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: September 30, 2020 ☐ 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 October 31, 2020
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 INFORMATION3

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.34

Item 3. Quantitative and Qualitative Disclosures About Market Risk.54

Item 4. Controls and Procedures.56

PART II. OTHER INFORMATION.57

Item 1. Legal Proceedings.57

Item1A. Risk Factors.57

Item 2. Unregistered Sales of Equity Securities and Use of Proceeds.58

Item 4. Mine Safety Disclosures.59

Item 5. Other Information.59

Item 6. Exhibits.59

Signatures - MGE Energy, Inc.60

Signatures - Madison Gas and Electric Company61

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' 2019 Annual Report on Form 10-K: Item 1A. Risk Factors, as updated by Part II, Item 1A. Risk Factors in this report, 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:

2006 PlanMGE Energy's 2006 Performance Unit Plan

2013 PlanMGE Energy's 2013 Director Incentive Plan

2020 PlanMGE Energy's 2020 Performance Unit 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

BARTBest Available Retrofit Technology

BATBest Available Technology

BlountBlount Station

BSERBest System of Emissions Reductions

CAVRClean Air Visibility Rule

CCRCoal Combustion Residual

codificationFinancial Accounting Standards Board Accounting Standards Codification

ColumbiaColumbia Energy Center

cooling degree daysMeasure of the extent to which the average daily temperature is above 65 degrees Fahrenheit, which is considered an indicator of possible increased demand for energy to provide cooling

COVID-19Coronavirus Disease 2019

CSAPRCross-State Air Pollution Rule

DthDekatherms, a quantity measure for natural gas

EGUsElectric Generating Units

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

4

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

NO_xNitrogen Oxide

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

PHMDCPublic Health Madison & Dane County

PHMDC DirectivesPublic Health Madison & Dane County's Forward Dane Plan and related emergency orders

PPAPurchased Power Agreement

PSCWPublic Service Commission of Wisconsin

RiversideRiverside Energy Center

ROEReturn on Equity

SaratogaSaratoga Wind Farm

SCRSelective Catalytic Reduction

SECSecurities and Exchange Commission

SO₂Sulfur Dioxide

Stock PlanDirect Stock Purchase and Dividend Reinvestment Plan of MGE Energy

Tax ActTax Cuts and Jobs Act

Two CreeksTwo Creeks Solar Farm

VIEVariable Interest Entity

WCCFWest Campus Cogeneration Facility

WDNRWisconsin Department of Natural Resources

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				Nine Months Ended
		September 30,				September 30,
		2020		2019		2020		2019
Operating Revenues:
Electric revenues	$	116,568	$	120,821	$	303,556	$	315,367
Gas revenues		18,643		17,377		98,568		112,547
Total Operating Revenues		135,211		138,198		402,124		427,914
Operating Expenses:
Fuel for electric generation		12,945		15,901		31,343		40,221
Purchased power		10,708		9,126		32,050		31,013
Cost of gas sold		3,812		3,092		40,950		55,220
Other operations and maintenance		45,819		48,070		136,412		143,979
Depreciation and amortization		18,592		18,193		55,193		53,423
Other general taxes		5,010		5,078		14,892		15,026
Total Operating Expenses		96,886		99,460		310,840		338,882
Operating Income		38,325		38,738		91,284		89,032
Other income, net		6,534		5,204		19,131		15,074
Interest expense, net		(5,765)		(5,831)		(17,740)		(17,227)
Income before income taxes		39,094		38,111		92,675		86,879
Income tax provision		(7,300)		(7,454)		(16,053)		(16,667)
Net Income	$	31,794	$	30,657	$	76,622	$	70,212
Earnings Per Share of Common Stock
(basic and diluted)	$	0.88	$	0.88	$	2.16	$	2.03
Dividends per share of common stock	$	0.370	$	0.353	$	1.075	$	1.028
Weighted Average Shares Outstanding
(basic and diluted)		36,163		34,668		35,427		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)

		Nine Months Ended
		September 30,
		2020		2019
Operating Activities:
Net income	$	76,622	$	70,212
Items not affecting cash:
Depreciation and amortization		55,193		53,423
Deferred income taxes		8,464		4,864
Provision for doubtful receivables		1,078		978
Employee benefit plan credit		(2,813)		(2,866)
Equity earnings in investments		(7,780)		(6,879)
Other items		382		692
Changes in working capital items:
Decrease in current assets		5,494		14,307
Decrease in current liabilities		(8,808)		(24,088)
Dividends from investments		6,929		5,526
Cash contributions to pension and other postretirement plans		(4,576)		(3,707)
Other noncurrent items, net		5,826		(760)
Cash Provided by Operating Activities		136,011		111,702
Investing Activities:
Capital expenditures		(139,055)		(128,389)
Capital contributions to investments		(4,007)		(5,894)
Other		(1,298)		(248)
Cash Used for Investing Activities		(144,360)		(134,531)
Financing Activities:
Issuance of common stock, net		79,635		-
Cash dividends paid on common stock		(38,349)		(35,622)
Repayments of long-term debt		(22,784)		(3,405)
Issuance of long-term debt		19,300		-
Net proceeds from short-term debt		-		41,500
Other		(1,175)		(1,331)
Cash Provided by Financing Activities		36,627		1,142
Change in cash, cash equivalents, and restricted cash		28,278		(21,687)
Cash, cash equivalents, and restricted cash at beginning of period		25,814		84,929
Cash, cash equivalents, and restricted cash at end of period	$	54,092	$	63,242
Supplemental disclosures of cash flow information:
Significant noncash investing activities:
Accrued capital expenditures	$	23,594	$	16,819
The accompanying notes are an integral part of the above unaudited consolidated financial statements.

7

MGE Energy, Inc.

Consolidated Balance Sheets (unaudited)

(In thousands)

		September 30,	December 31,
ASSETS		2020		2019
Current Assets:
Cash and cash equivalents	$	53,058	$	23,481
Accounts receivable, less reserves of $4,636 and $2,820, respectively		39,177		40,482
Other accounts receivable, less reserves of $1,248 and $438 , respectively		9,828		7,940
Unbilled revenues		20,029		25,899
Materials and supplies, at average cost		33,608		26,287
Fuel for electric generation, at average cost		5,793		8,358
Stored natural gas, at average cost		10,022		10,637
Prepaid taxes		11,759		16,892
Regulatory assets - current		7,845		11,432
Other current assets		8,814		10,233
Total Current Assets		199,933		181,641
Other long-term receivables		1,662		1,811
Regulatory assets		126,929		134,314
Pension benefit asset		21,848		13,630
Other deferred assets and other		18,087		19,093
Property, Plant, and Equipment:
Property, plant, and equipment, net		1,536,567		1,530,199
Construction work in progress		197,594		112,484
Total Property, Plant, and Equipment		1,734,161		1,642,683
Investments		93,106		88,492
Total Assets	$	2,195,726	$	2,081,664
LIABILITIES AND CAPITALIZATION
Current Liabilities:
Long-term debt due within one year	$	19,742	$	19,659
Accounts payable		56,054		55,161
Accrued interest and taxes		5,789		7,244
Accrued payroll related items		11,625		12,752
Regulatory liabilities - current		3,585		9,228
Derivative liabilities		9,640		10,100
Other current liabilities		9,045		14,676
Total Current Liabilities		115,480		128,820
Other Credits:
Deferred income taxes		253,411		243,302
Investment tax credit - deferred		2,692		763
Regulatory liabilities		171,637		164,965
Accrued pension and other postretirement benefits		68,632		68,665
Derivative liabilities		6,340		15,340
Finance lease liabilities		17,795		17,379
Other deferred liabilities and other		65,772		63,013
Total Other Credits		586,279		573,427
Capitalization:
Common shareholders' equity		973,584		855,676
Long-term debt		520,383		523,741
Total Capitalization		1,493,967		1,379,417
Commitments and contingencies (see Footnote 8)
Total Liabilities and Capitalization	$	2,195,726	$	2,081,664
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 September 30, 2019
Beginning Balance	34,668	$	34,668	$	316,268	$	481,861	$	-	$	832,797
Net income							30,657				30,657
Common stock dividends declared
($0.353 per share)							(12,220)				(12,220)
Ending Balance - September 30, 2019	34,668	$	34,668	$	316,268	$	500,298	$	-	$	851,234
Three Months Ended September 30, 2020
Beginning Balance	36,163	$	36,163	$	394,408	$	524,600	$	-	$	955,171
Net income							31,794				31,794
Common stock dividends declared
($0.3700 per share)							(13,381)				(13,381)
Ending Balance - September 30, 2020	36,163	$	36,163	$	394,408	$	543,013	$	-	$	973,584
Nine Months Ended September 30, 2019
Beginning Balance	34,668	$	34,668	$	316,268	$	465,708	$	-	$	816,644
Net income							70,212				70,212
Common stock dividends declared
($1.028 per share)							(35,622)				(35,622)
Ending Balance - September 30, 2019	34,668	$	34,668	$	316,268	$	500,298	$	-	$	851,234
Nine Months Ended September 30, 2020
Beginning Balance	34,668	$	34,668	$	316,268	$	504,740	$	-	$	855,676
Net income							76,622				76,622
Common stock dividends declared
($1.075 per share)							(38,349)				(38,349)
Common stock issued, net	1,495		1,495		78,140						79,635
Ending Balance - September 30, 2020	36,163	$	36,163	$	394,408	$	543,013	$	-	$	973,584
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				Nine Months Ended
		September 30,				September 30,
		2020		2019		2020		2019
Operating Revenues:
Electric revenues	$	116,568	$	120,821	$	303,556	$	315,367
Gas revenues		18,643		17,377		98,568		112,547
Total Operating Revenues		135,211		138,198		402,124		427,914
Operating Expenses:
Fuel for electric generation		12,945		15,901		31,343		40,221
Purchased power		10,708		9,126		32,050		31,013
Cost of gas sold		3,812		3,092		40,950		55,220
Other operations and maintenance		45,591		47,947		135,634		143,282
Depreciation and amortization		18,592		18,193		55,193		53,423
Other general taxes		5,010		5,078		14,892		15,026
Total Operating Expenses		96,658		99,337		310,062		338,185
Operating Income		38,553		38,861		92,062		89,729
Other income, net		4,093		2,672		11,005		7,837
Interest expense, net		(5,802)		(6,095)		(17,848)		(18,223)
Income before income taxes		36,844		35,438		85,219		79,343
Income tax provision		(6,611)		(6,687)		(14,028)		(14,579)
Net Income	$	30,233	$	28,751	$	71,191	$	64,764
Less: Net Income Attributable to Noncontrolling
Interest, net of tax		(5,493)		(5,614)		(16,754)		(16,725)
Net Income Attributable to MGE	$	24,740	$	23,137	$	54,437	$	48,039
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)

		Nine Months Ended
		September 30,
		2020		2019
Operating Activities:
Net income	$	71,191	$	64,764
Items not affecting cash:
Depreciation and amortization		55,193		53,423
Deferred income taxes		7,334		3,653
Provision for doubtful receivables		1,078		978
Employee benefit plan credit		(2,813)		(2,866)
Other items		1,234		1,653
Changes in working capital items:
Decrease in current assets		3,352		14,236
Decrease in current liabilities		(5,212)		(22,234)
Cash contributions to pension and other postretirement plans		(4,576)		(3,707)
Other noncurrent items, net		5,090		(880)
Cash Provided by Operating Activities		131,871		109,020
Investing Activities:
Capital expenditures		(139,055)		(128,389)
Other		(1,512)		(477)
Cash Used for Investing Activities		(140,567)		(128,866)
Financing Activities:
Distributions to parent from noncontrolling interest		(16,000)		(17,000)
Capital contribution from parent		30,000		-
Repayments of long-term debt		(22,784)		(3,405)
Issuance of long-term debt		19,300		-
Net proceeds from short-term debt		-		41,500
Other		(1,144)		(1,133)
Cash Provided by Financing Activities		9,372		19,962
Change in cash, cash equivalents, and restricted cash		676		116
Cash, cash equivalents, and restricted cash at beginning of period		5,529		6,670
Cash, cash equivalents, and restricted cash at end of period	$	6,205	$	6,786
Supplemental disclosures of cash flow information:
Significant noncash investing activities:
Accrued capital expenditures	$	23,594	$	16,819
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)

		September 30,	December 31,
ASSETS		2020		2019
Current Assets:
Cash and cash equivalents	$	5,171	$	3,196
Accounts receivable, less reserves of $4,636 and $2,820, respectively		39,177		40,482
Affiliate receivables		530		530
Other accounts receivable, less reserves of $1,248 and $438 , respectively		9,824		7,936
Unbilled revenues		20,029		25,899
Materials and supplies, at average cost		33,608		26,287
Fuel for electric generation, at average cost		5,793		8,358
Stored natural gas, at average cost		10,022		10,637
Prepaid taxes		12,373		15,463
Regulatory assets - current		7,845		11,432
Other current assets		8,746		10,065
Total Current Assets		153,118		160,285
Affiliate receivable long-term		2,251		2,648
Regulatory assets		126,929		134,314
Pension benefit asset		21,848		13,630
Other deferred assets and other		18,509		19,680
Property, Plant, and Equipment:
Property, plant, and equipment, net		1,536,595		1,530,227
Construction work in progress		197,594		112,484
Total Property, Plant, and Equipment		1,734,189		1,642,711
Investments		461		209
Total Assets	$	2,057,305	$	1,973,477
LIABILITIES AND CAPITALIZATION
Current Liabilities:
Long-term debt due within one year	$	19,742	$	19,659
Accounts payable		56,035		54,845
Accrued interest and taxes		8,602		8,754
Accrued payroll related items		11,625		12,752
Regulatory liabilities - current		3,585		9,228
Derivative liabilities		9,640		10,100
Other current liabilities		9,048		12,683
Total Current Liabilities		118,277		128,021
Other Credits:
Deferred income taxes		223,021		214,041
Investment tax credit - deferred		2,692		763
Regulatory liabilities		171,637		164,965
Accrued pension and other postretirement benefits		68,632		68,665
Derivative liabilities		6,340		15,340
Finance lease liabilities		17,795		17,379
Other deferred liabilities and other		65,748		62,973
Total Other Credits		555,865		544,126
Capitalization:
Common shareholder's equity		721,723		637,286
Noncontrolling interest		141,057		140,303
Total Equity		862,780		777,589
Long-term debt		520,383		523,741
Total Capitalization		1,383,163		1,301,330
Commitments and contingencies (see Footnote 8)
Total Liabilities and Capitalization	$	2,057,305	$	1,973,477
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 September 30, 2019
Beginning balance	17,348	$	17,348	$	192,417	$	363,493	$	-	$	141,065	$	714,323
Net income							23,137				5,614		28,751
Distributions to parent from
noncontrolling interest											(5,500)		(5,500)
Ending Balance - September 30, 2019	17,348	$	17,348	$	192,417	$	386,630	$	-	$	141,179	$	737,574
Three Months Ended September 30, 2020
Beginning balance	17,348	$	17,348	$	252,917	$	426,718	$	-	$	143,064	$	840,047
Net income							24,740				5,493		30,233
Distributions to parent from
noncontrolling interest											(7,500)		(7,500)
Ending Balance - September 30, 2020	17,348	$	17,348	$	252,917	$	451,458	$	-	$	141,057	$	862,780
Nine Months Ended September 30, 2019
Beginning balance	17,348	$	17,348	$	192,417	$	338,591	$	-	$	141,454	$	689,810
Net income							48,039				16,725		64,764
Distributions to parent from
noncontrolling interest											(17,000)		(17,000)
Ending Balance - September 30, 2019	17,348	$	17,348	$	192,417	$	386,630	$	-	$	141,179	$	737,574
Nine Months Ended September 30, 2020
Beginning balance	17,348	$	17,348	$	222,917	$	397,021	$	-	$	140,303	$	777,589
Net income							54,437				16,754		71,191
Capital contributions from parent					30,000								30,000
Distributions to parent from
noncontrolling interest											(16,000)		(16,000)
Ending Balance - September 30, 2020	17,348	$	17,348	$	252,917	$	451,458	$	-	$	141,057	$	862,780
The accompanying notes are an integral part of the above unaudited consolidated financial statements.

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

Notes to Consolidated Financial Statements (unaudited)

September 30, 2020

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 2019 Annual Report on Form 10-K (the 2019 Annual Report on Form 10-K).

The accompanying consolidated financial statements as of September 30, 2020, and during the three and nine 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 2019 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 54 through 107 of the 2019 Annual Report on Form 10-K.

b.COVID-19.

With the global outbreak of the Coronavirus Disease 2019 (COVID-19) and the declaration of a pandemic by the World Health Organization on March 11, 2020, U.S. governmental authorities have deemed electric and gas utilities to be critical infrastructure. MGE Energy therefore has an obligation to keep operating and maintaining our critical electric and gas infrastructure. Since then, MGE Energy has been subject to, and is following, local, state and federal public health and safety regulations and guidance to control the pandemic.

MGE Energy's and MGE's consolidated financial statements reflect estimates and assumptions made by management that affect the reported amounts of assets and liabilities at the date of the consolidated financial statements and reported amounts of revenue and expenses during the reporting periods presented. MGE Energy and MGE considered the impact of COVID-19 developments on the assumptions and estimates used in the preparation of these financial statements.

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c.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
		September 30,		December 31,		September 30,		December 31,
(In thousands)		2020		2019		2020		2019
Cash and cash equivalents	$	53,058	$	23,481	$	5,171	$	3,196
Restricted cash		484		619		484		619
Receivable - margin account		550		1,714		550		1,714
Cash, cash equivalents, and restricted cash	$	54,092	$	25,814	$	6,205	$	5,529

Cash Equivalents

MGE Energy and MGE consider 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.

d.Trade Receivables, Allowance for Credit Losses, and Concentration Risk.

Trade accounts receivable are recorded at the invoiced amount and do not bear interest. A 1% late payment charge is normally recorded on all receivables unpaid after the due date. In late March 2020, the 1% late payment charge was suspended in response to the PSCW's COVID-19 order. The order also suspended disconnection or refusal of services to any customer, with limited exceptions. The PSCW order was lifted on July 25, 2020; however, as permitted by regulatory action, MGE notified the PSCW of its election to continue to waive late fees until December 31, 2020. See Footnote 9.c. for further information.

The allowance for credit losses associated with these receivables represents MGE's best estimate of the amount of probable credit losses for existing accounts receivable. MGE manages concentration of credit risk through its credit and collection policies, which are consistent with state regulatory requirements. The allowance for credit losses is estimated based on historical write-off experience, regional economic data, review of the accounts receivable aging, and reasonable and supportable forecasts that affect the collectability of the reported amount. MGE has considered the effects of COVID-19 developments and associated governmental regulations, including suspension of disconnections for non-payment, in its estimate of allowance for credit losses by applying data from historical recessions and other significant economic downturns.

As of September 30, 2020, MGE had a reserve balance of $5.9 million against accounts receivable. During the three and nine months ended September 30, 2020, MGE recorded $0.3 million and $0.9 million in write-offs, respectively. During the three and nine months ended September 30, 2020, MGE recorded $1.1 million and $3.5 million of additional reserves, respectively, which include estimated impacts of COVID-19. The PSCW issued a deferral accounting order for deferral of incremental COVID-19-related costs. Recovery of these costs are expected to be addressed in future rate proceedings. As of September 30, 2020, MGE had deferred $2.5 million of incremental COVID-19-related costs as a regulatory asset. See Footnote 9.c. for further information.

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2.

New Accounting Standards - MGE Energy and MGE.

Recently Adopted

Credit Losses.

In June 2016, the Financial Accounting Standards Board issued authoritative guidance within the codification's Credit Losses topic, which introduced a new model for recognizing credit losses on financial instruments based on an estimate of current expected credit losses. The authoritative guidance became effective January 1, 2020. MGE adopted the standard on the effective date. The adoption of this standard did not have a material impact on MGE Energy's and MGE's financial statements. New disclosures are required under the new standard. See Footnote 1.d. for allowance for credit loss disclosures.

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				Nine Months Ended
		September 30,				September 30,
(In thousands)		2020		2019		2020		2019
Equity earnings from investment in ATC	$	2,319	$	2,364	$	7,724	$	6,879
Dividends from investments		2,349		1,781		6,620		5,526
Capital contributions to ATC		359		888		892		2,131

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.

In October 2020, MGE Transco made a $0.4 million capital contribution to ATC.

ATC's summarized financial data is as follows:

		Three Months Ended				Nine Months Ended
		September 30,				September 30,
(In thousands)		2020		2019		2020		2019
Operating revenues	$	187,833	$	184,833	$	577,705	$	544,760
Operating expenses		(92,975)		(94,713)		(285,697)		(278,673)
Other income, net		643		484		1,924		1,031
Interest expense, net		(28,801)		(29,165)		(83,947)		(87,121)
Earnings before members' income taxes	$	66,700	$	61,439	$	209,985	$	179,997

MGE receives transmission and other related services from ATC. During the three and nine months ended September 30, 2020, MGE recorded $7.7 million and $23.0 million, respectively, for transmission services received compared to $7.6 million and $22.8 million for the comparable periods in 2019. MGE also provides a variety of operational, maintenance, and project management services for ATC, which are reimbursed by ATC. As of September 30, 2020, and December 31, 2019, MGE had a receivable due from ATC of $2.7 million and $1.6 million, respectively. The receivable includes expenditures to fund transmission infrastructure upgrades at Badger Hollow I and II and Two Creeks. MGE will be reimbursed for these costs after the new

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generation assets have been placed into service.

4.

Taxes - MGE Energy and MGE.

Effective Tax Rate.

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

	MGE Energy				MGE
Three Months Ended September 30,	2020		2019		2020		2019
Statutory federal income tax rate	21.0	%	21.0	%	21.0	%	21.0	%
State income taxes, net of federal benefit	6.3		6.3		6.2		6.2
Amortized investment tax credits	(0.1)		(0.1)		(0.1)		(0.1)
Credit for electricity from wind energy	(5.0)		(4.8)		(5.4)		(5.2)
AFUDC equity, net	(1.1)		(0.4)		(1.2)		(0.4)
Amortization of utility excess deferred tax - tax reform(a)	(2.0)		(1.9)		(2.2)		(2.1)
Other, net, individually insignificant	(0.4)		(0.5)		(0.4)		(0.5)
Effective income tax rate	18.7	%	19.6	%	17.9	%	18.9	%
	MGE Energy				MGE
Nine Months Ended September 30,	2020		2019		2020		2019
Statutory federal income tax rate	21.0	%	21.0	%	21.0	%	21.0	%
State income taxes, net of federal benefit	6.3		6.3		6.2		6.2
Amortized investment tax credits	(0.1)		(0.1)		(0.1)		(0.1)
Credit for electricity from wind energy	(6.1)		(5.6)		(6.6)		(6.1)
AFUDC equity, net	(1.3)		(0.3)		(1.4)		(0.3)
Amortization of utility excess deferred tax - tax reform(a)	(2.4)		(2.2)		(2.6)		(2.4)
Other, net, individually insignificant	(0.1)		0.1		-		0.1
Effective income tax rate	17.3	%	19.2	%	16.5	%	18.4	%

(a)Included are impacts of the Tax Cuts and Jobs Act for the regulated utility for excess deferred taxes recognized using a normalization method of accounting. During the three and nine months ended September 30, 2020, MGE recognized $0.7 million and $2.0 million, respectively, compared to $0.6 million and $1.7 million for the comparable periods in 2019. The amount and timing of the cash impacts will depend on the period over which certain income tax benefits are provided to customers, as determined by the PSCW.

5.

Pension and Other Postretirement Plans - MGE Energy and MGE.

MGE maintains qualified and nonqualified pension plans, health care, and life insurance benefits and defined contribution 401(k) benefit plans for its employees and retirees.

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

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

		Three Months Ended				Nine Months Ended
		September 30,				September 30,
(In thousands)		2020		2019		2020		2019
Pension Benefits
Components of net periodic benefit cost:
Service cost	$	1,324	$	1,040	$	3,972	$	3,402
Interest cost		3,052		3,170		9,157		10,364
Expected return on assets		(6,807)		(5,054)		(20,422)		(16,523)
Amortization of:
Prior service credit		(31)		(26)		(93)		(85)
Actuarial loss		1,339		1,637		4,018		5,351
Net periodic benefit (credit) cost	$	(1,123)	$	767	$	(3,368)	$	2,509
Postretirement Benefits
Components of net periodic benefit cost:
Service cost	$	316	$	276	$	948	$	829
Interest cost		570		721		1,709		2,164
Expected return on assets		(789)		(677)		(2,366)		(2,034)
Amortization of:
Transition obligation		1		1		2		2
Prior service credit		(667)		(664)		(2,001)		(1,994)
Actuarial loss		55		100		165		300
Net periodic benefit (credit) cost	$	(514)	$	(243)	$	(1,543)	$	(733)

As a result of lower investment returns in the fourth quarter of 2018, pension and postretirement benefit costs increased in 2019. In August 2019, the PSCW approved MGE's request to defer the difference between estimated pension and other postretirement costs included in the 2019 and 2020 rate settlement and actual expense incurred. MGE expects that the deferred cost for employee benefit plans will be factored into future rate proceedings. During 2019, MGE deferred approximately $6.2 million of pension and other post-retirement costs. MGE expects actual costs will be lower than the amount included in the 2020 rate settlement, which will reduce the regulatory asset that MGE expects to be factored into future rate proceedings. During the three and nine months ended September 30, 2020, MGE collected approximately $0.2 million and $0.7 million, respectively, of pension and other postretirement costs, which reduced the amount deferred in 2019. During the three and nine months ended September 30, 2019, MGE deferred approximately $1.3 million and $4.6 million, respectively, of pension and postretirement costs. The impact of this deferral has not been reflected in the table above.

6.

Equity and Financing Arrangements.

a.Common Stock - MGE Energy.

MGE Energy sells shares of its common stock through its Direct Stock Purchase and Dividend Reinvestment Plan (the Stock Plan). Those shares may be newly issued shares or shares that are purchased in the open market by an independent agent for participants in the Stock Plan. All sales under the Stock Plan are covered by a shelf registration statement that MGE Energy filed with the SEC. During the three and nine months ended September 30, 2020 and 2019, MGE Energy issued no new shares of common stock under the Stock Plan.

In May 2020, MGE Energy issued 1.5 million shares of its common stock in an underwritten offering. MGE Energy received proceeds, net of underwriter fees and issuance costs, of $79.6 million from the issuance and sale of those shares. The net proceeds are being used for general corporate purposes, including funding capital expenditures being made by MGE.

b.Dilutive Shares Calculation - MGE Energy.

MGE Energy has no dilutive securities issued.

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c.Long-term Debt - MGE Energy and MGE.

In April 2020, MGE borrowed $19.3 million from the City of Madison, Wisconsin's issuance of Industrial Development Revenue Refunding Bonds (Madison Gas and Electric Company Project), Series 2020A. The bonds carry an interest rate of 2.05% per annum with interest payable semi-annually on April 1 and October 1 of each year, which commenced on October 1, 2020. The bonds require their holder to tender them on April 30, 2023, at which time the bonds will either be repriced and remarketed or redeemed and retired. MGE used the proceeds to redeem at par $19.3 million of existing Industrial Development Revenue Refunding Bonds (Madison Gas and Electric Company Project), Series 2002B due October 1, 2027.

The funds for the loan were provided by a purchaser of the bonds pursuant to a Bond Purchase and Covenants Agreement between that purchaser and MGE. That Agreement requires MGE to maintain a ratio of consolidated indebtedness to consolidated total capitalization not to exceed a maximum of 65%. Both consolidated indebtedness and consolidated total capitalization are to be determined in accordance with GAAP, except that amounts included within MGE's indebtedness and capitalization from "variable interest entities" are excluded. A change of control constitutes a default under the Bond Purchase Agreement. Change in control events are defined as (i) a failure by MGE Energy to hold 100% of the outstanding voting equity interest in MGE or (ii) the acquisition of beneficial ownership of 30% or more of the outstanding voting stock of MGE Energy by one person or two or more persons acting in concert. The ratio, and its calculation, and the change of control provision reflect the provisions contained in MGE’s credit agreements.

7.

Share-Based Compensation - MGE Energy and MGE.

a.

2013 Director Incentive Plan and 2006 Performance Unit Plan

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

In 2020, 5,048 units were granted under the 2013 Plan and are subject to a three-year graded vesting schedule. No units were granted under the 2006 Plan in 2020 in view of the adoption of the 2020 Performance Unit Plan described below. On the grant date, the cost of the director or employee services received in exchange for a performance unit award is measured based on the current market value of MGE Energy common stock. The fair value of the awards is remeasured quarterly, including as of September 30, 2020, as required by applicable accounting standards. Changes in quarterly fair value as well as the original grant are recognized as compensation cost. Since this amount is remeasured throughout the vesting period, the compensation cost is subject to variability.

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

During the three months ended September 30, 2020 and 2019, MGE recorded $0.1 million and $0.9 million, respectively, in compensation expense as a result of awards under the 2013 Plan and 2006 Plan. During the nine months ended September 30, 2020 and 2019, MGE recorded $0.3 million in compensation benefit and $2.8 million in compensation expense, respectively, as a result of awards under the 2013 Plan and 2006 Plan. In January 2020, cash payments of $2.0 million were distributed relating to awards that were granted in a prior year under the plans. No forfeitures of units occurred during the three and nine months ended September 30, 2020 and 2019. As of September 30, 2020, $3.4 million of outstanding awards are vested. Of this amount, no cash settlements have occurred as cash

19

payments are only made at the end of the period covered by the awards.

b.

2020 Performance Unit Plan

The 2020 Performance Unit Plan (the 2020 Plan) was adopted in February 2020 for eligible employees. Plan participants may receive awards of performance units, restricted units, or both. Performance units entitle the holder to receive a cash payment equal to the value of a designated number of shares of MGE Energy's common stock, plus dividend-equivalent payments thereon, based upon achievement of specified performance goals during a performance period set by the Compensation Committee of MGE Energy's Board of Directors. Restricted units entitle the holder to receive a cash payment equal to the value of a designated number of shares of MGE Energy's common stock, plus dividend-equivalent payments thereon, at the end of a defined time period. Awards are subject to vesting provisions providing for 100% vesting at the end of the performance period, in the case of performance units, and at the end of the defined time period in the case of restricted units. The performance units and restricted units will be paid out in cash and are accounted for as a liability award. No shares of common stock will be issued in connection with the 2020 Plan.

In April 2020, 9,822 performance units and 9,822 restricted units were granted under the 2020 Plan. The 2020 performance units contain market and performance conditions. The market condition is based on total shareowner return relative to an investor-owned utility peer group. The performance condition is based on achievement of targets specified in the award agreement (such as an earnings growth target). The fair value of each performance unit is based on the fair value of the underlying common stock on the grant date and the probability of satisfying the market and performance conditions contained in the award agreement during the three-year performance period. The actual payments upon vesting depends upon actual performance and may range from zero to 200% of the granted number of performance units. The 2020 restricted units will vest based on a three-year cliff vesting schedule.

During the three and nine months ended September 30, 2020, MGE recorded less than $0.1 million and $0.6 million, respectively, in compensation expense as a result of awards under the 2020 Plan.

8.

Commitments and Contingencies.

a.Environmental - MGE Energy and MGE.

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 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. 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 is analyzing the rule's impact and expects to have cost estimates in early 2021. MGE expects to continue to work with the Elm Road operator to determine the expected costs and timing of compliance. MGE does not expect this rule to have a material effect on Columbia.

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

20

(trapping aquatic life on screens). MGE must conduct studies of its Blount plant by the end of 2021 to help regulators determine BAT. Columbia's operator must also conduct studies to help determine BAT. Future BAT requirements at Blount and Columbia will be established by the WDNR based on the results of these intake studies and will be specified in the next facility discharge permits expected to be issued in 2023 or later. 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 2019, the EPA published a final rule creating the Affordable Clean Energy (ACE) rule to reduce greenhouse gas emissions from existing coal-fired EGUs. The ACE rule directs states to submit plans to the EPA for approval that implement standards of performance (called Best System of Emissions Reductions, or BSER) for individual coal-fired EGUs over 25 MW. The ACE rule defines BSER as on-site "inside the fenceline," heat-rate efficiency improvements. Under the ACE rule, states have the primary role in developing standards of performance that result from the application of BSER. States have three years to develop and submit compliance plans to the EPA. The EPA will have a year to review and approve those plans. States are then given 24 months from the approval date to implement the plan and can extend the compliance schedule for units that meet progress milestones.

The ACE rule applies to Columbia and the Elm Road Units. The State of Wisconsin has begun to develop an implementation plan and has shared its preliminary work with Wisconsin utilities. MGE is actively monitoring state activity on BSER development. Until the State of Wisconsin completes a plan that is accepted by the EPA, MGE cannot conclusively determine the final impact of the rule. Additionally, the ACE rule and repeal of the Clean Power Plan are subject to a legal challenge pending in the United States District Court of the District of Columbia. MGE will continue to evaluate the plan developments within the state and monitor ongoing and potential legal proceedings associated with the ACE rule.

•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 this 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 United States 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 our Elm Road Units in Milwaukee County. At this time, MGE expects that the 2015 Ozone NAAQS will not 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 U.S. Court of Appeals held that the EPA cannot provide a partial remedy to the Clean Air Act's "Good Neighbor Provision," which addresses interstate transport of pollutants from upwind states to downwind states. Wisconsin is considered an upwind and downwind state under CSAPR and is potentially impacted by rules that the EPA will develop

21

to address this remand. 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. While uncertainty remains around CSAPR due to legal challenges, MGE expects to meet ongoing CSAPR obligations for the foreseeable future. MGE will continue to monitor developments in EPA revisions after the remand and any ongoing litigation over this rule.

Columbia is subject to the best available retrofit technology (BART) regulations, a subsection of the EPA's CAVR, which may require pollution control retrofits. Columbia's existing pollution control upgrades, and the EPA's stance that compliance with the CSAPR equals compliance with BART, should mean that Columbia will not need to do additional work to meet BART requirements. At this time, however, the BART regulatory obligations, compliance strategies, and costs remain uncertain in Wisconsin due to the continued legal challenges surrounding CSAPR and CAVR. MGE will continue to monitor developments 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.

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. Columbia's operator is also exploring alternative compliance options to meet the rule requirements by the rule's deadline. MGE will continue to monitor the operator's plans for compliance to assess potential impacts on operations.

In December 2019, the EPA introduced a proposed rule to revise some of the closure standards that are in the 2015 CCR Rule. If the proposed rule is finalized, MGE does not anticipate that it will have a material impact on our operations.

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.

c.Purchase Contracts - MGE Energy and MGE.

MGE Energy and MGE have entered into various commodity supply, transportation, and storage contracts to meet their obligations to deliver electricity and natural gas to customers. Management expects to recover these costs in future customer rates. The following table shows future commitments related to purchase contracts as of September 30, 2020:

(In thousands)		2020		2021		2022		2023		2024		Thereafter
Coal(a)	$	6,381	$	6,405	$	6,439	$	1,515	$	-	$	-
Natural gas
Transportation and storage(b)		6,260		21,854		22,008		22,008		22,008		36,603
Supply(c)		8,541		12,567		-		-		-		-
	$	21,182	$	40,826	$	28,447	$	23,523	$	22,008	$	36,603

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

(b)

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

(c)These commitments include market-based pricing.

9.

Rate Matters - MGE Energy and MGE.

a.Rate Proceedings.

In August 2020, MGE filed with the PSCW a proposed settlement agreement for its pending 2021 rate case. The settlement agreement proposes 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 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 Tax Act not governed by IRS normalization rules. As part of the settlement, the fuel rules bandwidth will be set at plus or minus 1%. The gas rate increase covers infrastructure costs and technology improvements. The settlement agreement also seeks escrow accounting treatment for pension and other postretirement benefit costs, bad debt expense, and customer credit card fees. Escrow accounting treatment would allow MGE to defer to its next rate filing any difference between estimated costs in rates and actual costs incurred. Any difference, if allowed, would be recorded as a regulatory asset or regulatory liability. No change is proposed in the pending settlement agreement for 2021 from the 2020 authorized return on common equity or the financial capital structure. PSCW approval of the settlement agreement is pending. A final order is expected before the end of the year.

In December 2018, the PSCW approved a settlement agreement between MGE and intervening parties in its 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 tax impacts of the 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 Tax Act. The return on common stock equity for 2019 and 2020 is 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 the PSCW and Wisconsin utilities to defer electric fuel-related costs that fall outside a symmetrical cost tolerance band around the amount approved for a utility in its 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 currently set at plus or minus 2%. Under fuel rules, MGE would defer costs, less any excess revenues, if its actual electric fuel costs exceeded 102% of the electric fuel costs allowed in its latest rate order. Excess revenues are defined as revenues in the year in question that provide MGE with a greater return on common equity than authorized by the PSCW in MGE's latest rate order. Conversely, MGE is required to defer the benefit of lower costs if actual electric fuel costs were less than 98% of the electric fuel costs allowed in that order. These costs are subject to the PSCW's annual review of fuel costs completed in the year following the deferral.

The PSCW issued a final decision in the 2018 fuel rules proceedings for MGE to refund additional fuel savings realized in 2018 to its retail electric customers over a one-month period. MGE returned $9.5 million to electric customers in October 2019. There was no change to the refund in the fuel rules proceedings from the amount MGE deferred in the previous year.

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 proposed settlement to MGE's pending 2021 rate case or to refund the balance to customers in October 2020. There was no change to the refund in the fuel rules proceedings from the amount MGE deferred in the previous year. The 2019 fuel credit is currently included in the proposed settlement to MGE's pending 2021 rate case.

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As of September 30, 2020, MGE had deferred $2.0 million of 2020 fuel savings. These costs will be subject to the PSCW's annual review of 2020 fuel costs, which is expected to be completed in 2021.

c.COVID-19.

On March 24, 2020, the PSCW ordered changes to the tariff provisions of all public utilities in Wisconsin in response to the COVID-19 pandemic. The order prohibited late payment charges, service disconnections, service refusals, and cash deposits as a condition of service. The order also required utilities to offer deferred payment arrangements to customers. The order resulted in increased bad debt expense and foregone revenue from late payment charges. This order, as it pertained to the prohibitions on service disconnections for residential customers, was in effect until November 1, 2020, at which time the annual winter disconnection moratorium began and continues until April 15, 2021. All other restrictions were lifted in July 2020. As permitted by regulatory action, MGE notified the PSCW on July 16, 2020, of its election to continue to waive late fees until December 31, 2020 for all customer classes and seek recovery in a future period. In October 2020, the PSCW issued a decision to allow utilities to extend the election to waive late fees until April 15, 2021, if the utility requests such waiver.

On March 24, 2020, the PSCW issued a further order authorizing deferral of expenditures incurred to ensure the provision of safe, reliable, and affordable access to utility services during the COVID-19 pandemic and late payment charges. Expenditures may include items such as bad debt expense and personal protective equipment. Foregone revenue from late payment charges and the potential delay in payments from customers is expected to impact the timing of cash inflows. Subject to PSCW approval of recovery, foregone late payment charges are expected to be recognized as revenue when it is collected from customers, and deferred expenditures are expected to be recognized as a regulatory asset as costs are incurred (meaning that those expenditures will affect cash flows when paid but will not affect income until recovery is permitted by the PSCW). Recovery of expenditures and late payment charges is expected to be addressed in future rate proceedings. While management believes that cost recovery is probable, the timing of collection from customers cannot be estimated at this time. Management will continue to assess the probability of recovery of deferred costs as the COVID-19 pandemic progresses. As of September 30, 2020, MGE had deferred $2.8 million in costs as a regulatory asset.

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.

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b.Notional Amounts.

The gross notional volume of open derivatives is as follows:

	September 30, 2020		December 31, 2019
Commodity derivative contracts	330,400	MWh	417,840	MWh
Commodity derivative contracts	8,495,000	Dth	6,605,000	Dth
FTRs	4,589	MW	2,750	MW
PPA	1,000	MW	1,450	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 September 30, 2020, the fair value of exchange traded derivatives and FTRs exceeded their cost basis by $2.0 million. As of December 31, 2019, the cost basis of exchange traded derivatives and FTRs exceeded their fair value by $1.4 million.

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 September 30, 2020, and December 31, 2019, reflected a loss position of $16.0 million and $25.4 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
September 30, 2020
Commodity derivative contracts(a)	$	2,248	$	546	Other current assets
Commodity derivative contracts(a)		253		12	Other deferred charges
FTRs		20		-	Other current assets
PPA		N/A		9,640	Derivative liability (current)
PPA		N/A		6,340	Derivative liability (long-term)
December 31, 2019
Commodity derivative contracts(b)	$	157	$	1,521	Derivative liability (current)(c)
Commodity derivative contracts(b)		73		217	Derivative liability (long-term)
FTRs		73		-	Other current assets
PPA		N/A		10,100	Derivative liability (current)
PPA		N/A		15,340	Derivative liability (long-term)

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(a) As of September 30, 2020, collateral of $0.7 million was posted against derivative positions owed to counterparties under a master netting agreement on the consolidated balance sheet.

(b)As of December 31, 2019, collateral of $1.5 million was posted against and netted with derivative liability positions on the consolidated balance sheets.

(c) As of December 31, 2019, MGE posted $0.1 million as other current assets on the consolidated balance sheets.

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
September 30, 2020
Commodity derivative contracts	$	2,501	$	(558)	$	(650)	$	1,293
FTRs		20		-		-		20
December 31, 2019
Commodity derivative contracts	$	230	$	(192)	$	-	$	38
FTRs		73		-		-		73

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
September 30, 2020
Commodity derivative contracts	$	558	$	(558)	$	-	$	-
PPA		15,980		-		-		15,980
December 31, 2019
Commodity derivative contracts	$	1,738	$	(192)	$	(1,546)	$	-
PPA		25,440		-		-		25,440

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.

		2020				2019
(In thousands)		Current and Long-Term Regulatory Asset		Other Current Assets		Current and Long-Term Regulatory Asset		Other Current Assets
Three Months Ended September 30:
Balance as of July 1,	$	20,400	$	940	$	33,515	$	878
Unrealized (gain) loss		(4,695)		-		(4,560)		-
Realized (loss) gain reclassified to a deferred account		(207)		207		(411)		411
Realized (loss) gain reclassified to income statement		(1,481)		(164)		638		(258)
Balance as of September 30,	$	14,017	$	983	$	29,182	$	1,031
Nine Months Ended September 30:
Balance as of January 1,	$	26,875	$	1,100	$	31,830	$	377
Unrealized (gain) loss		(8,032)		-		(2,256)		-
Realized (loss) gain reclassified to a deferred account		(1,999)		1,999		(1,402)		1,402
Realized (loss) gain reclassified to income statement		(2,827)		(2,116)		1,010		(748)
Balance as of September 30,	$	14,017	$	983	$	29,182	$	1,031

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		Realized Losses (Gains)
		2020				2019
(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 September 30:
Commodity derivative contracts	$	680	$	28	$	471	$	83
FTRs		184		-		(429)		-
PPA		753		-		(505)		-
Nine Months Ended September 30:
Commodity derivative contracts	$	2,303	$	1,682	$	1,038	$	460
FTRs		78		-		(503)		-
PPA		880		-		(1,257)		-

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 above described treatment, 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 September 30, 2020, 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 September 30, 2020, and December 31, 2019, 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 September 30, 2020, 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 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.

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The estimated fair market value offinancial instruments are as follows:

		September 30, 2020				December 31, 2019
(In thousands)		Carrying Amount		Fair Value		Carrying Amount		Fair Value
MGE Energy
Assets:
Cash and cash equivalents	$	53,058	$	53,058	$	23,481	$	23,481
Liabilities:
Long-term debt(a)		544,395		658,008		547,879		611,909
MGE
Assets:
Cash and cash equivalents	$	5,171	$	5,171	$	3,196	$	3,196
Liabilities:
Long-term debt(a)		544,395		658,008		547,879		611,909

(a) Includes long-term debt due within one year. Excludes debt issuance costs and unamortized discount of $4.3 million and $4.5 million as of September 30, 2020, and December 31, 2019, 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 September 30, 2020
(In thousands)		Total		Level 1		Level 2		Level 3
MGE Energy
Assets:
Derivatives, net(b)	$	2,521	$	1,975	$	-	$	546
Exchange-traded investments		1,781		1,781		-		-
Total Assets	$	4,302	$	3,756	$	-	$	546
Liabilities:
Derivatives, net	$	16,538	$	265	$	-	$	16,273
Deferred compensation		3,349		-		3,349		-
Total Liabilities	$	19,887	$	265	$	3,349	$	16,273
MGE
Assets:
Derivatives, net(b)	$	2,521	$	1,975	$	-	$	546
Exchange-traded investments		461		461		-		-
Total Assets	$	2,982	$	2,436	$	-	$	546
Liabilities:
Derivatives, net	$	16,538	$	265	$	-	$	16,273
Deferred compensation		3,349		-		3,349		-
Total Liabilities	$	19,887	$	265	$	3,349	$	16,273

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		Fair Value as of December 31, 2019
(In thousands)		Total		Level 1		Level 2		Level 3
MGE Energy
Assets:
Derivatives, net	$	303	$	189	$	-	$	114
Exchange-traded investments		1,271		1,271		-		-
Total Assets	$	1,574	$	1,460	$	-	$	114
Liabilities:
Derivatives, net(c)	$	27,178	$	608	$	-	$	26,570
Deferred compensation		3,157		-		3,157		-
Total Liabilities	$	30,335	$	608	$	3,157	$	26,570
MGE
Assets:
Derivatives, net	$	303	$	189	$	-	$	114
Exchange-traded investments		209		209		-		-
Total Assets	$	512	$	398	$	-	$	114
Liabilities:
Derivatives, net(c)	$	27,178	$	608	$	-	$	26,570
Deferred compensation		3,157		-		3,157		-
Total Liabilities	$	30,335	$	608	$	3,157	$	26,570

(b) These amounts are shown gross and exclude $0.7 million of collateral against derivative positions owed to counterparties under a master netting agreement as of September 30, 2020.

(c) These amounts are shown gross and exclude $1.5 million of collateral that was posted against derivative positions with counterparties as December 31, 2019.

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

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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	September 30, 2020		December 31, 2019
Basis adjustment:
On peak	93.9	%	92.1	%
Off peak	93.7	%	92.7	%
Counterparty fuel mix:
Internal generation - range	46.0% - 65.0	%	40.0% - 60.0	%
Internal generation - weighted average	56.4	%	52.2	%
Purchased power - range	54.0% - 35.0	%	60.0% - 40.0	%
Purchased power - weighted average	43.6	%	47.8	%

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				Nine Months Ended
		September 30,				September 30,
(In thousands)		2020		2019		2020		2019
Beginning balance	$	(21,023)	$	(33,337)	$	(26,456)	$	(32,002)
Realized and unrealized gains (losses):
Included in regulatory assets		5,296		4,317		10,729		2,982
Included in other comprehensive income		-		-		-		-
Included in earnings		(1,524)		(492)		(4,687)		(1,928)
Included in current assets		(37)		4		(101)		(198)
Purchases		5,505		5,205		15,837		16,827
Sales		-		-		-		-
Issuances		-		-		-		-
Settlements		(3,944)		(4,717)		(11,049)		(14,701)
Transfers in and/or out of Level 3		-		-		-		-
Balance as of September 30,	$	(15,727)	$	(29,020)	$	(15,727)	$	(29,020)
Total gains (losses) included in earnings attributed to
the change in unrealized gains (losses) related to
assets and liabilities held as of September 30,(d)	$	-	$	-	$	-	$	-

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

		Three Months Ended				Nine Months Ended
		September 30,				September 30,
(In thousands)		2020		2019		2020		2019
Purchased Power Expense	$	(1,496)	$	(409)	$	(4,343)	$	(1,658)
Cost of Gas Sold Expense		(28)		(83)		(344)		(270)
Total	$	(1,524)	$	(492)	$	(4,687)	$	(1,928)

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

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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		September 30, 2020(a)		Operation
Two Creeks(b)	33	%	50	MW	$65	million	$63.1	million	November 2, 2020
Badger Hollow I(c)	33	%	50	MW	$65	million	$50.5	million	April 2021(d)
Badger Hollow II(c)	33	%	50	MW	$65	million	$5.0	million	December 2022(d)

(a)Excluding AFUDC.

(b) The Two Creeks solar generation array is located in the Town of Two Creeks and the City of Two Rivers in Manitowoc and Kewaunee Counties, Wisconsin.

(c)

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

(d)Estimated date of commercial operation.

MGE received specific approval to recover 100% AFUDC on each of these projects. During the three months ended September 30, 2020 and 2019, MGE recognized $1.9 million and $0.7 million, respectively, after tax, in AFUDC for Two Creeks and Badger Hollow I and II. During the nine months ended September 30, 2020 and 2019, MGE recognized $4.5 million and $0.8 million, respectively, after tax, in AFUDC for Two Creeks and Badger Hollow I and II.

13.

Revenue - MGE Energy and MGE.

Revenues disaggregated by revenue source were as follows:

		Three Months Ended				Nine Months Ended
(In thousands)		September 30,				September 30,
Electric revenues		2020		2019		2020		2019
Residential	$	45,009	$	42,442	$	113,311	$	107,772
Commercial		57,822		63,466		152,844		165,481
Industrial		3,234		3,760		8,797		10,013
Other-retail/municipal		8,620		9,543		24,874		26,728
Total retail		114,685		119,211		299,826		309,994
Sales to the market		1,554		1,163		2,604		3,914
Other revenues		115		233		660		978
Total electric revenues		116,354		120,607		303,090		314,886
Gas revenues
Residential		12,436		11,342		61,328		67,659
Commercial/Industrial		5,052		4,825		32,961		40,833
Total retail		17,488		16,167		94,289		108,492
Gas transportation		1,152		1,126		4,179		3,756
Other revenues		3		84		100		299
Total gas revenues		18,643		17,377		98,568		112,547
Non-regulated energy revenues		214		214		466		481
Total Operating Revenue	$	135,211	$	138,198		402,124	$	427,914

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.

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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 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.

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 2019 Annual Report on Form 10-K for additional discussion of each of these segments.

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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 September 30, 2020
Operating revenues from external customers	$	116,354	$	18,643	$	214	$	-	$	-	$	-	$	135,211
Interdepartmental revenues		209		3,494		10,102		-		-		(13,805)		-
Total operating revenues		116,563		22,137		10,316		-		-		(13,805)		135,211
Equity in earnings of investments		-		-		-		2,353		-		-		2,353
Net income (loss)		24,761		221		5,251		1,710		(149)		-		31,794
Three Months Ended September 30, 2019
Operating revenues from external customers	$	120,607	$	17,377	$	214	$	-	$	-	$	-	$	138,198
Interdepartmental revenues		225		5,679		10,019		-		-		(15,923)		-
Total operating revenues		120,832		23,056		10,233		-		-		(15,923)		138,198
Equity in earnings of investments		-		-		-		2,372		-		-		2,372
Net income (loss)		23,681		(61)		5,131		1,726		180		-		30,657
Nine Months Ended September 30, 2020
Operating revenues from external customers	$	303,090	$	98,568	$	466	$	-	$	-	$	-	$	402,124
Interdepartmental revenues		584		9,300		30,248		-		-		(40,132)		-
Total operating revenues		303,674		107,868		30,714		-		-		(40,132)		402,124
Equity in earnings of investments		-		-		-		7,780		-		-		7,780
Net income (loss)		46,439		9,216		15,536		5,659		(228)		-		76,622
Nine Months Ended September 30, 2019
Operating revenues from external customers	$	314,886	$	112,547	$	481	$	-	$	-	$	-	$	427,914
Interdepartmental revenues		622		12,571		29,987		-		-		(43,180)		-
Total operating revenues		315,508		125,118		30,468		-		-		(43,180)		427,914
Equity in earnings of investments		-		-		-		6,808		-		-		6,808
Net income		40,905		8,648		15,211		4,952		496		-		70,212

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 September 30, 2020
Operating revenues from external customers	$	116,354	$	18,643	$	214	$	-	$	135,211
Interdepartmental revenues		209		3,494		10,102		(13,805)		-
Total operating revenues		116,563		22,137		10,316		(13,805)		135,211
Net income attributable to MGE		24,761		221		5,251		(5,493)		24,740
Three Months Ended September 30, 2019
Operating revenues from external customers	$	120,607	$	17,377	$	214	$	-	$	138,198
Interdepartmental revenues		225		5,679		10,019		(15,923)		-
Total operating revenues		120,832		23,056		10,233		(15,923)		138,198
Net income (loss) attributable to MGE		23,681		(61)		5,131		(5,614)		23,137
Nine Months Ended September 30, 2020
Operating revenues from external customers	$	303,090	$	98,568	$	466	$	-	$	402,124
Interdepartmental revenues		584		9,300		30,248		(40,132)		-
Total operating revenues		303,674		107,868		30,714		(40,132)		402,124
Net income attributable to MGE		46,439		9,216		15,536		(16,754)		54,437
Nine Months Ended September 30, 2019
Operating revenues from external customers	$	314,886	$	112,547	$	481	$	-	$	427,914
Interdepartmental revenues		622		12,571		29,987		(43,180)		-
Total operating revenues		315,508		125,118		30,468		(43,180)		427,914
Net income attributable to MGE		40,905		8,648		15,211		(16,725)		48,039

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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 and distributes electricity to approximately 155,000 customers in Dane County, Wisconsin, including the city of Madison, and purchases and distributes natural gas to approximately 163,000 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 campus of the University of Wisconsin in Madison. 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 meets 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, including the reduction in its ownership of Columbia (a coal-fired generating facility) and its growing ownership of renewable generation sources. MGE will continue to focus on growing earnings while controlling operating and fuel costs. MGE maintains safe and efficient operations in addition to providing customer value. We believe it is critical to maintain a strong credit standing consistent with financial strength in MGE as well as the parent company in order to accomplish these goals.

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

 Weather, and its impact on customer sales,

 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 2019 Annual Report on Form 10-K.

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During the three months ended September 30, 2020, MGE Energy's earnings were $31.8 million or $0.88 per share compared to $30.7 million or $0.88 per share during the same period in the prior year. MGE's earnings during the three months ended September 30, 2020, were $24.7 million compared to $23.1 million during the same period in the prior year.

During the nine months ended September 30, 2020, MGE Energy's earnings were $76.6 million or $2.16 per share compared to $70.2 million or $2.03 per share during the same period in the prior year. MGE's earnings during the nine months ended September 30, 2020, were $54.4 million compared to $48.0 million during the same period in the prior year.

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

		Three Months Ended				Nine Months Ended
(In millions)		September 30,				September 30,
Business Segment:		2020		2019		2020		2019
Electric Utility	$	24.7	$	23.7	$	46.4	$	40.9
Gas Utility		0.2		-		9.2		8.6
Nonregulated Energy		5.2		5.1		15.5		15.2
Transmission Investments		1.8		1.7		5.7		5.0
All Other		(0.1)		0.2		(0.2)		0.5
Net Income	$	31.8	$	30.7	$	76.6	$	70.2

Our net income during the three and nine months ended September 30, 2020, compared to the same period in the prior year primarily reflects the effects of the following factors:

Electric Utility

Electric net income increased primarily due to AFUDC equity earned from the construction of Two Creeks and Badger Hollow I and II and savings in operating and maintenance costs. An increase in assets included in rate base also contributed to increased earnings for 2020. A reduction of retail sales driven by the impacts of COVID-19 and associated governmental regulations affected electric earnings in 2020. For the three and nine months ended September 30, 2020, commercial retail sales decreased approximately 8% and 7%, respectively, compared to the same period in the prior year. This decrease was partially mitigated by an increase in residential sales of approximately 9% and 7% for the three and nine months ended September 30, 2020, respectively, compared to the same period in the prior year. As businesses shifted their workforce to a remote work environment, residential sales increased.

Gas Utility

Gas net income increased primarily due to savings in operating and maintenance costs and customer growth. An increase in assets included in rate base also contributed to increased earnings for 2020. Colder than normal weather in the first quarter of 2019 and milder weather in the first quarter of 2020 partially offset this increase. Heating degree days (a measure for determining the impact of weather during the heating season) in 2020 decreased by approximately 10% compared to 2019.

The following developments affected the first nine months of 2020:

2019/2020 Rate Change Settlement: 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 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 Tax Act.

PSCW Approval of Deferral of Pension and Other Postretirement Benefit Costs: As a result of lower investment returns in the fourth quarter of 2018, pension and postretirement benefit costs increased in 2019. In August 2019, the PSCW approved MGE's request to defer the difference between estimated pension and other postretirement

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costs included in the 2019 and 2020 rate settlement and actual costs incurred. In the second quarter of 2019, upon receiving the PSCW decision, deferral of pension and other postretirement costs were recorded. No deferral of pension and other postretirement costs were recorded in the first quarter of 2019. During 2019, MGE deferred approximately $6.2 million of pension and other postretirement costs. MGE expects actual costs will be lower than the amount included in the 2020 rate settlement by approximately $0.9 million to $1.2 million. Net pension and other postretirement costs deferred over the two-year period is expected to be approximately $5 million by the end of 2020. The net deferred costs are expected to be factored into future rate proceedings. During the three and nine months ended September 30, 2020, MGE collected approximately $0.2 million and $0.7 million, respectively, of pension and other postretirement costs, which reduced the amount deferred in 2019. During the three and nine months ended September 30, 2019, MGE deferred approximately $1.3 million and $4.6 million of pension and postretirement costs.

Utility Solar: Three jointly-owned 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 each project. After tax, MGE recognized $2.0 million, $1.3 million, and $0.1 million of AFUDC equity on Two Creeks and Badger Hollow I and II, respectively, during the nine months ended September 30, 2020.

Project	Share of Generation	Share of Estimated Costs	Costs Incurred as of September 30, 2020(a)	Date of Commercial Operation
Two Creeks	50 MW	$65 million	$63.1 million	November 2, 2020
Badger Hollow I	50 MW	$65 million	$50.5 million	April 2021(b)
Badger Hollow II	50 MW	$65 million	$ 5.0 million	December 2022(b)

(a)Excluding AFUDC.

(b)Estimated date of commercial operation.

Equity Issuance: In May 2020, MGE Energy issued 1.5 million shares of common stock in an underwritten offering. The net proceeds of $79.6 million are being used for general corporate purposes including funding capital expenditures by MGE in projects such as Two Creeks, Badger Hollow I and II, Renewable Energy Rider solar projects, and other capital projects.

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

2021 Rate Change Settlement: In August 2020, MGE filed with the PSCW a proposed settlement agreement for its pending 2021 rate case. The settlement agreement proposes 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 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 Tax Act not governed by IRS normalization rules. As part of the settlement, the fuel rules bandwidth will be set at plus or minus 1%. The gas rate increase covers infrastructure costs and technology improvements. The settlement agreement also seeks escrow accounting treatment for pension and other postretirement benefit costs, bad debt expense, and customer credit card fees. Escrow accounting treatment would allow MGE to defer until its next rate filing any difference between estimated costs in rates and actual costs incurred. Any difference, if allowed, would be recorded as a regulatory asset or regulatory liability. No change is proposed in the pending settlement agreement for 2021 from the 2020 authorized return on common equity or the financial capital structure. PSCW approval of the settlement agreement is pending. A final order is expected before the end of the year.

Pension and Other Postretirement Benefit Costs: Costs for pension and other postretirement benefits are affected by actual investment returns on the assets held for those benefits and by the discount rate used to calculate those benefits. The discount rate is sensitive to changes in interest rates. Lower than expected employee benefit plan asset values could affect the value of pension and postretirement benefit obligations and may increase benefit costs in future years. As previously discussed, these costs are expected to be factored into future rate actions.

Tax Reform: Pursuant to the Tax Act, deferred income tax balances as of December 31, 2017, were remeasured to reflect the decrease in the corporate tax rate. A regulatory liability of approximately $131 million was recorded to reflect the fact that changes in income taxes are generally passed through in customer rates for the regulated

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utility. The amount and timing of the cash impact will depend on the period over which certain income tax benefits are provided to customers. Approximately $117 million of the regulatory liability is a protected benefit 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. As determined in the rate settlement agreement for 2019 and 2020, MGE has included approximately $8.3 million of the protected benefit in base rates. If approved by the PSCW, the proposed rate settlement agreement for 2021 would include approximately $5.3 million of the protected benefit in base rates and $18.2 million of the unprotected benefit in electric base rates. The collection of the remaining unprotected portion related to gas will be addressed by the PSCW in a future 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 7.3% and 6.8% of our net income during the nine months ended September 30, 2020 and 2019, 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 any 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 increase the costs of owning and operating fossil-fueled generating plants, such as Columbia and the Elm Road Units, from which we derived approximately 43% of our electric generating capacity as of September 30, 2020. We would expect to seek and receive recovery of any such costs in rates; however, it is difficult to estimate the amount of such costs due to the uncertainty as to the timing and form of the legislation and rules, and the scope and time of the recovery of costs in rates, which may occur after those costs are incurred.

EPA's Affordable Clean Energy (ACE) Rule: In July 2019, the EPA published a final ACE rule to reduce greenhouse gas emissions from existing coal-fired EGUs. The ACE rule directs states to submit plans to the EPA for approval that implement standards of performance (called Best System of Emissions Reductions, or BSER) for individual coal-fired EGUs over 25 MW. The ACE rule will apply to Columbia and the Elm Road Units. Compliance with the ACE rule may not be required until 2024 or later. Until the State of Wisconsin develops a plan that is accepted by the EPA, MGE will not be able to determine the final impact of the rule. Additionally, the ACE rule is subject to a legal challenge pending in the United States District Court of the District of Columbia. MGE will continue to evaluate the rule development within the state and monitor ongoing and potential legal proceedings associated with the rule.

O'Brien Wind Farm: In October 2020, MGE received approval from the PSCW to construct a 20 MW solar array in Fitchburg, Wisconsin, as part of its Renewable Energy Rider program. Capital costs are expected to be approximately $32 million and the project is anticipated to be completed by mid-2021.

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 being 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.

COVID-19 Update

With the global outbreak of the Coronavirus Disease 2019 (COVID-19) and the declaration of a pandemic by the World Health Organization on March 11, 2020, U.S. governmental authorities have deemed electric and gas utilities to be critical infrastructure. MGE Energy therefore has an obligation to keep operating and maintaining our critical electric and gas infrastructure. Since then, MGE Energy has been subject to, and is following, local, state and federal public health and safety regulations and guidance to control the pandemic. MGE Energy has operated continuously throughout the pandemic and suffered no material disruptions in service or employment.

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

 Governmental Actions. State and local governments and regulators have taken steps to address the

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pandemic and its effects, which have affected levels of economic activity, revenues and expense.

o State and Local Governments: State and local governments issued orders and regulations to restrict or manage business and individual activity that continues to evolve in response to changing health metrics and safety and health guidance. A late March 2020 statewide Stay at Home order has given way to phased activity resumption driven by local governments and public health departments. Actions by Public Health Madison & Dane County (PHMDC) affect Dane County, which comprises a majority of MGE's service area. PHMDC has issued several Emergency Orders and the Forward Dane plan (collectively, the PHMDC Directives) addressing activity during the pandemic. The PHMDC Directives provide for scaled re-opening of businesses and increased activity for residents based upon specific health metrics and consist of guidance and regulations concerning how and when residents can interact and conduct business. In general, the PHMDC Directives: identify "essential" and "non-essential" businesses; regulate how those entities may conduct business safely; restrict capacity inside businesses depending upon business type and sector; limit the size of private and public gatherings; and require masks for occupants of public and private buildings. The PHMDC Directives are subject to modification throughout the pandemic based upon current health metrics in the county.

o Regulatory – PSCW Orders: On March 24, 2020, the PSCW ordered changes to the tariff provisions of all public utilities in Wisconsin in response to the COVID-19 pandemic. The order prohibited late payment charges, service disconnections, service refusals, and cash deposits as a condition of service. The order also required utilities to offer deferred payment arrangements to customers. The order resulted in increased bad debt expense and foregone revenue from late payment charges. This order, as it pertained to the prohibitions on service disconnections for residential customers, was in effect until November 1, 2020, at which time the annual winter disconnection moratorium began and continues until April 15, 2021. All other restrictions were lifted in July 2020. As permitted by regulatory action, MGE notified the PSCW on July 16, 2020, of its election to continue to waive late fees until December 31, 2020, for all customer classes and seek recovery in a future period. In October 2020, the PSCW issued a decision to allow utilities to extend the election to waive late fees until April 15, 2021, if the utility requests such waiver.

On March 24, 2020, the PSCW issued a further order authorizing deferral of expenditures incurred to ensure the provision of safe, reliable, and affordable access to utility services during the COVID-19 pandemic and late payment charges. Expenditures may include items such as bad debt expense and personal protective equipment. Foregone revenue from late payment charges and the potential delay in payments from customers is expected to impact the timing of cash inflows. Subject to PSCW approval of recovery, foregone late payment charges are expected to be recognized as revenue when they are collected from customers, and deferred expenditures are expected to be recognized as a regulatory asset as costs are incurred (meaning that those expenditures will affect cash flows when paid but will not affect income until recovery is permitted by the PSCW). Recovery of expenditures and late payment charges is expected to be addressed in future rate proceedings. While management believes that cost recovery is probable, the timing of collection from customers cannot be estimated at this time. Management will continue to assess the probability of recovery of deferred costs as the COVID-19 pandemic progresses.

 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 September 30, 2020, MGE Energy and MGE had $53.1 million and $5.2 million, respectively, in cash and cash equivalents and had available borrowing capacity under revolving credit facilities as noted below.

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Borrower		Aggregate Bank Commitments		Outstanding Commercial Paper and Borrowings		Available Capacity	Expiration Date
(Dollars in millions)
MGE Energy	$	50.0	$	-	$	50.0	February 7, 2024
MGE	$	100.0	$	-	$	100.0	February 7, 2024

The credit agreements require the borrower to maintain a ratio of consolidated debt to consolidated total capitalization not to exceed a maximum of 65%. In the case of MGE, the ratio calculation excludes assets, liabilities, revenues, and expenses included in MGE's financial statements as a result of the consolidation of VIEs, such as MGE Power Elm Road and MGE Power West Campus. The ratio of consolidated debt to consolidated total capitalization for each of MGE Energy and MGE, as calculated under the credit agreements' covenant, was 35.7% and 38.4%, respectively, as of September 30, 2020, and 39.0% and 43.9%, respectively, as of December 31, 2019. See Item 7. Management’s Discussion and Analysis of Financial Condition and Results of Operations – Liquidity and Capital Resources – Credit Facilities in the 2019 Annual Report on Form 10-K for more information about our credit facilities.

 Revenue and Expense Impacts: We expect that adverse effects of COVID-19 and associated governmental regulations will be partially mitigated due to three primary factors. First, MGE has a large representation of commercial customers in essential sectors, such as government and healthcare, which we expect to return to more normal usage sooner than customers in nonessential sectors. Second, industrial customers comprise a small proportion of MGE's total customers, and we expect these customers to have the largest risk of changes in energy usage. Third, we believe residential sales will continue to increase due to the associated governmental regulations.

We began to see the impacts of COVID-19 and associated governmental regulations on customer demand in late March through the third quarter and continue to see lower retail sales. Commercial sales were down approximately 8% in the third quarter of 2020 compared to the same period in the prior year. In the third quarter of 2020, the reduction in revenue due to COVID-19 and associated governmental regulations was partially offset by cost containment measures, and we expect this trend to continue for the remainder of 2020. Residential sales increased approximately 9% in the third quarter of 2020 compared to the same period in the prior year. This effect was driven by businesses shifting their workforces to a remote work environment. We will continue to assess the degree to which our discretionary operations and maintenance expenses and capital spending can be reduced. This reduction could consist of deferring nonessential spending and management efforts to control spending, which includes travel, conferences, and other discretionary costs.

 Capital Expenditures: We have some meaningful ability to shift the timing of expenditures for capital projects during the next few years, should that become necessary. COVID-19 and associated governmental regulations did not significantly delay or disrupt the Two Creeks solar project, which entered commercial operation in November 2020. Badger Hollow I solar project was expected to be completed in 2020 and is now expected to be completed in April 2021. Badger Hollow II was expected to be completed in 2021 and is now expected to be completed in December 2022. The O'Brien solar project was expected to be completed by January 1, 2021 and is now expected to be completed in mid-2021. We have delayed other utility capital expenditures initially planned for 2020. No significant increase in costs is expected due to the delay. We will continue to monitor other capital project timelines as presented in the 2020-2022 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 2019 Annual Report on Form 10-K.

 Operations: 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 have seen some additional expenses associated with personal protective equipment and enhanced efforts to protect our personnel from the virus, which have been deferred as a regulatory asset.

As the duration of general economic disruption increases, so does the potential of a material adverse impact on

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our business. For this reason, although we expect sales for the remainder of 2020 to be negatively impacted by COVID-19 and associated governmental regulations, we cannot reasonably estimate with any degree of certainty the actual impact they may have on future results of operations, financial position, and liquidity. See Part II, Item 1A. "Risk Factors" "Pandemic virus or diseases, including COVID-19, could have a material adverse effect on our business, financial condition and liquidity."

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 September 30, 2020 and 2019

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

		Three Months Ended September 30,
(In millions)		2020		2019		$ Change
Electric revenues	$	116.4	$	120.6	$	(4.2)
Fuel for electric generation		(13.0)		(15.9)		2.9
Purchased power		(10.7)		(9.1)		(1.6)
Total Electric Margins		92.7		95.6		(2.9)
Gas revenues		18.6		17.4		1.2
Cost of gas sold		(3.8)		(3.1)		(0.7)
Total Gas Margins		14.8		14.3		0.5
Other operating revenues		0.2		0.2		-
Other operations and maintenance		(45.8)		(48.1)		2.3
Depreciation and amortization		(18.6)		(18.2)		(0.4)
Other general taxes		(5.0)		(5.1)		0.1
Operating Income	$	38.3	$	38.7	$	(0.4)

Operating income during the three months ended September 30, 2020, compared to the same period in the prior year primarily reflects the effects of the following factors:

 Electric revenues and fuel costs

o A $4.2 million decrease in electric revenue driven by lower commercial sales as a result of the COVID-19 pandemic and associated governmental regulations and restrictions on activity, partially offset by increased residential sales. Commercial retail sales decreased by 7.9%, and residential sales increased by 8.7%, when compared to the prior year.

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o A $2.9 million decrease in fuel for electric generation reflecting lower generation and market costs and a decrease in customer demand.

o A $1.6 million increase in purchased power costs driven by higher costs in the market. Average cost per MWH increased 20%.

 Gas revenues and cost of gas sold

o A $1.2 million increase in gas revenue driven by higher residential retail sales.

o A $0.7 million increase in cost of gas sold reflecting higher cost per therm of gas. Average cost per therm increased 17%.

 A $2.3 million decrease in other operations and maintenance. See consolidated operations and maintenance expenses section below for a description of the factors contributing to the decrease.

 A $0.4 million increase in depreciation and amortization expense.

Electric sales and revenues

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

		Revenues				Sales (kWh)
(In thousands, except cooling degree days)		Three Months Ended September 30,				Three Months Ended September 30,
		2020		2019	% Change	2020	2019	% Change
Residential	$	45,009	$	42,442	6.0 %	274,676	252,786	8.7 %
Commercial		57,822		63,466	(8.9)%	478,816	519,820	(7.9)%
Industrial		3,234		3,760	(14.0)%	43,257	45,772	(5.5)%
Other-retail/municipal		8,620		9,543	(9.7)%	97,493	99,055	(1.6)%
Total retail		114,685		119,211	(3.8)%	894,242	917,433	(2.5)%
Sales to the market		1,554		1,163	33.6 %	49,039	37,108	32.2 %
Other revenues		115		233	(50.6)%	-	-	- %
Total	$	116,354	$	120,607	(3.5)%	943,281	954,541	(1.2)%
Cooling degree days (normal 493)						519	535	(3.0)%

Electric margin, a non-GAAP measure, decreased $2.9 million during the three months ended September 30, 2020, compared to the same period in 2019, due to the following:

(In millions)
Decrease in commercial, industrial and other volume	$	(2.4)
Revenue subject to refund, net		(1.7)
Rate changes		(1.4)
Customer fixed and demand charges		(1.0)
Other		(0.2)
Increase in residential volume		2.6
Decreased fuel costs		1.2
Total	$	(2.9)

 Commercial, industrial, and other retail volume. During the three months ended September 30, 2020, there was a 7.9% 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.

 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 September 2019, MGE returned $2.2 million to electric customers through bill credits related to tax credits. The 2019 bill credit was deducted from revenues in previous years and held in a regulatory liability pending the refund to customers. As a result, the refund did not affect reported revenues in the current periods, although it did reduce cash and the corresponding regulatory liability.

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 Rate changes. Rates charged to retail customers during the three months ended September 30, 2020, were $1.4 million lower than those charged during the same period in the prior year. In December 2019, the PSCW approved the 2020 Fuel Cost Plan, which reflected lower fuel costs and authorized MGE to decrease 2020 rates for electric retail customers by 0.84%.

 Customer fixed and demand charges. During the three months ended September 30, 2020, fixed and demand charges decreased $1.0 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.

 Residential volume. During the three months ended September 30, 2020, there was an 8.7% 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 September 30, 2020, primarily as a result of lower costs to generate and purchase electricity in the market and lower customer demand.

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 September 30,				Three Months Ended September 30,
		2020		2019	% Change	2020	2019	% Change
Residential	$	12,436	$	11,342	9.6 %	6,537	5,707	14.5 %
Commercial/Industrial		5,052		4,825	4.7 %	9,368	9,195	1.9 %
Total retail		17,488		16,167	8.2 %	15,905	14,902	6.7 %
Gas transportation		1,152		1,126	2.3 %	16,092	15,514	3.7 %
Other revenues		3		84	(96.4)%	-	-	- %
Total	$	18,643	$	17,377	7.3 %	31,997	30,416	5.2 %
Heating degree days (normal 152)						175	57	207.0 %
Average rate per therm of
retail customer	$	1.100	$	1.085	1.4 %

Gas margin, a non-GAAP measure, increased $0.5 million during the three months ended September 30, 2020, compared to the same period in 2019, due to the following:

(In millions)
Other	$	0.2
Increase in volume		0.1
Rate changes		0.1
Revenue subject to refund, net		0.1
Total	$	0.5

 Rate changes. In December 2018, the PSCW authorized MGE to increase 2020 rates for retail gas customers by 1.46%.

 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 September 2019, MGE returned $1.0 million to gas customers through bill credits related to tax credits. The 2019 bill credit was deducted from revenues in previous years and held in a regulatory liability pending the refund to customers. As a result, the refund did not affect reported revenues in the current periods, although it did reduce cash and the corresponding regulatory liability.

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Consolidated operations and maintenance expenses

During the three months ended September 30, 2020, operations and maintenance expenses decreased $2.3 million, compared to the same period in the prior year. The following contributed to the net change:

(In millions)
Decreased administrative and general costs	$	(1.7)
Decreased transmission costs		(0.4)
Decreased other costs		(0.3)
Decreased electric production expenses		(0.2)
Increased gas distribution expenses		0.2
Increased electric distribution expenses		0.1
Total	$	(2.3)

 Decreased administrative and general costs are primarily related to a decrease in stock price and number of performance unit awards reducing the fair value associated with the performance unit awards, which is remeasured quarterly. See Footnote 7 of the Notes to Consolidated Financial Statements in this Report for additional information on performance unit awards. Other drivers include a reduction in nonessential spending driven by the COVID-19 pandemic and associated governmental regulations and management efforts to control spending, which includes training, travel expenses, and other discretionary spending.

Consolidated depreciation expense

Electric depreciation expense increased $0.3 million and gas depreciation expense increased $0.1 million during the three months ended September 30, 2020, compared to the same period in the prior year.

Electric and gas other income

Electric other income increased $1.3 million during the three months ended September 30, 2020, compared to the same period in the prior year, primarily related to the AFUDC Equity from the construction of Two Creeks and Badger Hollow I and II. Gas other income decreased $0.1 million during the three months ended September 30, 2020, compared to the same period in the prior year.

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 September 30, 2020 and 2019, net income at the nonregulated energy operations segment was $5.3 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 both the three months ended September 30, 2020 and 2019, other income at the transmission investment segment was $2.4 million. 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 2020, the effective electric tax rate decreased as a result of higher AFUDC equity from Badger Hollow I and II and Two Creeks, which is not included in taxable income, and a tax credit generated by the Saratoga Wind Farm. See Footnote 4 of the Notes to Consolidated Financial Statements in this Report for the effective tax rate reconciliation.

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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. 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
		September 30,
(In millions)		2020		2019
MGE Power Elm Road	$	3.7	$	3.8
MGE Power West Campus		1.8		1.8

Nine Months Ended September 30, 2020 and 2019

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

		Nine Months Ended September 30,
(In millions)		2020		2019		$ Change
Electric revenues	$	303.1	$	314.9	$	(11.8)
Fuel for electric generation		(31.3)		(40.2)		8.9
Purchased power		(32.0)		(31.0)		(1.0)
Total Electric Margins		239.8		243.7		(3.9)
Gas revenues		98.6		112.5		(13.9)
Cost of gas sold		(41.0)		(55.2)		14.2
Total Gas Margins		57.6		57.3		0.3
Other operating revenues		0.5		0.5		-
Other operations and maintenance		(136.5)		(144.0)		7.5
Depreciation and amortization		(55.2)		(53.4)		(1.8)
Other general taxes		(14.9)		(15.1)		0.2
Operating Income	$	91.3	$	89.0	$	2.3

Operating income during the nine months ended September 30, 2020, compared to the same period in the prior year primarily reflects the effects of the following factors:

 Electric revenues and fuel costs

o An $11.8 million decrease in electric revenue driven by lower commercial sales as a result of the COVID-19 pandemic and associated governmental regulations and restrictions on activity, partially offset by increased residential sales. Commercial retail sales decreased by 7.2% and residential sales increased by 7.2%, when compared to the prior year.

o An $8.9 million decrease in fuel for electric generation reflecting lower generation and market costs and a decrease in customer demand.

o A $1.0 million increase in purchased power costs primarily due to higher market purchases as a result of lower internal generation.

 Gas revenues and cost of gas sold

o A $13.9 million decrease in gas revenue driven by lower customer demand resulting from milder weather in the first quarter of 2020 and lower rates reflecting a lower cost of gas being recovered.

o A $14.2 million decrease in cost of gas sold driven by lower cost per therm of gas. Average cost per therm decreased 18%.

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 A $7.5 million decrease in other operations and maintenance. See consolidated operations and maintenance expenses section below for a description of the factors contributing to the decrease.

 A $1.8 million increase in depreciation and amortization expense driven by the timing of the commercial operation of Saratoga that took place in February 2019 as discussed in the consolidated depreciation expense section below.

Electric sales and revenues

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

		Revenues				Sales (kWh)
(In thousands, except cooling degree days)		Nine Months Ended September 30,				Nine Months Ended September 30,
		2020		2019	% Change	2020	2019	% Change
Residential	$	113,311	$	107,772	5.1 %	684,585	638,590	7.2 %
Commercial		152,844		165,481	(7.6)%	1,308,511	1,410,360	(7.2)%
Industrial		8,797		10,013	(12.1)%	122,106	131,195	(6.9)%
Other-retail/municipal		24,874		26,728	(6.9)%	263,029	276,795	(5.0)%
Total retail		299,826		309,994	(3.3)%	2,378,231	2,456,940	(3.2)%
Sales to the market		2,604		3,914	(33.5)%	92,539	110,246	(16.1)%
Other revenues		660		978	(32.5)%	-	-	- %
Total	$	303,090	$	314,886	(3.7)%	2,470,770	2,567,186	(3.8)%
Cooling degree days (normal 674)						732	653	12.1 %

Electric margin, a non-GAAP measure, decreased $3.9 million during the nine months ended September 30, 2020, compared to the same period in 2019, due to the following:

(In millions)
Decrease in commercial, industrial and other volume	$	(5.7)
Customer fixed and demand charges		(2.7)
Rate changes		(2.6)
Revenue subject to refund, net		(2.5)
Other		(0.3)
Increase in residential volume		5.1
Decreased fuel costs		4.8
Total	$	(3.9)

 Commercial, industrial, and other retail volume. During the nine months ended September 30, 2020, there was a 7.2% 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.

 Customer fixed and demand charges. During the nine months ended September 30, 2020, fixed and demand charges decreased $2.7 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.

 Rate changes. Rates charged to retail customers during the nine months ended September 30, 2020, were $2.6 million lower than those charged during the same period in the prior year. In December 2019, the PSCW approved the 2020 Fuel Cost Plan, which reflected lower fuel costs and authorized MGE to decrease 2020 rates for electric retail customers by 0.84%.

 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 September 2019, MGE returned $2.2 million to electric customers through bill credits related to tax credits. The 2019 bill credit was deducted from revenues in previous years and held in a

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regulatory liability pending the refund to customers. As a result, the refund did not affect reported revenues in the current periods, although it did reduce cash and the corresponding regulatory liability.

 Residential volume. During the nine months ended September 30, 2020, there was a 7.2% increase in residential sales driven by the impacts from 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 nine months ended September 30, 2020, primarily as a result of lower costs to generate and purchase electricity in the market and lower customer demand.

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)		Nine Months Ended September 30,				Nine Months Ended September 30,
		2020		2019	% Change	2020	2019	% Change
Residential	$	61,328	$	67,659	(9.4)%	68,394	74,769	(8.5)%
Commercial/Industrial		32,961		40,833	(19.3)%	62,582	70,255	(10.9)%
Total retail		94,289		108,492	(13.1)%	130,976	145,024	(9.7)%
Gas transportation		4,179		3,756	11.3 %	55,002	54,129	1.6 %
Other revenues		100		299	(66.6)%	-	-	- %
Total	$	98,568	$	112,547	(12.4)%	185,978	199,153	(6.6)%
Heating degree days (normal 4,530)						4,315	4,777	(9.7)%
Average rate per therm of
retail customer	$	0.720	$	0.748	(3.7)%

Gas margin, a non-GAAP measure, increased $0.3 million during the nine months ended September 30, 2020, compared to the same period in 2019, due to the following:

(In millions)
Rate changes	$	1.4
Other		0.7
Revenue subject to refund, net		0.5
Decrease in volume		(2.3)
Total	$	0.3

 Rate changes. In December 2018, the PSCW authorized MGE to increase 2020 rates for retail gas customers by 1.46%.

 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 September 2019, MGE returned $1.0 million to gas customers through bill credits related to tax credits. The 2019 bill credit was deducted from revenues in previous years and held in a regulatory liability pending the refund to customers. As a result, the refund did not affect reported revenues in the current periods, although it did reduce cash and the corresponding regulatory liability.

 Volume. During the nine months ended September 30, 2020, retail gas deliveries decreased 9.7% compared to the same period in the prior year primarily related to less favorable weather conditions in the first quarter of 2020.

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Consolidated operations and maintenance expenses

During the nine months ended September 30, 2020, operations and maintenance expenses decreased $7.5 million, compared to the same period in the prior year. The following contributed to the net change:

(In millions)
Decreased administrative and general costs	$	(4.9)
Decreased electric production expenses		(2.4)
Decreased transmission costs		(1.1)
Decreased other costs		(0.6)
Increased gas distribution expenses		0.8
Increased electric distribution expenses		0.7
Total	$	(7.5)

 Decreased administrative and general costs are primarily related to a decrease in stock price and number of performance unit awards reducing the fair value associated with the performance unit awards, which is remeasured quarterly. See Footnote 7 of the Notes to Consolidated Financial Statements in this Report for additional information on performance unit awards. Other drivers include a reduction in nonessential spending driven by the COVID-19 pandemic and associated governmental regulations and management efforts to control spending, which includes training, travel expenses, and other discretionary spending.

 Decreased electric production expenses are primarily related to decreased operations and maintenance costs at the Elm Road Units, Columbia, and Forward Wind facility. Scheduled maintenance outages have been delayed or reduced in 2020. The Columbia outage was delayed from spring to late 2020.

 Decreased transmission costs are related to lower transmission rates in 2020. The 2020 transmission rates reflect adjustments from a lower return on equity, approved in the FERC complaints, for prior year rates. The lower transmission rate is reflected in customer revenue as revenue subject to refund.

Consolidated depreciation expense

Electric depreciation expense increased $1.3 million and gas depreciation expense increased $0.5 million during the nine months ended September 30, 2020, compared to the same period in the prior year. MGE placed the Saratoga Wind Farm in service in February 2019. Timing of the in-service date contributed to the increase in electric depreciation expense.

Electric and gas other income

Electric other income increased $3.0 million during the nine months ended September 30, 2020, compared to the same period in the prior year, primarily related to the AFUDC Equity from the construction of Two Creeks and Badger Hollow I and II. Gas other income increased $0.6 million during the nine months ended September 30, 2020, compared to the same period in the prior year.

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 nine months ended September 30, 2020 and 2019, net income at the nonregulated energy operations segment was $15.5 million and $15.2 million, respectively.

Transmission Investment Operations - MGE Energy

The transmission investment segment holds our interest in ATC and ATC Holdco, and its income reflects our equity in the earnings of those investments. ATC Holdco was formed in December 2016 to pursue transmission development opportunities 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 nine months ended September 30, 2020 and 2019, other income at the transmission investment segment was $7.8 million and $6.8 million, respectively. In May 2020, the FERC issued an opinion further refining

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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 2020, the effective electric tax rate decreased as a result of higher AFUDC equity from Badger Hollow I and II and Two Creeks, which is not included in taxable income, and a tax credit generated by the Saratoga Wind Farm. 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

The noncontrolling interest, net of tax, reflects the accounting required for MGE Energy's interest in MGE Power Elm Road (the Elm Road Units) and MGE Power West Campus (WCCF). MGE Energy owns 100% of MGE Power Elm Road and MGE Power West Campus; however, due to the contractual agreements for these projects with MGE, the entities are considered VIEs 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:

		Nine Months Ended
		September 30,
(In millions)		2020		2019
MGE Power Elm Road	$	11.4	$	11.3
MGE Power West Campus		5.4		5.4

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 nine months ended September 30, 2020, except as noted below. Further discussion of the contractual obligations and commercial commitments is included in Footnote 16 of the Notes to Consolidated Financial Statements and "Contractual Obligations and Commercial Commitments for MGE Energy and MGE" under "Management's Discussion and Analysis of Financial Condition and Results of Operations" in the 2019 Annual Report on Form 10-K.

Purchase Contracts – MGE Energy and MGE

See item c. within Footnote 8 of Notes to Consolidated Financial Statements in this Report for a description of commitments as of September 30, 2020, that MGE Energy and MGE have entered with respect to various commodity supply and transportation contracts to meet their obligations to deliver electricity and natural gas to customers.

Capital Expenditures – MGE Energy and MGE

Various contractual obligations contain future minimum commitments related to capital expenditures for certain construction projects, including the Badger Hollow II and other service area renewable solar projects. As of September 30, 2020, MGE has additional future minimum construction commitments of $67.2 million. In October 2020, MGE entered into additional future minimum commitments of $3.4 million.

Long-term Debt - MGE Energy and MGE

MGE borrowed $19.3 million from the issuance by the City of Madison, Wisconsin of Industrial Development Revenue Refunding Bonds in April 2020. The bonds bear interest at 2.05% per annum for a term ending April 30, 2023, at which point they will either be repriced and remarketed or redeemed and retired. The proceeds of these bonds were used to refund $19.3 million of 3.45% City of Madison, Wisconsin Industrial Development Revenue Refunding Bonds due October 2027, which had been issued to loan funds to MGE. See Footnote 6 of the Notes to Consolidated Financial Statements in this Report for further discussion of the bond issuance.

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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, including tax exempt debt, short-term debt financing, or 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 2019 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 nine months ended September 30, 2020 and 2019:

		MGE Energy				MGE
(In thousands)		2020		2019		2020		2019
Cash provided by (used for):
Operating activities	$	136,011	$	111,702	$	131,871	$	109,020
Investing activities		(144,360)		(134,531)		(140,567)		(128,866)
Financing activities		36,627		1,142		9,372		19,962

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 nine months ended September 30, 2020, was $136.0 million, an increase of $24.3 million when compared to the same period in the prior year.

MGE Energy's net income increased $6.4 million during the nine months ended September 30, 2020, when compared to the same period in the prior year.

MGE Energy's federal and state taxes paid decreased $6.2 million during the nine months ended September 30, 2020 when compared to the same period in the prior year. The decrease in taxes paid is primarily related to increased production and investment tax credits.

Working capital accounts (excluding prepaid and accrued taxes) resulted in $8.3 million in cash used for operating activities during the nine months ended September 30, 2020, primarily due to decreased other current liabilities, increased inventories, and increased accounts receivable, partially offset by decreased unbilled revenues and increased accounts payable.

Working capital accounts (excluding prepaid and accrued taxes) resulted in $14.2 million in cash used for operating activities during the nine months ended September 30, 2019, primarily due to decreased accounts payable, decreased other current liabilities, and increased inventories, partially offset by decreased unbilled revenues and decreased accounts receivable. The decrease in other current liabilities is attributable to a $3.2 million one-time tax bill credit to retail customers in 2019.

An increase in pension contribution resulted in an additional $0.9 million in cash used for operating activities for the nine months ended September 30, 2020, when compared to the same period in the prior year. Pension contributions reflect amounts required by law and discretionary amounts.

Hosted software asset expenditures during the nine months ended September 30, 2020 were $1.5 million. This

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amount represents a decrease of $3.1 million of cash used when compared to the prior year.

MGE

Cash provided by operating activities during the nine months ended September 30, 2020, was $131.9 million, an increase of $22.9 million when compared to the same period in the prior year.

Net income increased $6.4 million during the nine months ended September 30, 2020, when compared to the same period in the prior year.

MGE's federal and state taxes paid decreased $6.2 million during the nine months ended September 30, 2020 when compared to the same period in the prior year. The decrease in taxes paid is primarily related to increased production and investment tax credits.

Working capital accounts (excluding prepaid and accrued taxes) resulted in $6.1 million in cash used for operating activities during the nine months ended September 30, 2020, primarily due decreased other current liabilities, increased inventories, and increased accounts receivable, partially offset by decreased unbilled revenues and increased accounts payable.

Working capital accounts (excluding prepaid and accrued taxes) resulted in $11.7 million in cash used for operating activities during the nine months ended September 30, 2019, primarily due to decreased accounts payable, decreased other current liabilities, and increased gas inventories, partially offset by decreased unbilled revenues and decreased accounts receivable. The decrease in other current liabilities is attributable to a $3.2 million one-time tax bill credit to retail customers in 2019.

An increase in pension contribution resulted in an additional $0.9 million in cash used for operating activities for the nine months ended September 30, 2020, when compared to the same period in the prior year. Pension contributions reflect amounts required by law and discretionary amounts.

Hosted software asset expenditures during the nine months ended September 30, 2020 were $1.5 million. This amount represents a decrease of $3.1 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 increased $9.8 million during the nine months ended September 30, 2020, when compared to the same period in the prior year.

Capital expenditures during the nine months ended September 30, 2020, were $139.1 million. This amount represents an increase of $10.7 million from the expenditures made in the same period in the prior year. This increase primarily reflects expenditures on the construction of the Two Creeks and Badger Hollow I and II solar construction projects. 2020 capital expenditures increased $15.2 million over the prior year related to the Two Creeks and Badger Hollow I and II solar construction projects.

MGE

MGE's cash used for investing activities increased $11.7 million during the nine months ended September 30, 2020, when compared to the same period in the prior year.

Capital expenditures during the nine months ended September 30, 2020, were $139.1 million. This amount represents an increase of $10.7 million from the expenditures made in the same period in the prior year. This increase primarily reflects expenditures on the construction of the Two Creeks and Badger Hollow I and II solar construction projects. 2020 capital expenditures increased $15.2 million over the prior year related to the Two Creeks and Badger Hollow I and II solar construction projects.

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Cash Provided by Financing Activities

MGE Energy

Cash provided by MGE Energy's financing activities was $36.6 million during the nine months ended September 30, 2020, compared to $1.1 million for the same period in the prior year.

During the nine months ended September 30, 2020, dividends paid were $38.3 million compared to $35.6 million in the prior year. The increase reflected a higher dividend rate per share ($1.075 vs. $1.028) and a greater number of outstanding shares since the completion of the public offering of shares in May 2020.

During the nine months ended September 30, 2020, MGE Energy issued common stock for net proceeds of $79.6 million, which are being used for general corporate purposes including funding capital expenditures at MGE, such as Two Creeks, Badger Hollow I and II, Renewable Energy Rider solar projects, and other capital projects.

During the nine months ended September 30, 2020, MGE borrowed $19.3 million through the issuance of Industrial Development Revenue Refunding Bonds which was used to refinance $19.3 million of existing Industrial Development Revenue Refunding Bonds at a lower interest rate.

During the nine months ended September 30, 2019, net short-term debt borrowings were $41.5 million. There were no net short-term debt borrowings during the nine months ended September 30, 2020.

MGE

During the nine months ended September 30, 2020, cash provided by MGE's financing activities was $9.4 million, compared to $20.0 million for the same period in the prior year.

Capital contributions made by MGE Energy to MGE were $30.0 million during the nine months ended September 30, 2020. There were no capital contributions made by MGE Energy to MGE during the nine months ended September 30, 2019.

Distributions to parent from noncontrolling interest, which represent distributions from MGE Power Elm Road and MGE Power West Campus to MGE Energy, were $16.0 million during the nine months ended September 30, 2020, compared to $17.0 million in the prior year.

During the nine months ended September 30, 2020, MGE borrowed $19.3 million through the issuance of Industrial Development Revenue Refunding Bonds which was used to refinance $19.3 million of existing Industrial Development Revenue Refunding Bonds at a lower interest rate.

During the nine months ended September 30, 2019, net short-term debt borrowings were $41.5 million. There were no net short-term debt borrowings during the nine months ended September 30, 2020.

Capitalization Ratios

MGE Energy's capitalization ratios were as follows:

	MGE Energy
	September 30, 2020	December 31, 2019
Common shareholders' equity	64.3 %	61.2 %
Long-term debt(a)	35.7 %	38.8 %

(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 nine months ended September 30, 2020, capital expenditures for MGE Energy and MGE totaled $139.1 million, which included $136.7 million of utility capital expenditures. Included in the utility capital expenditures are costs

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associated with the Two Creeks and Badger Hollow I and II solar construction projects.

The COVID-19 pandemic and associated governmental regulations did not significantly delay or disrupt the Two Creeks solar project, which entered commercial operation in November 2020. Badger Hollow I solar project was expected to be completed in 2020 and is now expected to be completed in April 2021. Badger Hollow II solar project was expected to be completed in December 2021 and is now expected to be completed in December 2022. The O'Brien solar project was expected to be completed by January 1, 2021 and is now expected to be completed in mid-2021. We have delayed other utility capital expenditures initially planned for 2020. No significant increase in costs is expected due to the delays. We will continue to monitor other capital project timelines as presented in the 2020-2022 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 2019 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

The following discussion is limited to updates or developments in environmental matters that occurred during the nine months ended September 30, 2020. Further discussion of environmental matters is included in the 2019 Annual Report on Form 10-K and Footnote 8.a. of Notes to Consolidated Financial Statements in this Report.

Federal and State Environmental Compliance During the Current Pandemic

MGE was identified as an essential business under the State of Wisconsin's Safer at Home directive. It has been operating with full staff and has continued to prioritize its compliance with all applicable environmental regulations. MGE continues to follow local orders, as well as state department of health and Center for Disease Control guidance to operate in a manner to address potential spread of COVID-19 in order for the essential utility services to operate without interruptions. The EPA and the WDNR have both provided guidance for regulated entities if compliance with regulations becomes unfeasible due to the current outbreak of COVID-19. In late June 2020, the EPA announced that COVID-19 guidance sunset on August 31, 2020. MGE has developed contingencies for remaining in compliance during the pandemic and does not expect to rely on state or federal noncompliance relief. However, management cannot predict with certainty whether COVID-19 will disrupt these compliance activities. MGE will continue to build contingencies into compliance operations and communicate with regulators as needed during this unprecedented time.

Ozone National Ambient Air Quality Standards (NAAQS): Remand of EPA's Decision to Give a Partial Attainment to Milwaukee County

In May 2018, the EPA issued a final rule that designated the northeast portion of Milwaukee County as being in nonattainment with the Ozone NAAQS. All other portions of Milwaukee County were deemed in attainment 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 United States District Court of the District of Columbia remanded the partial Milwaukee County attainment designation back to EPA for further explanation. MGE is monitoring the outcome of EPA's remand analysis and how it may affect our Elm Road Units in Milwaukee County. At this time, MGE expects that the 2015 Ozone NAAQS will not have a material effect on its existing plants based on final designations.

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

The EPA's promulgated water effluent limitations guidelines 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. 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 is analyzing the rule's impact and expects to have cost estimates in early 2021. MGE will continue to work with the Elm Road operator to determine the expected costs and timing of compliance. MGE does not expect this rule to have a material effect on Columbia.

Other Matters

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 change to ATC's ROE could result in lower equity earnings and distributions from ATC in the future.

In January 2015, FERC accepted the transmission owners' request for a 50 basis-point incentive ROE adder for participating in MISO. The adder became effective January 6, 2015.

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 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 $2.4 million. As of December 31, 2019, 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 7.3% and 6.8% of our net income during the nine months ended September 30, 2020 and 2019, 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. The fuel rules require the PSCW and Wisconsin utilities to defer electric fuel-related costs that fall outside a symmetrical cost tolerance band. Any over or under recovery of the actual costs in a year outside of the symmetrical cost tolerance band is determined in the following year and is then reflected in future billings to electric retail customers. Under the electric fuel rules, MGE is required to defer the benefit of lower costs if the actual electric fuel costs fall outside the lower end of the range and 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. Currently, MGE is subject to a plus or minus 2% range. MGE assumes the risks and benefits of variances that are within the cost tolerance band. For 2020, $73.9 million in fuel and purchased power costs are being recovered in rates and are subject to this rule and included in MGE's fuel monitoring level rates. See Footnote 9.b. of the Notes to Consolidated Financial Statements in this Report for additional information.

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

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

MGE has financial gas and electric commodity contracts to hedge commodity price risk in the gas and electric utility segments. These contracts are primarily comprised of exchange-traded option and future contracts. MGE also holds financial transmission rights (FTRs), which are used to hedge the risk of increased transmission congestion charges. As of September 30, 2020, the fair value of exchange traded derivatives and FTRs exceeded their cost basis by $2.0 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 September 30, 2020, reflected a loss position of $16.0 million.

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Interest Rate Risk

Both MGE Energy and MGE may have short term borrowings at varying interest rates. MGE issues commercial paper for its short-term borrowings, while MGE Energy draws from its current credit facility to meet its short-term borrowing needs. 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 nine months ended September 30, 2020.

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 September 30, 2020, 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, 2019, 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.

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Item 4. Controls and Procedures.

During the third quarter of 2020, 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 September 30, 2020, 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 September 30, 2020, 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.

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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 1A. Risk Factors.

Except as set forth below, during the nine months ended September 30, 2020, there were no material changes to the Risk Factors disclosed in Item 1A – "Risk Factors" in the 2019 Annual Report on Form 10-K.

Pandemic virus or diseases, including COVID-19, could have a material adverse effect on our business, financial condition and liquidity.

The outbreak of the Coronavirus Disease 2019 (COVID-19), and the implemented and evolving steps being taken to address it, could adversely affect our service area, our business, our financial condition and our liquidity. Possible effects include:

 Reduced economic activity impacting the use of electricity and gas services

The continued spread of COVID-19 may have a material adverse impact on the local economy in our service area, which could impact our business, results of operations, and financial condition. Federal, state, and local governments have implemented mitigation measures, including quarantines or closures or reduced operations of businesses, governmental agencies and other institutions. Reduced economic activity can lead to lower consumption of electricity and gas that may not be offset by residential consumption.

 Delay in, and possible loss of, payments for utility service

During the first several months of the pandemic, the PSCW ordered Wisconsin utilities not to charge for late payments and not to disconnect customers for non-payment, which, in combination with the economic hardship caused by quarantine or stay-at-home orders, could result in losses as those payments are received late or not at all. Further, significant delays in those payments could affect our liquidity. Although the PSCW order was lifted in July 2020, we have undertaken to continue to waive late fees until December 31, 2020.

 Regulatory delays

We operate in a regulated business. Delays in regulatory proceedings or the issuance of required permits or variances, due to limited operations, hours or ability to convene necessary meetings, could delay required approvals or permits and affect the timing of activities. The failure to get timely variances could expose us to fines and penalties.

 Regulatory recovery of deferred costs

Certain incurred costs are being deferred as regulatory assets for future recovery and not being recognized in the statements of income, reflecting a March 24, 2020, PSCW Order. These costs can affect our cash, but are not presently recoverable in rates. If recovery of those regulatory assets in customer rates is not approved or is no longer deemed probable, these deferred costs would be recognized as a current period expense, which could be material in the period in which such recognition is required.

 Employee and supplier disruptions

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Employee absences and supply interruptions could affect our ability to operate and maintain our system.

 Volatility in the capital markets

Concerns about COVID-19 and its effects have caused, and may continue to cause, significant volatility in the capital markets. Market volatility as a result of COVID-19 may have a material adverse impact on the value of our employee benefits trusts investments, which could impact our costs for those benefits. The price of our common stock has been volatile and has decreased significantly in recent months. The COVID-19 pandemic and the significant uncertainties it has caused for the global economy, business activity, and business confidence have had, and is likely to continue to have, a significant effect on the market price of securities generally, including our securities.

The situation around COVID-19 remains fluid and the potential for a material impact on the results of operations, financial condition, and liquidity increases the longer the virus disrupts the local economy. Although we expect sales for future periods in 2020 to be negatively impacted by the COVID-19 pandemic, we cannot reasonably estimate with any degree of certainty the actual impact COVID-19 may have on our results of operations, financial position, and liquidity. The extent to which the COVID-19 pandemic may impact our business, operating results, financial condition, or liquidity will depend on future developments, including the duration of the outbreak, business and workforce disruptions, and the effectiveness of actions taken to contain and treat the disease.

Moreover, the effects of the COVID-19 pandemic may heighten many of the other risks described in the section entitled "Risk Factors" in the 2019 Annual Report on Form 10-K including, but not limited to, interest rate changes, rating agency actions, governmental actions and market volatility.

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

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

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)
July 1-31, 2020	8,392	$	65.21	-	-
August 1-31, 2020	9,312		66.22	-	-
September 1-30, 2020	42,953		65.07	-	-
Total	60,657	$	65.27	-	-

(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 2020, 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.

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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.

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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: November 5, 2020	/s/ Jeffrey M. Keebler
	Jeffrey M. Keebler Chairman, President and Chief Executive Officer (Duly Authorized Officer)
Date: November 5, 2020	/s/ Jared J. Bushek
	Jared J. Bushek Vice President - Finance, Chief Information Officer and Treasurer (Chief Financial Officer)
Date: November 5, 2020	/s/ Tamara J. Johnson
	Tamara J. Johnson Vice President - Accounting and Controller (Chief Accounting Officer)

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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: November 5, 2020	/s/ Jeffrey M. Keebler
	Jeffrey M. Keebler Chairman, President and Chief Executive Officer (Duly Authorized Officer)
Date: November 5, 2020	/s/ Jared J. Bushek
	Jared J. Bushek Vice President - Finance, Chief Information Officer and Treasurer (Chief Financial Officer)
Date: November 5, 2020	/s/ Tamara J. Johnson
	Tamara J. Johnson Vice President - Accounting and Controller (Chief Accounting Officer)

61

EX-31

 

EXHIBIT 31.1

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

I, Jeffrey M. Keebler, certify that:

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

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

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

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

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

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

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

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

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

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

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

/s/ Jeffrey M. Keebler

Jeffrey M. Keebler

Chairman, President and Chief Executive Officer

Date: November 5, 2020

1

EX-31

 

EXHIBIT 31.2

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

I, Jared J. Bushek, certify that:

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

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

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

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

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

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

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

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

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

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

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

/s/ Jared J. Bushek

Jared J. Bushek

Vice President - Finance, Chief Information Officer and Treasurer

Date: November 5, 2020

1

EX-31

 

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: November 5, 2020

1

EX-31

 

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: November 5, 2020

1

EX-32

 

EXHIBIT 32.1

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

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

In connection with the quarterly report on Form 10-Q of MGE Energy, Inc. (the "Company"), for the period ended September 30, 2020, 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: November 5, 2020

1

EX-32

 

EXHIBIT 32.2

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

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

In connection with the quarterly report on Form 10-Q of MGE Energy, Inc. (the "Company"), for the period ended September 30, 2020, 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: November 5, 2020

1

EX-32

 

EXHIBIT 32.3

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

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

In connection with the quarterly report on Form 10-Q of Madison Gas and Electric Company (the "Company"), for the period ended September 30, 2020, 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: November 5, 2020

1

EX-32

 

EXHIBIT 32.4

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

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

In connection with the quarterly report on Form 10-Q of Madison Gas and Electric Company (the "Company"), for the period ended September 30, 2020, 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: November 5, 2020

1

XML

Document and Entity Information - shares	9 Months Ended
	Sep. 30, 2020	Oct. 31, 2020
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	Sep. 30, 2020
Amendment Flag	false
Trading Symbol	MGEE
Document Fiscal Year Focus	2020
Document Fiscal Period Focus	Q3
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	3 Months Ended		9 Months Ended
	Sep. 30, 2020	Sep. 30, 2019	Sep. 30, 2020	Sep. 30, 2019
Operating Revenues:
Electric revenues	$ 116,568,000	$ 120,821,000	$ 303,556,000	$ 315,367,000
Gas revenue	18,643,000	17,377,000	98,568,000	112,547,000
Total Operating Revenues	135,211,000	138,198,000	402,124,000	427,914,000
Operating Expenses:
Fuel for electric generation	12,945,000	15,901,000	31,343,000	40,221,000
Purchased power	10,708,000	9,126,000	32,050,000	31,013,000
Cost of gas sold	3,812,000	3,092,000	40,950,000	55,220,000
Other operations and maintenance	45,819,000	48,070,000	136,412,000	143,979,000
Depreciation and amortization	18,592,000	18,193,000	55,193,000	53,423,000
Other general taxes	5,010,000	5,078,000	14,892,000	15,026,000
Total Operating Expenses	96,886,000	99,460,000	310,840,000	338,882,000
Operating Income	38,325,000	38,738,000	91,284,000	89,032,000
Other income, net	6,534,000	5,204,000	19,131,000	15,074,000
Interest expense, net	(5,765,000)	(5,831,000)	(17,740,000)	(17,227,000)
Income before income taxes	39,094,000	38,111,000	92,675,000	86,879,000
Income tax provision	(7,300,000)	(7,454,000)	(16,053,000)	(16,667,000)
Net Income Including Noncontrolling Interest	31,794,000	30,657,000	76,622,000	70,212,000
Net Income	$ 31,794,000	$ 30,657,000	$ 76,622,000	$ 70,212,000
Earnings Per Share of Common Stock (basic and diluted)	$ 0.88	$ 0.88	$ 2.16	$ 2.03
Dividends per share of common stock	$ 0.370	$ 0.353	$ 1.075	$ 1.028
Weighted Average Shares Outstanding (basic and diluted)	36,163	34,668	35,427	34,668
MGE [Member]
Operating Revenues:
Electric revenues	$ 116,568,000	$ 120,821,000	$ 303,556,000	$ 315,367,000
Gas revenue	18,643,000	17,377,000	98,568,000	112,547,000
Total Operating Revenues	135,211,000	138,198,000	402,124,000	427,914,000
Operating Expenses:
Fuel for electric generation	12,945,000	15,901,000	31,343,000	40,221,000
Purchased power	10,708,000	9,126,000	32,050,000	31,013,000
Cost of gas sold	3,812,000	3,092,000	40,950,000	55,220,000
Other operations and maintenance	45,591,000	47,947,000	135,634,000	143,282,000
Depreciation and amortization	18,592,000	18,193,000	55,193,000	53,423,000
Other general taxes	5,010,000	5,078,000	14,892,000	15,026,000
Total Operating Expenses	96,658,000	99,337,000	310,062,000	338,185,000
Operating Income	38,553,000	38,861,000	92,062,000	89,729,000
Other income, net	4,093,000	2,672,000	11,005,000	7,837,000
Interest expense, net	(5,802,000)	(6,095,000)	(17,848,000)	(18,223,000)
Income before income taxes	36,844,000	35,438,000	85,219,000	79,343,000
Income tax provision	(6,611,000)	(6,687,000)	(14,028,000)	(14,579,000)
Net Income Including Noncontrolling Interest	30,233,000	28,751,000	71,191,000	64,764,000
Less Net Income Attributable to Noncontrolling Interest, net of tax	(5,493,000)	(5,614,000)	(16,754,000)	(16,725,000)
Net Income	$ 24,740,000	$ 23,137,000	$ 54,437,000	$ 48,039,000

XML

Consolidated Statements of Cash Flows (Unaudited) - USD ($) $ in Thousands	9 Months Ended
	Sep. 30, 2020	Sep. 30, 2019
Operating Activities:
Net Income	$ 76,622	$ 70,212
Items not affecting cash:
Depreciation and amortization	55,193	53,423
Deferred income taxes	8,464	4,864
Provision for doubtful receivables	1,078	978
Employee benefit plan credit	(2,813)	(2,866)
Equity earnings in investments	(7,780)	(6,879)
Other items	382	692
Changes in working capital items:
Decrease in current assets	5,494	14,307
Decrease in current liabilities	(8,808)	(24,088)
Dividends from investments	6,929	5,526
Cash contributions to pension and other postretirement plans	(4,576)	(3,707)
Other noncurrent items, net	5,826	(760)
Cash Provided by Operating Activities	136,011	111,702
Investing Activities:
Capital expenditures	(139,055)	(128,389)
Capital contributions to investments	(4,007)	(5,894)
Other	(1,298)	(248)
Cash Used for Investing Activities	(144,360)	(134,531)
Financing Activities:
Issuance of common stock, net	79,635	0
Cash dividends paid on common stock	(38,349)	(35,622)
Repayments of long-term debt	(22,784)	(3,405)
Issuance of long-term debt	19,300	0
Net proceeds from short-term debt	0	41,500
Other	(1,175)	(1,331)
Cash Provided by Financing Activities	36,627	1,142
Change in cash, cash equivalents, and restricted cash	28,278	(21,687)
Cash, cash equivalents, and restricted cash at beginning of period	25,814	84,929
Cash, cash equivalents, and restricted cash at end of period	54,092	63,242
Significant noncash investing activities:
Accrued capital expenditures	23,594	16,819
MGE [Member]
Operating Activities:
Net Income	71,191	64,764
Items not affecting cash:
Depreciation and amortization	55,193	53,423
Deferred income taxes	7,334	3,653
Provision for doubtful receivables	1,078	978
Employee benefit plan credit	(2,813)	(2,866)
Other items	1,234	1,653
Changes in working capital items:
Decrease in current assets	3,352	14,236
Decrease in current liabilities	(5,212)	(22,234)
Cash contributions to pension and other postretirement plans	(4,576)	(3,707)
Other noncurrent items, net	5,090	(880)
Cash Provided by Operating Activities	131,871	109,020
Investing Activities:
Capital expenditures	(139,055)	(128,389)
Other	(1,512)	(477)
Cash Used for Investing Activities	(140,567)	(128,866)
Financing Activities:
Distributions to parent from noncontrolling interest	(16,000)	(17,000)
Capital contributions from parent	30,000	0
Repayments of long-term debt	(22,784)	(3,405)
Issuance of long-term debt	19,300	0
Net proceeds from short-term debt	0	41,500
Other	(1,144)	(1,133)
Cash Provided by Financing Activities	9,372	19,962
Change in cash, cash equivalents, and restricted cash	676	116
Cash, cash equivalents, and restricted cash at beginning of period	5,529	6,670
Cash, cash equivalents, and restricted cash at end of period	6,205	6,786
Significant noncash investing activities:
Accrued capital expenditures	$ 23,594	$ 16,819

XML

Consolidated Balance Sheets (Unaudited) - USD ($) $ in Thousands	Sep. 30, 2020	Dec. 31, 2019
Current Assets:
Cash and cash equivalents	$ 53,058	$ 23,481
Accounts receivable, less reserves	39,177	40,482
Other accounts receivables, less reserves	9,828	7,940
Unbilled revenues	20,029	25,899
Materials and supplies, at average cost	33,608	26,287
Fuel for electric generation, at average cost	5,793	8,358
Stored natural gas, at average cost	10,022	10,637
Prepaid taxes	11,759	16,892
Regulatory assets - current	7,845	11,432
Other current assets	8,814	10,233
Total Current Assets	199,933	181,641
Other long-term receivables	1,662	1,811
Regulatory assets	126,929	134,314
Pension benefit asset	21,848	13,630
Other deferred assets and other	18,087	19,093
Property, Plant, and Equipment:
Property, plant, and equipment, net	1,536,567	1,530,199
Construction work in progress	197,594	112,484
Total Property, Plant, and Equipment	1,734,161	1,642,683
Investments	93,106	88,492
Total Assets	2,195,726	2,081,664
Current Liabilities:
Long-term debt due within one year	19,742	19,659
Accounts payable	56,054	55,161
Accrued interest and taxes	5,789	7,244
Accrued payroll related items	11,625	12,752
Regulatory liabilities - current	3,585	9,228
Derivative liabilities	9,640	10,100
Other current liabilities	9,045	14,676
Total Current Liabilities	115,480	128,820
Other Credits:
Deferred income taxes	253,411	243,302
Investment tax credit - deferred	2,692	763
Regulatory liabilities	171,637	164,965
Accrued pension and other postretirement benefits	68,632	68,665
Derivative liabilities	6,340	15,340
Finance lease liabilities	17,795	17,379
Other deferred liabilities and other	65,772	63,013
Total Other Credits	586,279	573,427
Capitalization:
Common shareholders equity	973,584	855,676
Long-term debt	520,383	523,741
Total Capitalization	1,493,967	1,379,417
Commitments and contingencies (see Footnote 8)
Total Liabilities and Capitalization	2,195,726	2,081,664
MGE [Member]
Current Assets:
Cash and cash equivalents	5,171	3,196
Accounts receivable, less reserves	39,177	40,482
Affiliate receivables	530	530
Other accounts receivables, less reserves	9,824	7,936
Unbilled revenues	20,029	25,899
Materials and supplies, at average cost	33,608	26,287
Fuel for electric generation, at average cost	5,793	8,358
Stored natural gas, at average cost	10,022	10,637
Prepaid taxes	12,373	15,463
Regulatory assets - current	7,845	11,432
Other current assets	8,746	10,065
Total Current Assets	153,118	160,285
Affiliate receivable long-term	2,251	2,648
Regulatory assets	126,929	134,314
Pension benefit asset	21,848	13,630
Other deferred assets and other	18,509	19,680
Property, Plant, and Equipment:
Property, plant, and equipment, net	1,536,595	1,530,227
Construction work in progress	197,594	112,484
Total Property, Plant, and Equipment	1,734,189	1,642,711
Investments	461	209
Total Assets	2,057,305	1,973,477
Current Liabilities:
Long-term debt due within one year	19,742	19,659
Accounts payable	56,035	54,845
Accrued interest and taxes	8,602	8,754
Accrued payroll related items	11,625	12,752
Regulatory liabilities - current	3,585	9,228
Derivative liabilities	9,640	10,100
Other current liabilities	9,048	12,683
Total Current Liabilities	118,277	128,021
Other Credits:
Deferred income taxes	223,021	214,041
Investment tax credit - deferred	2,692	763
Regulatory liabilities	171,637	164,965
Accrued pension and other postretirement benefits	68,632	68,665
Derivative liabilities	6,340	15,340
Finance lease liabilities	17,795	17,379
Other deferred liabilities and other	65,748	62,973
Total Other Credits	555,865	544,126
Capitalization:
Common shareholders equity	721,723	637,286
Noncontrolling interest	141,057	140,303
Total Equity	862,780	777,589
Long-term debt	520,383	523,741
Total Capitalization	1,383,163	1,301,330
Commitments and contingencies (see Footnote 8)
Total Liabilities and Capitalization	$ 2,057,305	$ 1,973,477

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Consolidated Balance Sheets (Unaudited) (Parentheticals) - USD ($) $ in Thousands	Sep. 30, 2020	Dec. 31, 2019
Receivables, Net
Reserve for uncollectible accounts receivable	$ 4,636	$ 2,820
Reserve for uncollectible other accounts receivable	1,248	438
MGE [Member]
Receivables, Net
Reserve for uncollectible accounts receivable	4,636	2,820
Reserve for uncollectible other accounts receivable	$ 1,248	$ 438

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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, 2018		34,668
Beginning balance, value at Dec. 31, 2018	$ 816,644	$ 34,668	$ 316,268	$ 465,708	$ 0
Increase (Decrease) In Stockholders' Equity [Roll Forward]
Net Income	70,212			70,212
Common stock dividends declared	(35,622)			(35,622)
Issuance of common stock, net	0
Ending balance, shares at Sep. 30, 2019		34,668
Ending balance, value at Sep. 30, 2019	851,234	$ 34,668	316,268	500,298	0
Beginning balance, shares at Jun. 30, 2019		34,668
Beginning balance, value at Jun. 30, 2019	832,797	$ 34,668	316,268	481,861	0
Increase (Decrease) In Stockholders' Equity [Roll Forward]
Net Income	30,657			30,657
Common stock dividends declared	(12,220)			(12,220)
Ending balance, shares at Sep. 30, 2019		34,668
Ending balance, value at Sep. 30, 2019	851,234	$ 34,668	316,268	500,298	0
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	76,622			76,622
Common stock dividends declared	$ (38,349)			(38,349)
Common stock issued during period	1,500	1,495
Issuance of common stock, net	$ 79,635	$ 1,495	78,140
Ending balance, shares at Sep. 30, 2020		36,163
Ending balance, value at Sep. 30, 2020	973,584	$ 36,163	394,408	543,013	0
Beginning balance, shares at Jun. 30, 2020		36,163
Beginning balance, value at Jun. 30, 2020	955,171	$ 36,163	394,408	524,600	0
Increase (Decrease) In Stockholders' Equity [Roll Forward]
Net Income	31,794			31,794
Common stock dividends declared	(13,381)			(13,381)
Ending balance, shares at Sep. 30, 2020		36,163
Ending balance, value at Sep. 30, 2020	$ 973,584	$ 36,163	$ 394,408	$ 543,013	$ 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] 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, 2018			34,668	17,348
Beginning balance, value at Dec. 31, 2018		$ 689,810		$ 17,348	$ 192,417	$ 338,591	$ 0	$ 141,454
Increase (Decrease) In Stockholders' Equity [Roll Forward]
Net Income	$ 70,212	64,764				48,039		16,725
Capital contributions from parent		0
Distributions to parent from noncontrolling interest		(17,000)						(17,000)
Ending balance, shares at Sep. 30, 2019			34,668	17,348
Ending balance, value at Sep. 30, 2019		737,574		$ 17,348	192,417	386,630	0	141,179
Beginning balance, shares at Jun. 30, 2019			34,668	17,348
Beginning balance, value at Jun. 30, 2019		714,323		$ 17,348	192,417	363,493	0	141,065
Increase (Decrease) In Stockholders' Equity [Roll Forward]
Net Income	30,657	28,751				23,137		5,614
Distributions to parent from noncontrolling interest		(5,500)						(5,500)
Ending balance, shares at Sep. 30, 2019			34,668	17,348
Ending balance, value at Sep. 30, 2019		737,574		$ 17,348	192,417	386,630	0	141,179
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	76,622	71,191				54,437		16,754
Capital contributions from parent		30,000			30,000
Distributions to parent from noncontrolling interest		(16,000)						(16,000)
Ending balance, shares at Sep. 30, 2020			36,163	17,348
Ending balance, value at Sep. 30, 2020		862,780		$ 17,348	252,917	451,458	0	141,057
Beginning balance, shares at Jun. 30, 2020			36,163	17,348
Beginning balance, value at Jun. 30, 2020		840,047		$ 17,348	252,917	426,718	0	143,064
Increase (Decrease) In Stockholders' Equity [Roll Forward]
Net Income	$ 31,794	30,233				24,740		5,493
Distributions to parent from noncontrolling interest		(7,500)						(7,500)
Ending balance, shares at Sep. 30, 2020			36,163	17,348
Ending balance, value at Sep. 30, 2020		$ 862,780		$ 17,348	$ 252,917	$ 451,458	$ 0	$ 141,057

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Consolidated Statements of Common Equity (Unaudited) (Parentheticals) - $ / shares	3 Months Ended		9 Months Ended
	Sep. 30, 2020	Sep. 30, 2019	Sep. 30, 2020	Sep. 30, 2019
Consolidated Statements of Common Equity
Dividends per share of common stock	$ 0.370	$ 0.353	$ 1.075	$ 1.028

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Summary of Significant Accounting Principles

9 Months Ended

Sep. 30, 2020

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 2019 Annual Report on Form 10-K (the 2019 Annual Report on Form 10-K).

The accompanying consolidated financial statements as of September 30, 2020, and during the three and nine 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 2019 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 54 through 107 of the 2019 Annual Report on Form 10-K.

b.COVID-19.

With the global outbreak of the Coronavirus Disease 2019 (COVID-19) and the declaration of a pandemic by the World Health Organization on March 11, 2020, U.S. governmental authorities have deemed electric and gas utilities to be critical infrastructure. MGE Energy therefore has an obligation to keep operating and maintaining our critical electric and gas infrastructure. Since then, MGE Energy has been subject to, and is following, local, state and federal public health and safety regulations and guidance to control the pandemic.

MGE Energy's and MGE's consolidated financial statements reflect estimates and assumptions made by management that affect the reported amounts of assets and liabilities at the date of the consolidated financial statements and reported amounts of revenue and expenses during the reporting periods presented. MGE Energy and MGE considered the impact of COVID-19 developments on the assumptions and estimates used in the preparation of these financial statements.

c.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
		September 30,		December 31,		September 30,		December 31,
(In thousands)		2020		2019		2020		2019
Cash and cash equivalents	$	53,058	$	23,481	$	5,171	$	3,196
Restricted cash		484		619		484		619
Receivable - margin account		550		1,714		550		1,714
Cash, cash equivalents, and restricted cash	$	54,092	$	25,814	$	6,205	$	5,529

Cash Equivalents

MGE Energy and MGE consider 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.

d.Trade Receivables, Allowance for Credit Losses, and Concentration Risk.

Trade accounts receivable are recorded at the invoiced amount and do not bear interest. A 1% late payment charge is normally recorded on all receivables unpaid after the due date. In late March 2020, the 1% late payment charge was suspended in response to the PSCW's COVID-19 order. The order also suspended disconnection or refusal of services to any customer, with limited exceptions. The PSCW order was lifted on July 25, 2020; however, as permitted by regulatory action, MGE notified the PSCW of its election to continue to waive late fees until December 31, 2020. See Footnote 9.c. for further information.

The allowance for credit losses associated with these receivables represents MGE's best estimate of the amount of probable credit losses for existing accounts receivable. MGE manages concentration of credit risk through its credit and collection policies, which are consistent with state regulatory requirements. The allowance for credit losses is estimated based on historical write-off experience, regional economic data, review of the accounts receivable aging, and reasonable and supportable forecasts that affect the collectability of the reported amount. MGE has considered the effects of COVID-19 developments and associated governmental regulations, including suspension of disconnections for non-payment, in its estimate of allowance for credit losses by applying data from historical recessions and other significant economic downturns.

As of September 30, 2020, MGE had a reserve balance of $5.9 million against accounts receivable. During the three and nine months ended September 30, 2020, MGE recorded $0.3 million and $0.9 million in write-offs, respectively. During the three and nine months ended September 30, 2020, MGE recorded $1.1 million and $3.5 million of additional reserves, respectively, which include estimated impacts of COVID-19. The PSCW issued a deferral accounting order for deferral of incremental COVID-19-related costs. Recovery of these costs are expected to be addressed in future rate proceedings. As of September 30, 2020, MGE had deferred $2.5 million of incremental COVID-19-related costs as a regulatory asset. See Footnote 9.c. for further information.

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Adoption of Accounting Principles and Recently Issued Accounting Pronouncements

9 Months Ended

Sep. 30, 2020

New Accounting Pronouncements and Changes in Accounting Principles [Abstract]

New Accounting Pronouncements

New Accounting Standards - MGE Energy and MGE.

Recently Adopted

Credit Losses.

In June 2016, the Financial Accounting Standards Board issued authoritative guidance within the codification's Credit Losses topic, which introduced a new model for recognizing credit losses on financial instruments based on an estimate of current expected credit losses. The authoritative guidance became effective January 1, 2020. MGE adopted the standard on the effective date. The adoption of this standard did not have a material impact on MGE Energy's and MGE's financial statements. New disclosures are required under the new standard. See Footnote 1.d. for allowance for credit loss disclosures.

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Investment in ATC and ATC Holdco

9 Months Ended

Sep. 30, 2020

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				Nine Months Ended
		September 30,				September 30,
(In thousands)		2020		2019		2020		2019
Equity earnings from investment in ATC	$	2,319	$	2,364	$	7,724	$	6,879
Dividends from investments		2,349		1,781		6,620		5,526
Capital contributions to ATC		359		888		892		2,131

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.

In October 2020, MGE Transco made a $0.4 million capital contribution to ATC.

ATC's summarized financial data is as follows:

		Three Months Ended				Nine Months Ended
		September 30,				September 30,
(In thousands)		2020		2019		2020		2019
Operating revenues	$	187,833	$	184,833	$	577,705	$	544,760
Operating expenses		(92,975)		(94,713)		(285,697)		(278,673)
Other income, net		643		484		1,924		1,031
Interest expense, net		(28,801)		(29,165)		(83,947)		(87,121)
Earnings before members' income taxes	$	66,700	$	61,439	$	209,985	$	179,997

MGE receives transmission and other related services from ATC. During the three and nine months ended September 30, 2020, MGE recorded $7.7 million and $23.0 million, respectively, for transmission services received compared to $7.6 million and $22.8 million for the comparable periods in 2019. MGE also provides a variety of operational, maintenance, and project management services for ATC, which are reimbursed by ATC. As of September 30, 2020, and December 31, 2019, MGE had a receivable due from ATC of $2.7 million and $1.6 million, respectively. The receivable includes expenditures to fund transmission infrastructure upgrades at Badger Hollow I and II and Two Creeks. MGE will be reimbursed for these costs after the newgeneration assets have been placed into service.

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Taxes

9 Months Ended

Sep. 30, 2020

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 September 30,	2020		2019		2020		2019
Statutory federal income tax rate	21.0	%	21.0	%	21.0	%	21.0	%
State income taxes, net of federal benefit	6.3		6.3		6.2		6.2
Amortized investment tax credits	(0.1)		(0.1)		(0.1)		(0.1)
Credit for electricity from wind energy	(5.0)		(4.8)		(5.4)		(5.2)
AFUDC equity, net	(1.1)		(0.4)		(1.2)		(0.4)
Amortization of utility excess deferred tax - tax reform(a)	(2.0)		(1.9)		(2.2)		(2.1)
Other, net, individually insignificant	(0.4)		(0.5)		(0.4)		(0.5)
Effective income tax rate	18.7	%	19.6	%	17.9	%	18.9	%
	MGE Energy				MGE
Nine Months Ended September 30,	2020		2019		2020		2019
Statutory federal income tax rate	21.0	%	21.0	%	21.0	%	21.0	%
State income taxes, net of federal benefit	6.3		6.3		6.2		6.2
Amortized investment tax credits	(0.1)		(0.1)		(0.1)		(0.1)
Credit for electricity from wind energy	(6.1)		(5.6)		(6.6)		(6.1)
AFUDC equity, net	(1.3)		(0.3)		(1.4)		(0.3)
Amortization of utility excess deferred tax - tax reform(a)	(2.4)		(2.2)		(2.6)		(2.4)
Other, net, individually insignificant	(0.1)		0.1		-		0.1
Effective income tax rate	17.3	%	19.2	%	16.5	%	18.4	%

(a)Included are impacts of the Tax Cuts and Jobs Act for the regulated utility for excess deferred taxes recognized using a normalization method of accounting. During the three and nine months ended September 30, 2020, MGE recognized $0.7 million and $2.0 million, respectively, compared to $0.6 million and $1.7 million for the comparable periods in 2019. The amount and timing of the cash impacts will depend on the period over which certain income tax benefits are provided to customers, as determined by the PSCW.

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Pension and Other Postretirement Plans

9 Months Ended

Sep. 30, 2020

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				Nine Months Ended
		September 30,				September 30,
(In thousands)		2020		2019		2020		2019
Pension Benefits
Components of net periodic benefit cost:
Service cost	$	1,324	$	1,040	$	3,972	$	3,402
Interest cost		3,052		3,170		9,157		10,364
Expected return on assets		(6,807)		(5,054)		(20,422)		(16,523)
Amortization of:
Prior service credit		(31)		(26)		(93)		(85)
Actuarial loss		1,339		1,637		4,018		5,351
Net periodic benefit (credit) cost	$	(1,123)	$	767	$	(3,368)	$	2,509
Postretirement Benefits
Components of net periodic benefit cost:
Service cost	$	316	$	276	$	948	$	829
Interest cost		570		721		1,709		2,164
Expected return on assets		(789)		(677)		(2,366)		(2,034)
Amortization of:
Transition obligation		1		1		2		2
Prior service credit		(667)		(664)		(2,001)		(1,994)
Actuarial loss		55		100		165		300
Net periodic benefit (credit) cost	$	(514)	$	(243)	$	(1,543)	$	(733)

As a result of lower investment returns in the fourth quarter of 2018, pension and postretirement benefit costs increased in 2019. In August 2019, the PSCW approved MGE's request to defer the difference between estimated pension and other postretirement costs included in the 2019 and 2020 rate settlement and actual expense incurred. MGE expects that the deferred cost for employee benefit plans will be factored into future rate proceedings. During 2019, MGE deferred approximately $6.2 million of pension and other post-retirement costs. MGE expects actual costs will be lower than the amount included in the 2020 rate settlement, which will reduce the regulatory asset that MGE expects to be factored into future rate proceedings. During the three and nine months ended September 30, 2020, MGE collected approximately $0.2 million and $0.7 million, respectively, of pension and other postretirement costs, which reduced the amount deferred in 2019. During the three and nine months ended September 30, 2019, MGE deferred approximately $1.3 million and $4.6 million, respectively, of pension and postretirement costs. The impact of this deferral has not been reflected in the table above.

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Equity and Financing Arrangements

9 Months Ended

Sep. 30, 2020

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 and nine months ended September 30, 2020 and 2019, MGE Energy issued no new shares of common stock under the Stock Plan.

In May 2020, MGE Energy issued 1.5 million shares of its common stock in an underwritten offering. MGE Energy received proceeds, net of underwriter fees and issuance costs, of $79.6 million from the issuance and sale of those shares. The net proceeds are being used for general corporate purposes, including funding capital expenditures being made by MGE.

b.Dilutive Shares Calculation - MGE Energy.

MGE Energy has no dilutive securities issued.

c.Long-term Debt - MGE Energy and MGE.

In April 2020, MGE borrowed $19.3 million from the City of Madison, Wisconsin's issuance of Industrial Development Revenue Refunding Bonds (Madison Gas and Electric Company Project), Series 2020A. The bonds carry an interest rate of 2.05% per annum with interest payable semi-annually on April 1 and October 1 of each year, which commenced on October 1, 2020. The bonds require their holder to tender them on April 30, 2023, at which time the bonds will either be repriced and remarketed or redeemed and retired. MGE used the proceeds to redeem at par $19.3 million of existing Industrial Development Revenue Refunding Bonds (Madison Gas and Electric Company Project), Series 2002B due October 1, 2027.

The funds for the loan were provided by a purchaser of the bonds pursuant to a Bond Purchase and Covenants Agreement between that purchaser and MGE. That Agreement requires MGE to maintain a ratio of consolidated indebtedness to consolidated total capitalization not to exceed a maximum of 65%. Both consolidated indebtedness and consolidated total capitalization are to be determined in accordance with GAAP, except that amounts included within MGE's indebtedness and capitalization from "variable interest entities" are excluded. A change of control constitutes a default under the Bond Purchase Agreement. Change in control events are defined as (i) a failure by MGE Energy to hold 100% of the outstanding voting equity interest in MGE or (ii) the acquisition of beneficial ownership of 30% or more of the outstanding voting stock of MGE Energy by one person or two or more persons acting in concert. The ratio, and its calculation, and the change of control provision reflect the provisions contained in MGE’s credit agreements.

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Share-Based Compensation

9 Months Ended

Sep. 30, 2020

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

Share-Based Compensation

Share-Based Compensation - MGE Energy and MGE.

a.

2013 Director Incentive Plan and 2006 Performance Unit Plan

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

In 2020, 5,048 units were granted under the 2013 Plan and are subject to a three-year graded vesting schedule. No units were granted under the 2006 Plan in 2020 in view of the adoption of the 2020 Performance Unit Plan described below. On the grant date, the cost of the director or employee services received in exchange for a performance unit award is measured based on the current market value of MGE Energy common stock. The fair value of the awards is remeasured quarterly, including as of September 30, 2020, as required by applicable accounting standards. Changes in quarterly fair value as well as the original grant are recognized as compensation cost. Since this amount is remeasured throughout the vesting period, the compensation cost is subject to variability.

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

During the three months ended September 30, 2020 and 2019, MGE recorded $0.1 million and $0.9 million, respectively, in compensation expense as a result of awards under the 2013 Plan and 2006 Plan. During the nine months ended September 30, 2020 and 2019, MGE recorded $0.3 million in compensation benefit and $2.8 million in compensation expense, respectively, as a result of awards under the 2013 Plan and 2006 Plan. In January 2020, cash payments of $2.0 million were distributed relating to awards that were granted in a prior year under the plans. No forfeitures of units occurred during the three and nine months ended September 30, 2020 and 2019. As of September 30, 2020, $3.4 million of outstanding awards are vested. Of this amount, no cash settlements have occurred as cash

payments are only made at the end of the period covered by the awards.

b.

2020 Performance Unit Plan

The 2020 Performance Unit Plan (the 2020 Plan) was adopted in February 2020 for eligible employees. Plan participants may receive awards of performance units, restricted units, or both. Performance units entitle the holder to receive a cash payment equal to the value of a designated number of shares of MGE Energy's common stock, plus dividend-equivalent payments thereon, based upon achievement of specified performance goals during a performance period set by the Compensation Committee of MGE Energy's Board of Directors. Restricted units entitle the holder to receive a cash payment equal to the value of a designated number of shares of MGE Energy's common stock, plus dividend-equivalent payments thereon, at the end of a defined time period. Awards are subject to vesting provisions providing for 100% vesting at the end of the performance period, in the case of performance units, and at the end of the defined time period in the case of restricted units. The performance units and restricted units will be paid out in cash and are accounted for as a liability award. No shares of common stock will be issued in connection with the 2020 Plan.

In April 2020, 9,822 performance units and 9,822 restricted units were granted under the 2020 Plan. The 2020 performance units contain market and performance conditions. The market condition is based on total shareowner return relative to an investor-owned utility peer group. The performance condition is based on achievement of targets specified in the award agreement (such as an earnings growth target). The fair value of each performance unit is based on the fair value of the underlying common stock on the grant date and the probability of satisfying the market and performance conditions contained in the award agreement during the three-year performance period. The actual payments upon vesting depends upon actual performance and may range from zero to 200% of the granted number of performance units. The 2020 restricted units will vest based on a three-year cliff vesting schedule.

During the three and nine months ended September 30, 2020, MGE recorded less than $0.1 million and $0.6 million, respectively, in compensation expense as a result of awards under the 2020 Plan.

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Commitments and Contingencies

9 Months Ended

Sep. 30, 2020

Commitments and Contingencies Disclosure [Abstract]

Commitments and Contingencies

Commitments and Contingencies.

a.Environmental - MGE Energy and MGE.

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 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. 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 is analyzing the rule's impact and expects to have cost estimates in early 2021. MGE expects to continue to work with the Elm Road operator to determine the expected costs and timing of compliance. MGE does not expect this rule to have a material effect on Columbia.

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

(trapping aquatic life on screens). MGE must conduct studies of its Blount plant by the end of 2021 to help regulators determine BAT. Columbia's operator must also conduct studies to help determine BAT. Future BAT requirements at Blount and Columbia will be established by the WDNR based on the results of these intake studies and will be specified in the next facility discharge permits expected to be issued in 2023 or later. 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 2019, the EPA published a final rule creating the Affordable Clean Energy (ACE) rule to reduce greenhouse gas emissions from existing coal-fired EGUs. The ACE rule directs states to submit plans to the EPA for approval that implement standards of performance (called Best System of Emissions Reductions, or BSER) for individual coal-fired EGUs over 25 MW. The ACE rule defines BSER as on-site "inside the fenceline," heat-rate efficiency improvements. Under the ACE rule, states have the primary role in developing standards of performance that result from the application of BSER. States have three years to develop and submit compliance plans to the EPA. The EPA will have a year to review and approve those plans. States are then given 24 months from the approval date to implement the plan and can extend the compliance schedule for units that meet progress milestones.

The ACE rule applies to Columbia and the Elm Road Units. The State of Wisconsin has begun to develop an implementation plan and has shared its preliminary work with Wisconsin utilities. MGE is actively monitoring state activity on BSER development. Until the State of Wisconsin completes a plan that is accepted by the EPA, MGE cannot conclusively determine the final impact of the rule. Additionally, the ACE rule and repeal of the Clean Power Plan are subject to a legal challenge pending in the United States District Court of the District of Columbia. MGE will continue to evaluate the plan developments within the state and monitor ongoing and potential legal proceedings associated with the ACE rule.

•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 this 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 United States 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 our Elm Road Units in Milwaukee County. At this time, MGE expects that the 2015 Ozone NAAQS will not 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 U.S. Court of Appeals held that the EPA cannot provide a partial remedy to the Clean Air Act's "Good Neighbor Provision," which addresses interstate transport of pollutants from upwind states to downwind states. Wisconsin is considered an upwind and downwind state under CSAPR and is potentially impacted by rules that the EPA will develop

to address this remand. 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. While uncertainty remains around CSAPR due to legal challenges, MGE expects to meet ongoing CSAPR obligations for the foreseeable future. MGE will continue to monitor developments in EPA revisions after the remand and any ongoing litigation over this rule.

Columbia is subject to the best available retrofit technology (BART) regulations, a subsection of the EPA's CAVR, which may require pollution control retrofits. Columbia's existing pollution control upgrades, and the EPA's stance that compliance with the CSAPR equals compliance with BART, should mean that Columbia will not need to do additional work to meet BART requirements. At this time, however, the BART regulatory obligations, compliance strategies, and costs remain uncertain in Wisconsin due to the continued legal challenges surrounding CSAPR and CAVR. MGE will continue to monitor developments 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.

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. Columbia's operator is also exploring alternative compliance options to meet the rule requirements by the rule's deadline. MGE will continue to monitor the operator's plans for compliance to assess potential impacts on operations.

In December 2019, the EPA introduced a proposed rule to revise some of the closure standards that are in the 2015 CCR Rule. If the proposed rule is finalized, MGE does not anticipate that it will have a material impact on our operations.

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.

c.Purchase Contracts - MGE Energy and MGE.

MGE Energy and MGE have entered into various commodity supply, transportation, and storage contracts to meet their obligations to deliver electricity and natural gas to customers. Management expects to recover these costs in future customer rates. The following table shows future commitments related to purchase contracts as of September 30, 2020:

(In thousands)		2020		2021		2022		2023		2024		Thereafter
Coal(a)	$	6,381	$	6,405	$	6,439	$	1,515	$	-	$	-
Natural gas
Transportation and storage(b)		6,260		21,854		22,008		22,008		22,008		36,603
Supply(c)		8,541		12,567		-		-		-		-
	$	21,182	$	40,826	$	28,447	$	23,523	$	22,008	$	36,603

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

(b)

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

(c)These commitments include market-based pricing.

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Rate Matters

9 Months Ended

Sep. 30, 2020

Regulated Operations [Abstract]

Rate Matters

Rate Matters - MGE Energy and MGE.

a.Rate Proceedings.

In August 2020, MGE filed with the PSCW a proposed settlement agreement for its pending 2021 rate case. The settlement agreement proposes 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 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 Tax Act not governed by IRS normalization rules. As part of the settlement, the fuel rules bandwidth will be set at plus or minus 1%. The gas rate increase covers infrastructure costs and technology improvements. The settlement agreement also seeks escrow accounting treatment for pension and other postretirement benefit costs, bad debt expense, and customer credit card fees. Escrow accounting treatment would allow MGE to defer to its next rate filing any difference between estimated costs in rates and actual costs incurred. Any difference, if allowed, would be recorded as a regulatory asset or regulatory liability. No change is proposed in the pending settlement agreement for 2021 from the 2020 authorized return on common equity or the financial capital structure. PSCW approval of the settlement agreement is pending. A final order is expected before the end of the year.

In December 2018, the PSCW approved a settlement agreement between MGE and intervening parties in its 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 tax impacts of the 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 Tax Act. The return on common stock equity for 2019 and 2020 is 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 the PSCW and Wisconsin utilities to defer electric fuel-related costs that fall outside a symmetrical cost tolerance band around the amount approved for a utility in its 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 currently set at plus or minus 2%. Under fuel rules, MGE would defer costs, less any excess revenues, if its actual electric fuel costs exceeded 102% of the electric fuel costs allowed in its latest rate order. Excess revenues are defined as revenues in the year in question that provide MGE with a greater return on common equity than authorized by the PSCW in MGE's latest rate order. Conversely, MGE is required to defer the benefit of lower costs if actual electric fuel costs were less than 98% of the electric fuel costs allowed in that order. These costs are subject to the PSCW's annual review of fuel costs completed in the year following the deferral.

The PSCW issued a final decision in the 2018 fuel rules proceedings for MGE to refund additional fuel savings realized in 2018 to its retail electric customers over a one-month period. MGE returned $9.5 million to electric customers in October 2019. There was no change to the refund in the fuel rules proceedings from the amount MGE deferred in the previous year.

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 proposed settlement to MGE's pending 2021 rate case or to refund the balance to customers in October 2020. There was no change to the refund in the fuel rules proceedings from the amount MGE deferred in the previous year. The 2019 fuel credit is currently included in the proposed settlement to MGE's pending 2021 rate case.

As of September 30, 2020, MGE had deferred $2.0 million of 2020 fuel savings. These costs will be subject to the PSCW's annual review of 2020 fuel costs, which is expected to be completed in 2021.

c.COVID-19.

On March 24, 2020, the PSCW ordered changes to the tariff provisions of all public utilities in Wisconsin in response to the COVID-19 pandemic. The order prohibited late payment charges, service disconnections, service refusals, and cash deposits as a condition of service. The order also required utilities to offer deferred payment arrangements to customers. The order resulted in increased bad debt expense and foregone revenue from late payment charges. This order, as it pertained to the prohibitions on service disconnections for residential customers, was in effect until November 1, 2020, at which time the annual winter disconnection moratorium began and continues until April 15, 2021. All other restrictions were lifted in July 2020. As permitted by regulatory action, MGE notified the PSCW on July 16, 2020, of its election to continue to waive late fees until December 31, 2020 for all customer classes and seek recovery in a future period. In October 2020, the PSCW issued a decision to allow utilities to extend the election to waive late fees until April 15, 2021, if the utility requests such waiver.

On March 24, 2020, the PSCW issued a further order authorizing deferral of expenditures incurred to ensure the provision of safe, reliable, and affordable access to utility services during the COVID-19 pandemic and late payment charges. Expenditures may include items such as bad debt expense and personal protective equipment. Foregone revenue from late payment charges and the potential delay in payments from customers is expected to impact the timing of cash inflows. Subject to PSCW approval of recovery, foregone late payment charges are expected to be recognized as revenue when it is collected from customers, and deferred expenditures are expected to be recognized as a regulatory asset as costs are incurred (meaning that those expenditures will affect cash flows when paid but will not affect income until recovery is permitted by the PSCW). Recovery of expenditures and late payment charges is expected to be addressed in future rate proceedings. While management believes that cost recovery is probable, the timing of collection from customers cannot be estimated at this time. Management will continue to assess the probability of recovery of deferred costs as the COVID-19 pandemic progresses. As of September 30, 2020, MGE had deferred $2.8 million in costs as a regulatory asset.

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Derivative and Hedging Instruments

9 Months Ended

Sep. 30, 2020

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:

	September 30, 2020		December 31, 2019
Commodity derivative contracts	330,400	MWh	417,840	MWh
Commodity derivative contracts	8,495,000	Dth	6,605,000	Dth
FTRs	4,589	MW	2,750	MW
PPA	1,000	MW	1,450	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 September 30, 2020, the fair value of exchange traded derivatives and FTRs exceeded their cost basis by $2.0 million. As of December 31, 2019, the cost basis of exchange traded derivatives and FTRs exceeded their fair value by $1.4 million.

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 September 30, 2020, and December 31, 2019, reflected a loss position of $16.0 million and $25.4 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
September 30, 2020
Commodity derivative contracts(a)	$	2,248	$	546	Other current assets
Commodity derivative contracts(a)		253		12	Other deferred charges
FTRs		20		-	Other current assets
PPA		N/A		9,640	Derivative liability (current)
PPA		N/A		6,340	Derivative liability (long-term)
December 31, 2019
Commodity derivative contracts(b)	$	157	$	1,521	Derivative liability (current)(c)
Commodity derivative contracts(b)		73		217	Derivative liability (long-term)
FTRs		73		-	Other current assets
PPA		N/A		10,100	Derivative liability (current)
PPA		N/A		15,340	Derivative liability (long-term)

(a) As of September 30, 2020, collateral of $0.7 million was posted against derivative positions owed to counterparties under a master netting agreement on the consolidated balance sheet.

(b)As of December 31, 2019, collateral of $1.5 million was posted against and netted with derivative liability positions on the consolidated balance sheets.

(c) As of December 31, 2019, MGE posted $0.1 million as other current assets on the consolidated balance sheets.

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
September 30, 2020
Commodity derivative contracts	$	2,501	$	(558)	$	(650)	$	1,293
FTRs		20		-		-		20
December 31, 2019
Commodity derivative contracts	$	230	$	(192)	$	-	$	38
FTRs		73		-		-		73

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
September 30, 2020
Commodity derivative contracts	$	558	$	(558)	$	-	$	-
PPA		15,980		-		-		15,980
December 31, 2019
Commodity derivative contracts	$	1,738	$	(192)	$	(1,546)	$	-
PPA		25,440		-		-		25,440

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.

		2020				2019
(In thousands)		Current and Long-Term Regulatory Asset		Other Current Assets		Current and Long-Term Regulatory Asset		Other Current Assets
Three Months Ended September 30:
Balance as of July 1,	$	20,400	$	940	$	33,515	$	878
Unrealized (gain) loss		(4,695)		-		(4,560)		-
Realized (loss) gain reclassified to a deferred account		(207)		207		(411)		411
Realized (loss) gain reclassified to income statement		(1,481)		(164)		638		(258)
Balance as of September 30,	$	14,017	$	983	$	29,182	$	1,031
Nine Months Ended September 30:
Balance as of January 1,	$	26,875	$	1,100	$	31,830	$	377
Unrealized (gain) loss		(8,032)		-		(2,256)		-
Realized (loss) gain reclassified to a deferred account		(1,999)		1,999		(1,402)		1,402
Realized (loss) gain reclassified to income statement		(2,827)		(2,116)		1,010		(748)
Balance as of September 30,	$	14,017	$	983	$	29,182	$	1,031

		Realized Losses (Gains)
		2020				2019
(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 September 30:
Commodity derivative contracts	$	680	$	28	$	471	$	83
FTRs		184		-		(429)		-
PPA		753		-		(505)		-
Nine Months Ended September 30:
Commodity derivative contracts	$	2,303	$	1,682	$	1,038	$	460
FTRs		78		-		(503)		-
PPA		880		-		(1,257)		-

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 above described treatment, 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 September 30, 2020, 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 September 30, 2020, and December 31, 2019, 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 September 30, 2020, no counterparties had defaulted.

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Fair Value of Financial Instruments

9 Months Ended

Sep. 30, 2020

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 offinancial instruments are as follows:

		September 30, 2020				December 31, 2019
(In thousands)		Carrying Amount		Fair Value		Carrying Amount		Fair Value
MGE Energy
Assets:
Cash and cash equivalents	$	53,058	$	53,058	$	23,481	$	23,481
Liabilities:
Long-term debt(a)		544,395		658,008		547,879		611,909
MGE
Assets:
Cash and cash equivalents	$	5,171	$	5,171	$	3,196	$	3,196
Liabilities:
Long-term debt(a)		544,395		658,008		547,879		611,909

(a) Includes long-term debt due within one year. Excludes debt issuance costs and unamortized discount of $4.3 million and $4.5 million as of September 30, 2020, and December 31, 2019, 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 September 30, 2020
(In thousands)		Total		Level 1		Level 2		Level 3
MGE Energy
Assets:
Derivatives, net(b)	$	2,521	$	1,975	$	-	$	546
Exchange-traded investments		1,781		1,781		-		-
Total Assets	$	4,302	$	3,756	$	-	$	546
Liabilities:
Derivatives, net	$	16,538	$	265	$	-	$	16,273
Deferred compensation		3,349		-		3,349		-
Total Liabilities	$	19,887	$	265	$	3,349	$	16,273
MGE
Assets:
Derivatives, net(b)	$	2,521	$	1,975	$	-	$	546
Exchange-traded investments		461		461		-		-
Total Assets	$	2,982	$	2,436	$	-	$	546
Liabilities:
Derivatives, net	$	16,538	$	265	$	-	$	16,273
Deferred compensation		3,349		-		3,349		-
Total Liabilities	$	19,887	$	265	$	3,349	$	16,273

		Fair Value as of December 31, 2019
(In thousands)		Total		Level 1		Level 2		Level 3
MGE Energy
Assets:
Derivatives, net	$	303	$	189	$	-	$	114
Exchange-traded investments		1,271		1,271		-		-
Total Assets	$	1,574	$	1,460	$	-	$	114
Liabilities:
Derivatives, net(c)	$	27,178	$	608	$	-	$	26,570
Deferred compensation		3,157		-		3,157		-
Total Liabilities	$	30,335	$	608	$	3,157	$	26,570
MGE
Assets:
Derivatives, net	$	303	$	189	$	-	$	114
Exchange-traded investments		209		209		-		-
Total Assets	$	512	$	398	$	-	$	114
Liabilities:
Derivatives, net(c)	$	27,178	$	608	$	-	$	26,570
Deferred compensation		3,157		-		3,157		-
Total Liabilities	$	30,335	$	608	$	3,157	$	26,570

(b) These amounts are shown gross and exclude $0.7 million of collateral against derivative positions owed to counterparties under a master netting agreement as of September 30, 2020.

(c) These amounts are shown gross and exclude $1.5 million of collateral that was posted against derivative positions with counterparties as December 31, 2019.

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	September 30, 2020		December 31, 2019
Basis adjustment:
On peak	93.9	%	92.1	%
Off peak	93.7	%	92.7	%
Counterparty fuel mix:
Internal generation - range	46.0% - 65.0	%	40.0% - 60.0	%
Internal generation - weighted average	56.4	%	52.2	%
Purchased power - range	54.0% - 35.0	%	60.0% - 40.0	%
Purchased power - weighted average	43.6	%	47.8	%

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				Nine Months Ended
		September 30,				September 30,
(In thousands)		2020		2019		2020		2019
Beginning balance	$	(21,023)	$	(33,337)	$	(26,456)	$	(32,002)
Realized and unrealized gains (losses):
Included in regulatory assets		5,296		4,317		10,729		2,982
Included in other comprehensive income		-		-		-		-
Included in earnings		(1,524)		(492)		(4,687)		(1,928)
Included in current assets		(37)		4		(101)		(198)
Purchases		5,505		5,205		15,837		16,827
Sales		-		-		-		-
Issuances		-		-		-		-
Settlements		(3,944)		(4,717)		(11,049)		(14,701)
Transfers in and/or out of Level 3		-		-		-		-
Balance as of September 30,	$	(15,727)	$	(29,020)	$	(15,727)	$	(29,020)
Total gains (losses) included in earnings attributed to
the change in unrealized gains (losses) related to
assets and liabilities held as of September 30,(d)	$	-	$	-	$	-	$	-

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

		Three Months Ended				Nine Months Ended
		September 30,				September 30,
(In thousands)		2020		2019		2020		2019
Purchased Power Expense	$	(1,496)	$	(409)	$	(4,343)	$	(1,658)
Cost of Gas Sold Expense		(28)		(83)		(344)		(270)
Total	$	(1,524)	$	(492)	$	(4,687)	$	(1,928)

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

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Joint Plant Ownership

9 Months Ended

Sep. 30, 2020

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		September 30, 2020(a)		Operation
Two Creeks(b)	33	%	50	MW	$65	million	$63.1	million	November 2, 2020
Badger Hollow I(c)	33	%	50	MW	$65	million	$50.5	million	April 2021(d)
Badger Hollow II(c)	33	%	50	MW	$65	million	$5.0	million	December 2022(d)

(a)Excluding AFUDC.

(b) The Two Creeks solar generation array is located in the Town of Two Creeks and the City of Two Rivers in Manitowoc and Kewaunee Counties, Wisconsin.

(c)

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

(d)Estimated date of commercial operation.

MGE received specific approval to recover 100% AFUDC on each of these projects. During the three months ended September 30, 2020 and 2019, MGE recognized $1.9 million and $0.7 million, respectively, after tax, in AFUDC for Two Creeks and Badger Hollow I and II. During the nine months ended September 30, 2020 and 2019, MGE recognized $4.5 million and $0.8 million, respectively, after tax, in AFUDC for Two Creeks and Badger Hollow I and II.

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Revenue

9 Months Ended

Sep. 30, 2020

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				Nine Months Ended
(In thousands)		September 30,				September 30,
Electric revenues		2020		2019		2020		2019
Residential	$	45,009	$	42,442	$	113,311	$	107,772
Commercial		57,822		63,466		152,844		165,481
Industrial		3,234		3,760		8,797		10,013
Other-retail/municipal		8,620		9,543		24,874		26,728
Total retail		114,685		119,211		299,826		309,994
Sales to the market		1,554		1,163		2,604		3,914
Other revenues		115		233		660		978
Total electric revenues		116,354		120,607		303,090		314,886
Gas revenues
Residential		12,436		11,342		61,328		67,659
Commercial/Industrial		5,052		4,825		32,961		40,833
Total retail		17,488		16,167		94,289		108,492
Gas transportation		1,152		1,126		4,179		3,756
Other revenues		3		84		100		299
Total gas revenues		18,643		17,377		98,568		112,547
Non-regulated energy revenues		214		214		466		481
Total Operating Revenue	$	135,211	$	138,198		402,124	$	427,914

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 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

9 Months Ended

Sep. 30, 2020

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 2019 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 September 30, 2020
Operating revenues from external customers	$	116,354	$	18,643	$	214	$	-	$	-	$	-	$	135,211
Interdepartmental revenues		209		3,494		10,102		-		-		(13,805)		-
Total operating revenues		116,563		22,137		10,316		-		-		(13,805)		135,211
Equity in earnings of investments		-		-		-		2,353		-		-		2,353
Net income (loss)		24,761		221		5,251		1,710		(149)		-		31,794
Three Months Ended September 30, 2019
Operating revenues from external customers	$	120,607	$	17,377	$	214	$	-	$	-	$	-	$	138,198
Interdepartmental revenues		225		5,679		10,019		-		-		(15,923)		-
Total operating revenues		120,832		23,056		10,233		-		-		(15,923)		138,198
Equity in earnings of investments		-		-		-		2,372		-		-		2,372
Net income (loss)		23,681		(61)		5,131		1,726		180		-		30,657
Nine Months Ended September 30, 2020
Operating revenues from external customers	$	303,090	$	98,568	$	466	$	-	$	-	$	-	$	402,124
Interdepartmental revenues		584		9,300		30,248		-		-		(40,132)		-
Total operating revenues		303,674		107,868		30,714		-		-		(40,132)		402,124
Equity in earnings of investments		-		-		-		7,780		-		-		7,780
Net income (loss)		46,439		9,216		15,536		5,659		(228)		-		76,622
Nine Months Ended September 30, 2019
Operating revenues from external customers	$	314,886	$	112,547	$	481	$	-	$	-	$	-	$	427,914
Interdepartmental revenues		622		12,571		29,987		-		-		(43,180)		-
Total operating revenues		315,508		125,118		30,468		-		-		(43,180)		427,914
Equity in earnings of investments		-		-		-		6,808		-		-		6,808
Net income		40,905		8,648		15,211		4,952		496		-		70,212

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 September 30, 2020
Operating revenues from external customers	$	116,354	$	18,643	$	214	$	-	$	135,211
Interdepartmental revenues		209		3,494		10,102		(13,805)		-
Total operating revenues		116,563		22,137		10,316		(13,805)		135,211
Net income attributable to MGE		24,761		221		5,251		(5,493)		24,740
Three Months Ended September 30, 2019
Operating revenues from external customers	$	120,607	$	17,377	$	214	$	-	$	138,198
Interdepartmental revenues		225		5,679		10,019		(15,923)		-
Total operating revenues		120,832		23,056		10,233		(15,923)		138,198
Net income (loss) attributable to MGE		23,681		(61)		5,131		(5,614)		23,137
Nine Months Ended September 30, 2020
Operating revenues from external customers	$	303,090	$	98,568	$	466	$	-	$	402,124
Interdepartmental revenues		584		9,300		30,248		(40,132)		-
Total operating revenues		303,674		107,868		30,714		(40,132)		402,124
Net income attributable to MGE		46,439		9,216		15,536		(16,754)		54,437
Nine Months Ended September 30, 2019
Operating revenues from external customers	$	314,886	$	112,547	$	481	$	-	$	427,914
Interdepartmental revenues		622		12,571		29,987		(43,180)		-
Total operating revenues		315,508		125,118		30,468		(43,180)		427,914
Net income attributable to MGE		40,905		8,648		15,211		(16,725)		48,039

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Significant Accounting Policies (Policies)

9 Months Ended

Sep. 30, 2020

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

MGE Energy and MGE consider 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.

Trade Receivables, Allowance for Credit Losses, and Concentration Risk

Trade accounts receivable are recorded at the invoiced amount and do not bear interest. A 1% late payment charge is normally recorded on all receivables unpaid after the due date. In late March 2020, the 1% late payment charge was suspended in response to the PSCW's COVID-19 order. The order also suspended disconnection or refusal of services to any customer, with limited exceptions. The PSCW order was lifted on July 25, 2020; however, as permitted by regulatory action, MGE notified the PSCW of its election to continue to waive late fees until December 31, 2020. See Footnote 9.c. for further information.

The allowance for credit losses associated with these receivables represents MGE's best estimate of the amount of probable credit losses for existing accounts receivable. MGE manages concentration of credit risk through its credit and collection policies, which are consistent with state regulatory requirements. The allowance for credit losses is estimated based on historical write-off experience, regional economic data, review of the accounts receivable aging, and reasonable and supportable forecasts that affect the collectability of the reported amount. MGE has considered the effects of COVID-19 developments and associated governmental regulations, including suspension of disconnections for non-payment, in its estimate of allowance for credit losses by applying data from historical recessions and other significant economic downturns.

New Accounting Pronouncements Disclosure

New Accounting Standards - MGE Energy and MGE.

Recently Adopted

Credit Losses.

In June 2016, the Financial Accounting Standards Board issued authoritative guidance within the codification's Credit Losses topic, which introduced a new model for recognizing credit losses on financial instruments based on an estimate of current expected credit losses. The authoritative guidance became effective January 1, 2020. MGE adopted the standard on the effective date. The adoption of this standard did not have a material impact on MGE Energy's and MGE's financial statements. New disclosures are required under the new standard. See Footnote 1.d. for allowance for credit loss disclosures.

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.

Share-based Compensation

2013 Director Incentive Plan and 2006 Performance Unit Plan

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

In 2020, 5,048 units were granted under the 2013 Plan and are subject to a three-year graded vesting schedule. No units were granted under the 2006 Plan in 2020 in view of the adoption of the 2020 Performance Unit Plan described below. On the grant date, the cost of the director or employee services received in exchange for a performance unit award is measured based on the current market value of MGE Energy common stock. The fair value of the awards is remeasured quarterly, including as of September 30, 2020, as required by applicable accounting standards. Changes in quarterly fair value as well as the original grant are recognized as compensation cost. Since this amount is remeasured throughout the vesting period, the compensation cost is subject to variability.

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

2020 Performance Unit Plan

The 2020 Performance Unit Plan (the 2020 Plan) was adopted in February 2020 for eligible employees. Plan participants may receive awards of performance units, restricted units, or both. Performance units entitle the holder to receive a cash payment equal to the value of a designated number of shares of MGE Energy's common stock, plus dividend-equivalent payments thereon, based upon achievement of specified performance goals during a performance period set by the Compensation Committee of MGE Energy's Board of Directors. Restricted units entitle the holder to receive a cash payment equal to the value of a designated number of shares of MGE Energy's common stock, plus dividend-equivalent payments thereon, at the end of a defined time period. Awards are subject to vesting provisions providing for 100% vesting at the end of the performance period, in the case of performance units, and at the end of the defined time period in the case of restricted units. The performance units and restricted units will be paid out in cash and are accounted for as a liability award. No shares of common stock will be issued in connection with the 2020 Plan.

Wisconsin Fuel Rules

Fuel rules require the PSCW and Wisconsin utilities to defer electric fuel-related costs that fall outside a symmetrical cost tolerance band around the amount approved for a utility in its 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 currently set at plus or minus 2%. Under fuel rules, MGE would defer costs, less any excess revenues, if its actual electric fuel costs exceeded 102% of the electric fuel costs allowed in its latest rate order. Excess revenues are defined as revenues in the year in question that provide MGE with a greater return on common equity than authorized by the PSCW in MGE's latest rate order. Conversely, MGE is required to defer the benefit of lower costs if actual electric fuel costs were less than 98% of the electric fuel costs allowed in that order. These costs are subject to the PSCW's annual review of fuel costs completed in the year following the deferral.

Derivative Hedging

As part of its regular operations, MGE enters into contracts, including options, swaps, futures, forwards, and other contractual commitments, to manage its exposure to commodity prices. To the extent that these contracts are derivatives, MGE assesses whether or not the normal purchases or normal sales exclusion applies. For contracts to which this exclusion cannot be applied, the derivatives are recognized in the consolidated balance sheets at fair value. MGE's financial commodity derivative activities are conducted in accordance with its electric and gas risk management program, which is approved by the PSCW and limits the volume MGE can hedge with specific risk management strategies. The maximum length of time over which cash flows related to energy commodities can be hedged is four years. If the derivative qualifies for regulatory deferral, the derivatives are marked to fair value and are offset with a corresponding regulatory asset or liability depending on whether the derivative is in a net loss or net gain position, respectively. The deferred gain or loss is recognized in earnings in the delivery month applicable to the instrument. Gains and losses related to hedges qualifying for regulatory treatment are recoverable in gas rates through the PGA or in electric rates as a component of the fuel rules mechanism.

Derivative Netting

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

Recurring Fair Value Measurements

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

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

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

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

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	September 30, 2020		December 31, 2019
Basis adjustment:
On peak	93.9	%	92.1	%
Off peak	93.7	%	92.7	%
Counterparty fuel mix:
Internal generation - range	46.0% - 65.0	%	40.0% - 60.0	%
Internal generation - weighted average	56.4	%	52.2	%
Purchased power - range	54.0% - 35.0	%	60.0% - 40.0	%
Purchased power - weighted average	43.6	%	47.8	%

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 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)

9 Months Ended

Sep. 30, 2020

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
		September 30,		December 31,		September 30,		December 31,
(In thousands)		2020		2019		2020		2019
Cash and cash equivalents	$	53,058	$	23,481	$	5,171	$	3,196
Restricted cash		484		619		484		619
Receivable - margin account		550		1,714		550		1,714
Cash, cash equivalents, and restricted cash	$	54,092	$	25,814	$	6,205	$	5,529

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Investment in ATC and ATC Holdco (Tables)

9 Months Ended

Sep. 30, 2020

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				Nine Months Ended
		September 30,				September 30,
(In thousands)		2020		2019		2020		2019
Equity earnings from investment in ATC	$	2,319	$	2,364	$	7,724	$	6,879
Dividends from investments		2,349		1,781		6,620		5,526
Capital contributions to ATC		359		888		892		2,131

ATC's summarized financial data is as follows:

		Three Months Ended				Nine Months Ended
		September 30,				September 30,
(In thousands)		2020		2019		2020		2019
Operating revenues	$	187,833	$	184,833	$	577,705	$	544,760
Operating expenses		(92,975)		(94,713)		(285,697)		(278,673)
Other income, net		643		484		1,924		1,031
Interest expense, net		(28,801)		(29,165)		(83,947)		(87,121)
Earnings before members' income taxes	$	66,700	$	61,439	$	209,985	$	179,997

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Taxes (Tables)

9 Months Ended

Sep. 30, 2020

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 September 30,	2020		2019		2020		2019
Statutory federal income tax rate	21.0	%	21.0	%	21.0	%	21.0	%
State income taxes, net of federal benefit	6.3		6.3		6.2		6.2
Amortized investment tax credits	(0.1)		(0.1)		(0.1)		(0.1)
Credit for electricity from wind energy	(5.0)		(4.8)		(5.4)		(5.2)
AFUDC equity, net	(1.1)		(0.4)		(1.2)		(0.4)
Amortization of utility excess deferred tax - tax reform(a)	(2.0)		(1.9)		(2.2)		(2.1)
Other, net, individually insignificant	(0.4)		(0.5)		(0.4)		(0.5)
Effective income tax rate	18.7	%	19.6	%	17.9	%	18.9	%
	MGE Energy				MGE
Nine Months Ended September 30,	2020		2019		2020		2019
Statutory federal income tax rate	21.0	%	21.0	%	21.0	%	21.0	%
State income taxes, net of federal benefit	6.3		6.3		6.2		6.2
Amortized investment tax credits	(0.1)		(0.1)		(0.1)		(0.1)
Credit for electricity from wind energy	(6.1)		(5.6)		(6.6)		(6.1)
AFUDC equity, net	(1.3)		(0.3)		(1.4)		(0.3)
Amortization of utility excess deferred tax - tax reform(a)	(2.4)		(2.2)		(2.6)		(2.4)
Other, net, individually insignificant	(0.1)		0.1		-		0.1
Effective income tax rate	17.3	%	19.2	%	16.5	%	18.4	%

(a)Included are impacts of the Tax Cuts and Jobs Act for the regulated utility for excess deferred taxes recognized using a normalization method of accounting. During the three and nine months ended September 30, 2020, MGE recognized $0.7 million and $2.0 million, respectively, compared to $0.6 million and $1.7 million for the comparable periods in 2019. The amount and timing of the cash impacts will depend on the period over which certain income tax benefits are provided to customers, as determined by the PSCW.

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Pension and Other Postretirement Plans (Tables)

9 Months Ended

Sep. 30, 2020

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				Nine Months Ended
		September 30,				September 30,
(In thousands)		2020		2019		2020		2019
Pension Benefits
Components of net periodic benefit cost:
Service cost	$	1,324	$	1,040	$	3,972	$	3,402
Interest cost		3,052		3,170		9,157		10,364
Expected return on assets		(6,807)		(5,054)		(20,422)		(16,523)
Amortization of:
Prior service credit		(31)		(26)		(93)		(85)
Actuarial loss		1,339		1,637		4,018		5,351
Net periodic benefit (credit) cost	$	(1,123)	$	767	$	(3,368)	$	2,509
Postretirement Benefits
Components of net periodic benefit cost:
Service cost	$	316	$	276	$	948	$	829
Interest cost		570		721		1,709		2,164
Expected return on assets		(789)		(677)		(2,366)		(2,034)
Amortization of:
Transition obligation		1		1		2		2
Prior service credit		(667)		(664)		(2,001)		(1,994)
Actuarial loss		55		100		165		300
Net periodic benefit (credit) cost	$	(514)	$	(243)	$	(1,543)	$	(733)

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Commitments and Contingencies (Tables)

9 Months Ended

Sep. 30, 2020

Commitments and Contingencies Disclosure [Abstract]

Purchase Contracts, Fiscal Year Maturity Schedule

The following table shows future commitments related to purchase contracts as of September 30, 2020:

(In thousands)		2020		2021		2022		2023		2024		Thereafter
Coal(a)	$	6,381	$	6,405	$	6,439	$	1,515	$	-	$	-
Natural gas
Transportation and storage(b)		6,260		21,854		22,008		22,008		22,008		36,603
Supply(c)		8,541		12,567		-		-		-		-
	$	21,182	$	40,826	$	28,447	$	23,523	$	22,008	$	36,603

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

(b)

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

(c)These commitments include market-based pricing.

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Derivative and Hedging Instruments (Tables)

9 Months Ended

Sep. 30, 2020

Derivative Instruments and Hedging Activities Disclosure [Abstract]

Gross Notional Volume of Open Derivatives

The gross notional volume of open derivatives is as follows:

	September 30, 2020		December 31, 2019
Commodity derivative contracts	330,400	MWh	417,840	MWh
Commodity derivative contracts	8,495,000	Dth	6,605,000	Dth
FTRs	4,589	MW	2,750	MW
PPA	1,000	MW	1,450	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
September 30, 2020
Commodity derivative contracts(a)	$	2,248	$	546	Other current assets
Commodity derivative contracts(a)		253		12	Other deferred charges
FTRs		20		-	Other current assets
PPA		N/A		9,640	Derivative liability (current)
PPA		N/A		6,340	Derivative liability (long-term)
December 31, 2019
Commodity derivative contracts(b)	$	157	$	1,521	Derivative liability (current)(c)
Commodity derivative contracts(b)		73		217	Derivative liability (long-term)
FTRs		73		-	Other current assets
PPA		N/A		10,100	Derivative liability (current)
PPA		N/A		15,340	Derivative liability (long-term)

(a) As of September 30, 2020, collateral of $0.7 million was posted against derivative positions owed to counterparties under a master netting agreement on the consolidated balance sheet.

(b)As of December 31, 2019, collateral of $1.5 million was posted against and netted with derivative liability positions on the consolidated balance sheets.

(c) As of December 31, 2019, MGE posted $0.1 million as other current assets on the consolidated balance sheets.

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
September 30, 2020
Commodity derivative contracts	$	2,501	$	(558)	$	(650)	$	1,293
FTRs		20		-		-		20
December 31, 2019
Commodity derivative contracts	$	230	$	(192)	$	-	$	38
FTRs		73		-		-		73

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
September 30, 2020
Commodity derivative contracts	$	558	$	(558)	$	-	$	-
PPA		15,980		-		-		15,980
December 31, 2019
Commodity derivative contracts	$	1,738	$	(192)	$	(1,546)	$	-
PPA		25,440		-		-		25,440

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.

		2020				2019
(In thousands)		Current and Long-Term Regulatory Asset		Other Current Assets		Current and Long-Term Regulatory Asset		Other Current Assets
Three Months Ended September 30:
Balance as of July 1,	$	20,400	$	940	$	33,515	$	878
Unrealized (gain) loss		(4,695)		-		(4,560)		-
Realized (loss) gain reclassified to a deferred account		(207)		207		(411)		411
Realized (loss) gain reclassified to income statement		(1,481)		(164)		638		(258)
Balance as of September 30,	$	14,017	$	983	$	29,182	$	1,031
Nine Months Ended September 30:
Balance as of January 1,	$	26,875	$	1,100	$	31,830	$	377
Unrealized (gain) loss		(8,032)		-		(2,256)		-
Realized (loss) gain reclassified to a deferred account		(1,999)		1,999		(1,402)		1,402
Realized (loss) gain reclassified to income statement		(2,827)		(2,116)		1,010		(748)
Balance as of September 30,	$	14,017	$	983	$	29,182	$	1,031

Derivative Gains and Losses in Income Statement

		Realized Losses (Gains)
		2020				2019
(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 September 30:
Commodity derivative contracts	$	680	$	28	$	471	$	83
FTRs		184		-		(429)		-
PPA		753		-		(505)		-
Nine Months Ended September 30:
Commodity derivative contracts	$	2,303	$	1,682	$	1,038	$	460
FTRs		78		-		(503)		-
PPA		880		-		(1,257)		-

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Fair Value of Financial Instruments (Tables)

9 Months Ended

Sep. 30, 2020

Fair Value Disclosures [Abstract]

Estimated Fair Market Value of Financial Instruments

The estimated fair market value offinancial instruments are as follows:

		September 30, 2020				December 31, 2019
(In thousands)		Carrying Amount		Fair Value		Carrying Amount		Fair Value
MGE Energy
Assets:
Cash and cash equivalents	$	53,058	$	53,058	$	23,481	$	23,481
Liabilities:
Long-term debt(a)		544,395		658,008		547,879		611,909
MGE
Assets:
Cash and cash equivalents	$	5,171	$	5,171	$	3,196	$	3,196
Liabilities:
Long-term debt(a)		544,395		658,008		547,879		611,909

(a) Includes long-term debt due within one year. Excludes debt issuance costs and unamortized discount of $4.3 million and $4.5 million as of September 30, 2020, and December 31, 2019, 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 September 30, 2020
(In thousands)		Total		Level 1		Level 2		Level 3
MGE Energy
Assets:
Derivatives, net(b)	$	2,521	$	1,975	$	-	$	546
Exchange-traded investments		1,781		1,781		-		-
Total Assets	$	4,302	$	3,756	$	-	$	546
Liabilities:
Derivatives, net	$	16,538	$	265	$	-	$	16,273
Deferred compensation		3,349		-		3,349		-
Total Liabilities	$	19,887	$	265	$	3,349	$	16,273
MGE
Assets:
Derivatives, net(b)	$	2,521	$	1,975	$	-	$	546
Exchange-traded investments		461		461		-		-
Total Assets	$	2,982	$	2,436	$	-	$	546
Liabilities:
Derivatives, net	$	16,538	$	265	$	-	$	16,273
Deferred compensation		3,349		-		3,349		-
Total Liabilities	$	19,887	$	265	$	3,349	$	16,273

		Fair Value as of December 31, 2019
(In thousands)		Total		Level 1		Level 2		Level 3
MGE Energy
Assets:
Derivatives, net	$	303	$	189	$	-	$	114
Exchange-traded investments		1,271		1,271		-		-
Total Assets	$	1,574	$	1,460	$	-	$	114
Liabilities:
Derivatives, net(c)	$	27,178	$	608	$	-	$	26,570
Deferred compensation		3,157		-		3,157		-
Total Liabilities	$	30,335	$	608	$	3,157	$	26,570
MGE
Assets:
Derivatives, net	$	303	$	189	$	-	$	114
Exchange-traded investments		209		209		-		-
Total Assets	$	512	$	398	$	-	$	114
Liabilities:
Derivatives, net(c)	$	27,178	$	608	$	-	$	26,570
Deferred compensation		3,157		-		3,157		-
Total Liabilities	$	30,335	$	608	$	3,157	$	26,570

(b) These amounts are shown gross and exclude $0.7 million of collateral against derivative positions owed to counterparties under a master netting agreement as of September 30, 2020.

(c) These amounts are shown gross and exclude $1.5 million of collateral that was posted against derivative positions with counterparties as December 31, 2019.

Significant Unobservable Inputs

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

	Model Input
Significant Unobservable Inputs	September 30, 2020		December 31, 2019
Basis adjustment:
On peak	93.9	%	92.1	%
Off peak	93.7	%	92.7	%
Counterparty fuel mix:
Internal generation - range	46.0% - 65.0	%	40.0% - 60.0	%
Internal generation - weighted average	56.4	%	52.2	%
Purchased power - range	54.0% - 35.0	%	60.0% - 40.0	%
Purchased power - weighted average	43.6	%	47.8	%

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				Nine Months Ended
		September 30,				September 30,
(In thousands)		2020		2019		2020		2019
Beginning balance	$	(21,023)	$	(33,337)	$	(26,456)	$	(32,002)
Realized and unrealized gains (losses):
Included in regulatory assets		5,296		4,317		10,729		2,982
Included in other comprehensive income		-		-		-		-
Included in earnings		(1,524)		(492)		(4,687)		(1,928)
Included in current assets		(37)		4		(101)		(198)
Purchases		5,505		5,205		15,837		16,827
Sales		-		-		-		-
Issuances		-		-		-		-
Settlements		(3,944)		(4,717)		(11,049)		(14,701)
Transfers in and/or out of Level 3		-		-		-		-
Balance as of September 30,	$	(15,727)	$	(29,020)	$	(15,727)	$	(29,020)
Total gains (losses) included in earnings attributed to
the change in unrealized gains (losses) related to
assets and liabilities held as of September 30,(d)	$	-	$	-	$	-	$	-

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

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^(d).

		Three Months Ended				Nine Months Ended
		September 30,				September 30,
(In thousands)		2020		2019		2020		2019
Purchased Power Expense	$	(1,496)	$	(409)	$	(4,343)	$	(1,658)
Cost of Gas Sold Expense		(28)		(83)		(344)		(270)
Total	$	(1,524)	$	(492)	$	(4,687)	$	(1,928)

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

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Joint Plant (Tables)

9 Months Ended

Sep. 30, 2020

Public Utilities Property Plant And Equipment [Abstract]

Schedule Of Jointly Owned Utility Plants [Text Block]

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		September 30, 2020(a)		Operation
Two Creeks(b)	33	%	50	MW	$65	million	$63.1	million	November 2, 2020
Badger Hollow I(c)	33	%	50	MW	$65	million	$50.5	million	April 2021(d)
Badger Hollow II(c)	33	%	50	MW	$65	million	$5.0	million	December 2022(d)

(a)Excluding AFUDC.

(b) The Two Creeks solar generation array is located in the Town of Two Creeks and the City of Two Rivers in Manitowoc and Kewaunee Counties, Wisconsin.

(c)

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

(d)Estimated date of commercial operation.

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Revenue (Tables)

9 Months Ended

Sep. 30, 2020

Revenue from Contract with Customer [Abstract]

Disaggregation of Revenue

Revenues disaggregated by revenue source were as follows:

		Three Months Ended				Nine Months Ended
(In thousands)		September 30,				September 30,
Electric revenues		2020		2019		2020		2019
Residential	$	45,009	$	42,442	$	113,311	$	107,772
Commercial		57,822		63,466		152,844		165,481
Industrial		3,234		3,760		8,797		10,013
Other-retail/municipal		8,620		9,543		24,874		26,728
Total retail		114,685		119,211		299,826		309,994
Sales to the market		1,554		1,163		2,604		3,914
Other revenues		115		233		660		978
Total electric revenues		116,354		120,607		303,090		314,886
Gas revenues
Residential		12,436		11,342		61,328		67,659
Commercial/Industrial		5,052		4,825		32,961		40,833
Total retail		17,488		16,167		94,289		108,492
Gas transportation		1,152		1,126		4,179		3,756
Other revenues		3		84		100		299
Total gas revenues		18,643		17,377		98,568		112,547
Non-regulated energy revenues		214		214		466		481
Total Operating Revenue	$	135,211	$	138,198		402,124	$	427,914

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Segment Information (Tables)

9 Months Ended

Sep. 30, 2020

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 September 30, 2020
Operating revenues from external customers	$	116,354	$	18,643	$	214	$	-	$	-	$	-	$	135,211
Interdepartmental revenues		209		3,494		10,102		-		-		(13,805)		-
Total operating revenues		116,563		22,137		10,316		-		-		(13,805)		135,211
Equity in earnings of investments		-		-		-		2,353		-		-		2,353
Net income (loss)		24,761		221		5,251		1,710		(149)		-		31,794
Three Months Ended September 30, 2019
Operating revenues from external customers	$	120,607	$	17,377	$	214	$	-	$	-	$	-	$	138,198
Interdepartmental revenues		225		5,679		10,019		-		-		(15,923)		-
Total operating revenues		120,832		23,056		10,233		-		-		(15,923)		138,198
Equity in earnings of investments		-		-		-		2,372		-		-		2,372
Net income (loss)		23,681		(61)		5,131		1,726		180		-		30,657
Nine Months Ended September 30, 2020
Operating revenues from external customers	$	303,090	$	98,568	$	466	$	-	$	-	$	-	$	402,124
Interdepartmental revenues		584		9,300		30,248		-		-		(40,132)		-
Total operating revenues		303,674		107,868		30,714		-		-		(40,132)		402,124
Equity in earnings of investments		-		-		-		7,780		-		-		7,780
Net income (loss)		46,439		9,216		15,536		5,659		(228)		-		76,622
Nine Months Ended September 30, 2019
Operating revenues from external customers	$	314,886	$	112,547	$	481	$	-	$	-	$	-	$	427,914
Interdepartmental revenues		622		12,571		29,987		-		-		(43,180)		-
Total operating revenues		315,508		125,118		30,468		-		-		(43,180)		427,914
Equity in earnings of investments		-		-		-		6,808		-		-		6,808
Net income		40,905		8,648		15,211		4,952		496		-		70,212

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 September 30, 2020
Operating revenues from external customers	$	116,354	$	18,643	$	214	$	-	$	135,211
Interdepartmental revenues		209		3,494		10,102		(13,805)		-
Total operating revenues		116,563		22,137		10,316		(13,805)		135,211
Net income attributable to MGE		24,761		221		5,251		(5,493)		24,740
Three Months Ended September 30, 2019
Operating revenues from external customers	$	120,607	$	17,377	$	214	$	-	$	138,198
Interdepartmental revenues		225		5,679		10,019		(15,923)		-
Total operating revenues		120,832		23,056		10,233		(15,923)		138,198
Net income (loss) attributable to MGE		23,681		(61)		5,131		(5,614)		23,137
Nine Months Ended September 30, 2020
Operating revenues from external customers	$	303,090	$	98,568	$	466	$	-	$	402,124
Interdepartmental revenues		584		9,300		30,248		(40,132)		-
Total operating revenues		303,674		107,868		30,714		(40,132)		402,124
Net income attributable to MGE		46,439		9,216		15,536		(16,754)		54,437
Nine Months Ended September 30, 2019
Operating revenues from external customers	$	314,886	$	112,547	$	481	$	-	$	427,914
Interdepartmental revenues		622		12,571		29,987		(43,180)		-
Total operating revenues		315,508		125,118		30,468		(43,180)		427,914
Net income attributable to MGE		40,905		8,648		15,211		(16,725)		48,039

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Summary of Significant Accounting Principles (Details-1) - USD ($) $ in Thousands	Sep. 30, 2020	Dec. 31, 2019	Sep. 30, 2019	Dec. 31, 2018
Cash Cash Equivalents And Restricted Cash [Line Items]
Cash and cash equivalents	$ 53,058	$ 23,481
Restricted cash	484	619
Receivable - margin account	550	1,714
Cash, cash equivalents, and restricted cash	54,092	25,814	$ 63,242	$ 84,929
MGE [Member]
Cash Cash Equivalents And Restricted Cash [Line Items]
Cash and cash equivalents	5,171	3,196
Restricted cash	484	619
Receivable - margin account	550	1,714
Cash, cash equivalents, and restricted cash	$ 6,205	$ 5,529	$ 6,786	$ 6,670

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Summary of Significant Accounting Principles (Details-2) $ in Millions	3 Months Ended	9 Months Ended
	Sep. 30, 2020 USD ($)	Sep. 30, 2020 USD ($)
Trade Receivables, Allowance for Doubtful Accounts, and Concentration Risk
Late payment charge on unpaid receivables	1.00%	1.00%
Late payment charge on unpaid receivables - suspended	1.00%	1.00%
Accounts Receivable, Allowance for Credit Loss [Roll Forward]
Accounts receivable, allowance for credit loss, writeoff	$ 0.3	$ 0.9
Accounts receivable, allowance for credit loss, period increase	1.1	3.5
Accounts receivable, allowance for credit loss	5.9	5.9
Deferred COVID Allowance For Credit Loss [Member]
Regulatory Asset [Line Items]
Regulatory Assets	$ 2.5	$ 2.5

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Investment in ATC and ATC Holdco (Details-1) - USD ($) $ in Thousands	1 Months Ended	3 Months Ended		9 Months Ended
	Oct. 31, 2020	Sep. 30, 2020	Sep. 30, 2019	Sep. 30, 2020	Sep. 30, 2019
Schedule Of Equity Method Investments [Line Items]
Equity earnings from investment				$ 7,780	$ 6,879
Dividends from investments				6,929	5,526
Capital contributions to investments				4,007	5,894
MGE Transco [Member] | ATC [Member]
Schedule Of Equity Method Investments [Line Items]
Equity earnings from investment		$ 2,319	$ 2,364	7,724	6,879
Dividends from investments		2,349	1,781	6,620	5,526
Capital contributions to investments		$ 359	$ 888	$ 892	$ 2,131
MGE Transco [Member] | ATC [Member] | Subsequent Event [Member]
Schedule Of Equity Method Investments [Line Items]
Capital contributions to investments	$ 400

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Investment in ATC and ATC Holdco (Details-2) - USD ($) $ in Thousands	3 Months Ended		9 Months Ended
	Sep. 30, 2020	Sep. 30, 2019	Sep. 30, 2020	Sep. 30, 2019	Dec. 31, 2019
ATC [Member]
Schedule Of Equity Method Investments [Line Items]
Operating revenues	$ 187,833	$ 184,833	$ 577,705	$ 544,760
Operating expenses	(92,975)	(94,713)	(285,697)	(278,673)
Other income, net	643	484	1,924	1,031
Interest expense, net	(28,801)	(29,165)	(83,947)	(87,121)
Earnings before members' income taxes	66,700	61,439	209,985	179,997
ATC [Member]
Related Party Transaction [Line Items]
Related party expenses	7,700	$ 7,600	23,000	$ 22,800
Due from related parties	$ 2,700		$ 2,700		$ 1,600

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Taxes (Details) - USD ($) $ in Millions		3 Months Ended		9 Months Ended
		Sep. 30, 2020	Sep. 30, 2019	Sep. 30, 2020	Sep. 30, 2019
Reconciliation of tax provision to statutory federal income tax rate [Abstract]
Statutory federal income tax rate		21.00%	21.00%	21.00%	21.00%
State income taxes, net of federal benefit		6.30%	6.30%	6.30%	6.30%
Amortized investment tax credits		(0.10%)	(0.10%)	(0.10%)	(0.10%)
Credit for electricity from wind energy		(5.00%)	(4.80%)	(6.10%)	(5.60%)
AFUDC equity, net		(1.10%)	(0.40%)	(1.30%)	(0.30%)
Amortization of utility excess deferred tax - tax reform	[1]	(2.00%)	(1.90%)	(2.40%)	(2.20%)
Other, net, individually significant		(0.40%)	(0.50%)	(0.10%)	0.10%
Effective income tax rate		18.70%	19.60%	17.30%	19.20%
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	$ 0.6	$ 2.0	$ 1.7
MGE [Member]
Reconciliation of tax provision to statutory federal income tax rate [Abstract]
Statutory federal income tax rate		21.00%	21.00%	21.00%	21.00%
State income taxes, net of federal benefit		6.20%	6.20%	6.20%	6.20%
Amortized investment tax credits		(0.10%)	(0.10%)	(0.10%)	(0.10%)
Credit for electricity from wind energy		(5.40%)	(5.20%)	(6.60%)	(6.10%)
AFUDC equity, net		(1.20%)	(0.40%)	(1.40%)	(0.30%)
Amortization of utility excess deferred tax - tax reform	[1]	(2.20%)	(2.10%)	(2.60%)	(2.40%)
Other, net, individually significant		(0.40%)	(0.50%)	0.00%	0.10%
Effective income tax rate		17.90%	18.90%	16.50%	18.40%

[1] Included are impacts of the Tax Cuts and Jobs Act for the regulated utility for excess deferred taxes recognized using a normalization method of accounting. During the three and nine months ended September 30, 2020, MGE recognized $0.7 million and $2.0 million, respectively, compared to $0.6 million and $1.7 million for the comparable periods in 2019. The amount and timing of the cash impacts will depend on the period over which certain income tax benefits are provided to customers, as determined by the PSCW.

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Pension and Other Postretirement Plans (Details) - USD ($) $ in Thousands	3 Months Ended		9 Months Ended		12 Months Ended
	Sep. 30, 2020	Sep. 30, 2019	Sep. 30, 2020	Sep. 30, 2019	Dec. 31, 2019
Defined Benefit Plan Deferred Pension And Other Postretirement Benefit Plan Costs Recovered [Abstract]
Deferred (recognized) pension and OPEB costs	$ (200)	$ 1,300	$ (700)	$ 4,600	$ 6,200
Pension Benefits [Member]
Components of net periodic benefit cost:
Service cost	1,324	1,040	3,972	3,402
Interest cost	3,052	3,170	9,157	10,364
Expected return on assets	(6,807)	(5,054)	(20,422)	(16,523)
Amortization of:
Prior service credit	(31)	(26)	(93)	(85)
Actuarial loss	1,339	1,637	4,018	5,351
Net periodic benefit (credit) cost	(1,123)	767	(3,368)	2,509
Postretirement Benefits [Member]
Components of net periodic benefit cost:
Service cost	316	276	948	829
Interest cost	570	721	1,709	2,164
Expected return on assets	(789)	(677)	(2,366)	(2,034)
Amortization of:
Transition obligation	1	1	2	2
Prior service credit	(667)	(664)	(2,001)	(1,994)
Actuarial loss	55	100	165	300
Net periodic benefit (credit) cost	$ (514)	$ (243)	$ (1,543)	$ (733)

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Equity and Financing Arrangements (Details) - USD ($)	3 Months Ended	9 Months Ended
	Sep. 30, 2019	Sep. 30, 2020	Sep. 30, 2019	Apr. 20, 2020
Common Stock [Abstract]
Common stock issued during period		1,500,000
Common stock issued during period under the stock plan	0	0
Issuance of common stock, net		$ 79,635,000	$ 0
Dilutive Shares Calculation [Abstract]
Dilutive securities		0
Future Debt Issuance, 2.05%, 2027 Series, Industrial Development Revenue Bonds
Debt Instrument [Line Items]
Face amount				$ 19,300,000
Interest rate				2.05%
Debt covenant, MGEE's outstanding voting equity interest in MGE				100.00%
Future Debt Issuance, 2.05%, 2027 Series, Industrial Development Revenue Bonds | Minimum [Member]
Debt Instrument [Line Items]
Debt covenant, ownership interest by outside party resulting in repurchase of notes at par value				30.00%
Future Debt Issuance, 2.05%, 2027 Series, Industrial Development Revenue Bonds | Maximum [Member]
Debt Instrument [Line Items]
Debt to total capitalization ratio				0.65
3.45%, 2027 Series, Industrial Development Revenue Bonds
Debt Instrument [Line Items]
Long-term debt, gross		$ 19,300,000

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Share Based Compensation (Details) - USD ($) $ in Millions	1 Months Ended		3 Months Ended		9 Months Ended
	Apr. 30, 2020	Jan. 31, 2020	Sep. 30, 2020	Sep. 30, 2019	Sep. 30, 2020	Sep. 30, 2019
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Compensation expense (benefit)			$ 0.1	$ 0.9	$ (0.3)	$ 2.8
Cash payments distributed related to awards previously granted and now payable		$ 2.0
Awards forfeited during period, value			$ 0.0	$ 0.0	$ 0.0	$ 0.0
Awards forfeited during period, units			0	0	0	0
Outstanding awards vested during period					$ 3.4
Director Incentive Agreement [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Awards granted during period (in units)					5,048
Award vesting period					3 years
2006 Performance Unit Plan [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Awards granted during period (in units)					0
Common stock to be issued with plan			0		0
2020 Performance Unit Plan [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Compensation expense (benefit)			$ 0.1		$ 0.6
Common stock to be issued with plan			0		0
2020 Performance Unit Plan [Member] | Performance Units [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Awards granted during period (in units)	9,822
Award vesting period					3 years
2020 Performance Unit Plan [Member] | Performance Units [Member] | Maximum [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Awards to be granted as percentage of target units	200.00%
2020 Performance Unit Plan [Member] | Performance Units [Member] | Minimum [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Awards to be granted as percentage of target units	0.00%
2020 Performance Unit Plan [Member] | Restricted Units [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Awards granted during period (in units)	9,822
Award vesting period					3 years

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Commitments and Contingencies (Details-1)	Sep. 30, 2020 MW
Minimum [Member]
EPA Greenhouse Gas Reduction Guidelines
Standard of Performance Plan For EGUs Over Threshold	25

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Commitments and Contingencies (Details-2) $ in Thousands	Sep. 30, 2020 USD ($)
Operating expense purchase contracts [Abstract]
Purchase obligation, 2020	$ 21,182
Purchase obligation, 2021	40,826
Purchase obligation, 2022	28,447
Purchase obligation, 2023	23,523
Purchase obligation, 2024	22,008
Purchase obligation, Thereafter	36,603
Coal [Member]
Operating expense purchase contracts [Abstract]
Purchase obligation, 2020	6,381	[1]
Purchase obligation, 2021	6,405	[1]
Purchase obligation, 2022	6,439	[1]
Purchase obligation, 2023	1,515	[1]
Purchase obligation, 2024	0	[1]
Purchase obligation, Thereafter	0	[1]
Natural Gas, Transportation and Storage [Member]
Operating expense purchase contracts [Abstract]
Purchase obligation, 2020	6,260	[2]
Purchase obligation, 2021	21,854	[2]
Purchase obligation, 2022	22,008	[2]
Purchase obligation, 2023	22,008	[2]
Purchase obligation, 2024	22,008	[2]
Purchase obligation, Thereafter	36,603	[2]
Natual Gas, Supply [Member]
Operating expense purchase contracts [Abstract]
Purchase obligation, 2020	8,541	[3]
Purchase obligation, 2021	12,567	[3]
Purchase obligation, 2022	0	[3]
Purchase obligation, 2023	0	[3]
Purchase obligation, 2024	0	[3]
Purchase obligation, Thereafter	$ 0	[3]

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

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

[3] These commitments include market-based pricing.

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Rate Matters (Details) - USD ($) $ in Millions	9 Months Ended	12 Months Ended
	Sep. 30, 2020	Dec. 31, 2021	Dec. 31, 2019	Oct. 31, 2019
Fuel Rules [Abstract]
Deferred fuel rules monitored costs	$ 2.0		$ 1.5
Deferred COVID Expenditures [Member]
Regulatory Assets And Liabilities Disclosure [Abstract]
Regulatory Assets	$ 2.8
PSCW [Member] | MGE [Member]
Rate Proceedings [Abstract]
Authorized return on equity, percentage	9.80%		9.80%
Approved equity capital structure, percentage	56.10%		56.60%
Fuel Rules [Abstract]
Fuel rules, bandwidth	2.00%
Fuel rules, electric fuel deferred costs upper threshold	102.00%
Fuel rules, electric fuel deferred costs lower threshold	98.00%
PSCW [Member] | MGE [Member] | Fuel Rules Refund, 2018 [Member]
Fuel Rules [Abstract]
Electric fuel credit ($)				$ 9.5
Electric Rate Proceeding [Member] | PSCW [Member] | MGE [Member]
Rate Proceedings [Abstract]
Authorized rate increase (decrease), percentage	(0.84%)		(2.24%)
Authorized rate increase (decrease), amount	$ (3.4)		$ (9.2)
Electric Rate Proceeding [Member] | PSCW [Member] | Proposed Rate Matters For Future Periods [Member] | MGE [Member]
Rate Proceedings [Abstract]
Proposed rate increase (decrease), percentage		0.00%
Fuel Rules [Abstract]
Fuel rules, bandwidth		1.00%
Effects Of The Tax Cuts And Jobs Act [Abstract]
Return of unprotected excess deferred taxes		$ 18.2
Gas Rate Proceeding [Member] | PSCW [Member] | MGE [Member]
Rate Proceedings [Abstract]
Authorized rate increase (decrease), percentage	1.46%		1.06%
Authorized rate increase (decrease), amount	$ 2.4		$ 1.7
Gas Rate Proceeding [Member] | PSCW [Member] | Proposed Rate Matters For Future Periods [Member] | MGE [Member]
Rate Proceedings [Abstract]
Proposed rate increase (decrease), percentage		4.00%

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Derivative and Hedging Instruments (Details-1) $ in Thousands		3 Months Ended		9 Months Ended		12 Months Ended
		Sep. 30, 2020 USD ($)		Sep. 30, 2020 USD ($) Dth MWh MW		Dec. 31, 2019 USD ($) Dth MWh MW	Jun. 30, 2020 USD ($)	Sep. 30, 2019 USD ($)	Jun. 30, 2019 USD ($)	Dec. 31, 2018 USD ($)
Derivative fair values [Abstract]
Collateral posted against derivative positions						$ 1,500
Collateral posted against derivative positions		$ 700		$ 700
Other Current Assets [Member]
Derivative fair values [Abstract]
Derivative fair value, net		983		983		1,100	$ 940	$ 1,031	$ 878	$ 377
Commodity Contracts And Financial Transimission Rights [Member]
Derivative fair values [Abstract]
Derivative fair value, net		2,000		$ 2,000		$ (1,400)
Commodity Derivative Contracts [Member]
Gross Notional Volume of Open Derivatives
Notional amount, energy measure (in MWh) | MWh				330,400		417,840
Notional amount, decatherm measure (in Dth) | Dth				8,495,000		6,605,000
Derivative fair values [Abstract]
Asset Derivatives, fair value, gross basis		2,501		$ 2,501		$ 230
Liability Derivatives, fair value, gross basis		558		558		1,738
Collateral posted against derivative positions		0		0		1,546
Collateral posted against derivative positions		650		650		0
Commodity Derivative Contracts [Member] | Other Current Assets [Member]
Derivative fair values [Abstract]
Asset Derivatives, fair value, gross basis		2,248	[1]	2,248	[1]	100
Liability Derivatives, fair value, gross basis	[1]	546		546
Commodity Derivative Contracts [Member] | Other Deferred Charges [Member]
Derivative fair values [Abstract]
Asset Derivatives, fair value, gross basis	[1]	253		253
Liability Derivatives, fair value, gross basis	[1]	12		12
Commodity Derivative Contracts [Member] | Derivative Liability (Current) [Member]
Derivative fair values [Abstract]
Asset Derivatives, fair value, gross basis	[2],[3]					157
Liability Derivatives, fair value, gross basis	[2],[3]					1,521
Commodity Derivative Contracts [Member] | Derivative Liability (Long-term) [Member]
Derivative fair values [Abstract]
Asset Derivatives, fair value, gross basis	[2],[3]					73
Liability Derivatives, fair value, gross basis	[2],[3]					217
Commodity Derivative Contracts [Member] | Cash Flow Hedging [Member]
Derivative fair values [Abstract]
Collateral posted against derivative positions						$ 1,500
Collateral posted against derivative positions		$ 700		$ 700
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				4,589		2,750
Derivative fair values [Abstract]
Asset Derivatives, fair value, gross basis		$ 20		$ 20		$ 73
Collateral posted against derivative positions		0		0		0
Financial Transmission Rights [Member] | Other Current Assets [Member]
Derivative fair values [Abstract]
Asset Derivatives, fair value, gross basis		20		20		73
Liability Derivatives, fair value, gross basis		0		$ 0		$ 0
PPA [Member]
Gross Notional Volume of Open Derivatives
Notional amount, power measure (in MW) | MW				1,000		1,450
Derivative fair values [Abstract]
Derivative fair value, net		(16,000)		$ (16,000)		$ (25,400)
Liability Derivatives, fair value, gross basis		15,980		15,980		25,440
Collateral posted against derivative positions		0		0		0
PPA [Member] | Derivative Liability (Current) [Member]
Derivative fair values [Abstract]
Liability Derivatives, fair value, gross basis		9,640		9,640		10,100
PPA [Member] | Derivative Liability (Long-term) [Member]
Derivative fair values [Abstract]
Liability Derivatives, fair value, gross basis		$ 6,340		$ 6,340		$ 15,340

[1] As of September 30, 2020, collateral of $0.7 million was posted against derivative positions owed to counterparties under a master netting agreement on the consolidated balance sheet.

[2] As of December 31, 2019, MGE posted $0.1 million as other current assets on the consolidated balance sheets.

[3] As of December 31, 2019, collateral of $1.5 million was posted against and netted with derivative liability positions on the consolidated balance sheets.

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Derivative and Hedging Instruments (Details-2) - USD ($) $ in Thousands	Sep. 30, 2020	Dec. 31, 2019
Offsetting Assets [Line Items]
Collateral posted against derivative positions	$ (700)
Commodity Derivative Contracts [Member]
Offsetting Assets [Line Items]
Gross amounts	2,501	$ 230
Gross amounts offset in balance sheet	(558)	(192)
Collateral posted against derivative positions	(650)	0
Net amount presented in balance sheet	1,293	38
Financial Transmission Rights [Member]
Offsetting Assets [Line Items]
Gross amounts	20	73
Gross amounts offset in balance sheet	0	0
Collateral posted against derivative positions	0	0
Net amount presented in balance sheet	$ 20	$ 73

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Derivative and Hedging Instruments (Details-3) - USD ($) $ in Thousands	Sep. 30, 2020	Dec. 31, 2019
Offsetting Liabilities [Line Items]
Collateral posted against derivative positions		$ (1,500)
Commodity Derivative Contracts [Member]
Offsetting Liabilities [Line Items]
Gross amounts	$ 558	1,738
Gross amounts offset in balance sheet	(558)	(192)
Collateral posted against derivative positions	0	(1,546)
Net amount presented in balance sheet	0	0
Purchased Power Agreement [Member]
Offsetting Liabilities [Line Items]
Gross amounts	15,980	25,440
Gross amounts offset in balance sheet	0	0
Collateral posted against derivative positions	0	0
Net amount presented in balance sheet	$ 15,980	$ 25,440

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Derivative and Hedging Instruments (Details-4) - USD ($) $ in Thousands	3 Months Ended		9 Months Ended
	Sep. 30, 2020	Sep. 30, 2019	Sep. 30, 2020	Sep. 30, 2019
Current and Long-Term Regulatory Asset [Member]
Change In Derivative Fair Value [Roll Forward]
Beginning balance,	$ 20,400	$ 33,515	$ 26,875	$ 31,830
Unrealized (gain) loss	(4,695)	(4,560)	(8,032)	(2,256)
Realized (loss) gain reclassified to a deferred account	(207)	(411)	(1,999)	(1,402)
Realized (loss) gain reclassified to income statement	(1,481)	638	(2,827)	1,010
Ending balance,	14,017	29,182	14,017	29,182
Other Current Assets [Member]
Change In Derivative Fair Value [Roll Forward]
Beginning balance,	940	878	1,100	377
Unrealized (gain) loss	0	0	0	0
Realized (loss) gain reclassified to a deferred account	207	411	1,999	1,402
Realized (loss) gain reclassified to income statement	(164)	(258)	(2,116)	(748)
Ending balance,	$ 983	$ 1,031	$ 983	$ 1,031

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Derivative and Hedging Instruments (Details-5)	3 Months Ended		9 Months Ended
	Sep. 30, 2020 USD ($) counterparty	Sep. 30, 2019 USD ($)	Sep. 30, 2020 USD ($) counterparty	Sep. 30, 2019 USD ($)	Dec. 31, 2019 USD ($)
Counterparties in net liability position or default [Abstract]
Derivative, net liability position of counterparties	$ 0		$ 0		$ 0
Number of counterparties in default | counterparty	0		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	$ 680,000	$ 471,000	$ 2,303,000	$ 1,038,000
Commodity Derivative Contracts [Member] | Cost Of Gas Sold Expense [Member]
Realized losses (gains) on income statement [Line Items]
Realized losses (gains) on income statement	28,000	83,000	1,682,000	460,000
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	184,000	(429,000)	78,000	(503,000)
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	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		20,000,000.0
Maximum collateral that may be required to be posted	40,000,000.0		40,000,000.0
Collateral posted	0		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	753,000	(505,000)	880,000	(1,257,000)
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	$ 0	$ 0

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Fair Value of Financial Instruments (Details-1) - USD ($) $ in Thousands		Sep. 30, 2020	Dec. 31, 2019
Fair Value Measurement [Domain]
Liabilities:
Unamortized discount and debt issuance costs, net		$ 4,300	$ 4,500
Carrying Amount [Member]
Assets:
Cash and cash equivalents		53,058	23,481
Liabilities:
Long-term debt	[1]	544,395	547,879
Fair Value [Member]
Assets:
Cash and cash equivalents		53,058	23,481
Liabilities:
Long-term debt	[1]	658,008	611,909
MGE [Member] | Carrying Amount [Member]
Assets:
Cash and cash equivalents		5,171	3,196
Liabilities:
Long-term debt	[1]	544,395	547,879
MGE [Member] | Fair Value [Member]
Assets:
Cash and cash equivalents		5,171	3,196
Liabilities:
Long-term debt	[1]	$ 658,008	$ 611,909

[1] Includes long-term debt due within one year. Excludes debt issuance costs and unamortized discount of $4.3 million and $4.5 million as of September 30, 2020, and December 31, 2019, respectively.

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Fair Value of Financial Instruments (Details-2) - USD ($) $ in Thousands	Sep. 30, 2020		Dec. 31, 2019
Assets:
Collateral posted against derivative positions	$ 700
Liabilities:
Collateral posted against derivative positions			$ 1,500
Recurring [Member]
Assets:
Derivatives	2,521	[1]	303
Total Assets	4,302		1,574
Liabilities:
Derivatives	16,538		27,178	[2]
Deferred compensation	3,349		3,157
Total liabilities	19,887		30,335
Recurring [Member] | Exchange Traded [Member]
Assets:
Available-for-sale securities	1,781		1,271
Recurring [Member] | Level 1 [Member]
Assets:
Derivatives	1,975	[1]	189
Total Assets	3,756		1,460
Liabilities:
Derivatives	265		608	[2]
Deferred compensation	0		0
Total liabilities	265		608
Recurring [Member] | Level 1 [Member] | Exchange Traded [Member]
Assets:
Available-for-sale securities	1,781		1,271
Recurring [Member] | Level 2 [Member]
Assets:
Derivatives	0	[1]	0
Total Assets	0		0
Liabilities:
Derivatives	0		0	[2]
Deferred compensation	3,349		3,157
Total liabilities	3,349		3,157
Recurring [Member] | Level 2 [Member] | Exchange Traded [Member]
Assets:
Available-for-sale securities	0		0
Recurring [Member] | Level 3 [Member]
Assets:
Derivatives	546	[1]	114
Total Assets	546		114
Liabilities:
Derivatives	16,273		26,570	[2]
Deferred compensation	0		0
Total liabilities	16,273		26,570
Recurring [Member] | Level 3 [Member] | Exchange Traded [Member]
Assets:
Available-for-sale securities	0		0
MGE [Member]
Assets:
Collateral posted against derivative positions	700
Liabilities:
Collateral posted against derivative positions			1,500
MGE [Member] | Recurring [Member]
Assets:
Derivatives	2,521	[1]	303
Total Assets	2,982		512
Liabilities:
Derivatives	16,538		27,178	[2]
Deferred compensation	3,349		3,157
Total liabilities	19,887		30,335
MGE [Member] | Recurring [Member] | Exchange Traded [Member]
Assets:
Available-for-sale securities	461		209
MGE [Member] | Recurring [Member] | Level 1 [Member]
Assets:
Derivatives	1,975	[1]	189
Total Assets	2,436		398
Liabilities:
Derivatives	265		608	[2]
Deferred compensation	0		0
Total liabilities	265		608
MGE [Member] | Recurring [Member] | Level 1 [Member] | Exchange Traded [Member]
Assets:
Available-for-sale securities	461		209
MGE [Member] | Recurring [Member] | Level 2 [Member]
Assets:
Derivatives	0	[1]	0
Total Assets	0		0
Liabilities:
Derivatives	0		0	[2]
Deferred compensation	3,349		3,157
Total liabilities	3,349		3,157
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	546	[1]	114
Total Assets	546		114
Liabilities:
Derivatives	16,273		26,570	[2]
Deferred compensation	0		0
Total liabilities	16,273		26,570
MGE [Member] | Recurring [Member] | Level 3 [Member] | Exchange Traded [Member]
Assets:
Available-for-sale securities	$ 0		$ 0

[1] These amounts are shown gross and exclude $0.7 million of collateral against derivative positions owed to counterparties under a master netting agreement as of September 30, 2020.

[2] These amounts are shown gross and exclude $1.5 million of collateral that was posted against derivative positions with counterparties as December 31, 2019.

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Fair Value of Financial Instruments (Details-3)	9 Months Ended	12 Months Ended
	Sep. 30, 2020	Dec. 31, 2019
Basis adjustment:
Basis adjustment - on peak	93.90%	92.10%
Basis adjustment - off peak	93.70%	92.70%
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	46.00%	40.00%
Purchased power	35.00%	40.00%
Maximum [Member]
Counterparty fuel mix:
Internal generation	65.00%	60.00%
Purchased power	54.00%	60.00%
Weighted Average [Member]
Counterparty fuel mix:
Internal generation	56.40%	52.20%
Purchased power	43.60%	47.80%

XML

Fair Value of Financial Instruments (Details-4) - USD ($) $ in Thousands		3 Months Ended		9 Months Ended
		Sep. 30, 2020	Sep. 30, 2019	Sep. 30, 2020	Sep. 30, 2019
Fair Value, Net Derivative Asset (Liability) Measured on Recurring Basis, Unobservable Input Reconciliation [Roll Forward]
Beginning balance,		$ (21,023)	$ (33,337)	$ (26,456)	$ (32,002)
Realized and unrealized gains (losses):
Included in regulatory assets		5,296	4,317	10,729	2,982
Included in other comprehensive income		0	0	0	0
Included in earnings	[1]	(1,524)	(492)	(4,687)	(1,928)
Included in current assets		(37)	4	(101)	(198)
Purchases		5,505	5,205	15,837	16,827
Sales		0	0	0	0
Issuances		0	0	0	0
Settlements		(3,944)	(4,717)	(11,049)	(14,701)
Transfers in and/or out of level 3		0	0	0	0
Ending balance,		$ (15,727)	$ (29,020)	$ (15,727)	$ (29,020)

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

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Fair Value of Financial Instruments (Details-5) - USD ($) $ in Thousands		3 Months Ended		9 Months Ended
		Sep. 30, 2020	Sep. 30, 2019	Sep. 30, 2020	Sep. 30, 2019
Fair Value Disclosures [Abstract]
Total gains (losses) included in earnings attributed to the change in unrealized gains (losses) related to assets and liabilities		$ 0	$ 0	$ 0	$ 0
Fair Value, Net Derivative Asset (Liability) Measured on Recurring Basis, Unobservable Input Reconciliation [Line Items]
Included in earnings	[1]	(1,524)	(492)	(4,687)	(1,928)
Purchased Power Expense [Member]
Fair Value, Net Derivative Asset (Liability) Measured on Recurring Basis, Unobservable Input Reconciliation [Line Items]
Included in earnings		1,496	409	4,343	1,658
Cost Of Gas Sold Expense [Member]
Fair Value, Net Derivative Asset (Liability) Measured on Recurring Basis, Unobservable Input Reconciliation [Line Items]
Included in earnings		$ 28	$ 83	$ 344	$ 270

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

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Joint Plant Ownership (Details) $ in Millions		3 Months Ended		9 Months Ended
		Sep. 30, 2020 USD ($) MW	Sep. 30, 2019 USD ($)	Sep. 30, 2020 USD ($) MW	Sep. 30, 2019 USD ($)
Allowance for Funds Used During Construction
AFUDC		$ 1.9	$ 0.7	$ 4.5	$ 0.8
Two Creeks Units [Member]
Jointly Owned Utility Plant Interests [Line Items]
Projected Solar Farm Project Costs	[1]	65.0		65.0
Public Utilities Property Plant And Equipment Construction Work In Progress	[1],[2]	$ 63.1		$ 63.1
Two Creeks Units [Member] | Public Service Commission of Wisconsin [Member]
Allowance for Funds Used During Construction
Authorized AFUDC rate - Signficiant projects (100%)		100.00%		100.00%
Two Creeks Units [Member] | MGE [Member]
Jointly Owned Utility Plant Interests [Line Items]
Jointly owned utility plant, ownership interest	[1]	33.00%		33.00%
Jointly owned utility plant, plant capacity (in MW) | MW	[1]	50		50
Badger Hollow I Units [Member]
Jointly Owned Utility Plant Interests [Line Items]
Projected Solar Farm Project Costs	[3]	$ 65.0		$ 65.0
Public Utilities Property Plant And Equipment Construction Work In Progress	[2],[3]	$ 50.5		$ 50.5
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%		100.00%
Badger Hollow I Units [Member] | MGE [Member]
Jointly Owned Utility Plant Interests [Line Items]
Jointly owned utility plant, ownership interest	[3]	33.00%		33.00%
Jointly owned utility plant, plant capacity (in MW) | MW	[3]	50		50
Badger Hollow II Units [Member]
Jointly Owned Utility Plant Interests [Line Items]
Projected Solar Farm Project Costs	[3]	$ 65.0		$ 65.0
Public Utilities Property Plant And Equipment Construction Work In Progress	[2],[3]	$ 5.0		$ 5.0
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%		100.00%
Badger Hollow II Units [Member] | MGE [Member]
Jointly Owned Utility Plant Interests [Line Items]
Jointly owned utility plant, ownership interest	[3]	33.00%		33.00%
Jointly owned utility plant, plant capacity (in MW) | MW	[3]	50		50

[1] The Two Creeks solar generation array is located in the Town of Two Creeks and the City of Two Rivers in Manitowoc and Kewaunee Counties, Wisconsin.

[2] Excluding AFUDC.

[3] The Badger Hollow I and Badger Hollow II solar farm is located in southwestern Wisconsin in Iowa County, near the villages of Montfort and Cobb.   (d)Estimated date of commercial operation.

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Revenue (Details-1) - USD ($) $ in Thousands	3 Months Ended		9 Months Ended
	Sep. 30, 2020	Sep. 30, 2019	Sep. 30, 2020	Sep. 30, 2019
Total Operating Revenue [Member]
Disaggregation of Revenue [Line Items]
Revenues recognized from contracts with customers	$ 135,211	$ 138,198	$ 402,124	$ 427,914
Electric [Member]
Disaggregation of Revenue [Line Items]
Revenues recognized from contracts with customers	116,354	120,607	303,090	314,886
Electric [Member] | Residential [Member]
Disaggregation of Revenue [Line Items]
Revenues recognized from contracts with customers	45,009	42,442	113,311	107,772
Electric [Member] | Commercial [Member]
Disaggregation of Revenue [Line Items]
Revenues recognized from contracts with customers	57,822	63,466	152,844	165,481
Electric [Member] | Industrial [Member]
Disaggregation of Revenue [Line Items]
Revenues recognized from contracts with customers	3,234	3,760	8,797	10,013
Electric [Member] | Other-retail/municipal
Disaggregation of Revenue [Line Items]
Revenues recognized from contracts with customers	8,620	9,543	24,874	26,728
Electric [Member] | Total Retail [Member]
Disaggregation of Revenue [Line Items]
Revenues recognized from contracts with customers	114,685	119,211	299,826	309,994
Electric [Member] | Sales To The Market [Member]
Disaggregation of Revenue [Line Items]
Revenues recognized from contracts with customers	1,554	1,163	2,604	3,914
Electric [Member] | Other Revenues [Member]
Disaggregation of Revenue [Line Items]
Revenues recognized from contracts with customers	115	233	660	978
Gas [Member]
Disaggregation of Revenue [Line Items]
Revenues recognized from contracts with customers	18,643	17,377	98,568	112,547
Gas [Member] | Residential [Member]
Disaggregation of Revenue [Line Items]
Revenues recognized from contracts with customers	12,436	11,342	61,328	67,659
Gas [Member] | Commercial/Industrial [Member]
Disaggregation of Revenue [Line Items]
Revenues recognized from contracts with customers	5,052	4,825	32,961	40,833
Gas [Member] | Total Retail [Member]
Disaggregation of Revenue [Line Items]
Revenues recognized from contracts with customers	17,488	16,167	94,289	108,492
Gas [Member] | Gas Transportation [Member]
Disaggregation of Revenue [Line Items]
Revenues recognized from contracts with customers	1,152	1,126	4,179	3,756
Gas [Member] | Other Revenues [Member]
Disaggregation of Revenue [Line Items]
Revenues recognized from contracts with customers	3	84	100	299
Non Regulated Energy [Member]
Disaggregation of Revenue [Line Items]
Revenues recognized from contracts with customers	$ 214	$ 214	$ 466	$ 481

XML

Segment Information (Details) - USD ($)	3 Months Ended		9 Months Ended
	Sep. 30, 2020	Sep. 30, 2019	Sep. 30, 2020	Sep. 30, 2019
Segment Reporting Information [Line Items]
Operating revenues	$ 135,211,000	$ 138,198,000	$ 402,124,000	$ 427,914,000
Equity in earnings of investment			7,780,000	6,879,000
Net Income Including Noncontrolling Interest	31,794,000	30,657,000	76,622,000	70,212,000
Net Income	31,794,000	30,657,000	76,622,000	70,212,000
Electric [Member]
Segment Reporting Information [Line Items]
Operating revenues	116,354,000	120,607,000	303,090,000	314,886,000
Gas [Member]
Segment Reporting Information [Line Items]
Operating revenues	18,643,000	17,377,000	98,568,000	112,547,000
Non Regulated Energy [Member]
Segment Reporting Information [Line Items]
Operating revenues	214,000	214,000	466,000	481,000
Transmission Investment [Member]
Segment Reporting Information [Line Items]
Operating revenues	0	0	0	0
All Others [Member]
Segment Reporting Information [Line Items]
Operating revenues	0	0	0	0
Operating Segments [Member]
Segment Reporting Information [Line Items]
Operating revenues	135,211,000	138,198,000	402,124,000	427,914,000
Equity in earnings of investment	2,353,000	2,372,000	7,780,000	6,808,000
Operating Segments [Member] | Electric [Member]
Segment Reporting Information [Line Items]
Operating revenues	116,563,000	120,832,000	303,674,000	315,508,000
Equity in earnings of investment	0	0	0	0
Net Income	24,761,000	23,681,000	46,439,000	40,905,000
Operating Segments [Member] | Gas [Member]
Segment Reporting Information [Line Items]
Operating revenues	22,137,000	23,056,000	107,868,000	125,118,000
Equity in earnings of investment	0	0	0	0
Net Income	221,000	(61,000)	9,216,000	8,648,000
Operating Segments [Member] | Non Regulated Energy [Member]
Segment Reporting Information [Line Items]
Operating revenues	10,316,000	10,233,000	30,714,000	30,468,000
Equity in earnings of investment	0	0	0	0
Net Income	5,251,000	5,131,000	15,536,000	15,211,000
Operating Segments [Member] | Transmission Investment [Member]
Segment Reporting Information [Line Items]
Operating revenues	0	0	0	0
Equity in earnings of investment	2,353,000	2,372,000	7,780,000	6,808,000
Net Income	1,710,000	1,726,000	5,659,000	4,952,000
Operating Segments [Member] | All Others [Member]
Segment Reporting Information [Line Items]
Operating revenues	0	0	0	0
Equity in earnings of investment	0	0	0	0
Net Income	(149,000)	180,000	(228,000)	496,000
Consolidation Elimination Entries [Member]
Segment Reporting Information [Line Items]
Operating revenues	(13,805,000)	(15,923,000)	(40,132,000)	(43,180,000)
Equity in earnings of investment	0	0	0	0
Net Income	0	0	0	0
Consolidation Elimination Entries [Member] | Electric [Member]
Segment Reporting Information [Line Items]
Operating revenues	209,000	225,000	584,000	622,000
Consolidation Elimination Entries [Member] | Gas [Member]
Segment Reporting Information [Line Items]
Operating revenues	3,494,000	5,679,000	9,300,000	12,571,000
Consolidation Elimination Entries [Member] | Non Regulated Energy [Member]
Segment Reporting Information [Line Items]
Operating revenues	10,102,000	10,019,000	30,248,000	29,987,000
Consolidation Elimination Entries [Member] | Transmission Investment [Member]
Segment Reporting Information [Line Items]
Operating revenues	0	0	0	0
Consolidation Elimination Entries [Member] | All Others [Member]
Segment Reporting Information [Line Items]
Operating revenues	0	0	0	0
MGE [Member]
Segment Reporting Information [Line Items]
Operating revenues	135,211,000	138,198,000	402,124,000	427,914,000
Net Income Including Noncontrolling Interest	30,233,000	28,751,000	71,191,000	64,764,000
Less Net Income Attributable to Noncontrolling Interest, net of tax	(5,493,000)	(5,614,000)	(16,754,000)	(16,725,000)
Net Income	24,740,000	23,137,000	54,437,000	48,039,000
MGE [Member] | Electric [Member]
Segment Reporting Information [Line Items]
Operating revenues	116,354,000	120,607,000	303,090,000	314,886,000
MGE [Member] | Gas [Member]
Segment Reporting Information [Line Items]
Operating revenues	18,643,000	17,377,000	98,568,000	112,547,000
MGE [Member] | Non Regulated Energy [Member]
Segment Reporting Information [Line Items]
Operating revenues	214,000	214,000	466,000	481,000
MGE [Member] | Operating Segments [Member]
Segment Reporting Information [Line Items]
Operating revenues	135,211,000	138,198,000	402,124,000	427,914,000
Net Income	24,740,000	23,137,000	54,437,000	48,039,000
MGE [Member] | Operating Segments [Member] | Electric [Member]
Segment Reporting Information [Line Items]
Operating revenues	116,563,000	120,832,000	303,674,000	315,508,000
Net Income	24,761,000	23,681,000	46,439,000	40,905,000
MGE [Member] | Operating Segments [Member] | Gas [Member]
Segment Reporting Information [Line Items]
Operating revenues	22,137,000	23,056,000	107,868,000	125,118,000
Net Income	221,000	(61,000)	9,216,000	8,648,000
MGE [Member] | Operating Segments [Member] | Non Regulated Energy [Member]
Segment Reporting Information [Line Items]
Operating revenues	10,316,000	10,233,000	30,714,000	30,468,000
Net Income	5,251,000	5,131,000	15,536,000	15,211,000
MGE [Member] | Consolidation Elimination Entries [Member]
Segment Reporting Information [Line Items]
Operating revenues	(13,805,000)	(15,923,000)	(40,132,000)	(43,180,000)
Net Income	(5,493,000)	(5,614,000)	(16,754,000)	(16,725,000)
MGE [Member] | Consolidation Elimination Entries [Member] | Electric [Member]
Segment Reporting Information [Line Items]
Operating revenues	209,000	225,000	584,000	622,000
MGE [Member] | Consolidation Elimination Entries [Member] | Gas [Member]
Segment Reporting Information [Line Items]
Operating revenues	3,494,000	5,679,000	9,300,000	12,571,000
MGE [Member] | Consolidation Elimination Entries [Member] | Non Regulated Energy [Member]
Segment Reporting Information [Line Items]
Operating revenues	$ 10,102,000	$ 10,019,000	$ 30,248,000	$ 29,987,000