock Plan.

b.Dilutive Shares Calculation - MGE Energy.

As of March 31, 2021, 1,543 shares were included in the calculation of diluted earnings per share related to nonvested equity awards. See Footnote 7 for additional information on shared-based compensation awards.

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Share-Based Compensation

3 Months Ended

Mar. 31, 2021

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

Share-Based Compensation

Share-Based Compensation - MGE Energy and MGE.

During the three months ended March 31, 2021 and 2020, MGE recorded $0.7 million in compensation expense and $0.6 million in compensation benefit, respectively, related to share-based compensation awards under the 2006 Performance Unit Plan, the 2020 Performance Unit Plan, the 2013 Director Incentive Plan, and the 2021 Long-Term Incentive Plan (2021 Plan).

In January 2021, cash payments of $1.9 million were distributed related to awards that were granted under the plans in 2018, for the 2013 Director Incentive Plan, and in 2016, for the 2006 Performance Unit Plan.

In February 2021, MGE issued 10,187 performance units and 16,267 restricted stock units under the 2021 Plan to eligible employees and non-employee directors.

The performance units can be paid out in either cash, shares of common stock or a combination of cash and stock and are accounted for as a liability award. The restricted stock units will be paid out in shares of common stock, and therefore accounted for as equity awards.

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Commitments and Contingencies

3 Months Ended

Mar. 31, 2021

Commitments and Contingencies Disclosure [Abstract]

Commitments and Contingencies

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 for Units 1 and 2 are subject to PSCW and regional regulatory reviews, including identification and approval of energy and capacity resources to replace Columbia. 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. The standards were finalized in August 2020.

In February 2021, MGE and the other owners of Columbia filed a Certificate of Authority (CA) application with the PSCW. The CA application commits to close Columbia's wet pond system to comply with the Coal Combustions Residuals (CCR) Rule 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 rule's requirements no later than December 31, 2023, as determined by the permitting authority. The operator of the Elm Road Units has been evaluating the rule impacts and has conducted an analysis of compliance obligations, pollution prevention technologies, and their associated costs. In February 2021, MGE and its co-owner filed a CA application with the PSCW. If approved, MGE's share of the estimated costs to comply with the rule is estimated to be approximately $4 million. Subject to approval from the PSCW, construction is expected to begin in 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 Wisconsin Pollution Discharge Elimination System permit assumes that the plant meets BTA for the duration of the permit, which expires in 2023. However, MGE must conduct studies of its Blount plant by the end of 2021 to help regulators determine BTA.

Columbia's river intakes are subject to this rule. BTA improvements may not be required given that Columbia could be fully retired before the issuance of the next permit, which is expected to be issued in 2023 or later. 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 January 2021, the U.S. Court of Appeals for the District of Columbia Circuit (D.C. Circuit) vacated and remanded to the EPA the Affordable Clean Energy Rule (ACE Rule) and the repeal of the predecessor Clean Power Plan Rule (CPP Rule), both of which regulated greenhouse gas emissions from existing electric generation units pursuant to Section 111(d) of the Clean Air Act. As a result of these legal proceedings, neither the CPP nor ACE rules are currently in effect. MGE will continue to evaluate the rule development and monitor ongoing and potential legal proceedings.

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

In May 2018, the EPA issued a final rule that designated the northeast portion of Milwaukee County as being in nonattainment with Ozone NAAQS. The Elm Road Units are located in Milwaukee County, outside the designated nonattainment area. In August 2018, several environmental groups, the City of Chicago, and the State of Illinois filed federal lawsuits challenging several of the EPA's attainment designation decisions, including the partial Milwaukee County designation as being too narrow and not sufficiently protective. In July 2020, the U.S. District Court of the District of Columbia remanded the partial Milwaukee County attainment designation back to the EPA for further explanation. MGE is monitoring

the outcome of the EPA's remand analysis and how it may affect the Elm Road Units in Milwaukee County. 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 (NO_x) and sulfur dioxide (SO₂) emissions, including the Cross State Air Pollution Rule (CSAPR) and Clean Air Visibility Rule (CAVR).

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. In September 2019, the D.C. Circuit remanded the rule to the EPA holding that the rule improperly provided only a partial remedy for addressing interstate transport of pollutants from upwind to downwind states. In March 2021, the EPA addressed the remand by finalizing its revised CSAPR Update Rule. The revised rule does not require further emission reductions from Wisconsin stationary sources beyond those under the original CSAPR. MGE has met its current CSAPR obligations through a combination of reduced emissions through pollution control (e.g., SCR installation at Columbia), as well as owned, received, and purchased allowances. MGE expects to meet ongoing CSAPR obligations for the foreseeable future. MGE will continue to monitor legal developments and any future updates to this rule.

•The EPA's Coal Combustion Residuals Rule (CCR), which regulates coal ash from burning coal for the purpose of generating electricity as a solid waste 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. In August 2020, the EPA revised the CCR rule to require 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 comply by October 2022. The EPA will address the remaining issues on remand in a subsequent action.

Review of the Elm Road Units has indicated that the costs to comply with this rule are not expected to be significant. Columbia's operator has completed a review of its system and has developed a compliance plan. In February 2021, a CA application was filed with the PSCW for approval to install technology required to cease bottom ash transport water discharges rather than extend the longevity of the ash ponds. If approved, MGE's share of the estimated costs of the project would 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.

In January 2021, certain environmental groups filed a petition against the PSCW regarding MGE's 2021 rate settlement. MGE has intervened in the petition in cooperation with the PSCW. See Footnote 9.a. for more information regarding this matter.

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Rate Matters

3 Months Ended

Mar. 31, 2021

Regulated Operations [Abstract]

Rate Matters

Rate Matters - MGE Energy and MGE.

a.Rate Proceedings.

In May 2021, MGE filed an application with the PSCW requesting a 5.9% increase to electric rates and a

3.0% increase to gas rates for 2022. The proposed electric and gas rate increases are primarily 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 is the completion in 2020 of the one-time return of the electric excess deferred tax credit related to the 2017 Tax Act not restricted by IRS normalization rules. In its application, MGE is proposing to address potential 2023 rate changes through an electric limited rate case re-opener and a 1.65% increase in gas rates. The proposed return on common stock equity for 2022 is 9.8% based on a proposed capital structure consisting of 55.6% common equity in 2022. PSCW approval of the application is pending. A final order is expected before the end of the year.

In December 2020, the PSCW approved a settlement agreement for MGE's 2021 rate case. The settlement agreement provides for a zero percent increase for electric rates and an approximately 4% increase for gas rates in 2021. The electric rate settlement includes an increase in rate base but the associated rate increase is primarily offset by lower fuel and purchase 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 is 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 covers infrastructure costs and technology improvements. The settlement agreement also includes 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 its next rate filing. Any difference would be recorded as a regulatory asset or regulatory liability. The return on common stock equity for 2021 is 9.8% based on a capital structure of 55.8% common equity in 2021.

On January 27, 2021, Sierra Club and Vote Solar filed a petition with the Dane County Circuit Court seeking review of the PSCW decision approving the rate settlement in MGE's 2021 rate case. The PSCW is named as the responding party; MGE is not named as a party. The petition challenges the process the PSCW used to approve the portion of the settlement 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 settlement has not been challenged. The PSCW is expected to vigorously defend its approval of the rate case settlement. MGE has intervened in the proceedings to further defend the PSCW’s decision.

In December 2018, the PSCW approved a settlement agreement between MGE and intervening parties in the then pending rate case. The settlement decreased electric rates by 2.24%, or $9.2 million, in 2019. The decrease in electric rates reflected the ongoing impacts of the 2017 Tax Act. Lower fuel costs and an increase in rate base from renewable generation assets further impacted the rate change. In 2020, electric rates decreased a further 0.84%, or $3.4 million, as approved by the PSCW in December 2019 in MGE's 2020 Fuel Cost Plan, which reflected lower fuel costs. The settlement agreement increased gas rates by 1.06%, or $1.7 million, in 2019 and 1.46%, or $2.4 million, in 2020. The gas increase covered infrastructure costs. It also reflected the impacts of the 2017 Tax Act. The return on common stock equity for 2019 and 2020 was 9.8% based on a capital structure consisting of 56.6% common equity in 2019 and 56.1% common equity in 2020.

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% in 2021. 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. In 2020 the fuel rules bandwidth was set at plus or minus 2%. 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.

As of December 31, 2020, MGE had deferred $3.2 million of 2020 fuel-related savings. These costs will be subject to the PSCW's annual review of 2020 fuel costs, which is expected to be completed in 2021. In March 2021, as part of the 2020 fuel costs application filed with the PSCW, MGE seeks to return the 2020 fuel-related savings to customers in 2022 as part of the 2022 rate case.

As of March 31, 2021, MGE had deferred $0.5 million of 2021 fuel savings. These costs will be subject to the PSCW's annual review of 2021 fuel costs, which is expected to be completed in 2022.

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Derivative and Hedging Instruments

3 Months Ended

Mar. 31, 2021

Derivative Instruments and Hedging Activities Disclosure [Abstract]

Derivative and Hedging Instruments

Derivative and Hedging Instruments - MGE Energy and MGE.

a.Purpose.

As part of its regular operations, MGE enters into contracts, including options, swaps, futures, forwards, and other contractual commitments, to manage its exposure to commodity prices. 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, 2021		December 31, 2020
Commodity derivative contracts	277,400	MWh	259,080	MWh
Commodity derivative contracts	2,190,000	Dth	6,030,000	Dth
FTRs	1,152	MW	2,869	MW
PPA	700	MW	850	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, 2021, and December 31,

2020, the fair value of exchange traded derivatives and FTRs exceeded their cost basis by $0.5 million and $0.2 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 also allows MGE an option to extend the contract after the base term. The agreement is accounted for as a derivative contract and is recognized at its fair value on the consolidated balance 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, 2021, and December 31, 2020, reflected a loss position of $11.6 million and $14.1 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, 2021
Commodity derivative contracts(a)	$	653	$	174	Other current assets
Commodity derivative contracts(a)		30		16	Other deferred charges
FTRs		38		-	Other current assets
PPA		N/A		9,790	Derivative liability (current)
PPA		N/A		1,800	Derivative liability (long-term)
December 31, 2020
Commodity derivative contracts(a)	$	617	$	593	Other current assets
Commodity derivative contracts(a)		189		39	Other deferred charges
FTRs		-		23	Other current liabilities
PPA		N/A		10,160	Derivative liability (current)
PPA		N/A		3,980	Derivative liability (long-term)

(a) No collateral was posted against derivative positions as of March 31, 2021, and December 31, 2020.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, 2021
Commodity derivative contracts	$	683	$	(190)	$	-	$	493
FTRs		38		-		-		38
December 31, 2020
Commodity derivative contracts	$	806	$	(632)	$	-	$	174

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, 2021
Commodity derivative contracts	$	190	$	(190)	$	-	$	-
PPA		11,590		-		-		11,590
December 31, 2020
Commodity derivative contracts	$	632	$	(632)	$	-	$	-
FTRs		23		-		-		23
PPA		14,140		-		-		14,140

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.

		2021				2020
(In thousands)		Current and Long-Term Regulatory Asset		Other Current Assets		Current and Long-Term Regulatory Asset		Other Current Assets
Three Months Ended March 31:
Balance at January 1,	$	13,989	$	1,162	$	26,875	$	1,100
Unrealized gain		(3,588)		-		(689)		-
Realized (loss) gain reclassified to a deferred account		(50)		50		(1,063)		1,063
Realized gain (loss) reclassified to income statement		708		(1,039)		204		(1,733)
Balance at March 31,	$	11,059	$	173	$	25,327	$	430

		Realized losses (gains)
		2021				2020
(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	$	(195)	$	1,022	$	680	$	1,607
FTRs		(256)		-		(65)		-
PPA		(240)		-		(693)		-

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, 2021, 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, 2021, and December 31, 2020, 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, 2021, no counterparties had defaulted.

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Fair Value of Financial Instruments

3 Months Ended

Mar. 31, 2021

Fair Value Disclosures [Abstract]

Fair Value of Financial Instruments

Fair Value of Financial Instruments - MGE Energy and MGE.

Fair value is defined as the price that would be received to sell an asset or would be paid to transfer a liability (an exit price) in the principal or most advantageous market for the asset or liability in an orderly

transaction between market participants at the measurement date. The 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, 2021				December 31, 2020
(In thousands)		Carrying Amount		Fair Value		Carrying Amount		Fair Value
MGE Energy
Assets:
Cash and cash equivalents	$	40,239	$	40,239	$	44,738	$	44,738
Liabilities:
Short-term debt - commercial paper		54,000		54,000		52,500		52,500
Long-term debt(a)		527,038		590,748		528,220		639,271
MGE
Assets:
Cash and cash equivalents	$	6,709	$	6,709	$	4,103	$	4,103
Liabilities:
Short-term debt - commercial paper		54,000		54,000		52,500		52,500
Long-term debt(a)		527,038		590,748		528,220		639,271

(a) Includes long-term debt due within one year. Excludes debt issuance costs and unamortized discount of $4.0 million and $4.1 million as of March 31, 2021, and December 31, 2020, 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, 2021
(In thousands)		Total		Level 1		Level 2		Level 3
MGE Energy
Assets:
Derivatives, net(b)	$	721	$	423	$	-	$	298
Exchange-traded investments		1,474		1,474		-		-
Total Assets	$	2,195	$	1,897	$	-	$	298
Liabilities:
Derivatives, net(b)	$	11,780	$	115	$	-	$	11,665
Deferred compensation		3,581		-		3,581		-
Total Liabilities	$	15,361	$	115	$	3,581	$	11,665
MGE
Assets:
Derivatives, net(b)	$	721	$	423	$	-	$	298
Exchange-traded investments		431		431		-		-
Total Assets	$	1,152	$	854	$	-	$	298
Liabilities:
Derivatives, net(b)	$	11,780	$	115	$	-	$	11,665
Deferred compensation		3,581		-		3,581		-
Total Liabilities	$	15,361	$	115	$	3,581	$	11,665

		Fair Value as of December 31, 2020
(In thousands)		Total		Level 1		Level 2		Level 3
MGE Energy
Assets:
Derivatives, net(b)	$	806	$	436	$	-	$	370
Exchange-traded investments		1,750		1,750		-		-
Total Assets	$	2,556	$	2,186	$	-	$	370
Liabilities:
Derivatives, net(b)	$	14,795	$	370	$	-	$	14,425
Deferred compensation		3,509		-		3,509		-
Total Liabilities	$	18,304	$	370	$	3,509	$	14,425
MGE
Assets:
Derivatives, net(b)	$	806	$	436	$	-	$	370
Exchange-traded investments		603		603		-		-
Total Assets	$	1,409	$	1,039	$	-	$	370
Liabilities:
Derivatives, net(b)	$	14,795	$	370	$	-	$	14,425
Deferred compensation		3,509		-		3,509		-
Total Liabilities	$	18,304	$	370	$	3,509	$	14,425

(b) These amounts are shown gross. No collateral was posted against derivative positions with counterparties as of March 31, 2021, or December 31, 2020.

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
Significant Unobservable Inputs	March 31, 2021		December 31, 2020
Basis adjustment:
On peak	94.4	%	94.2	%
Off peak	95.0	%	94.5	%
Counterparty fuel mix:
Internal generation - range	41.0% - 66.0	%	46.0% - 65.0	%
Internal generation - weighted average	56.9	%	56.5	%
Purchased power - range	59.0% - 34.0	%	54.0% - 35.0	%
Purchased power - weighted average	43.1	%	43.5	%

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)		2021		2020
Beginning balance	$	(14,055)	$	(26,456)
Realized and unrealized gains (losses):
Included in regulatory assets		2,688		810
Included in other comprehensive income		-		-
Included in earnings		307		(1,453)
Included in current assets		355		247
Purchases		5,884		5,015
Sales		-		-
Issuances		-		-
Settlements		(6,546)		(3,810)
Balance as of March 31,	$	(11,367)	$	(25,647)
Total gains (losses) included in earnings attributed to the change in unrealized gains (losses) related to assets and liabilities held at 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)		2021		2020
Purchased power expense	$	702	$	(1,184)
Cost of gas sold expense		(395)		(269)
Total	$	307	$	(1,453)

(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, 2021

Public Utilities Property Plant And Equipment [Abstract]

Jointly Owned Electric Utility Plant

Joint Plant 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		Date of Commercial
Project	Interest		Generation		Estimated Costs		March 31, 2021(a)		Operation
Badger Hollow I(b)	33	%	50	MW	$65	million	$56.4	million	Q3 2021(c)
Badger Hollow II(b)	33	%	50	MW	$65	million	$5.3	million	December 2022(c)

(a)Excluding AFUDC.

(b)The Badger Hollow I and Badger Hollow II solar farms are located in southwestern Wisconsin in Iowa County, near the villages of Montfort and Cobb.

(c)Estimated date of commercial operation.

MGE received specific approval to recover 100% AFUDC on each of these projects. During the three months ended March 31, 2021 and 2020, MGE recognized $1.1 million and $0.4 million, respectively, after tax, in AFUDC for Badger Hollow I and II.

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Revenue

3 Months Ended

Mar. 31, 2021

Revenue from Contract with Customer [Abstract]

Revenue from Contract with Customer

Revenue - MGE Energy and MGE.

Revenues disaggregated by revenue source were as follows:

		Three Months Ended
(In thousands)		March 31,
Electric revenues		2021		2020
Residential	$	36,694	$	33,428
Commercial		47,883		47,634
Industrial		3,001		2,800
Other-retail/municipal		8,170		8,204
Total retail		95,748		92,066
Sales to the market		4,639		482
Other revenues		222		442
Total electric revenues	$	100,609	$	92,990
Gas revenues
Residential		39,758		33,487
Commercial/Industrial		25,507		21,471
Total retail		65,265		54,958
Gas transportation		2,002		1,794
Other revenues		3		93
Total gas revenues	$	67,270	$	56,845
Non-regulated energy revenues		36		38
Total Operating Revenue	$	167,915	$	149,873

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, 2021

Segment Reporting [Abstract]

Segment Information

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 2020 Annual Report on Form 10-K for additional discussion of each of these segments.

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

(In thousands) MGE Energy		Electric		Gas		Nonregulated Energy		Transmission Investment		All Others		Consolidation/ Elimination		Consolidated Total
Three Months Ended March 31, 2021
Operating revenues from external customers	$	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
Three Months Ended March 31, 2020
Operating revenues from external customers	$	92,990	$	56,845	$	38	$	-	$	-	$	-	$	149,873
Interdepartmental revenues		191		3,451		10,056		-		-		(13,698)		-
Total operating revenues		93,181		60,296		10,094		-		-		(13,698)		149,873
Equity in earnings of investments		-		-		-		2,286		-		-		2,286
Net income (loss)		11,463		8,034		5,060		1,663		(183)		-		26,037

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

(In thousands) MGE		Electric		Gas		Nonregulated Energy		Consolidation/ Elimination		Consolidated Total
Three Months Ended March 31, 2021
Operating revenues from external customers	$	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
Three Months Ended March 31, 2020
Operating revenues from external customers	$	92,990	$	56,845	$	38	$	-	$	149,873
Interdepartmental revenues		191		3,451		10,056		(13,698)		-
Total operating revenues		93,181		60,296		10,094		(13,698)		149,873
Net income attributable to MGE		11,463		8,034		5,060		(5,493)		19,064

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Significant Accounting Policies (Policies)

3 Months Ended

Mar. 31, 2021

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 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 Pronouncements Disclosure

New Accounting Standards - MGE Energy and MGE.

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

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% in 2021. 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. In 2020 the fuel rules bandwidth was set at plus or minus 2%. 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.

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
Significant Unobservable Inputs	March 31, 2021		December 31, 2020
Basis adjustment:
On peak	94.4	%	94.2	%
Off peak	95.0	%	94.5	%
Counterparty fuel mix:
Internal generation - range	41.0% - 66.0	%	46.0% - 65.0	%
Internal generation - weighted average	56.9	%	56.5	%
Purchased power - range	59.0% - 34.0	%	54.0% - 35.0	%
Purchased power - weighted average	43.1	%	43.5	%

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, 2021

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)		2021		2020		2021		2020
Cash and cash equivalents	$	40,239	$	44,738	$	6,709	$	4,103
Restricted cash		467		644		467		644
Receivable - margin account		796		1,657		796		1,657
Cash, cash equivalents, and restricted cash	$	41,502	$	47,039	$	7,972	$	6,404

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Investment in ATC and ATC Holdco (Tables)

3 Months Ended

Mar. 31, 2021

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)		2021		2020
Equity earnings from investment in ATC	$	2,420	$	2,266
Dividends from ATC		1,967		2,391
Capital contributions to ATC		-		178

ATC's summarized financial data is as follows:

		Three Months Ended
		March 31,
(In thousands)		2021		2020
Operating revenues	$	188,694	$	186,801
Operating expenses		(95,104)		(95,211)
Other income, net		378		375
Interest expense, net		(28,871)		(28,888)
Earnings before members' income taxes	$	65,097	$	63,077

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Taxes (Tables)

3 Months Ended

Mar. 31, 2021

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,	2021		2020		2021		2020
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	(1.6)		(0.1)		(1.8)		(0.1)
Credit for electricity from wind energy	(7.1)		(6.9)		(7.8)		(7.5)
AFUDC equity, net	(0.6)		(1.6)		(0.6)		(1.7)
Amortization of utility excess deferred tax - tax reform(a)	(16.7)		(2.6)		(18.3)		(2.8)
Other, net, individually insignificant	-		-		(0.1)		(0.1)
Effective income tax rate	1.3	%	16.1	%	(1.3)	%	15.1	%

(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, 2021 and 2020, MGE recognized $0.7 million. 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.

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Pension and Other Postretirement Plans (Tables)

3 Months Ended

Mar. 31, 2021

Compensation and Retirement Disclosure [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)		2021		2020
Pension Benefits
Components of net periodic benefit cost:
Service cost	$	1,422	$	1,316
Interest cost		2,272		3,023
Expected return on assets		(7,375)		(6,811)
Amortization of:
Prior service credit		(31)		(31)
Actuarial loss		1,580		1,286
Net periodic benefit (credit) cost	$	(2,132)	$	(1,217)
Postretirement Benefits
Components of net periodic benefit cost:
Service cost	$	351	$	311
Interest cost		384		573
Expected return on assets		(817)		(790)
Amortization of:
Transition obligation		1		1
Prior service credit		(380)		(667)
Actuarial loss		109		70
Net periodic benefit (credit) cost	$	(352)	$	(502)

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Derivative and Hedging Instruments (Tables)

3 Months Ended

Mar. 31, 2021

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, 2021		December 31, 2020
Commodity derivative contracts	277,400	MWh	259,080	MWh
Commodity derivative contracts	2,190,000	Dth	6,030,000	Dth
FTRs	1,152	MW	2,869	MW
PPA	700	MW	850	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, 2021
Commodity derivative contracts(a)	$	653	$	174	Other current assets
Commodity derivative contracts(a)		30		16	Other deferred charges
FTRs		38		-	Other current assets
PPA		N/A		9,790	Derivative liability (current)
PPA		N/A		1,800	Derivative liability (long-term)
December 31, 2020
Commodity derivative contracts(a)	$	617	$	593	Other current assets
Commodity derivative contracts(a)		189		39	Other deferred charges
FTRs		-		23	Other current liabilities
PPA		N/A		10,160	Derivative liability (current)
PPA		N/A		3,980	Derivative liability (long-term)

(a) No collateral was posted against derivative positions as of March 31, 2021, and December 31, 2020.

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, 2021
Commodity derivative contracts	$	683	$	(190)	$	-	$	493
FTRs		38		-		-		38
December 31, 2020
Commodity derivative contracts	$	806	$	(632)	$	-	$	174

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, 2021
Commodity derivative contracts	$	190	$	(190)	$	-	$	-
PPA		11,590		-		-		11,590
December 31, 2020
Commodity derivative contracts	$	632	$	(632)	$	-	$	-
FTRs		23		-		-		23
PPA		14,140		-		-		14,140

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.

		2021				2020
(In thousands)		Current and Long-Term Regulatory Asset		Other Current Assets		Current and Long-Term Regulatory Asset		Other Current Assets
Three Months Ended March 31:
Balance at January 1,	$	13,989	$	1,162	$	26,875	$	1,100
Unrealized gain		(3,588)		-		(689)		-
Realized (loss) gain reclassified to a deferred account		(50)		50		(1,063)		1,063
Realized gain (loss) reclassified to income statement		708		(1,039)		204		(1,733)
Balance at March 31,	$	11,059	$	173	$	25,327	$	430

Derivative Gains and Losses in Income Statement

		Realized losses (gains)
		2021				2020
(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	$	(195)	$	1,022	$	680	$	1,607
FTRs		(256)		-		(65)		-
PPA		(240)		-		(693)		-

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Fair Value of Financial Instruments (Tables)

3 Months Ended

Mar. 31, 2021

Fair Value Disclosures [Abstract]

Estimated Fair Market Value of Financial Instruments

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

		March 31, 2021				December 31, 2020
(In thousands)		Carrying Amount		Fair Value		Carrying Amount		Fair Value
MGE Energy
Assets:
Cash and cash equivalents	$	40,239	$	40,239	$	44,738	$	44,738
Liabilities:
Short-term debt - commercial paper		54,000		54,000		52,500		52,500
Long-term debt(a)		527,038		590,748		528,220		639,271
MGE
Assets:
Cash and cash equivalents	$	6,709	$	6,709	$	4,103	$	4,103
Liabilities:
Short-term debt - commercial paper		54,000		54,000		52,500		52,500
Long-term debt(a)		527,038		590,748		528,220		639,271

(a) Includes long-term debt due within one year. Excludes debt issuance costs and unamortized discount of $4.0 million and $4.1 million as of March 31, 2021, and December 31, 2020, 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, 2021
(In thousands)		Total		Level 1		Level 2		Level 3
MGE Energy
Assets:
Derivatives, net(b)	$	721	$	423	$	-	$	298
Exchange-traded investments		1,474		1,474		-		-
Total Assets	$	2,195	$	1,897	$	-	$	298
Liabilities:
Derivatives, net(b)	$	11,780	$	115	$	-	$	11,665
Deferred compensation		3,581		-		3,581		-
Total Liabilities	$	15,361	$	115	$	3,581	$	11,665
MGE
Assets:
Derivatives, net(b)	$	721	$	423	$	-	$	298
Exchange-traded investments		431		431		-		-
Total Assets	$	1,152	$	854	$	-	$	298
Liabilities:
Derivatives, net(b)	$	11,780	$	115	$	-	$	11,665
Deferred compensation		3,581		-		3,581		-
Total Liabilities	$	15,361	$	115	$	3,581	$	11,665

		Fair Value as of December 31, 2020
(In thousands)		Total		Level 1		Level 2		Level 3
MGE Energy
Assets:
Derivatives, net(b)	$	806	$	436	$	-	$	370
Exchange-traded investments		1,750		1,750		-		-
Total Assets	$	2,556	$	2,186	$	-	$	370
Liabilities:
Derivatives, net(b)	$	14,795	$	370	$	-	$	14,425
Deferred compensation		3,509		-		3,509		-
Total Liabilities	$	18,304	$	370	$	3,509	$	14,425
MGE
Assets:
Derivatives, net(b)	$	806	$	436	$	-	$	370
Exchange-traded investments		603		603		-		-
Total Assets	$	1,409	$	1,039	$	-	$	370
Liabilities:
Derivatives, net(b)	$	14,795	$	370	$	-	$	14,425
Deferred compensation		3,509		-		3,509		-
Total Liabilities	$	18,304	$	370	$	3,509	$	14,425

(b) These amounts are shown gross. No collateral was posted against derivative positions with counterparties as of March 31, 2021, or December 31, 2020.

Significant Unobservable Inputs

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

	Model Input
Significant Unobservable Inputs	March 31, 2021		December 31, 2020
Basis adjustment:
On peak	94.4	%	94.2	%
Off peak	95.0	%	94.5	%
Counterparty fuel mix:
Internal generation - range	41.0% - 66.0	%	46.0% - 65.0	%
Internal generation - weighted average	56.9	%	56.5	%
Purchased power - range	59.0% - 34.0	%	54.0% - 35.0	%
Purchased power - weighted average	43.1	%	43.5	%

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)		2021		2020
Beginning balance	$	(14,055)	$	(26,456)
Realized and unrealized gains (losses):
Included in regulatory assets		2,688		810
Included in other comprehensive income		-		-
Included in earnings		307		(1,453)
Included in current assets		355		247
Purchases		5,884		5,015
Sales		-		-
Issuances		-		-
Settlements		(6,546)		(3,810)
Balance as of March 31,	$	(11,367)	$	(25,647)
Total gains (losses) included in earnings attributed to the change in unrealized gains (losses) related to assets and liabilities held at 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)		2021		2020
Purchased power expense	$	702	$	(1,184)
Cost of gas sold expense		(395)		(269)
Total	$	307	$	(1,453)

(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, 2021

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		Date of Commercial
Project	Interest		Generation		Estimated Costs		March 31, 2021(a)		Operation
Badger Hollow I(b)	33	%	50	MW	$65	million	$56.4	million	Q3 2021(c)
Badger Hollow II(b)	33	%	50	MW	$65	million	$5.3	million	December 2022(c)

(a)Excluding AFUDC.

(b)The Badger Hollow I and Badger Hollow II solar farms are located in southwestern Wisconsin in Iowa County, near the villages of Montfort and Cobb.

(c)Estimated date of commercial operation.

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Revenue (Tables)

3 Months Ended

Mar. 31, 2021

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		2021		2020
Residential	$	36,694	$	33,428
Commercial		47,883		47,634
Industrial		3,001		2,800
Other-retail/municipal		8,170		8,204
Total retail		95,748		92,066
Sales to the market		4,639		482
Other revenues		222		442
Total electric revenues	$	100,609	$	92,990
Gas revenues
Residential		39,758		33,487
Commercial/Industrial		25,507		21,471
Total retail		65,265		54,958
Gas transportation		2,002		1,794
Other revenues		3		93
Total gas revenues	$	67,270	$	56,845
Non-regulated energy revenues		36		38
Total Operating Revenue	$	167,915	$	149,873

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Segment Information (Tables)

3 Months Ended

Mar. 31, 2021

Segment Reporting [Abstract]

Segment Information

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

(In thousands) MGE Energy		Electric		Gas		Nonregulated Energy		Transmission Investment		All Others		Consolidation/ Elimination		Consolidated Total
Three Months Ended March 31, 2021
Operating revenues from external customers	$	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
Three Months Ended March 31, 2020
Operating revenues from external customers	$	92,990	$	56,845	$	38	$	-	$	-	$	-	$	149,873
Interdepartmental revenues		191		3,451		10,056		-		-		(13,698)		-
Total operating revenues		93,181		60,296		10,094		-		-		(13,698)		149,873
Equity in earnings of investments		-		-		-		2,286		-		-		2,286
Net income (loss)		11,463		8,034		5,060		1,663		(183)		-		26,037

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

(In thousands) MGE		Electric		Gas		Nonregulated Energy		Consolidation/ Elimination		Consolidated Total
Three Months Ended March 31, 2021
Operating revenues from external customers	$	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
Three Months Ended March 31, 2020
Operating revenues from external customers	$	92,990	$	56,845	$	38	$	-	$	149,873
Interdepartmental revenues		191		3,451		10,056		(13,698)		-
Total operating revenues		93,181		60,296		10,094		(13,698)		149,873
Net income attributable to MGE		11,463		8,034		5,060		(5,493)		19,064

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Summary of Significant Accounting Principles (Details-1) - USD ($)	Mar. 31, 2021	Dec. 31, 2020	Mar. 31, 2020	Dec. 31, 2019
Cash Cash Equivalents And Restricted Cash [Line Items]
Cash and cash equivalents	$ 40,239,000	$ 44,738,000
Restricted cash	467,000	644,000
Receivable - margin account	796,000	1,657,000
Cash, cash equivalents, and restricted cash	41,502,000	47,039,000	$ 19,794,000	$ 25,814,000
MGE [Member]
Cash Cash Equivalents And Restricted Cash [Line Items]
Cash and cash equivalents	6,709,000	4,103,000
Restricted cash	467,000	644,000
Receivable - margin account	796,000	1,657,000
Cash, cash equivalents, and restricted cash	$ 7,972,000	$ 6,404,000	$ 5,664,000	$ 5,529,000

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Investment in ATC and ATC Holdco (Details-1) - USD ($) $ in Thousands	3 Months Ended
	Mar. 31, 2021	Mar. 31, 2020
Schedule Of Equity Method Investments [Line Items]
Equity earnings from investment	$ 2,444	$ 2,266
Dividends from investments	1,967	2,700
Capital contributions to investments	670	1,643
MGE Transco [Member] | ATC [Member]
Schedule Of Equity Method Investments [Line Items]
Equity earnings from investment	2,420	2,266
Dividends from investments	1,967	2,391
Capital contributions to investments	$ 0	$ 178

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Investment in ATC and ATC Holdco (Details-2) - USD ($) $ in Thousands	3 Months Ended
	Mar. 31, 2021	Mar. 31, 2020	Dec. 31, 2020
ATC [Member]
Schedule Of Equity Method Investments [Line Items]
Operating revenues	$ 188,694	$ 186,801
Operating expenses	(95,104)	(95,211)
Other income, net	378	375
Interest expense, net	(28,871)	(28,888)
Earnings before members' income taxes	65,097	63,077
ATC [Member]
Related Party Transaction [Line Items]
Related party expenses	8,000	$ 7,700
Due from related parties	$ 3,000		$ 2,600

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Taxes (Details) - USD ($) $ in Millions		3 Months Ended
		Mar. 31, 2021	Mar. 31, 2020
Reconciliation of tax provision to statutory federal income tax rate [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		(1.60%)	(0.10%)
Credit for electricity from wind energy		(7.10%)	(6.90%)
AFUDC equity, net		(0.60%)	(1.60%)
Amortization of utility excess deferred tax - tax reform	[1]	(16.70%)	(2.60%)
Other, net, individually significant		0.00%	0.00%
Effective income tax rate		1.30%	16.10%
Excess Deferred Taxes, Tax Cuts And Jobs Act [Member]
Effects Of The Tax Cuts And Jobs Act [Abstract]
Excess deferred tax - Income statement effect		$ 0.7	$ 0.7
Return of unprotected excess deferred taxes		$ 3.3
MGE [Member]
Reconciliation of tax provision to statutory federal income tax rate [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		(1.80%)	(0.10%)
Credit for electricity from wind energy		(7.80%)	(7.50%)
AFUDC equity, net		(0.60%)	(1.70%)
Amortization of utility excess deferred tax - tax reform	[1]	(18.30%)	(2.80%)
Other, net, individually significant		(0.10%)	(0.10%)
Effective income tax rate		(1.30%)	15.10%

[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, 2021 and 2020, MGE recognized $0.7 million. 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.

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Pension and Other Postretirement Plans (Details) - USD ($) $ in Thousands	3 Months Ended
	Mar. 31, 2021	Mar. 31, 2020
Defined Benefit Plan Deferred Pension And Other Postretirement Benefit Plan Costs Recovered [Abstract]
Deferred (recognized) pension and OPEB costs	$ (3,400)	$ (400)
Pension Benefits [Member]
Components of net periodic benefit cost:
Service cost	1,422	1,316
Interest cost	2,272	3,023
Expected return on assets	(7,375)	(6,811)
Amortization of:
Prior service credit	(31)	(31)
Actuarial loss	1,580	1,286
Net periodic benefit (credit) cost	(2,132)	(1,217)
Postretirement Benefits [Member]
Components of net periodic benefit cost:
Service cost	351	311
Interest cost	384	573
Expected return on assets	(817)	(790)
Amortization of:
Transition obligation	1	1
Prior service credit	(380)	(667)
Actuarial loss	109	70
Net periodic benefit (credit) cost	$ (352)	$ (502)

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Equity and Financing Arrangements (Details) - shares	3 Months Ended
	Mar. 31, 2021	Mar. 31, 2020
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	1,543

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Share Based Compensation (Details) - USD ($) $ in Millions		1 Months Ended	3 Months Ended
	Feb. 19, 2021	Jan. 31, 2021	Mar. 31, 2021	Mar. 31, 2020
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Compensation expense (benefit)			$ 0.7	$ (0.6)
2021 Long Term Incentive Plan [Member] | Performance Units [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Awards granted during period (in units)	10,187
2021 Long Term Incentive Plan [Member] | Restricted Units [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Awards granted during period (in units)	16,267
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		$ 1.9

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Commitments and Contingencies (Details-1) $ in Millions	Mar. 31, 2021 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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Rate Matters (Details) - USD ($) $ in Millions	3 Months Ended	12 Months Ended
	Mar. 31, 2021	Dec. 31, 2023	Dec. 31, 2022	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Fuel Rules [Abstract]
Deferred fuel rules monitored costs	$ 0.5				$ 3.2	$ 1.5
Rate Matters For Future Periods [Member] | Subsequent Event [Member]
Rate Proceedings [Abstract]
Proposed return on equity, percentage			9.80%
Proposed equity capital structure, percentage			55.60%
PSCW [Member] | MGE [Member]
Rate Proceedings [Abstract]
Authorized return on equity, percentage	9.80%				9.80%	9.80%
Approved equity capital structure, percentage	55.80%				56.10%	56.60%
Fuel Rules [Abstract]
Fuel rules, bandwidth	1.00%				2.00%
Fuel rules, electric fuel deferred costs upper threshold	101.00%
Fuel rules, electric fuel deferred costs lower threshold	99.00%
Electric Rate Proceeding [Member] | Rate Matters For Future Periods [Member] | Subsequent Event [Member]
Rate Proceedings [Abstract]
Proposed rate increase (decrease), percentage			5.90%
Electric Rate Proceeding [Member] | PSCW [Member] | MGE [Member]
Rate Proceedings [Abstract]
Authorized rate increase (decrease), percentage	0.00%				(0.84%)	(2.24%)
Authorized rate increase (decrease), amount					$ (3.4)	$ (9.2)
Electric Rate Proceeding [Member] | PSCW [Member] | Rate Matters For Future Periods [Member] | MGE [Member]
Effects Of The Tax Cuts And Jobs Act [Abstract]
Return of unprotected excess deferred taxes				$ 18.2
Gas Rate Proceeding [Member] | Rate Matters For Future Periods [Member] | Subsequent Event [Member]
Rate Proceedings [Abstract]
Proposed rate increase (decrease), percentage		1.65%	3.00%
Gas Rate Proceeding [Member] | PSCW [Member] | MGE [Member]
Rate Proceedings [Abstract]
Authorized rate increase (decrease), percentage	4.00%				1.46%	1.06%
Authorized rate increase (decrease), amount					$ 2.4	$ 1.7

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Derivative and Hedging Instruments (Details-1)		3 Months Ended	12 Months Ended
		Mar. 31, 2021 USD ($) Dth MWh MW	Dec. 31, 2020 USD ($) Dth MWh MW	Mar. 31, 2020 USD ($)	Dec. 31, 2019 USD ($)
Derivative fair values [Abstract]
Collateral posted against derivative positions		$ 0	$ 0
Other Current Assets [Member]
Derivative fair values [Abstract]
Derivative fair value, net		173,000	1,162,000	$ 430,000	$ 1,100,000
Commodity Contracts And Financial Transimission Rights [Member]
Derivative fair values [Abstract]
Derivative fair value, net		$ 500,000	$ 200,000
Commodity Derivative Contracts [Member]
Gross Notional Volume of Open Derivatives
Notional amount, energy measure (in MWh) | MWh		277,400	259,080
Notional amount, decatherm measure (in Dth) | Dth		2,190,000	6,030,000
Derivative fair values [Abstract]
Asset Derivatives, fair value, gross basis		$ 683,000	$ 806,000
Liability Derivatives, fair value, gross basis		190,000	632,000
Collateral posted against derivative positions		0	0
Collateral posted against derivative positions		0	0
Commodity Derivative Contracts [Member] | Other Current Assets [Member]
Derivative fair values [Abstract]
Asset Derivatives, fair value, gross basis	[1]	653,000	617,000
Liability Derivatives, fair value, gross basis	[1]	174,000	593,000
Commodity Derivative Contracts [Member] | Other Deferred Charges [Member]
Derivative fair values [Abstract]
Asset Derivatives, fair value, gross basis	[1]	30,000	189,000
Liability Derivatives, fair value, gross basis	[1]	16,000	39,000
Commodity Derivative Contracts [Member] | Cash Flow Hedging [Member]
Derivative fair values [Abstract]
Collateral posted against derivative positions		$ 0	$ 0
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
Notional amount, power measure (in MW) | MW		1,152	2,869
Derivative fair values [Abstract]
Asset Derivatives, fair value, gross basis		$ 38,000
Liability Derivatives, fair value, gross basis			$ 23,000
Collateral posted against derivative positions			0
Collateral posted against derivative positions		0
Financial Transmission Rights [Member] | Other Current Assets [Member]
Derivative fair values [Abstract]
Asset Derivatives, fair value, gross basis		38,000
Liability Derivatives, fair value, gross basis		$ 0
Financial Transmission Rights [Member] | Other Current Liabilities [Member]
Derivative fair values [Abstract]
Asset Derivatives, fair value, gross basis			0
Liability Derivatives, fair value, gross basis			$ 23,000
PPA [Member]
Gross Notional Volume of Open Derivatives
Notional amount, power measure (in MW) | MW		700	850
Derivative fair values [Abstract]
Derivative fair value, net		$ (11,600,000)	$ (14,100,000)
Liability Derivatives, fair value, gross basis		11,590,000	14,140,000
Collateral posted against derivative positions		0	0
PPA [Member] | Derivative Liability (Current) [Member]
Derivative fair values [Abstract]
Liability Derivatives, fair value, gross basis		9,790,000	10,160,000
PPA [Member] | Derivative Liability (Long-term) [Member]
Derivative fair values [Abstract]
Liability Derivatives, fair value, gross basis		$ 1,800,000	$ 3,980,000

[1] No collateral was posted against derivative positions as of March 31, 2021, and December 31, 2020

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Derivative and Hedging Instruments (Details-2) - USD ($) $ in Thousands	Mar. 31, 2021	Dec. 31, 2020
Commodity Derivative Contracts [Member]
Offsetting Assets [Line Items]
Gross amounts	$ 683	$ 806
Gross amounts offset in balance sheet	(190)	(632)
Collateral posted against derivative positions	0	0
Net amount presented in balance sheet	493	$ 174
Financial Transmission Rights [Member]
Offsetting Assets [Line Items]
Gross amounts	38
Gross amounts offset in balance sheet	0
Collateral posted against derivative positions	0
Net amount presented in balance sheet	$ 38

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Derivative and Hedging Instruments (Details-3) - USD ($)	Mar. 31, 2021	Dec. 31, 2020
Offsetting Liabilities [Line Items]
Collateral posted against derivative positions	$ 0	$ 0
Commodity Derivative Contracts [Member]
Offsetting Liabilities [Line Items]
Gross amounts	190,000	632,000
Gross amounts offset in balance sheet	(190,000)	(632,000)
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		23,000
Gross amounts offset in balance sheet		0
Collateral posted against derivative positions		0
Net amount presented in balance sheet		23,000
Purchased Power Agreement [Member]
Offsetting Liabilities [Line Items]
Gross amounts	11,590,000	14,140,000
Gross amounts offset in balance sheet	0	0
Collateral posted against derivative positions	0	0
Net amount presented in balance sheet	$ 11,590,000	$ 14,140,000

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Derivative and Hedging Instruments (Details-4) - USD ($) $ in Thousands	3 Months Ended
	Mar. 31, 2021	Mar. 31, 2020
Current and Long-Term Regulatory Asset [Member]
Change In Derivative Fair Value [Roll Forward]
Beginning balance,	$ 13,989	$ 26,875
Unrealized (gain) loss	(3,588)	(689)
Realized (loss) gain reclassified to a deferred account	(50)	(1,063)
Realized (loss) gain reclassified to income statement	708	204
Ending balance,	11,059	25,327
Other Current Assets [Member]
Change In Derivative Fair Value [Roll Forward]
Beginning balance,	1,162	1,100
Unrealized (gain) loss	0	0
Realized (loss) gain reclassified to a deferred account	50	1,063
Realized (loss) gain reclassified to income statement	(1,039)	(1,733)
Ending balance,	$ 173	$ 430

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Derivative and Hedging Instruments (Details-5)	3 Months Ended
	Mar. 31, 2021 USD ($) counterparty	Mar. 31, 2020 USD ($)	Dec. 31, 2020 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 Derivative Contracts [Member] | Fuel For Electric Generation Purchased Power [Member]
Realized losses (gains) on income statement [Line Items]
Realized losses (gains) on income statement	$ (195,000)	$ 680,000
Commodity Derivative Contracts [Member] | Cost Of Gas Sold Expense [Member]
Realized losses (gains) on income statement [Line Items]
Realized losses (gains) on income statement	1,022,000	1,607,000
Financial Transmission Rights [Member] | Fuel For Electric Generation Purchased Power [Member]
Realized losses (gains) on income statement [Line Items]
Realized losses (gains) on income statement	(256,000)	(65,000)
Financial Transmission Rights [Member] | Cost Of Gas Sold Expense [Member]
Realized losses (gains) on income statement [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	20,000,000.0
Maximum collateral that may be required to be posted	40,000,000.0
Collateral posted	0
Purchased Power Agreement [Member] | Fuel For Electric Generation Purchased Power [Member]
Realized losses (gains) on income statement [Line Items]
Realized losses (gains) on income statement	(240,000)	(693,000)
Purchased Power Agreement [Member] | Cost Of Gas Sold Expense [Member]
Realized losses (gains) on income statement [Line Items]
Realized losses (gains) on income statement	$ 0	$ 0

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Fair Value of Financial Instruments (Details-1) - USD ($) $ in Thousands		Mar. 31, 2021	Dec. 31, 2020
Fair Value Measurement [Domain]
Liabilities:
Unamortized discount and debt issuance costs, net		$ 4,000	$ 4,100
Carrying Amount [Member]
Assets:
Cash and cash equivalents		40,239	44,738
Liabilities:
Short-term debt - commercial paper		54,000	52,500
Long-term debt	[1]	527,038	528,220
Fair Value [Member]
Assets:
Cash and cash equivalents		40,239	44,738
Liabilities:
Short-term debt - commercial paper		54,000	52,500
Long-term debt	[1]	590,748	639,271
MGE [Member] | Fair Value Measurement [Domain]
Liabilities:
Unamortized discount and debt issuance costs, net		4,000	4,100
MGE [Member] | Carrying Amount [Member]
Assets:
Cash and cash equivalents		6,709	4,103
Liabilities:
Short-term debt - commercial paper		54,000	52,500
Long-term debt	[1]	527,038	528,220
MGE [Member] | Fair Value [Member]
Assets:
Cash and cash equivalents		6,709	4,103
Liabilities:
Short-term debt - commercial paper		54,000	52,500
Long-term debt	[1]	$ 590,748	$ 639,271

[1] Includes long-term debt due within one year. Excludes debt issuance costs and unamortized discount of $4.0 million and $4.1 million as of March 31, 2021, and December 31, 2020, respectively.

XML

Fair Value of Financial Instruments (Details-2) - USD ($)		Mar. 31, 2021	Dec. 31, 2020
Liabilities:
Collateral posted against derivative positions		$ 0	$ 0
Recurring [Member]
Assets:
Derivatives	[1]	721,000	806,000
Total Assets		2,195,000	2,556,000
Liabilities:
Derivatives	[1]	11,780,000	14,795,000
Deferred compensation		3,581,000	3,509,000
Total liabilities		15,361,000	18,304,000
Recurring [Member] | Exchange Traded [Member]
Assets:
Available-for-sale securities		1,474,000	1,750,000
Recurring [Member] | Level 1 [Member]
Assets:
Derivatives	[1]	423,000	436,000
Total Assets		1,897,000	2,186,000
Liabilities:
Derivatives	[1]	115,000	370,000
Deferred compensation		0	0
Total liabilities		115,000	370,000
Recurring [Member] | Level 1 [Member] | Exchange Traded [Member]
Assets:
Available-for-sale securities		1,474,000	1,750,000
Recurring [Member] | Level 2 [Member]
Assets:
Derivatives	[1]	0	0
Total Assets		0	0
Liabilities:
Derivatives	[1]	0	0
Deferred compensation		3,581,000	3,509,000
Total liabilities		3,581,000	3,509,000
Recurring [Member] | Level 2 [Member] | Exchange Traded [Member]
Assets:
Available-for-sale securities		0	0
Recurring [Member] | Level 3 [Member]
Assets:
Derivatives	[1]	298,000	370,000
Total Assets		298,000	370,000
Liabilities:
Derivatives	[1]	11,665,000	14,425,000
Deferred compensation		0	0
Total liabilities		11,665,000	14,425,000
Recurring [Member] | Level 3 [Member] | Exchange Traded [Member]
Assets:
Available-for-sale securities		0	0
MGE [Member] | Recurring [Member]
Assets:
Derivatives	[1]	721,000	806,000
Total Assets		1,152,000	1,409,000
Liabilities:
Derivatives	[1]	11,780,000	14,795,000
Deferred compensation		3,581,000	3,509,000
Total liabilities		15,361,000	18,304,000
MGE [Member] | Recurring [Member] | Exchange Traded [Member]
Assets:
Available-for-sale securities		431,000	603,000
MGE [Member] | Recurring [Member] | Level 1 [Member]
Assets:
Derivatives	[1]	423,000	436,000
Total Assets		854,000	1,039,000
Liabilities:
Derivatives	[1]	115,000	370,000
Deferred compensation		0	0
Total liabilities		115,000	370,000
MGE [Member] | Recurring [Member] | Level 1 [Member] | Exchange Traded [Member]
Assets:
Available-for-sale securities		431,000	603,000
MGE [Member] | Recurring [Member] | Level 2 [Member]
Assets:
Derivatives	[1]	0	0
Total Assets		0	0
Liabilities:
Derivatives	[1]	0	0
Deferred compensation		3,581,000	3,509,000
Total liabilities		3,581,000	3,509,000
MGE [Member] | Recurring [Member] | Level 2 [Member] | Exchange Traded [Member]
Assets:
Available-for-sale securities		0	0
MGE [Member] | Recurring [Member] | Level 3 [Member]
Assets:
Derivatives	[1]	298,000	370,000
Total Assets		298,000	370,000
Liabilities:
Derivatives	[1]	11,665,000	14,425,000
Deferred compensation		0	0
Total liabilities		11,665,000	14,425,000
MGE [Member] | Recurring [Member] | Level 3 [Member] | Exchange Traded [Member]
Assets:
Available-for-sale securities		$ 0	$ 0

[1] These amounts are shown gross. No collateral was posted against derivative positions with counterparties as of March 31, 2021, or December 31, 2020.

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Fair Value of Financial Instruments (Details-3)	3 Months Ended	12 Months Ended
	Mar. 31, 2021	Dec. 31, 2020
Basis adjustment:
Basis adjustment - on peak	94.40%	94.20%
Basis adjustment - off peak	95.00%	94.50%
US Treasury Bill Securities [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%	46.00%
Purchased power	34.00%	35.00%
Maximum [Member]
Counterparty fuel mix:
Internal generation	66.00%	65.00%
Purchased power	59.00%	54.00%
Weighted Average [Member]
Counterparty fuel mix:
Internal generation	56.90%	56.50%
Purchased power	43.10%	43.50%

XML

Fair Value of Financial Instruments (Details-4) - USD ($) $ in Thousands		3 Months Ended
		Mar. 31, 2021	Mar. 31, 2020
Fair Value, Net Derivative Asset (Liability) Measured on Recurring Basis, Unobservable Input Reconciliation [Roll Forward]
Beginning balance,		$ (14,055)	$ (26,456)
Realized and unrealized gains (losses):
Included in regulatory assets		2,688	810
Included in other comprehensive income		0	0
Included in earnings	[1]	307	(1,453)
Included in current assets		355	247
Purchases		5,884	5,015
Sales		0	0
Issuances		0	0
Settlements		(6,546)	(3,810)
Ending balance,		$ (11,367)	$ (25,647)

[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.

XML

Fair Value of Financial Instruments (Details-5) - USD ($) $ in Thousands		3 Months Ended
		Mar. 31, 2021	Mar. 31, 2020
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]	307	(1,453)
Purchased Power Expense [Member]
Fair Value, Net Derivative Asset (Liability) Measured on Recurring Basis, Unobservable Input Reconciliation [Line Items]
Included in earnings		702	(1,184)
Cost Of Gas Sold Expense [Member]
Fair Value, Net Derivative Asset (Liability) Measured on Recurring Basis, Unobservable Input Reconciliation [Line Items]
Included in earnings		$ (395)	$ (269)

[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.

XML

Joint Plant Ownership (Details) $ in Millions		3 Months Ended
		Mar. 31, 2021 USD ($) MW	Mar. 31, 2020 USD ($)
Badger Hollow I Units [Member]
Jointly Owned Utility Plant Interests [Line Items]
Projected Solar Farm Project Costs	[1]	$ 65.0
Public Utilities Property Plant And Equipment Construction Work In Progress	[1],[2]	$ 56.4
Badger Hollow I Units [Member] | Public Service Commission of Wisconsin [Member]
Allowance for Funds Used During Construction
Authorized AFUDC rate - Signficiant projects (100%)		100.00%
Badger Hollow I Units [Member] | MGE [Member]
Jointly Owned Utility Plant Interests [Line Items]
Jointly owned utility plant, ownership interest	[1]	33.00%
Jointly owned utility plant, plant capacity (in MW) | MW	[1]	50
Badger Hollow II Units [Member]
Jointly Owned Utility Plant Interests [Line Items]
Projected Solar Farm Project Costs	[1]	$ 65.0
Public Utilities Property Plant And Equipment Construction Work In Progress	[1],[2]	$ 5.3
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	[1]	33.00%
Jointly owned utility plant, plant capacity (in MW) | MW	[1]	50
Badger Hollow I and II [Member]
Allowance for Funds Used During Construction
AFUDC		$ 1.1	$ 0.4

[1] The Badger Hollow I and Badger Hollow II solar farms are located in southwestern Wisconsin in Iowa County, near the villages of Montfort and Cobb.

[2] Excluding AFUDC.

XML

Revenue (Details-1) - USD ($) $ in Thousands	3 Months Ended
	Mar. 31, 2021	Mar. 31, 2020
Total Operating Revenue [Member]
Disaggregation of Revenue [Line Items]
Revenues recognized from contracts with customers	$ 167,915	$ 149,873
Electric [Member]
Disaggregation of Revenue [Line Items]
Revenues recognized from contracts with customers	100,609	92,990
Electric [Member] | Residential [Member]
Disaggregation of Revenue [Line Items]
Revenues recognized from contracts with customers	36,694	33,428
Electric [Member] | Commercial [Member]
Disaggregation of Revenue [Line Items]
Revenues recognized from contracts with customers	47,883	47,634
Electric [Member] | Industrial [Member]
Disaggregation of Revenue [Line Items]
Revenues recognized from contracts with customers	3,001	2,800
Electric [Member] | Other-retail/municipal
Disaggregation of Revenue [Line Items]
Revenues recognized from contracts with customers	8,170	8,204
Electric [Member] | Total Retail [Member]
Disaggregation of Revenue [Line Items]
Revenues recognized from contracts with customers	95,748	92,066
Electric [Member] | Sales To The Market [Member]
Disaggregation of Revenue [Line Items]
Revenues recognized from contracts with customers	4,639	482
Electric [Member] | Other Revenues [Member]
Disaggregation of Revenue [Line Items]
Revenues recognized from contracts with customers	222	442
Gas [Member]
Disaggregation of Revenue [Line Items]
Revenues recognized from contracts with customers	67,270	56,845
Gas [Member] | Residential [Member]
Disaggregation of Revenue [Line Items]
Revenues recognized from contracts with customers	39,758	33,487
Gas [Member] | Commercial/Industrial [Member]
Disaggregation of Revenue [Line Items]
Revenues recognized from contracts with customers	25,507	21,471
Gas [Member] | Total Retail [Member]
Disaggregation of Revenue [Line Items]
Revenues recognized from contracts with customers	65,265	54,958
Gas [Member] | Gas Transportation [Member]
Disaggregation of Revenue [Line Items]
Revenues recognized from contracts with customers	2,002	1,794
Gas [Member] | Other Revenues [Member]
Disaggregation of Revenue [Line Items]
Revenues recognized from contracts with customers	3	93
Non Regulated Energy [Member]
Disaggregation of Revenue [Line Items]
Revenues recognized from contracts with customers	$ 36	$ 38

XML

Segment Information (Details) - USD ($) $ in Thousands	3 Months Ended
	Mar. 31, 2021	Mar. 31, 2020
Segment Reporting Information [Line Items]
Operating revenues	$ 167,915	$ 149,873
Equity in earnings of investment	2,444	2,266
Net Income	34,933	26,037
Electric [Member]
Segment Reporting Information [Line Items]
Operating revenues	100,609	92,990
Gas [Member]
Segment Reporting Information [Line Items]
Operating revenues	67,270	56,845
Non Regulated Energy [Member]
Segment Reporting Information [Line Items]
Operating revenues	36	38
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	167,915	149,873
Equity in earnings of investment	2,444	2,286
Operating Segments [Member] | Electric [Member]
Segment Reporting Information [Line Items]
Operating revenues	100,882	93,181
Equity in earnings of investment	0	0
Net Income	18,024	11,463
Operating Segments [Member] | Gas [Member]
Segment Reporting Information [Line Items]
Operating revenues	72,081	60,296
Equity in earnings of investment	0	0
Net Income	10,556	8,034
Operating Segments [Member] | Non Regulated Energy [Member]
Segment Reporting Information [Line Items]
Operating revenues	10,209	10,094
Equity in earnings of investment	0	0
Net Income	5,194	5,060
Operating Segments [Member] | Transmission Investment [Member]
Segment Reporting Information [Line Items]
Operating revenues	0	0
Equity in earnings of investment	2,444	2,286
Net Income	1,778	1,663
Operating Segments [Member] | All Others [Member]
Segment Reporting Information [Line Items]
Operating revenues	0	0
Equity in earnings of investment	0	0
Net Income	(619)	(183)
Consolidation Elimination Entries [Member]
Segment Reporting Information [Line Items]
Operating revenues	(15,257)	(13,698)
Equity in earnings of investment	0	0
Net Income	0	0
Consolidation Elimination Entries [Member] | Electric [Member]
Segment Reporting Information [Line Items]
Operating revenues	273	191
Consolidation Elimination Entries [Member] | Gas [Member]
Segment Reporting Information [Line Items]
Operating revenues	4,811	3,451
Consolidation Elimination Entries [Member] | Non Regulated Energy [Member]
Segment Reporting Information [Line Items]
Operating revenues	10,173	10,056
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	167,915	149,873
Net Income	28,273	19,064
MGE [Member] | Electric [Member]
Segment Reporting Information [Line Items]
Operating revenues	100,609	92,990
MGE [Member] | Gas [Member]
Segment Reporting Information [Line Items]
Operating revenues	67,270	56,845
MGE [Member] | Non Regulated Energy [Member]
Segment Reporting Information [Line Items]
Operating revenues	36	38
MGE [Member] | Operating Segments [Member]
Segment Reporting Information [Line Items]
Operating revenues	167,915	149,873
Net Income	28,273	19,064
MGE [Member] | Operating Segments [Member] | Electric [Member]
Segment Reporting Information [Line Items]
Operating revenues	100,882	93,181
Net Income	18,024	11,463
MGE [Member] | Operating Segments [Member] | Gas [Member]
Segment Reporting Information [Line Items]
Operating revenues	72,081	60,296
Net Income	10,556	8,034
MGE [Member] | Operating Segments [Member] | Non Regulated Energy [Member]
Segment Reporting Information [Line Items]
Operating revenues	10,209	10,094
Net Income	5,194	5,060
MGE [Member] | Consolidation Elimination Entries [Member]
Segment Reporting Information [Line Items]
Operating revenues	(15,257)	(13,698)
Net Income	(5,501)	(5,493)
MGE [Member] | Consolidation Elimination Entries [Member] | Electric [Member]
Segment Reporting Information [Line Items]
Operating revenues	273	191
MGE [Member] | Consolidation Elimination Entries [Member] | Gas [Member]
Segment Reporting Information [Line Items]
Operating revenues	4,811	3,451
MGE [Member] | Consolidation Elimination Entries [Member] | Non Regulated Energy [Member]
Segment Reporting Information [Line Items]
Operating revenues	$ 10,173	$ 10,056