
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, ~~2022~~2023 ☐ Transition Report Pursuant to Section 13 or 15(d) of the Securities Exchange Act of 1934 For the transition period from _______________ to _______________
Commission File No.	Name of Registrant, State of Incorporation, Address of Principal Executive Offices, and Telephone No.	IRS Employer Identification No.
000-49965	MGE Energy, Inc. (a Wisconsin Corporation) 133 South Blair Street Madison, Wisconsin 53788 (608) 252-7000 \| mgeenergy.com	39-2040501
000-1125	Madison Gas and Electric Company (a Wisconsin Corporation) 133 South Blair Street Madison, Wisconsin 53788 (608) 252-7000 \| mge.com	39-0444025

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


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

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


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

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


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

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


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

Indicate by check mark whether the registrants are shell companies (as defined in Rule 12b-2 of the Exchange Act):


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

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


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


Number of Shares Outstanding of Each Class of Common Stock as of October 31, ~~2022~~2023
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.).

Table of Contents


PART I. FINANCIAL INFORMATION	3
Filing Format	3
Forward-Looking Statements	3
Where to Find More Information	3
Definitions, Abbreviations, and Acronyms Used in the Text and Notes of this Report	4
Item 1. Financial Statements.	6
MGE Energy, Inc.	6
Consolidated Statements of Income (unaudited)	6
Consolidated Statements of Cash Flows (unaudited)	7
Consolidated Balance Sheets (unaudited)	8
Consolidated Statements of Common Equity (unaudited)	9
Madison Gas and Electric Company	10
Consolidated Statements of Income (unaudited)	10
Consolidated Statements of Cash Flows (unaudited)	11
Consolidated Balance Sheets (unaudited)	12
Consolidated Statements of Equity (unaudited)	13
MGE Energy, Inc., and Madison Gas and Electric Company - Notes to Consolidated Financial Statements (unaudited)	14
1. Summary of Significant Accounting Policies.	14
2. New Accounting Standards.	15
3. Investment in ATC and ATC Holdco.	15
4. Taxes.	16
5. Pension and Other Postretirement Plans.	17
6. Equity and Financing Arrangements.	17
7. Share-Based Compensation.	18
8. Commitments and Contingencies.	18
9. Rate Matters.	22
10. Derivative and Hedging Instruments.	23
11. Fair Value of Financial Instruments.	2526
12. Joint Plant Construction Project Ownership.	2829
13. Revenue.	29
14. Segment Information.	30
Item 2. Management's Discussion and Analysis of Financial Condition and Results of Operations.	31
Item 3. Quantitative and Qualitative Disclosures About Market Risk.	4950
Item 4. Controls and Procedures.	4950
PART II. OTHER INFORMATION.	5051
Item 1. Legal Proceedings.	5051
Item 1A. Risk Factors.	5051
Item 2. Unregistered Sales of Equity Securities and Use of Proceeds.	5051
Item 3. Defaults Upon Senior Securities.	5051
Item 4. Mine Safety Disclosures.	5051
Item 5. Other Information.	5051
Item 6. Exhibits.	52
Signatures - MGE Energy, Inc.	53
Signatures - Madison Gas and Electric Company	54

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 and rate recovery, financial resources, regulatory matters, and the scope and expense associated with future environmental regulation. These forward-looking statements are made pursuant to the provisions of the Private Securities Litigation Reform Act of 1995. Words such as "believe," "expect," "anticipate," "estimate," "could," "should," "intend," "will," and other similar words, and words relating to goals, targets and projections, generally identify forward-looking statements. Both MGE Energy and MGE caution investors that these forward-looking statements are subject to known and unknown risks and uncertainties that may cause actual results to differ materially from those projected, expressed, or implied.

The factors that could cause actual results to differ materially from the forward-looking statements made by a registrant include: (a) those factors discussed in the registrants' ~~2021~~2022 Annual Report on Form 10-K: Item 1A. Risk Factors, Item 7. Management's Discussion and Analysis of Financial Condition and Results of Operations, as updated by Part I, Item 2. Management's Discussion and Analysis of Financial Condition and Results of Operations in this report, and Item 8. Financial Statements and Supplementary Data – Note 16, as updated by Part I, Item 1. Financial Statements – Note 8 in this report, and (b) other factors discussed herein and in other filings made by that registrant with the SEC.

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

Where to Find More Information

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

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

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

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


MGE Energy and Subsidiaries:

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

Other Defined Terms:

2017 Tax Act	Tax Cut and Jobs Act of 2017
~~2021~~2022 Annual Report on Form 10-K	MGE Energy's and MGE's Annual Report on Form 10-K for the year ended December 31, ~~2021~~2022
2021 Plan	MGE Energy's 2021 Long-Term Incentive Plan
AFUDC	Allowance for Funds Used During Construction
ATC	American Transmission Company LLC
ATC Holdco	ATC Holdco, LLC
Badger Hollow I	Badger Hollow I Solar Farm
Badger Hollow II	Badger Hollow II Solar Farm
Blount	Blount Station
BTA	Best technology available
CA	Certificate of Authority
CASAC	Clean Air Scientific Advisory Committee
CBP	U.S. Customs and Border Protection
CCR	Coal Combustion Residual
Columbia	Columbia Energy Center
cooling degree days (CDD)	Measure of the extent to which the average daily temperature is above 65 degrees Fahrenheit, which is considered an indicator of possible increased demand for energy to provide cooling
~~COVID-19~~	~~Coronavirus Disease 2019~~
CSAPR	Cross-State Air Pollution Rule
D.C. Circuit	United States Court of Appeals for the District of Columbia Circuit
Darien	Darien Solar Energy Center
Dth	Dekatherms, a quantity measure for natural gas
EGU	Electric generating unit
ELG	Effluent Limitations Guidelines
Elm Road Units	Elm Road Generating Station
EPA	United States Environmental Protection Agency
FASB	Financial Accounting Standards Board
FERC	Federal Energy Regulatory Commission
FIP	Federal Implementation Plan
FTR	Financial Transmission Rights
~~GAAP~~	~~Generally Accepted Accounting Principles~~
GHG	Greenhouse gas
heating degree days (HDD)	Measure of the extent to which the average daily temperature is below 65 degrees Fahrenheit, which is considered an indicator of possible increased demand for energy to provide heating
IRS	Internal Revenue Service
kWh	Kilowatt-hour, a measure of electric energy produced
MISO	Midcontinent Independent System Operator (a regional transmission organization)
MW	Megawatt, a measure of electric energy generating capacity
MWh	Megawatt-hour, a measure of electric energy produced
NAAQS	National Ambient Air Quality Standards
Nasdaq	The Nasdaq Stock Market
NOx	Nitrogen oxide
NSPS	New Source Performance Standards
Paris	Paris Solar and Battery Park
the Petition	Petition for Judicial Review of Agency Action
PGA	Purchased Gas Adjustment clause, a regulatory mechanism used to reconcile natural gas costs recovered in rates to actual costs
PM	Particulate Matter


PPA	Purchased Power Agreement
PSCW	Public Service Commission of Wisconsin
ROE	Return on equity
~~Saratoga~~	~~Saratoga Wind Farm~~
~~SCR~~	~~Selective Catalytic Reduction~~
SEC	Securities and Exchange Commission
~~SIP~~	~~State Implementation Plan~~
SO2	Sulfur dioxide
Stock Plan	Direct Stock Purchase and Dividend Reinvestment Plan of MGE Energy
~~Two Creeks~~UFLPA	~~Two Creeks Solar Farm~~Uyghur Forced Labor Protection Act
USDOC	U.S. Department of Commerce
WCCF	West Campus Cogeneration Facility
WDNR	Wisconsin Department of Natural Resources
WEPCO	Wisconsin Electric Power Company, a subsidiary of WEC Energy Group, Inc.
West Riverside	West Riverside Energy Center in Beloit, Wisconsin
working capital	Current assets less current liabilities
WPDES	Wisconsin Pollutant Discharge Elimination System
WPL	Wisconsin Power and Light Company, a subsidiary of Alliant Energy Corporation
WRO	Withhold Release Order
XBRL	eXtensible Business Reporting Language

Item 1. Financial Statements.

MGE Energy, Inc.

Consolidated Statements of Income (unaudited)

(In thousands, except per share amounts)


	Three Months Ended						Nine Months Ended						Three Months Ended						Nine Months Ended
	September 30,						September 30,						September 30,						September 30,
	2022			2021			2022			2021			2023			2022			2023			2022
Operating Revenues:
Electric revenues	$	133,090		$	121,853		$	355,381		$	324,574		$	139,104		$	133,090		$	378,102		$	355,381
Gas revenues		30,310			24,020			169,305			119,944			21,424			30,310			147,677			169,305
Total Operating Revenues		163,400			145,873			524,686			444,518			160,528			163,400			525,779			524,686

Operating Expenses:
Fuel for electric generation		21,045			18,486			48,410			42,570			19,712			21,045			47,118			48,410
Purchased power		9,593			8,646			35,757			28,914			7,021			9,593			28,252			35,757
Cost of gas sold		14,523			8,780			100,638			57,728			5,160			14,523			80,296			100,638
Other operations and maintenance		49,194			48,494			150,714			144,563			53,997			49,194			156,004			150,714
Depreciation and amortization		21,447			18,991			63,780			55,968			25,241			21,447			74,971			63,780
Other general taxes		5,111			4,878			15,579			14,730			5,605			5,111			16,922			15,579
Total Operating Expenses		120,913			108,275			414,878			344,473			116,736			120,913			403,563			414,878
Operating Income		42,487			37,598			109,808			100,045			43,792			42,487			122,216			109,808

Other income, net		6,068			6,164			20,736			14,353			10,549			6,068			20,841			20,736
Interest expense, net		(6,652	)		(6,079	)		(19,686	)		(17,591	)		(7,654	)		(6,652	)		(22,901	)		(19,686	)
Income before income taxes		41,903			37,683			110,858			96,807			46,687			41,903			120,156			110,858
Income tax provision		(8,183	)		(2,766	)		(20,957	)		(4,106	)		(8,830	)		(8,183	)		(22,540	)		(20,957	)
Net Income	$	33,720		$	34,917		$	89,901		$	92,701		$	37,857		$	33,720		$	97,616		$	89,901

Earnings Per Share of Common Stock
Basic	$	0.93		$	0.97		$	2.49		$	2.56		$	1.05		$	0.93		$	2.70		$	2.49
Diluted	$	0.93		$	0.97		$	2.49		$	2.56		$	1.05		$	0.93		$	2.70		$	2.49

Dividends per share of common stock	$	0.408		$	0.388		$	1.183		$	1.128		$	0.428		$	0.408		$	1.243		$	1.183

Weighted Average Shares Outstanding
Basic		36,163			36,163			36,163			36,163			36,163			36,163			36,163			36,163
Diluted		36,176			36,170			36,174			36,176			36,189			36,176			36,185			36,174

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

MGE Energy, Inc.

Consolidated Statements of Cash Flows (unaudited)

(In thousands)


	Nine Months Ended						Nine Months Ended
	September 30,						September 30,
	2022			2021			2023			2022
Operating Activities:
Net income	$	89,901		$	92,701		$	97,616		$	89,901
Items not affecting cash:
Depreciation and amortization		63,780			55,968			74,971			63,780
Deferred income taxes		18,021			1,955			16,326			18,021
Provision for doubtful receivables		1,323			1,163			1,323			1,323
Employee benefit plan cost (credit)		(6,087	)		(935	)		(2,976	)		(6,087	)
Equity earnings in investments		(6,626	)		(7,440	)		(7,930	)		(6,626	)
Other items		(2,821	)		(618	)		(2,502	)		(2,821	)
Changes in working capital items:
Increase in current assets		(5,992	)		(11,240	)
(Decrease) increase in current liabilities		(5,831	)		4,429
Decrease (increase) in current assets								33,976			(5,992	)
(Decrease) increase in accounts payable								(16,586	)		66
Decrease in other current liabilities								(3,714	)		(5,897	)
Dividends from investments		5,964			5,842			6,305			5,964
Cash contributions to pension and other postretirement plans		(5,095	)		(4,823	)		(5,290	)		(5,095	)
Other noncurrent items, net		(2,255	)		4,295			2,519			(2,255	)
Cash Provided by Operating Activities		144,282			141,297			194,038			144,282

Investing Activities:
Capital expenditures		(133,409	)		(114,142	)		(150,298	)		(133,409	)
Capital contributions to investments		(3,938	)		(4,227	)		(5,986	)		(3,938	)
Other		128			22			(206	)		128
Cash Used for Investing Activities		(137,219	)		(118,347	)		(156,490	)		(137,219	)

Financing Activities:
Cash dividends paid on common stock		(42,763	)		(40,774	)		(44,933	)		(42,763	)
Repayments of long-term debt		(3,655	)		(3,567	)		(53,048	)		(3,655	)
Issuance of long-term debt		—			100,000			109,300			—
Proceeds from (repayments of) short-term debt		34,500			(52,500	)
(Repayments of) proceeds from short-term debt								(48,500	)		34,500
Other		(745	)		(1,503	)		(2,128	)		(745	)
Cash (Used for) Provided by Financing Activities		(12,663	)		1,656
Cash Used for Financing Activities								(39,309	)		(12,663	)

Change in cash, cash equivalents, and restricted cash		(5,600	)		24,606			(1,761	)		(5,600	)
Cash, cash equivalents, and restricted cash at beginning of period		18,835			47,039			17,968			18,835
Cash, cash equivalents, and restricted cash at end of period	$	13,235		$	71,645		$	16,207		$	13,235

Supplemental disclosures of cash flow information:
Significant noncash investing activities:
Accrued capital expenditures	$	11,218		$	8,213		$	17,716		$	11,218

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

MGE Energy, Inc.

Consolidated Balance Sheets (unaudited)

(In thousands)


	September 30,		December 31,		September 30,		December 31,
ASSETS	2022		2021		2023		2022
Current Assets:
Cash and cash equivalents	$	10,615	$	17,438	$	11,269	$	11,604
Accounts receivable, less reserves of $7,633 and $6,940, respectively		44,460		46,205
Other accounts receivable, less reserves of $1,069 and $1,364, respectively		13,863		16,094
Accounts receivable, less reserves of $6,082 and $7,050, respectively						43,819		55,407
Other accounts receivable, less reserves of $1,490 and $1,323, respectively						17,270		11,418
Unbilled revenues		22,975		34,812		24,687		43,086
Materials and supplies, at average cost		32,208		29,863		35,329		33,465
Fuel for electric generation, at average cost		7,021		6,429		9,492		7,962
Stored natural gas, at average cost		36,167		15,668		27,595		32,848
Prepaid taxes		13,106		20,214		13,856		19,132
Regulatory assets - current		3,685		1,465		18,308		9,541
Other current assets		15,747		11,183		14,786		19,017
Total Current Assets		199,847		199,371		216,411		243,480
Other long-term receivables		574		1,155
Regulatory assets		110,807		107,547		96,764		103,900
Pension benefit asset		71,104		58,757		74,087		68,872
Other deferred assets and other		24,888		27,548		21,485		24,365
Property, Plant, and Equipment:
Property, plant, and equipment, net		1,848,053		1,828,171		1,902,032		1,865,352
Construction work in progress		106,451		50,603		168,504		105,748
Total Property, Plant, and Equipment		1,954,504		1,878,774		2,070,536		1,971,100
Investments		103,962		98,754		111,249		105,883
Total Assets	$	2,465,686	$	2,371,906	$	2,590,532	$	2,517,600

LIABILITIES AND CAPITALIZATION
Current Liabilities:
Long-term debt due within one year	$	54,282	$	4,889	$	5,112	$	54,314
Short-term debt		40,000		5,500		22,000		70,500
Accounts payable		60,227		64,149		53,593		59,334
Accrued interest and taxes		7,819		10,385		7,368		7,868
Accrued payroll related items		10,464		12,951		13,155		13,064
Regulatory liabilities - current		14,611		9,365		13,462		11,925
Derivative liabilities		—		2,140
Other current liabilities		7,390		8,468		8,148		8,057
Total Current Liabilities		194,793		117,847		122,838		225,062
Other Credits:
Deferred income taxes		245,584		231,149		271,453		252,190
Investment tax credit - deferred		49,242		44,836		47,369		48,735
Regulatory liabilities		155,260		154,298		155,026		156,988
Accrued pension and other postretirement benefits		72,001		73,085		54,531		53,607
Finance lease liabilities		17,189		17,322		17,932		17,108
Other deferred liabilities and other		94,851		91,690		96,102		96,990
Total Other Credits		634,127		612,380		642,413		625,618
Capitalization:
Common shareholders' equity		1,075,200		1,027,468		1,135,253		1,081,674
Long-term debt		561,566		614,211		690,028		585,246
Total Capitalization		1,636,766		1,641,679		1,825,281		1,666,920
Commitments and contingencies (see Footnote 8)
Total Liabilities and Capitalization	$	2,465,686	$	2,371,906	$	2,590,532	$	2,517,600

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

MGE Energy, Inc.

Consolidated Statements of Common Equity (unaudited)

(In thousands, except per share amounts)


										Accumulated														Accumulated
					Additional					Other									Additional					Other
	Common Stock				Paid-in		Retained			Comprehensive					Common Stock				Paid-in		Retained			Comprehensive
	Shares		Value		Capital		Earnings			Income/(Loss)		Total
Three Months Ended September 30, 2021
Beginning Balance		36,163	$	36,163	$	394,686	$	576,452		$	—	$	1,007,301
Net income								34,917					34,917
Common stock dividends declared ($0.388 per share)								(14,013	)				(14,013	)
Equity-based compensation plans and other						80							80
Ending Balance - September 30, 2021		36,163	$	36,163	$	394,766	$	597,356		$	—	$	1,028,285
															Shares		Value		Capital		Earnings			Income/(Loss)		Total
Three Months Ended September 30, 2022
Beginning Balance		36,163	$	36,163	$	395,338	$	624,556		$	—	$	1,056,057			36,163	$	36,163	$	395,338	$	624,556		$	—	$	1,056,057
Net income								33,720					33,720									33,720					33,720
Common stock dividends declared ($0.408 per share)								(14,736	)				(14,736	)								(14,736	)				(14,736	)
Equity-based compensation plans and other						159							159							159							159
Ending Balance - September 30, 2022		36,163	$	36,163	$	395,497	$	643,540		$	—	$	1,075,200			36,163	$	36,163	$	395,497	$	643,540		$	—	$	1,075,200

Nine Months Ended September 30, 2021
Three Months Ended September 30, 2023
Beginning Balance		36,163	$	36,163	$	394,408	$	545,429		$	—	$	976,000			36,163	$	36,163	$	396,281	$	680,140		$	—	$	1,112,584
Net income								92,701					92,701									37,857					37,857
Common stock dividends declared ($1.128 per share)								(40,774	)				(40,774	)
Common stock dividends declared ($0.428 per share)																						(15,460	)				(15,460	)
Equity-based compensation plans and other						358							358							272							272
Ending Balance - September 30, 2021		36,163	$	36,163	$	394,766	$	597,356		$	—	$	1,028,285
Ending Balance - September 30, 2023																36,163	$	36,163	$	396,553	$	702,537		$	—	$	1,135,253

Nine Months Ended September 30, 2022
Beginning Balance		36,163	$	36,163	$	394,903	$	596,402		$	—	$	1,027,468			36,163	$	36,163	$	394,903	$	596,402		$	—	$	1,027,468
Net income								89,901					89,901									89,901					89,901
Common stock dividends declared ($1.183 per share)								(42,763	)				(42,763	)								(42,763	)				(42,763	)
Equity-based compensation plans and other						594							594							594							594
Ending Balance - September 30, 2022		36,163	$	36,163	$	395,497	$	643,540		$	—	$	1,075,200			36,163	$	36,163	$	395,497	$	643,540		$	—	$	1,075,200

Nine Months Ended September 30, 2023
Beginning Balance																36,163	$	36,163	$	395,657	$	649,854		$	—	$	1,081,674
Net income																						97,616					97,616
Common stock dividends declared ($1.243 per share)																						(44,933	)				(44,933	)
Equity-based compensation plans and other																				896							896
Ending Balance - September 30, 2023																36,163	$	36,163	$	396,553	$	702,537		$	—	$	1,135,253

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

Madison Gas and Electric Company

Consolidated Statements of Income (unaudited)

(In thousands)


	Three Months Ended						Nine Months Ended						Three Months Ended						Nine Months Ended
	September 30,						September 30,						September 30,						September 30,
	2022			2021			2022			2021			2023			2022			2023			2022
Operating Revenues:
Electric revenues	$	133,090		$	121,853		$	355,381		$	324,574		$	139,104		$	133,090		$	378,102		$	355,381
Gas revenues		30,310			24,020			169,305			119,944			21,424			30,310			147,677			169,305
Total Operating Revenues		163,400			145,873			524,686			444,518			160,528			163,400			525,779			524,686

Operating Expenses:
Fuel for electric generation		21,045			18,486			48,410			42,570			19,712			21,045			47,118			48,410
Purchased power		9,593			8,646			35,757			28,914			7,021			9,593			28,252			35,757
Cost of gas sold		14,523			8,780			100,638			57,728			5,160			14,523			80,296			100,638
Other operations and maintenance		48,989			48,315			150,024			143,978			53,847			48,989			155,251			150,024
Depreciation and amortization		21,447			18,991			63,780			55,968			25,241			21,447			74,971			63,780
Other general taxes		5,106			4,878			15,573			14,730			5,605			5,106			16,922			15,573
Total Operating Expenses		120,703			108,096			414,182			343,888			116,586			120,703			402,810			414,182
Operating Income		42,697			37,777			110,504			100,630			43,942			42,697			122,969			110,504

Other income, net		4,430			3,306			12,467			6,375			7,824			4,430			13,985			12,467
Interest expense, net		(6,662	)		(6,089	)		(19,709	)		(17,623	)		(7,721	)		(6,662	)		(23,056	)		(19,709	)
Income before income taxes		40,465			34,994			103,262			89,382			44,045			40,465			113,898			103,262
Income tax provision		(7,664	)		(1,993	)		(18,781	)		(1,853	)		(8,093	)		(7,664	)		(20,696	)		(18,781	)
Net Income	$	32,801		$	33,001		$	84,481		$	87,529		$	35,952		$	32,801		$	93,202		$	84,481
Less: Net Income Attributable to Noncontrolling Interest, net of tax		(5,603	)		(5,627	)		(15,947	)		(16,755	)		(5,487	)		(5,603	)		(16,382	)		(15,947	)
Net Income Attributable to MGE	$	27,198		$	27,374		$	68,534		$	70,774		$	30,465		$	27,198		$	76,820		$	68,534

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

Madison Gas and Electric Company

Consolidated Statements of Cash Flows (unaudited)

(In thousands)


	Nine Months Ended						Nine Months Ended
	September 30,						September 30,
	2022			2021			2023			2022
Operating Activities:
Net income	$	84,481		$	87,529		$	93,202		$	84,481
Items not affecting cash:
Depreciation and amortization		63,780			55,968			74,971			63,780
Deferred income taxes		17,706			1,375			15,218			17,706
Provision for doubtful receivables		1,323			1,163			1,323			1,323
Employee benefit plan cost (credit)		(6,087	)		(935	)		(2,976	)		(6,087	)
Other items		(636	)		864			(2,604	)		(636	)
Changes in working capital items:
Increase in current assets		(7,238	)		(11,777	)
(Decrease) increase in current liabilities		(3,642	)		2,528
Decrease (increase) in current assets								33,076			(7,238	)
(Decrease) increase in accounts payable								(16,583	)		64
Decrease in other current liabilities								(1,809	)		(3,706	)
Cash contributions to pension and other postretirement plans		(5,095	)		(4,823	)		(5,290	)		(5,095	)
Other noncurrent items, net		(2,806	)		3,559			1,840			(2,806	)
Cash Provided by Operating Activities		141,786			135,451			190,368			141,786

Investing Activities:
Capital expenditures		(133,409	)		(114,142	)		(150,298	)		(133,409	)
Other		(680	)		(1,449	)		(1,338	)		(680	)
Cash Used for Investing Activities		(134,089	)		(115,591	)		(151,636	)		(134,089	)

Financing Activities:
Cash dividends paid to parent by MGE		(21,000	)		—			(30,000	)		(21,000	)
Distributions to parent from noncontrolling interest		(17,500	)		(10,500	)		(17,250	)		(17,500	)
Repayments of long-term debt		(3,655	)		(3,567	)		(53,048	)		(3,655	)
Issuance of long-term debt		—			100,000			109,300			—
Proceeds from (repayments of) short-term debt		34,500			(52,500	)
(Repayments of) proceeds from short-term debt								(48,500	)		34,500
Other		(745	)		(1,503	)		(2,128	)		(745	)
Cash (Used for) Provided by Financing Activities		(8,400	)		31,930
Cash Used for Financing Activities								(41,626	)		(8,400	)

Change in cash, cash equivalents, and restricted cash		(703	)		51,790			(2,894	)		(703	)
Cash, cash equivalents, and restricted cash at beginning of period		7,798			6,404			10,500			7,798
Cash, cash equivalents, and restricted cash at end of period	$	7,095		$	58,194		$	7,606		$	7,095

Supplemental disclosures of cash flow information:
Significant noncash investing activities:
Accrued capital expenditures	$	11,218		$	8,213		$	17,716		$	11,218

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

Madison Gas and Electric Company

Consolidated Balance Sheets (unaudited)

(In thousands)


	September 30,		December 31,		September 30,		December 31,
ASSETS	2022		2021		2023		2022
Current Assets:
Cash and cash equivalents	$	4,475	$	6,401	$	2,668	$	4,136
Accounts receivable, less reserves of $7,633 and $6,940, respectively		44,460		46,205
Affiliate receivables		542		558
Other accounts receivable, less reserves of $1,069 and $1,364, respectively		13,862		16,092
Accounts receivable, less reserves of $6,082 and $7,050, respectively						43,819		55,407
Other accounts receivable, less reserves of $1,490 and $1,323, respectively						17,268		11,416
Unbilled revenues		22,975		34,812		24,687		43,086
Materials and supplies, at average cost		32,208		29,863		35,329		33,465
Fuel for electric generation, at average cost		7,021		6,429		9,492		7,962
Stored natural gas, at average cost		36,167		15,668		27,595		32,848
Prepaid taxes		13,488		19,379		14,055		18,467
Regulatory assets - current		3,685		1,465		18,308		9,541
Other current assets		15,679		11,071		15,284		19,479
Total Current Assets		194,562		187,943		208,505		235,807
Affiliate receivable long-term		1,191		1,589
Regulatory assets		110,807		107,547		96,764		103,900
Pension benefit asset		71,104		58,757		74,087		68,872
Other deferred assets and other		24,995		27,907		21,611		24,817
Property, Plant, and Equipment:
Property, plant, and equipment, net		1,848,081		1,828,199		1,902,060		1,865,380
Construction work in progress		106,451		50,603		168,504		105,748
Total Property, Plant, and Equipment		1,954,532		1,878,802		2,070,564		1,971,128
Investments		99		230		83		115
Total Assets	$	2,357,290	$	2,262,775	$	2,471,614	$	2,404,639

LIABILITIES AND CAPITALIZATION
Current Liabilities:
Long-term debt due within one year	$	54,282	$	4,889	$	5,112	$	54,314
Short-term debt		40,000		5,500		22,000		70,500
Accounts payable		60,206		64,130		53,578		59,317
Accrued interest and taxes		7,774		10,649		7,323		7,912
Accrued payroll related items		10,464		12,951		13,155		13,064
Regulatory liabilities - current		14,611		9,365		13,462		11,925
Derivative liabilities		—		2,140
Other current liabilities		7,389		5,968		8,148		6,062
Total Current Liabilities		194,726		115,592		122,778		223,094
Other Credits:
Deferred income taxes		213,005		198,885		237,414		219,258
Investment tax credit - deferred		49,242		44,836		47,369		48,735
Regulatory liabilities		155,260		154,298		155,026		156,988
Accrued pension and other postretirement benefits		72,001		73,085		54,531		53,607
Finance lease liabilities		17,189		17,322		17,932		17,108
Other deferred liabilities and other		95,926		92,152		98,198		98,217
Total Other Credits		602,623		580,578		610,470		593,913
Capitalization:
Common shareholder's equity		851,341		803,807		901,043		854,223
Noncontrolling interest		147,034		148,587		147,295		148,163
Total Equity		998,375		952,394		1,048,338		1,002,386
Long-term debt		561,566		614,211		690,028		585,246
Total Capitalization		1,559,941		1,566,605		1,738,366		1,587,632
Commitments and contingencies (see Footnote 8)
Total Liabilities and Capitalization	$	2,357,290	$	2,262,775	$	2,471,614	$	2,404,639

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

Madison Gas and Electric Company

Consolidated Statements of Equity (unaudited)

(In thousands)


										Accumulated																	Accumulated
					Additional					Other		Non-										Additional					Other		Non-
	Common Stock				Paid-in		Retained			Comprehensive		Controlling						Common Stock				Paid-in		Retained			Comprehensive		Controlling
	Shares		Value		Capital		Earnings			Income/(Loss)		Interest			Total
Three Months Ended September 30, 2021
Beginning balance		17,348	$	17,348	$	252,917	$	503,551		$	—	$	144,824		$	918,640
Net income								27,374					5,627			33,001
Distributions to parent from noncontrolling interest													(3,000	)		(3,000	)
Ending Balance - September 30, 2021		17,348	$	17,348	$	252,917	$	530,925		$	—	$	147,451		$	948,641
																		Shares		Value		Capital		Earnings			Income/(Loss)		Interest			Total
Three Months Ended September 30, 2022
Beginning balance		17,348	$	17,348	$	252,917	$	562,878		$	—	$	145,681		$	978,824			17,348	$	17,348	$	252,917	$	562,878		$	—	$	145,681		$	978,824
Net income								27,198					5,603			32,801									27,198					5,603			32,801
Cash dividends paid to parent by MGE								(9,000	)							(9,000	)								(9,000	)							(9,000	)
Distributions to parent from noncontrolling interest													(4,250	)		(4,250	)													(4,250	)		(4,250	)
Ending Balance - September 30, 2022		17,348	$	17,348	$	252,917	$	581,076		$	—	$	147,034		$	998,375			17,348	$	17,348	$	252,917	$	581,076		$	—	$	147,034		$	998,375

Nine Months Ended September 30, 2021
Three Months Ended September 30, 2023
Beginning balance		17,348	$	17,348	$	252,917	$	460,151		$	—	$	141,196		$	871,612			17,348	$	17,348	$	252,917	$	609,313		$	—	$	148,808		$	1,028,386
Net income								70,774					16,755			87,529									30,465					5,487			35,952
Cash dividends paid to parent by MGE																									(9,000	)							(9,000	)
Distributions to parent from noncontrolling interest													(10,500	)		(10,500	)													(7,000	)		(7,000	)
Ending Balance - September 30, 2021		17,348	$	17,348	$	252,917	$	530,925		$	—	$	147,451		$	948,641
Ending Balance - September 30, 2023																			17,348	$	17,348	$	252,917	$	630,778		$	—	$	147,295		$	1,048,338

Nine Months Ended September 30, 2022
Beginning balance		17,348	$	17,348	$	252,917	$	533,542		$	—	$	148,587		$	952,394			17,348	$	17,348	$	252,917	$	533,542		$	—	$	148,587		$	952,394
Net income								68,534					15,947			84,481									68,534					15,947			84,481
Cash dividends paid to parent by MGE								(21,000	)							(21,000	)								(21,000	)							(21,000	)
Distributions to parent from noncontrolling interest													(17,500	)		(17,500	)													(17,500	)		(17,500	)
Ending Balance - September 30, 2022		17,348	$	17,348	$	252,917	$	581,076		$	—	$	147,034		$	998,375			17,348	$	17,348	$	252,917	$	581,076		$	—	$	147,034		$	998,375

Nine Months Ended September 30, 2023
Beginning balance																			17,348	$	17,348	$	252,917	$	583,958		$	—	$	148,163		$	1,002,386
Net income																									76,820					16,382			93,202
Cash dividends paid to parent by MGE																									(30,000	)							(30,000	)
Distributions to parent from noncontrolling interest																														(17,250	)		(17,250	)
Ending Balance - September 30, 2023																			17,348	$	17,348	$	252,917	$	630,778		$	—	$	147,295		$	1,048,338

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

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

Notes to Consolidated Financial Statements (unaudited)

September 30, ~~2022~~2023

Summary of Significant Accounting Policies – MGE Energy and MGE.

Basis of Presentation.

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

MGE Power Elm Road and MGE Power West Campus own electric generating assets and lease those assets to MGE. Both entities are variable interest entities under applicable authoritative accounting guidance. MGE is considered the primary beneficiary of these entities as a result of contractual agreements. As a result, MGE has consolidated MGE Power Elm Road and MGE Power West Campus. See Footnote 3 of Notes to Consolidated Financial Statements under Item 8, Financial Statements and Supplementary Data, of MGE Energy's and MGE's ~~2021~~2022 Annual Report on Form 10-K (the ~~2021~~2022 Annual Report on Form 10-K).

The accompanying consolidated financial statements as of September 30, ~~2022,~~2023, 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 ~~2021~~2022 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 6157 through ~~115~~107 of the ~~2021~~2022 Annual Report on Form 10-K.

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				MGE Energy				MGE
	September 30,		December 31,		September 30,		December 31,		September 30,		December 31,		September 30,		December 31,
(In thousands)	2022		2021		2022		2021		2023		2022		2023		2022
Cash and cash equivalents	$	10,615	$	17,438	$	4,475	$	6,401	$	11,269	$	11,604	$	2,668	$	4,136
Restricted cash		651		847		651		847		645		867		645		867
Receivable - margin account		1,969		550		1,969		550		4,293		5,497		4,293		5,497
Cash, cash equivalents, and restricted cash	$	13,235	$	18,835	$	7,095	$	7,798	$	16,207	$	17,968	$	7,606	$	10,500

Cash Equivalents

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

Restricted Cash

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

Receivable – Margin Account

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

Property, Plant, and Equipment.

Columbia.

An asset that will be retired in the near future and substantially in advance of its previously expected retirement date is subject to abandonment accounting. In the second quarter of 2021, the operator of Columbia received approval from MISO to retire Columbia Units 1 and 2. The co-owners ~~initially intended~~intend to retire Unit 1 ~~by the end of 2023~~ and Unit 2 by ~~the end of 2024. In~~ June 2022, the target retirement date for both Units was updated to June 2026 after consideration by the owners of supply chain disruptions impacting the completion dates of current and planned renewable generation projects and the impact of those delays upon energy supply availability, reliability and cost. The postponement is not expected to affect MGE's goal to achieve 80% carbon reduction by 2030.2026. Final timing and retirement dates are subject to change depending on operational, regulatory, and other factors. As of September 30, ~~2022,~~2023, early retirement of Columbia was probable.

The net book value of our ownership share of this generating unit was $~~150.9~~133.0 million as of September 30, ~~2022.~~2023. This amount was classified as plant to be retired within "Property, plant, and equipment, net" on the consolidated balance sheets. Assets for Columbia Unit 1 and Unit 2 are currently included in rate base, and MGE continues to depreciate them on a straight-line basis using the composite depreciation rates approved by the PSCW that ~~included~~include retirement dates of 2029 for Unit 1 and 2038 for Unit 2. MGE is currently seeking approval from the PSCW in its 2023 electric rate case limited reopener to revise the depreciation schedule for Columbia Unit 2 to 2029 to align with Unit 1. See ~~Footnote 9~~ ~~for further details on MGE's rate proceedings.~~both Units.

If it becomes probable that regulators will disallow full recovery or a return on the remaining net book value of a generating unit that is either abandoned or probable of being abandoned, an impairment loss would be required. An impairment loss would be recorded to the extent that the remaining net book value of the generating unit exceeds the present value of the amount expected to be recovered from ratepayers. No impairment was recorded as of September 30, ~~2022.~~2023.

New Accounting Standards - MGE Energy and MGE.

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

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				Three Months Ended				Nine Months Ended
	September 30,				September 30,				September 30,				September 30,
(In thousands)	2022		2021		2022		2021		2023		2022		2023		2022
Equity earnings from investment in ATC	$	1,473	$	2,500	$	6,543	$	7,333	$	2,662	$	1,473	$	7,844	$	6,543
Dividends received from ATC		2,005		1,942		5,964		5,842		2,057		2,005		6,305		5,964
Capital contributions to ATC		536		—		2,319		—		1,075		536		3,033		2,319

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

In October ~~2022,~~2023, MGE Transco made a $~~0.4~~0.7 million capital contribution to ATC.

ATC's summarized financial data is as follows:


	Three Months Ended						Nine Months Ended						Three Months Ended						Nine Months Ended
	September 30,						September 30,						September 30,						September 30,
(In thousands)	2022			2021			2022			2021			2023			2022			2023			2022
Operating revenues	$	169,779		$	186,785		$	552,383		$	561,379		$	206,197		$	169,779		$	610,399		$	552,383
Operating expenses		(97,629	)		(91,340	)		(288,376	)		(278,828	)		(102,819	)		(97,629	)		(303,412	)		(288,376	)
Other income, net		272			123			1,020			1,164			701			272			1,657			1,020
Interest expense, net		(34,794	)		(28,674	)		(92,293	)		(86,337	)		(33,555	)		(34,794	)		(99,969	)		(92,293	)
Earnings before members' income taxes	$	37,628		$	66,894		$	172,734		$	197,378		$	70,524		$	37,628		$	208,675		$	172,734

MGE receives transmission and other related services from ATC. During the three and nine months ended September 30, ~~2022,~~2023, MGE recorded $8.5 million and $25.4 million, respectively, for transmission service compared to $7.9 million and $23.6 million ~~respectively, for transmission services compared to $8.0~~ ~~million and $24.0~~ ~~million~~ for comparable periods in ~~2021.~~2022. MGE also provides a variety of operational, maintenance, and project management work for ATC, which is reimbursed by ATC. As of September 30, ~~2022,~~2023, and December 31, ~~2021,~~2022, MGE had a receivable due from ATC of $~~4.6~~5.3 million and $~~7.0~~4.8 million, respectively. The receivable is primarily related to transmission interconnection activities at Badger Hollow and Paris solar generation sites. MGE will be reimbursed for these costs after the new generation assets are placed into service.

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								MGE Energy								MGE
Three Months Ended September 30,	2022				2021				2022				2021				2023				2022				2023				2022
Statutory federal income tax rate		21.0		%		21.0		%		21.0		%		21.0		%		21.0		%		21.0		%		21.0		%		21.0		%
State income taxes, net of federal benefit		6.2				6.2				6.2				6.2				6.2				6.2				6.2				6.2
Amortized investment tax credits		(0.6	)			(1.2	)			(0.7	)			(1.3	)			(0.6	)			(0.6	)			(0.6	)			(0.7	)
Credit for electricity from wind energy		(4.9	)			(4.8	)			(5.2	)			(5.2	)
Credit for electricity from renewable energy																		(4.9	)			(4.9	)			(5.2	)			(5.2	)
AFUDC equity, net		(0.4	)			(1.1	)			(0.4	)			(1.2	)			(0.9	)			(0.4	)			(1.0	)			(0.4	)
Amortization of utility excess deferred tax - tax reform(a)		(1.7	)			(12.4	)			(1.8	)			(13.5	)			(1.4	)			(1.7	)			(1.5	)			(1.8	)
Other, net, individually insignificant		(0.1	)			(0.4	)			(0.2	)			(0.3	)			(0.5	)			(0.1	)			(0.5	)			(0.2	)
Effective income tax rate		19.5		%		7.3		%		18.9		%		5.7		%		18.9		%		19.5		%		18.4		%		18.9		%

																	MGE Energy								MGE
Nine Months Ended September 30,																	2023				2022				2023				2022
Statutory federal income tax rate																		21.0		%		21.0		%		21.0		%		21.0		%
State income taxes, net of federal benefit																		6.3				6.2				6.3				6.2
Amortized investment tax credits																		(0.7	)			(0.7	)			(0.7	)			(0.7	)
Credit for electricity from renewable energy																		(5.4	)			(5.3	)			(5.7	)			(5.7	)
AFUDC equity, net																		(0.6	)			(0.4	)			(0.7	)			(0.5	)
Amortization of utility excess deferred tax - tax reform(a)																		(1.6	)			(1.8	)			(1.7	)			(1.9	)
Other, net, individually insignificant																		(0.2	)			(0.1	)			(0.3	)			(0.2	)
Effective income tax rate																		18.8		%		18.9		%		18.2		%		18.2		%

MGE Energy

MGE
Nine Months Ended September 30,

2022

2021

2022

2021
Statutory federal income tax rate

21.0

%

21.0

%

21.0

%

21.0

%
State income taxes, net of federal benefit

6.2

6.2

6.2

6.2

Amortized investment tax credits

(0.7
)

(1.4
)

(0.7
)

(1.5
)

Credit for electricity from wind energy

(5.3
)

(6.0
)

(5.7
)

(6.6
)

AFUDC equity, net

(0.4
)

(1.0
)

(0.5
)

(1.1
)

Amortization of utility excess deferred tax - tax reform(a)

(1.8
)

(14.5
)

(1.9
)

(15.9
)

Other, net, individually insignificant

(0.1
)

(0.1
)

(0.2
)

—

Effective income tax rate

18.9

%

4.2

%

18.2

%

2.1

%

(a)

Included are impacts of the 2017 Tax Act for the regulated utility for excess deferred taxes recognized using a normalization method of accounting in recognition of IRS rules that restrict the rate at which the excess deferred taxes may be returned to utility customers. For the three months ended September 30, ~~2022~~2023 and ~~2021,~~2022, MGE recognized $~~1.0~~0.9 million and $~~0.7~~1.0 million, respectively. For the nine months ended September 30, ~~2022~~2023 and ~~2021,~~2022, MGE recognized $~~2.9~~2.7 million and $~~2.0~~ million, respectively. Included in the 2021 rate settlement was a one-time return to customers of the electric portion of excess deferred taxes related to the 2017 Tax Act not restricted by IRS normalization rules. For the three and nine months ended September 30, 2021, MGE recognized $~~3.3~~ ~~million and $9.9~~2.9 million, respectively. Included in the 2022 and 2023 rate settlement was a net collection from customers of the gas portion of deficient deferred taxes related to the 2017 Tax Act not restricted by IRS normalization rules. For both the three ~~and nine~~ months ended September 30, 2023 and 2022, MGE recognized $0.3 ~~million~~million. For both the nine months ended September 30, 2023 and 2022, MGE recognized $1.0 ~~million, respectively.~~million.

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						Three Months Ended						Nine Months Ended
	September 30,						September 30,						September 30,						September 30,
(In thousands)	2022			2021			2022			2021			2023			2022			2023			2022
Pension Benefits
Components of net periodic benefit cost:
Service cost	$	1,266		$	1,432		$	3,798		$	4,296		$	723		$	1,266		$	2,169		$	3,798
Interest cost		2,791			2,280			8,371			6,840			4,330			2,791			12,989			8,371
Expected return on assets		(7,848	)		(7,372	)		(23,543	)		(22,115	)		(6,312	)		(7,848	)		(18,936	)		(23,543	)
Amortization of:
Prior service credit		(5	)		(31	)		(15	)		(93	)		—			(5	)		—			(15	)
Actuarial loss		604			1,662			1,812			4,985			440			604			1,320			1,812
Net periodic benefit (credit) cost	$	(3,192	)	$	(2,029	)	$	(9,577	)	$	(6,087	)	$	(819	)	$	(3,192	)	$	(2,458	)	$	(9,577	)

Postretirement Benefits
Components of net periodic benefit cost:
Service cost	$	323		$	362		$	970		$	1,086		$	195		$	323		$	585		$	970
Interest cost		485			387			1,455			1,161			827			485			2,481			1,455
Expected return on assets		(842	)		(819	)		(2,524	)		(2,457	)		(649	)		(842	)		(1,946	)		(2,524	)
Amortization of:
Transition obligation		1			1			2			2			1			1			2			2
Prior service credit		(74	)		(379	)		(223	)		(1,138	)		—			(74	)		—			(223	)
Actuarial loss		37			123			109			370
Actuarial (gain) loss														(48	)		37			(143	)		109
Net periodic benefit (credit) cost	$	(70	)	$	(325	)	$	(211	)	$	(976	)	$	326		$	(70	)	$	979		$	(211	)

As approved by the PSCW, MGE is allowed to defer differences between actual employee benefit plan costs and costs reflected in current rates. The deferred costs may be recovered or refunded in MGE's next rate filing. During the three and nine months ended September 30, 2023, MGE deferred $1.6 million and $2.4 million, respectively, of pension and other postretirement costs. During the three and nine months ended September 30, 2022, MGE recovered $0.2 million and $0.8 million, respectively, of pension and other postretirement costs ~~respectively, compared to approximately $0.3~~ ~~million and $3.9~~ ~~million for the comparable periods in 2021. The recovery of these~~previously deferred. These costs ~~reduced the amount previously deferred and has not been reflected in the table above.~~

~~During the three and nine months ended September 30, 2022, MGE deferred and recorded as a regulatory liability $0.3~~ ~~million and $1.1~~ ~~million, respectively, of savings from employee benefit plan costs compared to $2.8~~ ~~million and $5.4~~ ~~million for the comparable periods in 2021. During the three and nine months ended September 30, 2022, MGE refunded in rates $1.0~~ ~~million and $3.1~~ ~~million, respectively, of savings from 2021 employee benefit plan costs. The deferred savings has~~have not been reflected in the table above.

Equity and Financing Arrangements.

Common Stock - MGE Energy.

Shares of MGE Energy ~~sells shares of its~~ common stock are sold through ~~its~~MGE Energy's Direct Stock Purchase and Dividend Reinvestment Plan (the Stock Plan). Those shares may be newly issued shares or shares that are purchased in the open market by an independent agent for participants in the Stock Plan. Sales of newly issued shares under the Stock Plan are covered by a shelf registration statement that MGE Energy filed with the SEC.

During the three and nine months ended September 30, ~~2022~~2023 and ~~2021,~~2022, MGE Energy issued no new shares of common stock under the Stock Plan.

Dilutive Shares Calculation - MGE Energy.

As of September 30, ~~2022,~~2023, ~~10,331~~21,423 shares were included in the calculation of diluted earnings per share related to nonvested equity awards. See Footnote 7 for additional information on share-based compensation awards.

Long-Term Debt ~~Issuance~~ - MGE Energy and MGE.

~~On November 1, 2022,~~In March 2023, $19.3 million of City of Madison, Wisconsin Industrial Development Revenue Refunding Bonds (Madison Gas and Electric Company Project), Series 2020A were remarketed. As a result of the remarketing, the Series 2020A Bonds will carry an interest rate of 3.75% per annum over its remaining 5-year life. The remarketed Series 2020A Bonds will not be subject to further remarketing or optional redemption prior to their maturity.

In August 2023, MGE entered into a private placement Note Purchase Agreement in which it committed to issue $2540 million of new long-term debt (Series A), carrying an interest rate of ~~5.43~~5.61% per annum over its ~~10-year~~11-year life, and $1530 million of new long-term debt (Series B), carrying an interest rate of ~~5.43~~5.91% per

annum over its ~~10-year life, and $~~35 ~~million of new long-term debt (Series C), carrying an interest rate of~~ ~~5.53% per annum over its 12-year~~30-year life. Funding ~~will~~occurred on September 13, 2023, for Series A and funding for Series B is expected to occur on December 1, ~~2022 for Series A and on February 28, 2023 for Series B and Series C.~~2023. The proceeds of the debt financing ~~will be~~were used to repay at maturity $30 million long-term debt due September 15, 2023, and will assist with capital expenditures and other corporate obligations. The covenants of this debt are substantially consistent with MGE's existing unsecured ~~long-term debt.~~senior notes.

Share-Based Compensation - MGE Energy and MGE.

During the three and nine months ended September 30, ~~2022,~~2023, MGE recorded less than $0.1 million and $1.8 million, respectively, in compensation expense related to share-based compensation awards compared to $0.6 million in compensation benefit and $0.1 million in compensation expense respectively, related to share-based compensation awards under the 2006 Performance Unit Plan, the 2020 Performance Unit Plan, the 2013 Director Incentive Plan, and the 2021 Long-Term Incentive Plan (2021 Plan) compared to $~~0.3~~ ~~million and $1.6~~ ~~million in compensation expense~~ for the comparable periods in ~~2021.~~2022.

In ~~January 2022,~~the first quarter of 2023, cash payments of $~~1.8~~3.6 million were distributed related to awards that were granted in ~~2019~~2020 under the 2013 Director Incentive Plan, ~~and in 2017~~2018 under the 2006 Performance Unit Plan, and 2020 under the 2020 Performance Unit Plan.

In ~~February 2022,~~March 2023, MGE issued ~~10,395~~11,320 performance units and ~~15,931~~20,472 restricted stock units under the 2021 Plan to eligible employees and non-employee directors.

MGE recognizes stock-based compensation expense on a straight-line basis over the requisite service period. Awards classified as equity awards are measured based on their grant-date fair value. Awards classified as liability awards are recorded at fair value each reporting period. The performance units can be paid out in either cash, shares of common stock or a combination of cash and stock and are classified as a liability award. The restricted stock units will be paid out in shares of common stock, and therefore are classified as equity awards.

Commitments and ~~Contingencies.~~

~~Environmental~~Contingencies - MGE Energy and MGE.

Environmental.

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

MGE Energy and MGE are subject to frequently changing local, state, and federal regulations concerning air quality, water quality, land use, threatened and endangered species, hazardous materials handling, and solid waste disposal. These regulations affect the manner in which operations are conducted, the costs of operations, as well as capital and operating expenditures. Several of these

environmental rules are subject to legal challenges, reconsideration and/or other uncertainties. Regulatory initiatives, proposed rules, and court challenges to adopted rules could have a material

effect on capital expenditures and operating costs. Management believes compliance costs will be recovered in future rates based on previous treatment of environmental compliance projects.

These initiatives, proposed rules, and court challenges include:

•

The EPA's promulgated water Effluent Limitations Guidelines (ELG) and standards for steam electric power plants which focus on the reduction of metals and other pollutants in wastewater from new and existing power plants.

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

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

In March 2023, the EPA published a proposed update to this rule that further regulates the wastewater discharges associated with coal-fired power plants. The proposed rule focuses on wastewater discharges from flue gas desulfurization, bottom ash transport water, and combustion residual leachate. The proposed rule includes some flexibility for plants that have already installed pollution controls based on previous versions of the rule, and flexibility for plants that will be retiring or switching to natural gas by certain dates. MGE expects this rule, if finalized as proposed, to impact our Elm Road Units. However, we will not know the impact of this rule with any certainty until the rule is finalized.

•

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

Blount received its most recent WPDES permit from the Wisconsin Department of Natural Resources (WDNR) in October 2023. Blount's latest WPDES permit assumes that the plant meets BTA standards for entrainment for the duration of ~~the~~this permit which expires in ~~2023. Before the next permit renewal, MGE is required~~2028. The WDNR included a requirement to ~~complete~~conduct an ~~entrainment study and recommend a BTA along with alternative technologies considered. MGE completed the entrainment~~impingement study in ~~2021 and submitted~~ the ~~results to the WDNR. The WDNR will make the final BTA determination and include any BTA requirements in Blount's next~~latest permit ~~renewal,~~ which ~~is expected~~needs to be completed byin the ~~end of 2022 and effective in 2023. Management believes that~~next three years. Once the ~~BTA determination~~WDNR determines the impingement requirements at Blount, MGE will ~~not~~ be ~~material for MGE.~~able to determine any compliance costs of meeting Blount's permit requirements.

~~Columbia's river intakes~~Intakes at Columbia are subject to this rule. ~~Columbia's operator received a~~The Columbia operator's most recent permit ~~in 2019 requiring~~requires that studies of intake structures to be submitted to the WDNR by November 2023 to help determine BTA. Columbia's permit renewal application is due in 2024. BTA improvements may be limited or not be required in the renewal permit given ~~that~~ the ~~owners are planning~~owners' plan to retire both units by June of 2026. MGE will continue to work with Columbia's operator to evaluate ~~all~~ regulatory requirements ~~applicable to~~in light of the planned retirements.

MGE does not expect this rule to have a material effect on ~~its existing plants.~~Columbia.

•

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

In ~~October 2021, as part~~May 2023, the EPA proposed a rule under section 111 of the ~~Biden administration's Unified Agenda, the EPA announced its intention~~Clean Air Act to ~~issue a new rule~~establish NSPS and emission guidelines to ~~reduce greenhouse gas~~limit GHG emissions from existing fossil fuel-fired ~~EGUs. In June 2022, the U.S. Supreme Court held that the Clean Air Act does not authorize the~~EGUs and new, modified, and/or reconstructed fossil fuel-fired power plants. The EPA ~~to regulate GHG emissions using generation shifting (e.g., shifting from coal to natural gas and/or renewable generation sources). MGE will continue to evaluate greenhouse gas~~anticipates promulgating a final rule ~~developments, including any new EPA actions towards rule development, and any further court decisions on the EPA~~in'~~s authority to regulate greenhouse gases.~~

2024. MGE fossil fuel-fired generation units would be subject to the rule as proposed. MGE expects larger-sized units with long range retirement plans, West Riverside and the Elm Road units, may need to employ technology to achieve reduction. Columbia may not be impacted due to the owners' planned retirement of the existing fossil fuel fired units by 2026. However, we will not know the impact of this rule with any certainty until the rule is finalized.

•

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

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

•

The EPA's proposed rule to regulate Fine Particulate Matter (PM2.5).

In January 2023, the EPA published a proposed rule to lower the average annual PM2.5 NAAQS from its current level. The EPA has also solicited comments on whether to lower the annual standard further than the proposed level, and whether to lower the maximum 24-hour limit to be consistent with recommendations from its Clean Air Scientific Advisory Committee (CASAC). Neither the proposed annual PM2.5 NAAQS nor the 24-hour limit recommended by the CASAC are expected to impact the counties where Columbia and the Elm Road Units are located. However, if the annual PM2.5 NAAQS is lowered further than the EPA's currently proposed value, Milwaukee County may be in nonattainment with the standard. A nonattainment designation would require the State of Wisconsin to develop a plan to get into attainment, which may include additional emission limitations for the Elm Road units. However, we will not know the impact of this rule until it is finalized, the EPA determines the attainment status of Wisconsin counties, and the State of Wisconsin develops an attainment implementation plan. MGE will continue to follow the rule's developments.

•

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

The EPA's CSAPR and its progeny are a suite of interstate air pollution transport rules designed to reduce ozone and ~~fine particulate (PM2.5)~~PM2.5 ambient air levels in areas that the EPA has determined as being significantly impacted by pollution from upwind states. This is accomplished ~~in the CSAPR~~ through a reduction in SONO2x and NOSOx2 from qualifying fossil-fuel fired power plants and industrial boilers in upwind "contributing" states. NOxand SO2 contribute to fine particulate pollution and NOxcontributes to ozone formation in downwind areas. Reductions are generally achieved through a cap-and-trade system. Individual plants can meet their caps through reducing emissions and/or buying allowances on the market.

In ~~April 2022,~~March 2023, the EPA ~~published a proposed~~finalized its Federal Implementation Plan (FIP) to address state obligations under the Clean Air Act "good neighbor" provisions for the 2015 Ozone NAAQS. ~~This proposed~~The final rule impacts 2623 states, including ~~Wisconsin, and is designed to both revise the current NO~~x ~~CSAPR ozone season cap-and-trade obligations for fossil-fuel generated power plants and add NO~~x ~~limitations for certain industries in specified states.~~Wisconsin. For Wisconsin, the ~~proposed~~ rule includes revisions to the current obligations for fossil-fuel power generation, ~~as well as~~which includes Blount, Columbia, the ~~new limitations for certain industries.~~

~~If finalized, the proposed~~Elm Road Units, WCCF, West Riverside, and West Marinette. The final rule ~~would be~~became effective ~~beginning with~~partway through the 2023 ozone season ~~and start with emissions~~in August 2023. Emissions budgets ~~that~~ can be ~~achieved~~met with ~~what the EPA has defined as~~planned retirements, fuel switching, and immediately available measures, including consistently operating emissions controls already installed at power plants. MGE expects to meet the emission reductions with immediately available measures. In 2026, additional obligations would go into effect, including ~~potential daily~~a further reduction in emissions ~~limits and technology upgrades to coal-fired power plants without existing emission controls.~~budgets. Wisconsin would need to submit a ~~SIP~~State Implementation Plan to meet its obligations or accept the EPA's ~~proposed~~ FIP.

MGE ~~has met its~~is reviewing the final rule. Based on our current ~~CSAPR obligations through a combination of reduced emissions through pollution control (e.g., SCR installation at Columbia),~~evaluation, the 2026 additional emission reductions may impact the Elm Road Units and ~~owned, received, and purchased allowances. MGE expects the rule, if finalized as written,~~additional upgrades may be needed to ~~impact our fossil-fueled generation assets. However,~~comply, however, we will not know the final impact ~~of this rule with any certainty~~ until ~~it is finalized. We will continue to monitor rule developments.~~evaluations are completed.

•

The EPA's Coal Combustion Residuals (CCR) Rule.

The CCR rule regulates ~~as a~~the disposal of solid waste coal ash ~~from burning coal for the purpose of generating electricity~~ and defines what ash use activities would be considered generally exempt beneficial reuse of coal ash. The CCR rule also regulates landfills, ash ponds, and other surface impoundments used for coal combustion residuals by regulating their design, location, monitoring, and operation. The CCR rule requires owners or operators of coal-fired power plants to stop transporting CCR and non-CCR wastewater to unlined surface impoundments. In addition, regulated entities must initiate impoundment closure as soon as feasible and in no event later than April 2021, unless the EPA grants an extension. A site-specific extension to initiate closure of the primary ash pond at Columbia by ~~December~~March 31, ~~2022~~2023, was ~~requested.~~requested, and was met. The EPA has ~~not formally approved~~confirmed that Columbia met the ~~extension.~~required extension requirements, has documented that Columbia ceased the receipt of waste on March 23, 2023, and has noted that Columbia's obligations under this portion of the CCR Rule are now complete.

In July 2021, the PSCW approved a CA application filed by MGE and the other owners of Columbia to install technology required to cease bottom ash transport water discharges rather than extend the longevity of the ash ponds. ~~Construction of the~~The coal combustion residuals system that ~~will replace~~replaced the unlined surface impoundment ~~is undergoing final testing. Construction is expected to be completed by the end of 2022.~~was placed in-service in March 2023. MGE's share of the costs of the project is ~~expected to be~~ approximately $4 million.

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

In May 2023, the EPA proposed a CCR Legacy Rule that if finalized as currently written, will apply to previously closed CCR sites. Columbia's operator would likely need to complete a site evaluation to determine if the CCR Legacy Rule applies to Columbia's previously closed site. MGE is currently evaluating this proposed rule. However, we will not know the impact of this rule with any certainty until the rule is finalized.

Legal ~~Matters - MGE Energy and MGE.~~Matters.

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

Certain environmental groups filed petitions against the PSCW ~~regarding~~challenging the fixed customer charge set in MGE's ~~two most recent~~2022/2023 rate ~~settlements.~~settlement and 2023 electric limited reopener. MGE has intervened in the petitions in cooperation with the PSCW. See Footnote 9.a. for more information regarding this matter.

Purchase ~~Contracts - MGE Energy and MGE.~~Contracts.

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, ~~2022:~~2023:


(In thousands)	2022		2023		2024		2025		2026		Thereafter		2023		2024		2025		2026		2027		Thereafter
Coal(a)	$	11,461	$	26,323	$	18,216	$	9,043	$	2,922	$	—	$	8,511	$	23,173	$	14,425	$	2,581	$	—	$	—
Natural gas(b)														20,009		41,502		25,517		14,873		2,165		11,995
Transportation and storage(b)		9,069		31,660		31,660		31,660		18,265		14,449
Supply(c)		24,959		25,682		—		—		—		—
Renewable energy(d)		5,847		3,108		2,025		2,040		2,056		28,529
	$	51,336	$	86,773	$	51,901	$	42,743	$	23,243	$	42,978	$	28,520	$	64,675	$	39,942	$	17,454	$	2,165	$	11,995

(a)

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

(b)

MGE's natural gas transportation and storage contracts require fixed monthly payments for firm supply pipeline transportation and storage capacity. The pricing components of the fixed monthly payments for the transportation and

storage contracts are ~~established~~approved by FERC but may be subject to change.

~~(c)~~

~~These~~ MGE's natural gas supply commitments include market-based pricing.

~~(d)~~

~~Operational commitments for solar and wind facilities.~~

Rate Matters - MGE Energy and MGE.

Rate Proceedings.


	Rate increase	Return on Common Equity	Common Equity Component of Regulatory Capital Structure	Effective Date	Rate increase	Return on Common Equity	Common Equity Component of Regulatory Capital Structure	Effective Date
Approved 2021 settlement(a)
Electric	—%	9.8%	55.8%	1/1/2021
Gas	4.00%	9.8%	55.8%	1/1/2021
Approved 2022/2023 settlement(b)
Approved 2022/2023 settlement(a)
Electric	8.81%	9.8%	55.6%	1/1/2022	8.81%	9.8%	55.6%	1/1/2022
Gas	2.15%	9.8%	55.6%	1/1/2022	2.15%	9.8%	55.6%	1/1/2022
Gas	0.96%	9.8%	55.6%	1/1/2023	0.96%	9.8%	55.6%	1/1/2023
Proposed limited 2023 reopener(c)
Approved limited 2023 reopener(b)
Electric	4.38%	9.8%	55.6%	1/1/2023	9.01%	9.8%	55.6%	1/1/2023
Proposed 2024/2025 rate proceeding(c)
Electric(d)					3.75%	9.8%	56.1%	1/1/2024
Gas(d)					2.56%	9.8%	56.1%	1/1/2024
Electric(e)					3.41%	9.8%	56.1%	1/1/2025
Gas(e)					1.66%	9.8%	56.1%	1/1/2025

(a)

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

~~(b)~~

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

~~(c)~~(b)

The electric rate increase iswas driven by additions to generation assets including our investments in Badger Hollow II (solar), Paris (solar and battery), Red Barn (wind), and West Riverside (natural gas). In addition, the reopener request ~~includes a reduction~~included an increase in fuel costs ~~which MGE has partially offset with~~and the recovery of deferred 2021 fuel costs. ~~Changes in the fuel forecast are updated in the limited reopener filing prior to the final PSCW approval.~~ The reopener also ~~revises~~revised the depreciation schedule for Columbia Unit 2 and shared equipment to 2029 to align with the depreciation schedule for ~~Columbia~~ Unit 1.

(c)

In April 2023, MGE filed a proposed 2-year rate case and PSCW approval is pending. In October 2023, MGE filed an updated 2024 fuel cost forecast with the PSCW which will decease forecasted fuel costs filed in the original rate application and reduce the rates ultimately approved. That reduction is not reflected in the proposed rates in the table above. MGE will file an updated 2025 fuel forecast with the PSCW in 2024 which may impact rates in 2025, depending on any variance between the forecast submitted as a part of the proposed rates and updated forecast. MGE has also requested to update renewable project construction costs to include force majeure claims and changes to in-service dates for projects under construction or to begin construction during 2024 and 2025. These renewable project updates have not been reflected in the proposed rates in the table above. Staff audit is completed, and a PSCW decision is expected in November 2023 ~~limited reopener is pending. A~~with a final order is expected before the end of 2023. MGE cannot predict with any certainty the ~~year.~~final outcome of the rate proceeding.

(d)

The proposed electric rate increase is driven by an increase in rate base including our investments made in West Riverside, local solar, and continued investment in grid modernization. Also driving the requested electric increase are higher costs for transmission, pension and OPEB, and uncollectible costs (including costs previously deferred from prior years). This increase in electric costs is offset by a decrease in fuel costs and benefit from lower tax expense (including impacts from the Inflation Reduction Act). The proposed gas rate increase is also attributable to our investment made in grid modernization and higher pension and OPEB and uncollectible costs (including costs previously deferred from prior years). The proposed gas increase is offset by a tax benefit related to excess deferred taxes. In total for both electric and gas rates, MGE has requested recovery of $9.7 million of incremental uncollectible costs deferred from the periods 2020 through 2023. Regulated entities are allowed to defer certain costs that would otherwise be charged to expense if the regulated entity believes the recovery of those costs is probable. Recovery of the deferred costs in future rates is subject to the review and approval by the PSCW. Any disallowance of previously deferred costs would be charged to income in the current period.

(e)

The proposed electric and gas rate increases are driven by an increase in rate base for our continued investment in grid modernization projects and an increase in labor costs.

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

settlement, and Sierra Club and Vote Solar have now appealed that decision to the Wisconsin Court of Appeals.

Fuel Rules.

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


	Fuel Costs (in millions)	Refund or Recovery Period
~~2019 deferred fuel savings~~	$(~~1.5~~)~~(a)~~	~~January 2021 through December 2021~~
~~2020 deferred fuel savings~~	$(~~3.2~~)~~(a)~~	~~October 2021~~
2021 deferred fuel costs	$3.3(a)	January 2023 through December 2023(b)
2022 deferred fuel costs	$~~4.4~~8.8(a)	October 2023 through September 2024(c)
2023 deferred fuel savings	($4.3)	(d)

(a)

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

(b)

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

(c)

In August 2023, the PSCW issued a final decision in the 2022 fuel rules proceedings for MGE.

(d)

These costs will be subject to the PSCW's annual review of ~~2022~~2023 fuel costs, expected to be completed in ~~2023.~~2024.

10.

Derivative and Hedging Instruments - MGE Energy and MGE.

Purpose.

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

Notional Amounts.

The gross notional volume of open derivatives is as follows:

September 30, 2022

December 31, 2021

September 30, 2023

December 31, 2022

Commodity derivative contracts

293,200

MWh

278,000

MWh

384,080

MWh

353,600

MWh

Commodity derivative contracts

8,235,000

Dth

5,735,000

Dth

7,780,000

Dth

8,070,000

Dth

FTRs

3,015

2,127

2,901

1,945

PPA

—

250

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, ~~2022,~~2023, and December 31, ~~2021,~~2022, the ~~fair value~~cost basis of exchange traded derivatives and FTRs exceeded their ~~cost basis~~fair value by $~~5.2~~2.5 million and $~~2.8~~5.1 million, respectively.

MGE was a party to a purchased power agreement that provided MGE with firm capacity and energy during a base term from June 1, 2012, through May 31, 2022. The agreement was accounted for as a derivative contract and was recognized at its fair value on the consolidated balance sheets. However,

the derivative qualified for regulatory deferral and was recognized with a corresponding regulatory asset or liability depending on whether the fair value was in a loss or gain position. The actual cost was recognized in purchased power expense in the month of purchase.

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


	Derivative		Derivative			Derivative		Derivative
(In thousands)	Assets		Liabilities		Balance Sheet Location	Assets		Liabilities		Balance Sheet Location
September 30, 2022
September 30, 2023
Commodity derivative contracts(a)	$	8,793	$	4,533	Other current assets	$	837	$	3,424	Other current liabilities
Commodity derivative contracts(a)		932		81	Other deferred charges		115		413	Other deferred liabilities and other
FTRs		102		—	Other current assets		337		—	Other current assets

December 31, 2021
Commodity derivative contracts(b)	$	2,959	$	811	Other current assets
Commodity derivative contracts(b)		420		38	Other deferred charges
December 31, 2022
Commodity derivative contracts(a)						$	2,164	$	7,687	Other current liabilities
Commodity derivative contracts(a)							802		476	Other deferred liabilities and other
FTRs		227		—	Other current assets		103		—	Other current assets
PPA	N/A			2,140	Derivative liability (current)

(a)

NoAs of September 30, 2023, and December 31, 2022, collateral of $2.9 ~~collateral~~million and $5.2 million, respectively, was posted against and netted with derivative liability positions ~~as of September 30, 2022.~~

~~(b)~~

~~As of December 31, 2021, MGE received collateral of $1.3~~ ~~million from counterparties under a master netting agreement for outstanding exchange traded derivative positions.~~on the consolidated balance sheets. The fair value of the derivative ~~asset~~liability disclosed in this table has not been reduced for the collateral ~~received.~~posted.

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		Gross Amounts		Gross Amounts Offset in Balance Sheets			Collateral Posted Against Derivative Positions		Net Amount Presented in Balance Sheets
September 30, 2022
September 30, 2023
Commodity derivative contracts	$	9,725	$	(4,614	)	$	—		$	5,111	$	952	$	(952	)	$	—	$	—
FTRs		102		—			—			102		337		—			—		337

December 31, 2021
December 31, 2022
Commodity derivative contracts	$	3,379	$	(849	)	$	(1,254	)	$	1,276	$	2,966	$	(2,966	)	$	—	$	—
FTRs		227		—			—			227		103		—			—		103

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		Gross Amounts		Gross Amounts Offset in Balance Sheets			Collateral Posted Against Derivative Positions			Net Amount Presented in Balance Sheets
September 30, 2022
September 30, 2023
Commodity derivative contracts	$	4,614	$	(4,614	)	$	—	$	—	$	3,837	$	(952	)	$	(2,885	)	$	—

December 31, 2021
December 31, 2022
Commodity derivative contracts	$	849	$	(849	)	$	—	$	—	$	8,163	$	(2,966	)	$	(5,197	)	$	—
PPA		2,140		—			—		2,140

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


	2022						2021						2023						2022
(In thousands)	Current and Long-Term Regulatory Asset (Liability)			Other Current Assets			Current and Long-Term Regulatory Asset (Liability)			Other Current Assets			Current and Long-Term Regulatory Asset (Liability)			Other Current Assets			Current and Long-Term Regulatory Asset (Liability)			Other Current Assets
Three Months Ended September 30:
Balance as of July 1,	$	(8,484	)	$	(161	)	$	2,581		$	520		$	5,017		$	1,074		$	(8,484	)	$	(161	)
Unrealized gain		(4,385	)		—			(18,677	)		—
Realized gain (loss) reclassified to a deferred account		1,122			(1,122	)		65			(65	)
Realized gain reclassified to income statement		6,534			1,916			2,356			311
Unrealized loss (gain)														1,100			—			(4,385	)		—
Realized (loss) gain reclassified to a deferred account														(1,676	)		1,676			1,122			(1,122	)
Realized (loss) gain reclassified to income statement														(1,893	)		(2,155	)		6,534			1,916
Balance as of September 30,	$	(5,213	)	$	633		$	(13,675	)	$	766		$	2,548		$	595		$	(5,213	)	$	633

Nine Months Ended September 30:
Balance as of January 1,	$	(617	)	$	770		$	13,989		$	1,162		$	5,094		$	2,747		$	(617	)	$	770
Unrealized gain		(21,706	)		—			(30,314	)		—
Realized gain (loss) reclassified to a deferred account		3,952			(3,952	)		(351	)		351
Realized gain (loss) reclassified to income statement		13,158			3,815			3,001			(747	)
Unrealized loss (gain)														15,495			—			(21,706	)		—
Realized (loss) gain reclassified to a deferred account														(10,581	)		10,581			3,952			(3,952	)
Realized (loss) gain reclassified to income statement														(7,460	)		(12,733	)		13,158			3,815
Balance as of September 30,	$	(5,213	)	$	633		$	(13,675	)	$	766		$	2,548		$	595		$	(5,213	)	$	633


	Realized Losses (Gains)											Realized Losses (Gains)
	2022						2021					2023					2022
(In thousands)	Fuel for Electric Generation/ Purchased Power			Cost of Gas Sold			Fuel for Electric Generation/ Purchased Power			Cost of Gas Sold		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	$	(8,698	)	$	36		$	(1,586	)	$	—	$	4,179		$	—	$	(8,698	)	$	36
FTRs		212			—			(132	)		—		(131	)		—		212			—
PPA		—			—			(949	)		—

Nine Months Ended September 30:
Commodity derivative contracts	$	(14,343	)	$	(800	)	$	(2,107	)	$	1,055	$	14,566		$	6,451	$	(14,343	)	$	(800	)
FTRs		812			—			(443	)		—		(824	)		—		812			—
PPA		(2,642	)		—			(759	)		—		—			—		(2,642	)		—

MGE's commodity derivative contracts, FTRs, and PPA are subject to regulatory deferral. These derivatives are marked to fair value and are offset with a corresponding regulatory asset or liability. Realized gains and losses are deferred on the consolidated balance sheets and are recognized in earnings in the delivery month applicable to the instrument. As a result of the treatment described above, there are no unrealized gains or losses that flow through earnings.

Certain counterparties extend MGE a credit limit. If MGE exceeds these limits, the counterparties may require collateral to be posted. As of September 30, ~~2022,~~2023, and December 31, ~~2021,~~2022, 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, ~~2022,~~2023, 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.

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

The carrying amount of cash, cash equivalents, and outstanding commercial paper approximates fair market value due to the short maturity of those investments and obligations. The estimated fair market value of long-term debt is based on quoted market prices for similar financial instruments. Since long-term debt is not traded in an active market, it is classified as Level 2. The estimated fair market value of financial instruments are as follows:


	September 30, 2022				December 31, 2021				September 30, 2023				December 31, 2022
(In thousands)	Carrying Amount		Fair Value		Carrying Amount		Fair Value		Carrying Amount		Fair Value		Carrying Amount		Fair Value
Long-term debt(a)	$	619,794	$	549,585	$	623,449	$	729,914	$	699,812	$	606,355	$	643,560	$	571,374

(a)

Includes long-term debt due within one year. Excludes debt issuance costs and unamortized discount of $~~3.9~~4.7 million and $~~4.3~~4.0 million as of September 30, ~~2022,~~2023, and December 31, ~~2021,~~2022, respectively.

Recurring Fair Value Measurements.

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


	Fair Value as of September 30, 2022								Fair Value as of September 30, 2023
(In thousands)	Total		Level 1		Level 2		Level 3		Total		Level 1		Level 2		Level 3
MGE Energy
Assets:
Derivatives, net(b)	$	9,827	$	5,446	$	—	$	4,381	$	1,289	$	766	$	—	$	523
Exchange-traded investments		1,504		1,504		—		—		1,771		1,771		—		—
Total Assets	$	11,331	$	6,950	$	—	$	4,381	$	3,060	$	2,537	$	—	$	523
Liabilities:
Derivatives, net(b)	$	4,614	$	4,087	$	—	$	527	$	3,837	$	2,190	$	—	$	1,647
Deferred compensation		3,782		—		3,782		—		5,077		—		5,077		—
Total Liabilities	$	8,396	$	4,087	$	3,782	$	527	$	8,914	$	2,190	$	5,077	$	1,647

MGE
Assets:
Derivatives, net(b)	$	9,827	$	5,446	$	—	$	4,381	$	1,289	$	766	$	—	$	523
Exchange-traded investments		99		99		—		—		83		83		—		—
Total Assets	$	9,926	$	5,545	$	—	$	4,381	$	1,372	$	849	$	—	$	523
Liabilities:
Derivatives, net(b)	$	4,614	$	4,087	$	—	$	527	$	3,837	$	2,190	$	—	$	1,647
Deferred compensation		3,782		—		3,782		—		5,077		—		5,077		—
Total Liabilities	$	8,396	$	4,087	$	3,782	$	527	$	8,914	$	2,190	$	5,077	$	1,647


	Fair Value as of December 31, 2022
(In thousands)	Total		Level 1		Level 2		Level 3
MGE Energy
Assets:
Derivatives, net(b)	$	3,069	$	1,353	$	—	$	1,716
Exchange-traded investments		1,516		1,516		—		—
Total Assets	$	4,585	$	2,869	$	—	$	1,716
Liabilities:
Derivatives, net(b)	$	8,163	$	5,581	$	—	$	2,582
Deferred compensation		4,743		—		4,743		—
Total Liabilities	$	12,906	$	5,581	$	4,743	$	2,582

MGE
Assets:
Derivatives, net(b)	$	3,069	$	1,353	$	—	$	1,716
Exchange-traded investments		115		115		—		—
Total Assets	$	3,184	$	1,468	$	—	$	1,716
Liabilities:
Derivatives, net(b)	$	8,163	$	5,581	$	—	$	2,582
Deferred compensation		4,743		—		4,743		—
Total Liabilities	$	12,906	$	5,581	$	4,743	$	2,582

Fair Value as of December 31, 2021

(In thousands)

Total

Level 1

Level 2

Level 3

MGE Energy

Assets:

Derivatives, net(c)

$
3,606

$
1,170

$
—

$
2,436

Exchange-traded investments

1,296

1,296

—

—

Total Assets

$
4,902

$
2,466

$
—

$
2,436

Liabilities:

Derivatives, net

$
2,989

$
731

$
—

$
2,258

Deferred compensation

3,653

—

3,653

—

Total Liabilities

$
6,642

$
731

$
3,653

$
2,258

MGE

Assets:

Derivatives, net(c)

$
3,606

$
1,170

$
—

$
2,436

Exchange-traded investments

230

230

—

—

Total Assets

$
3,836

$
1,400

$
—

$
2,436

Liabilities:

Derivatives, net

$
2,989

$
731

$
—

$
2,258

Deferred compensation

3,653

—

3,653

—

Total Liabilities

$
6,642

$
731

$
3,653

$
2,258

(b)

No ~~collateral was posted against derivative positions as~~As of September 30, ~~2022.~~

~~(c)~~

~~As of~~2023, and December 31, ~~2021 MGE received~~2022, collateral of $2.9 million and $~~1.3~~5.2 million, ~~from counterparties under a master netting agreement for outstanding exchange traded~~respectively, was posted against and netted with derivative ~~positions.~~liability positions on the consolidated balance sheets. The fair value of the derivative ~~asset~~liability disclosed in this table has not been reduced for the collateral ~~received.~~posted.

Exchange-traded Investments.Investments include exchange-traded investment securities valued using quoted prices on active exchanges and are therefore classified as Level 1.

Deferred Compensation.

The deferred compensation ~~plan allows~~plans allow participants to defer certain cash compensation into a notional investment ~~account.~~accounts. These amounts are included within ~~other~~"Other deferred liabilities and other" in the consolidated balance sheets. The value of certain deferred compensation obligations is based on the market value of the participants' notional investment accounts. The

underlying notional investments are comprised primarily of equities, mutual funds, and fixed income securities which are based on directly and indirectly observable market prices. Since the deferred compensation obligations themselves are not exchanged in an active market, they are classified as Level 2.

The value of legacy deferred compensation obligations are based on notional investments that 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.Derivatives include exchange-traded derivative contracts, over-the-counter transactions, a purchased power agreement, and FTRs. Most exchange-traded derivative contracts are valued based on unadjusted quoted prices in active markets and are therefore classified as Level 1. A small number of exchange-traded derivative contracts are valued using quoted market pricing in markets with insufficient volumes and are therefore considered unobservable and classified as Level 3. Transactions done with an over-the-counter party are on inactive markets and are therefore classified as Level 3. These transactions are valued based on quoted prices from markets with similar exchange-traded transactions. FTRs are priced based upon monthly auction results for identical or similar instruments in a closed market with limited data available and are therefore classified as Level 3.

The purchased power agreement, with a term ended May 2022, (see Footnote 10) was valued using an internal pricing model and therefore was classified as Level 3. See the ~~2021~~2022 Annual Report on Form 10-K for details on the internal pricing model and significant unobservable inputs.

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				Three Months Ended				Nine Months Ended
	September 30,				September 30,				September 30,				September 30,
(In thousands)	2022		2021		2022		2021		2023		2022		2023		2022
Beginning balance	$	8,959	$	(4,533)	$	178	$	(14,055)	$	(2,892)	$	8,959	$	(866)	$	178
Realized and unrealized gains (losses):
Included in regulatory assets										1,768		—		(258)		—
Included in regulatory liability		(5,105)		8,122		3,675		17,644		—		(5,105)		—		3,675
Included in other comprehensive income		—		—		—		—		—		—		—		—
Included in earnings		6,609		2,476		13,607		2,686		(2,016)		6,609		(7,590)		13,607
Included in current assets		(73)		—		45		175		—		(73)		—		45
Purchases		108		6,638		11,911		18,899		—		108		—		11,911
Sales		—		—		—		—		—		—		—		—
Issuances		—		—		—		—		—		—		—		—
Settlements		(6,644)		(9,114)		(25,562)		(21,760)		2,016		(6,644)		7,590		(25,562)
Balance as of September 30,	$	3,854	$	3,589	$	3,854	$	3,589	$	(1,124)	$	3,854	$	(1,124)	$	3,854
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)	$	—	$	—	$	—	$	—
Total gains (losses) included in earnings attributed to the change in unrealized gains (losses) related to assets and liabilities held as of September 30,(c)									$	—	$	—	$	—	$	—

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


	Three Months Ended				Nine Months Ended				Three Months Ended				Nine Months Ended
	September 30,				September 30,				September 30,				September 30,
(In thousands)	2022		2021		2022		2021		2023		2022		2023		2022
Purchased power expense	$	6,644	$	2,476	$	13,805	$	3,113	$	(2,016)	$	6,644	$	(7,590)	$	13,805
Cost of gas sold expense		(35)		—		(198)		(427)		—		(35)		—		(198)
Total	$	6,609	$	2,476	$	13,607	$	2,686	$	(2,016)	$	6,609	$	(7,590)	$	13,607

~~(d)~~(c)

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

12.

Joint Plant Construction Project Ownership - MGE Energy and MGE

MGE ~~currently~~ has ~~ongoing jointly-owned solar~~ownership interests in generation projects with other co-owners, some of which are under construction, ~~projects,~~ as shown in the following table. Incurred costs are reflected in "Property, plant, and equipment, net" or "Construction work in progress" on the consolidated balance sheets.

Project

Ownership Interest

Source

Share of
Generation

Share of

~~Costs incurred~~ Estimated
~~as of September 30,~~

Estimated Date of
Commercial

~~Project~~

~~Interest~~

~~Generation~~

~~Estimated~~ Costs(a)

~~2022~~Costs incurred as
of September 30, 2023(a)

Date of
Commercial
Operation

Red Barn(b)

10%

Wind

9.16 MW

$18 million

$~~0.6~~16.5 million

~~Early~~April 2023

Badger Hollow II(c)

33%

Solar

50 MW

$7686 million~~(e)~~(i)

$~~46.8~~58.9 million(f)

~~First Half of~~Late 2023 or
early 2024(g)

Paris(d)

10%

31Solar/Battery

20 MW/11 MW

$5161 million~~(e)~~(i)

$~~21.8~~34.5 million

~~2023~~2024(g) Solar
2025(g) Battery

Darien(e)

10%

Solar

25 MW

$46 million(i)(j)

$21.9 million

2024(g)

West Riverside

3.4%

Natural Gas

25 MW

$25 million

$24.7 million

(h)

(a)

Excluding AFUDC.

(b)

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

(c)

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

(d)

Paris Solar-Battery Park is located in the Town of Paris in Kenosha County, Wisconsin.

(e)

~~In 2022, MGE notified the PSCW of increases~~Darien Solar Energy Center is located in ~~projected costs at Badger Hollow II~~Walworth and ~~Paris. The main drivers were increases~~Rock Counties in ~~the costs of key commodities, labor, and solar modules resulting from supply chain and market disruptions. MGE expects to recover the incremental costs through future rates.~~southern Wisconsin.

(f)

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

(g)

~~Battery storage~~Estimated date of commercial operation.

(h)

In March 2023, MGE purchased an ownership interest in West Riverside, a natural gas-fired facility located in Beloit, WI, from WPL, operator and co-owner of the plant. West Riverside was placed in-service in 2020.

(i)

Estimated costs are expected to exceed PSCW previously approved CA levels. Notifications are provided to the PSCW when costs increase above CA levels. MGE has and will continue to request recovery of the updates in its rate case proceedings.

(j)

As part of its order, the PSCW approved battery capacity with this project, which is no longer included in the current estimate. We will continue to evaluate timing, ~~to be determined.~~cost, and feasibility of the installation of batteries.

MGE received specific approval to recover 100% AFUDC on Badger Hollow II, Paris, and ~~Paris.~~Darien. During the three and nine months ended September 30, ~~2022,~~2023, MGE recognized $1.9 million and $4.8 million, respectively, after tax, in AFUDC for these projects compared to $1.1 million and $2.1 million ~~respectively, after~~

~~tax, in AFUDC for these projects compared to $0.2~~ ~~million and $0.4~~ ~~million~~ for the comparable ~~period~~periods in ~~2021.~~2022.

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

2022

2021

2022

2021

Residential

$
45,154

$
44,398

$
123,183

$
117,229

Commercial

65,468

60,996

177,877

161,270

Industrial

3,912

3,380

10,535

9,469

Other-retail/municipal

10,010

9,478

28,215

26,340

Total retail

124,544

118,252

339,810

314,308

Sales to the market

7,858

3,071

13,938

8,854

Other

474

316

1,167

948

Total electric revenues

132,876

121,639

354,915

324,110

Gas revenues

Residential

17,167

14,643

97,498

72,286

Commercial/Industrial

11,490

8,069

66,913

42,972

Total retail

28,657

22,712

164,411

115,258

Gas transportation

1,588

1,256

4,804

4,589

Other

65

52

90

97

Total gas revenues

30,310

24,020

169,305

119,944

Non-regulated energy revenues

214

214

466

464

Total Operating Revenue

$
163,400

$
145,873

$
524,686

$
444,518


	Three Months Ended				Nine Months Ended
(In thousands)	September 30,				September 30,
Electric revenues	2023		2022		2023		2022
Residential	$	50,008	$	45,154	$	131,552	$	123,183
Commercial		70,795		65,468		193,760		177,877
Industrial		3,715		3,912		10,578		10,535
Other-retail/municipal		10,991		10,010		30,853		28,215
Total retail		135,509		124,544		366,743		339,810
Sales to the market		3,305		7,858		9,617		13,938
Other		77		474		1,267		1,167
Total electric revenues		138,891		132,876		377,627		354,915

Gas revenues
Residential		13,719		17,167		86,131		97,498
Commercial/Industrial		6,016		11,490		55,726		66,913
Total retail		19,735		28,657		141,857		164,411
Gas transportation		1,587		1,588		5,354		4,804
Other		102		65		466		90
Total gas revenues		21,424		30,310		147,677		169,305

Non-regulated energy revenues		213		214		475		466
Total Operating Revenue	$	160,528	$	163,400	$	525,779	$	524,686

14.

Segment Information - MGE Energy and MGE.

MGE Energy operates in the following business segments: electric utility, gas utility, nonregulated energy, transmission investment, and all other. See the ~~2021~~2022 Annual Report on Form 10-K for additional discussion of each of these segments.


(In thousands) MGE Energy	Electric		Gas			Non-Regulated Energy		Transmission Investment		All Others			Consolidation/ Elimination			Consolidated Total		Electric		Gas			Non-Regulated Energy		Transmission Investment		All Others			Consolidation/ Elimination			Consolidated Total
Three Months Ended September 30, 2023
Operating revenues																		$	138,891	$	21,424		$	213	$	—	$	—		$	—		$	160,528
Interdepartmental revenues																			512		3,547			10,398		—		—			(14,457	)		—
Total operating revenues																			139,403		24,971			10,611		—		—			(14,457	)		160,528
Equity in earnings of investments																			—		—			—		2,690		—			—			2,690
Net income (loss)																			31,126		(801	)		5,627		1,957		(52	)		—			37,857

Three Months Ended September 30, 2022
Operating revenues	$	132,876	$	30,310		$	214	$	—	$	—		$	—		$	163,400	$	132,876	$	30,310		$	214	$	—	$	—		$	—		$	163,400
Interdepartmental revenues		24		12,465			10,405		—		—			(22,894	)		—		24		12,465			10,405		—		—			(22,894	)		—
Total operating revenues		132,900		42,775			10,619		—		—			(22,894	)		163,400		132,900		42,775			10,619		—		—			(22,894	)		163,400
Equity in earnings of investments		—		—			—		1,499		—			—			1,499		—		—			—		1,499		—			—			1,499
Net income (loss)		27,619		(394	)		5,576		1,091		(172	)		—			33,720		27,619		(394	)		5,576		1,091		(172	)		—			33,720

Three Months Ended September 30, 2021
Nine Months Ended September 30, 2023
Operating revenues	$	121,639	$	24,020		$	214	$	—	$	—		$	—		$	145,873	$	377,627	$	147,677		$	475	$	—	$	—		$	—		$	525,779
Interdepartmental revenues		89		6,689			10,224		—		—			(17,002	)		—		653		12,978			31,143		—		—			(44,774	)		—
Total operating revenues		121,728		30,709			10,438		—		—			(17,002	)		145,873		378,280		160,655			31,618		—		—			(44,774	)		525,779
Equity in earnings of investments		—		—			—		2,532		—			—			2,532		—		—			—		7,930		—			—			7,930
Net income (loss)		27,833		(218	)		5,386		1,842		74			—			34,917		65,996		10,539			16,667		5,770		(1,356	)		—			97,616

Nine Months Ended September 30, 2022
Operating revenues	$	354,915	$	169,305		$	466	$	—	$	—		$	—		$	524,686	$	354,915	$	169,305		$	466	$	—	$	—		$	—		$	524,686
Interdepartmental revenues		76		26,645			31,073		—		—			(57,794	)		—		76		26,645			31,073		—		—			(57,794	)		—
Total operating revenues		354,991		195,950			31,539		—		—			(57,794	)		524,686		354,991		195,950			31,539		—		—			(57,794	)		524,686
Equity in earnings of investments		—		—			—		6,626		—			—			6,626		—		—			—		6,626		—			—			6,626
Net income		55,248		12,782			16,451		4,821		599			—			89,901		55,248		12,782			16,451		4,821		599			—			89,901

Nine Months Ended September 30, 2021
Operating revenues	$	324,110	$	119,944		$	464	$	—	$	—		$	—		$	444,518
Interdepartmental revenues		316		14,377			30,595		—		—			(45,288	)		—
Total operating revenues		324,426		134,321			31,059		—		—			(45,288	)		444,518
Equity in earnings of investments		—		—			—		7,440		—			—			7,440
Net income (loss)		59,979		11,615			15,935		5,413		(241	)		—			92,701


(In thousands) MGE	Electric		Gas			Non-Regulated Energy		Consolidation/ Elimination			Consolidated Total		Electric		Gas			Non-Regulated Energy		Consolidation/ Elimination			Consolidated Total
Three Months Ended September 30, 2023
Operating revenues													$	138,891	$	21,424		$	213	$	—		$	160,528
Interdepartmental revenues														512		3,547			10,398		(14,457	)		—
Total operating revenues														139,403		24,971			10,611		(14,457	)		160,528
Net income (loss) attributable to MGE														31,126		(801	)		5,627		(5,487	)		30,465

Three Months Ended September 30, 2022
Operating revenues	$	132,876	$	30,310		$	214	$	—		$	163,400	$	132,876	$	30,310		$	214	$	—		$	163,400
Interdepartmental revenues		24		12,465			10,405		(22,894	)		—		24		12,465			10,405		(22,894	)		—
Total operating revenues		132,900		42,775			10,619		(22,894	)		163,400		132,900		42,775			10,619		(22,894	)		163,400
Net income (loss) attributable to MGE		27,619		(394	)		5,576		(5,603	)		27,198		27,619		(394	)		5,576		(5,603	)		27,198

Three Months Ended September 30, 2021
Nine Months Ended September 30, 2023
Operating revenues	$	121,639	$	24,020		$	214	$	—		$	145,873	$	377,627	$	147,677		$	475	$	—		$	525,779
Interdepartmental revenues		89		6,689			10,224		(17,002	)		—		653		12,978			31,143		(44,774	)		—
Total operating revenues		121,728		30,709			10,438		(17,002	)		145,873		378,280		160,655			31,618		(44,774	)		525,779
Net income (loss) attributable to MGE		27,833		(218	)		5,386		(5,627	)		27,374
Net income attributable to MGE														65,996		10,539			16,667		(16,382	)		76,820

Nine Months Ended September 30, 2022
Operating revenues	$	354,915	$	169,305		$	466	$	—		$	524,686	$	354,915	$	169,305		$	466	$	—		$	524,686
Interdepartmental revenues		76		26,645			31,073		(57,794	)		—		76		26,645			31,073		(57,794	)		—
Total operating revenues		354,991		195,950			31,539		(57,794	)		524,686		354,991		195,950			31,539		(57,794	)		524,686
Net income attributable to MGE		55,248		12,782			16,451		(15,947	)		68,534		55,248		12,782			16,451		(15,947	)		68,534

Nine Months Ended September 30, 2021
Operating revenues	$	324,110	$	119,944		$	464	$	—		$	444,518
Interdepartmental revenues		316		14,377			30,595		(45,288	)		—
Total operating revenues		324,426		134,321			31,059		(45,288	)		444,518
Net income attributable to MGE		59,979		11,615			15,935		(16,755	)		70,774

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

General

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

•

Regulated electric utility operations, conducted through MGE,

•

Regulated gas utility operations, conducted through MGE,

•

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

•

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

•

All other, which includes corporate operations and services.

Our principal subsidiary is MGE, which generates and distributes electric energy, distributes natural gas, and represents a majority portion of our assets, liabilities, revenues, and expenses. MGE generates, purchases, and distributes electricity to approximately ~~159,000~~161,000 customers in Dane County, Wisconsin, including the city of Madison, and purchases and distributes natural gas to approximately ~~169,000~~173,000 customers in the Wisconsin counties of Columbia, Crawford, Dane, Iowa, Juneau, Monroe, and Vernon.

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

Executive Overview

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

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

•

Weather, and its impact on customer sales,

•

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

•

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

•

Energy commodity prices, including natural gas prices,

•

Equity price risk pertaining to pension related assets,

•

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

•

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

•

~~Impacts on activity arising from COVID-19~~ and ~~its variants, including government restrictions on activity,~~

~~increased employee health and welfare costs, precautions for dealing with members of the public, and supply chain disruptions, and~~

•

Other factors listed in "Item 1A. Risk Factors" in our ~~2021~~2022 Annual Report on Form 10-K.

During the three months ended September 30, ~~2022,~~2023, MGE Energy's earnings were ~~$33.7~~$37.9 million or ~~$0.93~~$1.05 per share compared to ~~$34.9~~$33.7 million or ~~$0.97~~$0.93 per share during the same period in the prior year. MGE's earnings during the three months ended September 30, ~~2022,~~2023, were ~~$27.2~~$30.5 million compared to ~~$27.4~~$27.2 million during the same period in the prior year.

During the nine months ended September 30, ~~2022,~~2023, MGE Energy's earnings were ~~$89.9~~$97.6 million or ~~$2.49~~$2.70 per share compared to ~~$92.7~~$89.9 million or ~~$2.56~~$2.49 per share during the same period in the prior year. MGE's earnings during the nine months ended September 30, ~~2022,~~2023, were ~~$68.5~~$76.8 million compared to ~~$70.8~~$68.5 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				Three Months Ended				Nine Months Ended
(In millions)	September 30,				September 30,				September 30,				September 30,
Business Segment:	2022		2021		2022		2021		2023		2022		2023		2022
Electric Utility	$	27.6	$	27.8	$	55.2	$	60.0	$	31.1	$	27.6	$	66.0	$	55.2
Gas Utility		(0.4)		(0.2)		12.8		11.6		(0.8)		(0.4)		10.5		12.8
Nonregulated Energy		5.6		5.4		16.5		15.9		5.6		5.6		16.7		16.5
Transmission Investments		1.1		1.8		4.8		5.4		2.0		1.1		5.8		4.8
All Other		(0.2)		0.1		0.6		(0.2)		—		(0.2)		(1.4)		0.6
Net Income	$	33.7	$	34.9	$	89.9	$	92.7	$	37.9	$	33.7	$	97.6	$	89.9

Our net income during the three and nine months ended September 30, ~~2022,~~2023, compared to the same periods in the prior year primarily reflects the effects of the following factors:

Electric Utility

An increase in electric investments contributed to earnings for ~~2022.~~2023. Timing of ~~2021~~ depreciation expense and ~~other operations and maintenance~~lower fuel costs also contributed to higher earnings in ~~2021.~~the first nine months of 2023. Depreciation ~~and operations and maintenance costs increased during the remainder of 2021 and into 2022~~expense is expected to increase after significant capital projects ~~were~~(Badger Hollow II and Paris) are completed. ~~The new customer information system went live~~Weather during 2023 has also impacted electric earnings. Warmer than normal weather during the heating season in ~~September 2021~~the first quarter of 2023 lowered electric retail sales reducing earnings and ~~Badger Hollow I was completed~~warmer than normal weather in ~~November 2021. MGE received approval~~the third quarter of 2023 increased electric retail sales increasing earnings. Electric retail sales decreased approximately 1% during the first nine months of 2023 compared to ~~recover 100% AFUDC~~the same period in the prior year. Electric retail sales increased approximately 1% during ~~construction~~the third quarter of ~~these projects.~~2023 compared to the same period in the prior year.

Gas Utility

~~An increase in gas investments contributed to increased earnings for 2022. Higher~~Lower gas retail sales resulting from ~~colder~~warmer than normal weather in the first ~~half~~quarter of ~~2022~~2023 contributed to ~~higher~~lower gas earnings for the nine months ended September 30, ~~2022.~~2023. Gas retail sales decreased approximately 11%. Heating degree days (a measure for determining the impact of weather during the heating season) ~~increased~~decreased by approximately 7%15% in the first nine months of ~~2022~~2023 compared to the same period in the prior year.

Transmission Investments

In September 2022, our share of ATC's earnings reflected an estimated possible loss of approximately $0.8 million inclusive of interest and net of tax, related to the August 2022 developments in the MISO transmission owners complaints on authorized return on equity. See additional information in "Other Matters" below.

All Other

Investment losses from our venture capital funds resulted in lower earnings in 2023 compared to the same period in the prior year. These venture capital investments support early-stage companies working to advance smart technologies, the customer experience, distributed energy resources, electrification, cybersecurity and other priorities for utility companies such as greater sustainability.

The following developments affected the first nine months of ~~2022:~~2023:

2022/2023 Rate Settlement ~~Agreement:~~Agreement and 2023 Electric Limited Rate Case Reopener: In December 2021, the PSCW approved a settlement agreement for MGE's 2022 rate case. ~~The settlement agreement provides for an 8.81% increase to electric rates and a 2.15% increase to gas rates for 2022.~~ As part of that settlement agreement, the PSCW approved a 0.96% increase in 2023 gas rates and a ~~potential~~ 2023 electric rate change to be addressed through a

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

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

Project

Ownership Interest

Source

Share of Generation

Share of
Estimated Costs(a)

Costs ~~Incurred~~ incurred
as of
September 30, ~~2022~~2023(a)

~~Estimated~~ Date of
Commercial
Operation

Red Barn

10%

~~9.16MW~~

Wind

9.16 MW

$18 million

$~~0.6~~16.5 million

~~Early~~April 2023

Badger Hollow II

33%

Solar

50 MW

$7686 million(e)

$~~46.8~~58.9 million(b)(c)

~~First Half of~~Late 2023 or
early 2024(d)

Paris

10%

31Solar/Battery

20 MW/11 MW

$5161 million(e)

$~~21.8~~34.5 million(b)

~~2023~~2024(d) Solar
2025(d) Battery

Darien

10%

Solar

25 MW

$46 million(e)(f)

$21.9 million(b)

2024(d)

(a)

Excluding AFUDC.

(b)

MGE received specific approval to recover 100% ~~AFUDC on Badger Hollow II and Paris.~~AFUDC. After tax, MGE recognized ~~$1.9~~$4.8 million, $1.7 million, and $0.3 million of AFUDC equity through September 30, ~~2022,~~2023, on Badger Hollow II, Paris, and ~~Paris,~~Darien, respectively, during construction. AFUDC has been excluded from the costs incurred in the table above.

(c)

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

(d)

~~Battery storage~~Estimated date of commercial operation.

(e)

(f)

West Riverside: In March 2023, MGE purchased a 3.4% ownership interest in the natural gas-fired facility West Riverside from WPL, the operator of the plant, for approximately $25 million. MGE's share of the generation capacity of West Riverside is 25 MW.

Deferred Fuel ~~Costs: MGE has under-recovered fuel costs through the nine months ended September 30, 2022.~~Savings: As of September 30, ~~2022,~~2023, MGE ~~had~~has deferred ~~$4.4~~$4.3 million of ~~2022~~2023 fuel costs. Coal transportation constraints resulted in reduced generation at Columbia, which required MGE to purchase power in the market at higher cost. We may continue to see increased fuel costs in the near term because of these coal transportation constraints.savings. These costs will be subject to the PSCW's annual review of ~~2022~~2023 fuel costs, expected to be completed during ~~2023.~~2024. See Footnote ~~9.b.~~9 of the Notes to the Consolidated Financial Statements in this Report for further information regarding fuel cost proceedings.

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

~~2021~~2022 Annual Fuel Proceeding: MGE under-recovered fuel costs in ~~2021.~~2022. As of December 31, ~~2021,~~2022, MGE had deferred ~~$3.3~~$8.8 million of ~~2021~~2022 fuel costs. In August ~~2022,~~2023, the PSCW issued a final decision in the ~~2021~~2022 fuel rules proceedings for MGE to ~~include the recovery of~~recover these costs ~~as part of the~~over a 12-month period from October 2023 ~~electric limited rate case reopener.~~through September 2024. There was no change to the costs to be recovered in the fuel rule proceedings from the amount MGE deferred in the previous year.

~~2023 Electric Limited~~2024/2025 Rate ~~Case Reopener:~~Proceeding: In April ~~2022,~~2023, MGE filed with the PSCW a proposed 2024/2025 rate application. MGE has proposed a 3.75% increase for electric ~~limited rate case reopener.~~rates and a 2.56% increase to gas rates for 2024. The ~~limited rate case reopener~~proceeding also proposes a ~~4.38%~~3.41% increase for electric rates and a 1.66% increase to ~~electric~~gas rates for 2025. A final order is expected before the end of 2023. MGE cannot predict with any certainty the final outcome of the rate proceeding. Regulated entities are allowed to defer certain costs that would otherwise be charged to expense if the regulated entity believes the recovery of those costs is probable. Recovery of the deferred costs in future rates is subject to the review and approval by the PSCW. Any disallowance of previously deferred costs would be charged to income in the current period. See "Other Matters" below for additional information on the ~~2023 electric limited~~2024/2025 rate ~~case reopener.~~proceeding.

ATC Return on Equity: As discussed in "Other Matters" below, ATC's authorized ROE, which is used in calculating its rates and revenues, is the subject of a challenge before FERC. A decrease in ATC's ROE could result in lower equity earnings and distributions from ATC in the future. We derived approximately ~~5.1%~~5.7% and ~~5.7%~~5.1% of our net income during the nine months ended September 30, ~~2022~~2023 and ~~2021,~~2022, respectively, from our investment in ATC.

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

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

•

Transitioning away from coal. Columbia: ~~In February 2021,~~ MGE, along with the other plant co-owners, announced plans to retire ~~the two-unit coal-fired~~ Columbia ~~generating plant near Portage, Wisconsin. MGE currently owns 19% of the facility. The co-owners initially intended to retire~~ Unit 1 ~~by the end of~~

~~2023~~ and Unit 2 by ~~the end of 2024. In~~ June 2022, the target retirement date for both Units was updated to June 2026 after consideration by the owners of supply chain disruptions impacting the completion dates of current and planned renewable generation projects and the impact of those delays upon energy supply availability, reliability and cost. The postponement is not expected to affect MGE's goal to achieve 80% carbon reduction by 2030.2026. Final timing and retirement dates for Units 1 and 2 are subject to change depending on operational, regulatory, and other factors. MGE continues to evaluate additional investments to replace the generation from Columbia while maintaining electric service reliability. These investments include cost-effective, clean energy projects to help achieve MGE's carbon reduction goals.

Elm Road Units: ~~In November 2021,~~ MGE, along with the plant co-owners, announced plans to end the use of coal as a primary fuel at the Elm Road Units and transition the plant to natural gas. ~~MGE is a minority owner of Elm Road, owning 8.33%. The approximately 1,230 MW coal-fired plant is co-owned by WEC Energy Group, whose subsidiary serves as operator, and by WPPI Energy, Inc.~~ Transition plans and costs will be subject to PSCW approval. MGE's remaining use of coal is expected to be further reduced as the Elm Road Units transition to natural gas. By the end of 2030, MGE expects coal to be used only as a backup fuel at the Elm Road Units. This transition will help MGE meet its 2030 carbon reduction goals. By ~~2035,~~2032, MGE expects that the Elm Road Units will be fully transitioned away from coal, which will eliminate coal as an internal generation source for MGE.

•

Growing renewable generation. During 2023 through 2028 MGE ~~is seeking to acquire a joint interest in~~has forecasted nearly 50% of its total capital expenditures will be for several renewable generation projects. The forecasted capital expenditures include announced projects such as Red Barn (Wind; 9.16 MW), Badger Hollow II (Solar; 50 MW), Paris (Solar and Battery; 20 MW/11 MW), Darien (Solar; 25 MW), Koshkonong (Solar; 30 MW), and other projects to be announced in the future. See the ~~2022-2025~~2023-2028 capital expenditures forecast included under "Liquidity and Capital Resources" below for information on these projects.

•

Natural gas as a fuel source. West Riverside: MGE is seeking PSCW approval ~~for a sale and~~to purchase ofan additional ownership interest in West Riverside. See the ~~2022-2025~~2023-2028 capital expenditures forecast included under "Liquidity and Capital Resources" below for information on West Riverside.

Environmental Initiatives – Natural gas distribution: Building upon our long-standing commitment to providing affordable, sustainable energy, MGE has set a goal to achieve net-zero methane emissions from its natural gas distribution system by 2035. If MGE can accelerate plans to achieve net-zero methane emissions from its natural gas system—through the evolution of new technologies, such as renewable natural gas—it will. MGE is working to reduce overall emissions from its natural gas distribution system cost-effectively as quickly as possible.

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

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

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

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

Results of Operations

Three Months Ended September 30, ~~2022~~2023 and ~~2021~~2022

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)			Revenues					Sales (kWh)
	Three Months Ended September 30,					Three Months Ended September 30,			Three Months Ended September 30,					Three Months Ended September 30,
(In thousands, except CDD)	2022		2021		% Change	2022	2021	% Change	2023		2022		% Change	2023	2022	% Change
Residential	$	45,154	$	44,398	1.7%	252,457	263,833	(4.3)%	$	50,008	$	45,154	10.7%	264,678	252,457	4.8%
Commercial		65,468		60,996	7.3%	495,135	500,434	(1.1)%		70,795		65,468	8.1%	496,161	495,135	0.2%
Industrial		3,912		3,380	15.7%	41,304	42,400	(2.6)%		3,715		3,912	(5.0)%	39,908	41,304	(3.4)%
Other-retail/municipal		10,010		9,478	5.6%	104,548	106,919	(2.2)%		10,991		10,010	9.8%	102,400	104,548	(2.1)%
Total retail		124,544		118,252	5.3%	893,444	913,586	(2.2)%		135,509		124,544	8.8%	903,147	893,444	1.1%
Sales to the market		7,858		3,071	n.m.%	48,632	67,536	(28.0)%		3,305		7,858	(57.9)%	72,916	48,632	49.9%
Other		474		316	50.0%	—	—	—%		77		474	(83.8)%	—	—	—%
Total	$	132,876	$	121,639	9.2%	942,076	981,122	(4.0)%	$	138,891	$	132,876	4.5%	976,063	942,076	3.6%

Cooling degree days (normal 500)						507	511	(0.8)%
Cooling degree days (normal 502)														549	507	8.3%

~~n.m. not meaningful~~

Electric revenue increased ~~$11.2~~$6.0 million during the three months ended September 30, ~~2022,~~2023, compared to the same period in ~~2021,~~the prior year, due to the following:


(In millions)
Rate changes	$	7.8		$	12.3
Increase in residential volume					1.8
Sales to the market		4.8			(4.5	)
Revenue subject to refund, net		0.4			(2.9	)
Customer fixed and demand charges					(0.3	)
Other		0.4			(0.4	)
Decrease in residential volume		(1.6	)
Net decrease in commercial, industrial and other-retail/municipal volume		(0.6	)
Total	$	11.2		$	6.0

•

Rate changes. In December ~~2021,~~2022, the PSCW authorized MGE to increase ~~2022~~2023 rates for retail electric customers by approximately ~~8.81%~~9.01%. Rates charged to retail customers during the three months ended September 30, ~~2022~~2023, were ~~$7.8~~$12.3 million higher than those charged during the same period in the prior year. See Footnote 9 of the Notes to Consolidated Financial Statements in this Report for further information on the rate increase. Any increase in rates associated with fuel or purchase power costs are generally offset in fuel and purchased power costs and do not have a significant impact on net income.

•

Residential Volume. During the three months ended September 30, 2023, residential sales increased by approximately 5% compared to the same period in the prior year. This increase was driven by warmer than normal weather in the third quarter of 2023.

•

Sales to the market. Sales to the market typically occur when MGE has more generation and purchases in the MISO market than are needed for its customer demand. The excess electricity is then sold to other utilities or power marketers in the MISO market. During the three months ended September 30, ~~2022,~~2023, sales ~~were~~ made at ~~higher~~lower market prices ~~and~~were partially offset by ~~decreased~~higher market ~~volume~~volumes compared to the same period in the prior year, reflecting ~~a decrease~~an increase in sales. The revenue generated from these sales is included in fuel rules ~~monitored~~ costs. See fuel rules discussion in Footnote 9 of the Notes to Consolidated Financial Statements.

•

revenue in the period incurred, as the over-collection is expected to be refunded to customers in a subsequent period. In the year the over-collection is refunded, rates are reduced and offset as revenue

subject to refund. There is no net income impact in the year the costs are refunded.

•

~~Residential volume.~~ During the three months ended September 30, 2022, residential sales decreased by approximately 4% compared to the same period in the prior year. This decrease was driven by a shift in usage patterns reflecting a reduction in remote work associated with the COVID-19 pandemic.

Electric fuel and purchased power


	Three Months Ended September 30,						Three Months Ended September 30,
(In millions)	2022		2021		$ Change		2023		2022		$ Change
Fuel for electric generation	$	21.0	$	18.5	$	2.5	$	19.7	$	21.0	$	(1.3)
Purchased power		9.6		8.6		1.0		7.0		9.6		(2.6)

The ~~$2.5~~$1.3 million ~~increase~~decrease in fuel for electric generation was due to an approximately ~~29% increase~~18% decrease in the average cost offset by an approximately ~~12% decrease~~15% increase in internal generation. ~~Coal transportation constraints resulted in reduced~~Columbia generation ~~at Columbia, which required MGE~~was higher during the three months ended September 30, 2023, compared to ~~purchase power~~the same period in the prior year as a result of market ~~at higher cost.~~prices.

The ~~$1.0~~$2.6 million ~~increase~~decrease in purchased power was due to an approximately 40% ~~increase~~decrease in market purchases as a result of ~~lower~~higher internal ~~generation.~~generation, partially offset by an approximately 4% increase in average cost.

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

Gas deliveries and revenues

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


	Revenues					Therms Delivered			Revenues					Therms Delivered
(In thousands, except HDD and average	Three Months Ended September 30,					Three Months Ended September 30,			Three Months Ended September 30,					Three Months Ended September 30,
rate per therm of retail customer)	2022		2021		% Change	2022	2021	% Change	2023		2022		% Change	2023	2022	% Change
Residential	$	17,167	$	14,643	17.2%	6,166	5,987	3.0%	$	13,719	$	17,167	(20.1)%	6,202	6,166	0.6%
Commercial/Industrial		11,490		8,069	42.4%	9,555	8,889	7.5%		6,016		11,490	(47.6)%	9,335	9,555	(2.3)%
Total retail		28,657		22,712	26.2%	15,721	14,876	5.7%		19,735		28,657	(31.1)%	15,537	15,721	(1.2)%
Gas transportation		1,588		1,256	26.4%	15,183	15,212	(0.2)%		1,587		1,588	(0.1)%	15,014	15,183	(1.1)%
Other		65		52	25.0%	—	—	—%		102		65	56.9%	—	—	—%
Total	$	30,310	$	24,020	26.2%	30,904	30,088	2.7%	$	21,424	$	30,310	(29.3)%	30,551	30,904	(1.1)%

Heating degree days (normal 134)						135	50	170.0%
Heating degree days (normal 138)														70	135	(48.1)%

Average rate per therm of retail customer	$	1.823	$	1.527	19.4%				$	1.270	$	1.823	(30.3)%

Gas revenue ~~increased $6.3~~decreased $8.9 million during the three months ended September 30, ~~2022,~~2023, compared to the same period in ~~2021,~~the prior year, due to the following:


(In millions)
Rate changes	$	3.9	$	(8.5	)
Increase in volume		2.0
Decrease in volume				(0.7	)
Other		0.4		0.3
Total	$	6.3	$	(8.9	)

•

Rate changes. In December 2021, the PSCW authorized MGE to increase ~~2022~~2023 rates for retail gas customers by approximately ~~2.15%~~0.96%.

affect revenues but do not change net income in view of the pass-through treatment of the costs. Payments for natural gas ~~increased~~decreased driving ~~higher~~lower rates during the three months ended September 30, ~~2022.~~2023.

The average retail rate per therm for the three months ended ~~2022, increased~~September 30, 2023, decreased approximately ~~19%~~30% compared to ~~2021,~~the same period in the prior year, reflecting a ~~$5.7 million increase~~decrease in natural gas commodity costs (recovered through the PGA).

•

~~Volume.~~ ~~For 2022, retail~~Cost of gas ~~deliveries increased approximately 6%~~sold

Cost of gas sold decreased $9.4 million during the three months ended September 30, 2023, compared to the same period in the prior ~~year primarily related to favorable weather conditions in September 2022.~~

~~Cost of gas sold~~

~~A $5.7 million increase in cost of gas sold driven by higher cost per therm of gas.~~year. Average cost per therm ~~increased~~decreased approximately ~~62%~~64% and therms delivered decreased approximately 2%. MGE recovers the cost of natural gas in its gas segment through the PGA as described under gas deliveries and revenue above.

Consolidated operations and maintenance expenses

During the three months ended September 30, ~~2022,~~2023, operations and maintenance expenses increased ~~$0.7~~$4.8 million, compared to the same period in the prior year. The following contributed to the net change:


(In millions)
Increased customer accounts costs	$	0.5
Increased administrative and general costs				$	4.1
Increased electric distribution expenses					0.6
Increased electric production expenses		0.4			0.3
Increased transmission costs		0.3
Decreased other expenses		(0.5	)
Increased other expenses					0.2
Decreased customer accounts costs					(0.4	)
Total	$	0.7		$	4.8

•

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

Consolidated depreciation expense

Electric depreciation expense increased ~~$1.7~~$3.7 million and gas depreciation expense increased ~~$0.7~~$0.1 million during the three months ended September 30, ~~2022,~~2023, compared to the same period in the prior year. ~~MGE placed Badger Hollow I in service in November 2021. The timing~~As part of the ~~in-service date~~PSCW approved electric limited reopener for 2023, MGE accelerated the depreciation schedule for Columbia Unit 2 from 2038 to 2029 to align with the depreciation schedule previously approved for Columbia Unit 1. The accelerated depreciation schedule, which began in 2023, for Columbia Unit 2 contributed to the increase in electric depreciation expense. ~~The new customer information system went live in September 2021, which increased depreciation expense for both electric and gas in 2022.~~

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 both the three months ended September 30, ~~2022~~2023 and ~~2021,~~2022, net income at the nonregulated energy operations segment was $5.6 ~~million and $5.4 million, respectively.~~million.

Transmission Investment Operations - MGE Energy

The transmission investment segment holds our interest in ATC and ATC Holdco, and its income reflects our equity in the earnings of those investments. ATC Holdco was formed in December 2016 to pursue transmission development opportunities that typically have long development and investment lead times before becoming operational. ATC Holdco's transmission development activities have been suspended for the near term. During the three months ended September 30, ~~2022~~2023 and ~~2021,~~2022, other income at the transmission investment segment primarily reflects ATC's operations and was $2.7 million and $1.5 million, ~~and $2.5 million,~~ respectively. In August 2022, the U.S. Court of Appeals for the D.C. Circuit vacated the underlying FERC orders regarding methodology for setting authorized return on equity resulting in an additional estimated possible loss. See Footnote 3 of the Notes to Consolidated Financial Statements in this Report for summarized financial information regarding ATC and "Other Matters" below for additional information concerning ~~ATC and summarized financial information regarding~~ ATC.

Consolidated Income Taxes - MGE Energy and MGE

In 2022, the effective electric tax rate increased as a result of the return of electric excess deferred taxes related to the 2017 Tax Act not governed by IRS normalization rules in 2021. These costs were recorded as a regulatory liability in the year of remeasurement. See Footnote 4 of the Notes to Consolidated Financial Statements in this Report for the effective tax rate reconciliation.

Noncontrolling Interest, Net of Tax - MGE

Noncontrolling interest, net of tax, reflects the accounting required for MGE Energy's interest in MGE Power Elm Road (the Elm Road Units) and MGE Power West Campus (WCCF). MGE Energy owns 100% of MGE Power Elm Road and MGE Power West Campus. They are not owned by MGE. Due to the contractual agreements for these projects with MGE, the entities are considered VIEs with respect to MGE and their results are consolidated with those of MGE, the primary beneficiary of the VIEs. The following table shows MGE Energy's noncontrolling interest, net of tax, reflected on MGE's consolidated statement of income:


	Three Months Ended				Three Months Ended
	September 30,				September 30,
(In millions)	2022		2021		2023		2022
MGE Power Elm Road	$	3.8	$	3.8	$	3.7	$	3.8
MGE Power West Campus		1.8		1.8		1.8		1.8

Results of Operations

Nine Months Ended September 30, ~~2022~~2023 and ~~2021~~2022

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)				Revenues				Sales (kWh)
		Nine Months Ended September 30,				Nine Months Ended September 30,				Nine Months Ended September 30,				Nine Months Ended September 30,
(In thousands, except CDD)		2022		2021	% Change	2022	2021	% Change		2023		2022	% Change	2023	2022	% Change
Residential	$	123,183	$	117,229	5.1%	679,308	693,739	(2.1)%	$	131,552	$	123,183	6.8%	672,760	679,308	(1.0)%
Commercial		177,877		161,270	10.3%	1,368,060	1,352,091	1.2%		193,760		177,877	8.9%	1,356,286	1,368,060	(0.9)%
Industrial		10,535		9,469	11.3%	120,827	122,493	(1.4)%		10,578		10,535	0.4%	114,514	120,827	(5.2)%
Other-retail/municipal		28,215		26,340	7.1%	276,843	276,950	—%		30,853		28,215	9.3%	274,875	276,843	(0.7)%
Total retail		339,810		314,308	8.1%	2,445,038	2,445,273	—%		366,743		339,810	7.9%	2,418,435	2,445,038	(1.1)%
Sales to the market		13,938		8,854	57.4%	121,848	201,902	(39.6)%		9,617		13,938	(31.0)%	126,739	121,848	4.0%
Other revenues		1,167		948	23.1%	—	—	—%		1,267		1,167	8.6%	—	—	—%
Total	$	354,915	$	324,110	9.5%	2,566,886	2,647,175	(3.0)%	$	377,627	$	354,915	6.4%	2,545,174	2,566,886	(0.8)%

Cooling degree days (normal 690)						784	820	(4.4)%
Cooling degree days (normal 696)														754	784	(3.8)%

Electric revenue increased ~~$30.8~~$22.7 million during the nine months ended September 30, ~~2022,~~2023, compared to the same period in ~~2021,~~the prior year, due to the following:


(In millions)
Rate changes	$	~~27.7~~	32.6
Other		0.1
Sales to the market		~~5.1~~		(4.3	)
Customer fixed and demand charges		~~2.2~~		(2.7	)
Net ~~increase~~decrease in commercial, industrial and other-retail/municipal volume		~~0.7~~
~~Other~~		~~0.2~~
~~Revenue subject to refund, net~~		(~~3.2~~1.7	)
Decrease in residential volume		(~~1.9~~1.0	)
Revenue subject to refund, net		(0.3	)
Total	$	~~30.8~~	22.7

•

See Footnote 9 of the Notes to Consolidated Financial Statements in this Report for further information on the rate increase. Any increase in rates associated with fuel or purchase power costs are generally offset in fuel and purchased power costs and do not have a significant impact on net income.

•

Sales to the market. Sales to the market typically occur when MGE has more generation and purchases in the

MISO market than are needed for its customer demand. The excess electricity is then sold to other utilities or power marketers in the MISO market. During the nine months ended September 30, ~~2022,~~2023, sales were made at ~~higher~~lower market prices and partially offset by ~~decreased~~increased market ~~volume~~volumes compared to the same period in the prior year, reflecting ~~a decrease~~an increase in sales. The revenue generated from these sales is included in fuel rules ~~monitored~~ costs. See fuel rules discussion in Footnote 9 of the Notes to Consolidated Financial Statements.

•

Customer fixed and demand charges. During the nine months ended September 30, 2023, fixed and demand charges decreased $2.7 million primarily attributable to the decrease in demand charges for commercial customers and decreased fixed residential customer charge.

•

Commercial, industrial and other-retail/municipal volume. During the nine months ended September 30, 2023, sales decreased by approximately 1% compared to the same period in the prior year driven by warmer weather in the first quarter of 2023.

•

Residential volume. During the nine months ended September 30, ~~2022, fixed and demand charges increased $2.2 million primarily attributable~~2023, residential sales decreased by approximately 1% compared to the ~~increase~~same period in ~~demand charges for commercial customers.~~the prior year. This decrease was driven by warmer than normal weather in the first quarter of 2023.

•

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

•

~~Residential volume.~~ ~~During the~~nine months ended September 30, 2022, there was an approximately 2% decrease in residential volume driven by a shift in usage patterns reflecting a reduction in remote work associated with the COVID-19 pandemic.

Electric fuel and purchased power


	Nine Months Ended September 30,						Nine Months Ended September 30,
(In millions)	2022		2021		$ Change		2023		2022		$ Change
Fuel for electric generation	$	48.4	$	42.6	$	5.8	$	47.1	$	48.4	$	(1.3)
Purchased power		35.8		28.9		6.9		28.3		35.8		(7.5)

The ~~$5.8~~$1.3 million ~~increase~~decrease in fuel for electric generation was due to an approximately ~~31% increase~~8% decrease in the average cost offset by an approximately ~~13% decrease~~6% increase in internal generation. ~~Coal transportation constraints resulted~~West Riverside was purchased in ~~reduced~~March 2023 contributing to the increase in internal generation ~~at Columbia, which required MGE~~during the nine months ended September 30, 2023, compared to ~~purchase power~~the same period in the ~~market at higher cost.~~prior year.

The ~~$6.9~~$7.5 million ~~increase~~decrease in purchased power was due to an approximately ~~43% increase~~21% decrease in market purchases as a result of lower customer sales and increased internal generation. An approximately 19% decrease in average cost also contributed to the decrease in purchase power costs.

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				Revenues				Therms Delivered
(In thousands, except HDD and average		Nine Months Ended September 30,				Nine Months Ended September 30,				Nine Months Ended September 30,				Nine Months Ended September 30,
rate per therm of retail customer)		2022		2021	% Change	2022	2021	% Change		2023		2022	% Change	2023	2022	% Change
Residential	$	97,498	$	72,286	34.9%	77,091	68,791	12.1%	$	86,131	$	97,498	(11.7)%	66,948	77,091	(13.2)%
Commercial/Industrial		66,913		42,972	55.7%	73,349	64,179	14.3%		55,726		66,913	(16.7)%	66,584	73,349	(9.2)%
Total retail		164,411		115,258	42.6%	150,440	132,970	13.1%		141,857		164,411	(13.7)%	133,532	150,440	(11.2)%
Gas transportation		4,804		4,589	4.7%	58,059	55,150	5.3%		5,354		4,804	11.4%	53,319	58,059	(8.2)%
Other revenues		90		97	(7.2)%	—	—	—%		466		90	n.m.%	—	—	—%
Total	$	169,305	$	119,944	41.2%	208,499	188,120	10.8%	$	147,677	$	169,305	(12.8)%	186,851	208,499	(10.4)%

Heating degree days (normal 4,479)						4,723	4,404	7.2%
Heating degree days (normal 4,503)														3,999	4,723	(15.3)%

Average rate per therm of retail customer	$	1.093	$	0.867	26.1%				$	1.062	$	1.093	(2.8)%

n.m. not meaningful

Gas revenue ~~increased $49.4~~decreased $21.6 million during the nine months ended September 30, ~~2022,~~2023, compared to the same period in ~~2021,~~the prior year, due to the following:


(In millions)
Decrease in volume			$	(12.4	)
Rate changes	$	38.2		(10.4	)
Increase in volume		9.9
Other		1.3		1.2
Total	$	49.4	$	(21.6	)

•

Volume. For the nine months ended September 30, 2023, retail gas deliveries decreased approximately 11% compared to the same period in the prior year primarily attributable to warmer than normal weather in the first quarter of 2023. During the first quarter of 2022, the weather was slightly colder than normal.

•

Rate changes. In December 2021, the PSCW authorized MGE to increase ~~2022~~2023 rates for retail gas customers by approximately ~~2.15%~~0.96%.

MGE recovers the cost of natural gas in its gas segment through the purchased gas adjustment clause (PGA). Under the PGA, MGE is able to pass through to its gas customers the cost of gas. Changes in PGA recoveries affect revenues but do not change net income in view of the pass-through treatment of the costs. Payments for natural gas ~~increased~~decreased driving ~~higher~~lower rates during the nine months ended September 30, ~~2022.~~2023.

The average retail rate per therm excluding customer fixed charge for the nine months ended ~~2022, increased~~September 30, 2023, decreased approximately ~~26%~~3% compared to ~~2021,~~the same period in the prior year, reflecting a ~~$42.9 million increase~~decrease in natural gas commodity costs (recovered through the PGA).

•

~~Volume.~~ ~~For 2022, retail gas deliveries increased approximately 13% compared to the same period in the prior year primarily related to favorable weather conditions in the current year.~~

•

Other.Other revenues increased primarily related to increase in gas customers in ~~2022~~2023 increasing revenue recorded for fixed customer charge compared to the same period in the prior year.

Cost of gas sold

~~The $42.9 million increase in cost~~Cost of gas sold ~~was driven by higher~~decreased $20.3 million during the nine months ended September 30, 2023, compared to the same period in the same period in the prior year. Therms delivered decreased approximately 12% and cost per ~~therm of gas. Average cost per therm increased approximately 56%. An increase in volume of approximately 12% also contributed to the increase in cost.~~

therm decreased approximately 9%. MGE recovers the cost of natural gas in its gas segment through the PGA as described under gas deliveries and revenue above.

Consolidated operations and maintenance expenses

During the nine months ended September 30, ~~2022,~~2023, operations and maintenance expenses increased ~~$6.1~~$5.3 million, compared to the same period in the prior year. The following contributed to the net change:


(In millions)
Increased administrative and general costs	$	4.2		$	4.7
Increased customer accounts costs		2.6
Increased electric distribution expenses		0.5
Increased electric production expenses					1.5
Increased customer services					0.6
Increased other expenses		0.5			0.3
Decreased electric production expenses		(1.3	)
Decreased customer services		(0.4	)
Decreased customer accounts costs					(1.6	)
Decreased electric distribution expenses					(0.2	)
Total	$	6.1		$	5.3

•

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

•

Increased electric production expenses are primarily related to an increase in Columbia maintenance costs.

•

Decreased customer accounts costs are primarily related to ~~increased~~lower technology support costs ~~associated with~~which were higher in 2022 during the stabilization period of the new customer information system ~~which~~that went live in September 2021.

•

Decreased electric production expenses are primarily related to lower Columbia costs. A $2.6 million additional expense was recorded in 2021 for Columbia inventory obsolescence and employee severance reserves associated with the Columbia retirement. MGE expects to request PSCW approval for regulatory recovery of these costs at a future date. The decrease in costs is offset by increased maintenance costs for Blount, Saratoga, Two Creeks, and Badger Hollow I.

Consolidated depreciation expense

Electric depreciation expense increased ~~$5.7~~$10.9 million and gas depreciation expense increased ~~$2.2~~$0.3 million during the nine months ended September 30, ~~2022,~~2023, compared to the same period in the prior year. ~~MGE placed Badger Hollow I in service in November 2021. The timing~~As part of the ~~in-service date~~PSCW approved electric limited reopener for 2023, MGE accelerated the depreciation schedule for Columbia Unit 2 from 2038 to 2029 to align with the depreciation schedule previously approved for Columbia Unit 1. The accelerated depreciation schedule, which began in 2023, for Columbia Unit 2 contributed to the increase in electric depreciation expense. ~~The new customer information system went live in September 2021, which increased depreciation expense for both electric and gas in 2022.~~

~~Electric and gas other income~~

Electric other income increased $2.3 million and gas other income increased $3.7 million during the nine months ended September 30, 2022, compared to the same period in the prior year, primarily related to the collection in 2021 of the deferred pension and other postretirement other than service costs from 2019.

Nonregulated Energy Operations - MGE Energy and MGE

The nonregulated energy operations are conducted through MGE Energy's subsidiaries: MGE Power Elm Road (the Elm Road Units) and MGE Power West Campus (WCCF), which have been formed to own and lease electric generating capacity to assist MGE. During the nine months ended September 30, ~~2022~~2023 and ~~2021,~~2022, net income at the nonregulated energy operations segment was ~~$16.5~~$16.7 million and ~~$15.9~~$16.5 million, respectively.

Transmission Investment Operations - MGE Energy

The transmission investment segment holds our interest in ATC and ATC Holdco, and its income reflects our equity in the earnings of those investments. ATC Holdco was formed in December 2016 to pursue transmission development opportunities that typically have long development and investment lead times before becoming operational. ATC Holdco's transmission development activities have been suspended for the near term. During the nine months ended September 30, ~~2022~~2023 and ~~2021,~~2022, other income at the transmission investment segment primarily reflects ATC's operations and was $7.9 million and $6.6 million, ~~and $7.4 million,~~ respectively. In August 2022, the U.S. Court of Appeals for the D.C. Circuit vacated the underlying FERC orders regarding methodology for setting authorized return on equity resulting in an additional estimated possible loss. See Footnote 3 of the Notes to Consolidated Financial Statements in this Report for summarized financial information regarding ATC and "Other Matters" below for additional information concerning ~~ATC and summarized financial information regarding~~ ATC.

All Other Operations - MGE Energy

Other income

The decrease of $2.7 million in other income from all other operations during the nine months ended September 30, 2023, primarily results from increased investment losses from our venture capital funds compared

to the same period in the prior year. These venture capital investments support early-stage companies working to advance smart technologies, the customer experience, distributed energy resources, electrification, cybersecurity and other priorities for utility companies such as greater sustainability.

Consolidated Income Taxes - MGE Energy and MGE

Noncontrolling Interest, Net of Tax - MGE


	Nine Months Ended				Nine Months Ended
	September 30,				September 30,
(In millions)	2022		2021		2023		2022
MGE Power Elm Road	$	10.5	$	11.4	$	11.0	$	10.5
MGE Power West Campus		5.4		5.4		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, ~~2022,~~2023, except as noted below. Further discussion of the contractual obligations and commercial commitments is included in Footnote 16 of the Notes to Consolidated Financial Statements and "Contractual Obligations and Commercial Commitments for MGE Energy and MGE" under "Management's Discussion and Analysis of Financial Condition and Results of Operations" in the ~~2021~~2022 Annual Report on Form 10-K.

Purchase Contracts – MGE Energy and MGE

See Footnote 8.c. of Notes to Consolidated Financial Statements in this Report for a description of commitments as of September 30, ~~2022,~~2023, 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.

Long-term Debt – MGE Energy and MGE

In ~~November 2022,~~March 2023, $19.3 million of City of Madison, Wisconsin Industrial Development Revenue Refunding Bonds, Series 2020A were remarketed. In August 2023, MGE entered into a private placement Note Purchase Agreement in which it committed to issue ~~$75~~$70 million of new long-term debt. See Footnote 6.c. of Notes to Consolidated Financial Statements in this Report for further ~~information on long-term debt issuance.~~information.

Liquidity and Capital Resources

MGE Energy and MGE expect to have adequate liquidity to support future operations and capital expenditures over the next twelve months. Available resources include cash and cash equivalents, operating cash flows, liquid assets, borrowing ~~working~~ capacity under revolving credit facilities, and access to equity and debt capital markets. MGE Energy expects to generate funds from operations and both long-term and short-term debt financing. See "Credit Facilities" under Part II, Item 7, Management's Discussion and Analysis of Financial Condition and Results of Operations – Liquidity and Capital Resources in the ~~2021~~2022 Annual Report on Form 10-K for information regarding MGE Energy's and MGE's credit facilities.

Cash Flows

The following summarizes cash flows for MGE Energy and MGE during the nine months ended September 30, ~~2022~~2023 and ~~2021:~~2022:


	MGE Energy				MGE				MGE Energy				MGE
(In thousands)	2022		2021		2022		2021		2023		2022		2023		2022
Cash provided by (used for):
Operating activities	$	144,282	$	141,297	$	141,786	$	135,451	$	194,038	$	144,282	$	190,368	$	141,786
Investing activities		(137,219)		(118,347)		(134,089)		(115,591)		(156,490)		(137,219)		(151,636)		(134,089)
Financing activities		(12,663)		1,656		(8,400)		31,930		(39,309)		(12,663)		(41,626)		(8,400)

Cash Provided by Operating Activities

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

MGE Energy

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

Cash provided by operating activities during the nine months ended September 30, ~~2022,~~2023, was ~~$144.3~~$194.0 million, an increase of ~~$3.0~~$49.8 million when compared to the same period in the prior ~~year.~~year, driven by:

~~MGE Energy's net income decreased $2.8~~•

A $40.6 million increase in cash from lower payments for fuel and purchased power at our generation plants, as well as lower natural gas costs to our customers during the nine months ended September 30, ~~2022,~~2023, when compared to the ~~same period~~prior year, primarily driven by a decrease in the ~~prior year.~~price of natural gas.

•

~~MGE Energy's federal and state taxes paid decreased $3.0~~

A $14.0 million increase in cash as a result of higher overall collections from customers during the nine months ended September 30, ~~2022,~~2023, when compared to the prior year. This increase was driven by the 2023 rates approved by the PSCW, effective January 1, 2023.

•

~~Working capital accounts (excluding prepaid and accrued taxes) resulted in $17.7~~

An increase of $3.8 million in cash ~~used~~from lower payments for other operation and maintenance expenses.

These increases in net cash provided by operating activities were partially offset by:

•

A decrease of $5.4 million in cash from higher payments for MGE Energy's federal and state taxes during the nine months ended September 30, ~~2022. Working capital accounts were impacted by increased gas inventory driven by the increase in cost of gas and decreased other current liabilities, partially offset by decreased unbilled revenues.~~

Working capital accounts (excluding prepaid and accrued taxes) resulted in $9.1 million in cash used for operating activities during the nine months ended September 30, 2021. Actual purchased gas costs were $6.3 million higher than the amount collected in rates primarily due to the extreme cold weather experienced in the U.S. in February 2021. These costs were deferred as a regulatory asset and recovered throughout 2021. In addition, working capital accounts were impacted by increased accounts receivable and increased inventories, partially offset by increased other current liabilities, decreased unbilled revenues, and increased accounts payable.

~~Hosted software asset expenditures during the nine months ended September 30, 2022, were $0.5 million. This amount represents a decrease of $2.5 million of cash used~~2023, when compared to the prior year.

•

A decrease of $3.2 million in cash from higher payments for interest, driven by MGE's issuance of long-term debt during the fourth quarter of 2022 and first quarter of 2023, compared to the prior period.

MGE

Cash provided by operating activities during the nine months ended September 30, ~~2022,~~2023, was ~~$141.8~~$190.4 million, an increase of ~~$6.3~~$48.6 million when compared to the same period in the prior ~~year.~~year, driven by:

~~Net income decreased $3.0~~•

•

~~MGE's federal and state taxes paid decreased $4.2~~

•

~~Working capital accounts (excluding prepaid and accrued taxes) resulted in $15.3~~

An increase of $3.3 million in cash ~~used~~from lower payments for other operation and maintenance expenses.

These increases in net cash provided by operating activities were partially offset by:

•

A decrease of $6.0 million in cash from higher payments for MGE's federal and state taxes during the nine months ended September 30, ~~2022. Working capital accounts were impacted by increased gas inventory driven by the increase in cost of gas and decreased current liabilities, partially offset by decreased unbilled revenues.~~

•

Capital Requirements and Investing Activities

MGE Energy

MGE Energy's cash used for investing activities increased ~~$18.9~~$19.3 million during the nine months ended September 30, ~~2022,~~2023, when compared to the same period in the prior year.

Capital expenditures during the nine months ended September 30, ~~2022,~~2023, were ~~$133.4~~$150.3 million. This amount represents an increase of ~~$19.3~~$16.9 million from the expenditures made in the same period in the prior year. This increase primarily reflects the ~~increase~~purchase of ~~expenditures for Badger Hollow II~~25 MW of West Riverside and ~~Paris.~~purchase of Red Barn wind farm.

~~Proceeds from the sale of~~Capital contributions in ATC and other investments ~~decreased $0.8~~increased $2.0 million during the nine months ended September 30, ~~2022,~~2023, when compared to the same period in the prior year.

MGE

MGE's cash used for investing activities increased ~~$18.5~~$17.5 million during the nine months ended September 30, ~~2022,~~2023, when compared to the same period in the prior year.

Capital Expenditures

The following table shows MGE Energy's forecasted capital expenditures for ~~2022~~2023 through ~~2025:~~2028:


	Forecasted								Forecasted
(In thousands)	2022(a)		2023		2024		2025		2023(a)		2024		2025		2026		2027		2028
Electric	$	138,200	$	181,000	$	185,100	$	174,400	$	173,000	$	177,000	$	186,000	$	193,000	$	222,000	$	207,000
Gas		25,300		26,200		25,600		23,200		33,000		28,000		29,000		32,000		29,000		28,000
Utility plant total		163,500		207,200		210,700		197,600		206,000		205,000		215,000		225,000		251,000		235,000
Nonregulated		7,700		7,900		7,800		6,100		6,000		9,000		10,000		7,000		6,000		8,000
MGE Energy total	$	171,200	$	215,100	$	218,500	$	203,700	$	212,000	$	214,000	$	225,000	$	232,000	$	257,000	$	243,000

(a)

Includes actual capital expenditures already incurred in ~~2022~~2023 and estimated capital expenditures for the remainder of the year.

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

MGE is targeting at least 80% carbon reduction from electric generation by 2030 (from 2005 levels) and net-zero carbon electricity by 2050. Solar, wind, and battery storage projects are a major step toward deep decarbonization and greater use of clean energy sources in pursuit of our goal. MGE continues to evaluate solar, wind, and battery

storage projects that align with its goals as legacy fossil fuel-fired facilities are retired. The target early retirement

date for Columbia is June 2026. MGE has included forecasted capital expenditures for the years ~~2022~~2023 through ~~2025~~2026 for projects to replace Columbia's generation. ~~Additional replacement~~

The following table provides further detail of MGE Energy's forecasted capital expenditures, ~~are expected to continue beyond 2025.~~separating spending into capital project categories for 2024 through 2028:


(In thousands)	Forecasted
For the years ended December 31,	2024		2025		2026		2027		2028
Electric renewables(a)	$	76,000	$	102,000	$	114,000	$	146,000	$	132,000
Electric production		42,000		21,000		20,000		13,000		13,000
Electric distribution		59,000		63,000		59,000		63,000		62,000
Gas distribution		28,000		29,000		32,000		29,000		28,000
Utility plant total		205,000		215,000		225,000		251,000		235,000
Nonregulated		9,000		10,000		7,000		6,000		8,000
MGE Energy total	$	214,000	$	225,000	$	232,000	$	257,000	$	243,000

(a)

Includes solar and wind generation and battery storage.

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

Project

Source

Ownership Interest

Share of
Generation/
Battery Storage

Share of
Estimated
Costs~~(c)~~(b)

~~Estimated~~ Date of
Commercial Operation

Red Barn(a)

Wind

10%

9.16MW

$18 million~~(e)~~(d)

~~Early~~April 2023

Badger Hollow II(a)

Solar

33%

50 MW

$7686 million(c)(d)~~(e)~~

~~First Half of~~Late 2023 or early 2024(f)

Paris(a)

Solar/Battery

10%

3120 MW/11 MW

$5161 million(c)(d)~~(e)~~

~~2023~~2024(f)Solar
2025(f) Battery

Darien~~(b)~~(a)

~~Solar/Battery~~

Solar

10%

~~25MW/7.5MW~~

25 MW

$4546 million(c)(d)(e)

2024(f)

Koshkonong~~(b)~~(a)

~~Solar/Battery~~

Solar

10%

~~30MW/16.5MW~~

30 MW

$6554 million~~(d)~~(c)(e)

~~2025~~2026(f)

(a)

Approved by the PSCW.

(b)

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

(c)

~~Excluding AFUDC.~~

~~(d)~~

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

~~(e)~~(d)

See Footnote 12 of Notes to Consolidated Financial Statements in the Report for information on costs incurred.

(e)

As part of its order, the PSCW approved battery capacity with these projects, which are no longer included in the current estimate. We will continue to evaluate timing, cost, and feasibility of the installation of batteries.

(f)

~~Battery storage timing to be determined.~~Estimated date of commercial operation.

In ~~2022,~~2023, MGE notified the PSCW of increases in projected costs at Badger Hollow II, Paris, and ~~Paris.~~Darien. The main drivers were increases in the costs of key commodities, labor, and solar modules resulting from supply chain and market disruptions. See Footnote 12 of Notes to Consolidated Financial Statements in this Report for more information on these projects. Furthermore, solar procurement disruptions have also shifted construction ~~timelines for Darien and Koshkonong. Projected completion dates of these projects are one year later than originally anticipated.~~timelines. MGE continues to assess the potential impact of these disruptions on current and future solar projects ~~which~~that may result in an increase in costs or delays in construction timelines. See further information on procurement disruptions discussed ~~earlier~~ under ~~"Executive Overview.~~"Other Matters" section below.

West Riverside: In ~~2016,~~March 2023, MGE ~~entered into an agreement with WPL under which MGE may acquire up to 50~~purchased 25 MW of capacity ~~in a gas-fired generating plant constructed by WPL at its~~of West ~~Riverside Energy Center in Beloit, Wisconsin, during the five-year period following the in-service date of the plant. The plant was placed in service in May 2020.~~Riverside. In ~~January 2022,~~September 2023, MGE, along with joint applicants, filed an application with the PSCW requesting approval for a sale and purchase of additional ownership interests in West Riverside. If approved, MGE's share of West Riverside will beincrease 25 MW at a purchase price of approximately $25 million. The closing and actual transfer of ownership is expected to occur in ~~March 2023. MGE also retains the option to purchase an additional 25 MW of capacity from West Riverside until May 2025. MGE currently expects to exercise this option in a future period.~~June 2024.

Electric and Gas Distribution: In ~~2022~~2023 through ~~2025,~~2028, electric and gas capital expenditures include investment in enhanced metering solutions to provide customers with more timely and detailed energy use information. Investments in advanced metering infrastructure will provide additional benefits including outage and demand

response and automated meter reading capabilities. Forecasted total capital expenditures infor those years is approximately ~~$24~~$47 million.

Cash Used ~~for/Provided by~~for Financing Activities

MGE Energy

Cash used for MGE Energy's financing activities was ~~$12.7~~$39.3 million during the nine months ended September 30, ~~2022,~~2023, compared to ~~cash proceeds of $1.7~~$12.7 million for the same period in the prior year.

During the nine months ended September 30, ~~2022,~~2023, dividends paid were ~~$42.8~~$44.9 million compared to ~~$40.8~~$42.8 million in the prior year. The increase reflected a higher dividend rate per share ($~~1.183~~1.243 vs. ~~$1.128)~~$1.183).

During the nine months ended September 30, ~~2021,~~2023, MGE ~~borrowed $100.0~~issued $90 million of senior unsecured notes which ~~was~~were used to repay $30 million of maturing unsecured senior notes and to assist with financing additional capital expenditures and other corporate obligations. In addition, $19.3 million of Industrial Development Revenue Bonds were tendered by their holders as required by the terms of the bonds and remarketed as permitted by those terms. There were no long-term debt borrowings during the nine months ended September 30, 2022.

During the nine months ended September 30, ~~2022,~~2023, net short-term debt ~~borrowings~~repayments were ~~$34.5~~$48.5 million, compared to ~~$52.5~~$34.5 million of ~~repayments~~borrowings in the same period in the prior year.

MGE

During the nine months ended September 30, ~~2022,~~2023, cash used for MGE's financing activities was ~~$8.4~~$41.6 million, compared to ~~cash proceeds of $31.9~~$8.4 million for the same period in the prior year.

~~Cash~~During the nine months ended September 30, 2023, cash dividends to parent (MGE Energy) were $30.0 million, compared to $21.0 million ~~during the nine months ended September 30, 2022. There were no cash dividends to parent~~ in the same period in the prior year.

Distributions to parent from noncontrolling interest, which represent distributions from MGE Power Elm Road and MGE Power West Campus to MGE Energy, were ~~$17.5~~$17.3 million during the nine months ended September 30, ~~2022,~~2023, compared to ~~$10.5~~$17.5 million in the same period in the prior year.

Capitalization Ratios

MGE Energy's capitalization ratios were as follows:


	MGE Energy		MGE Energy
	September 30, 2022	December 31, 2021	September 30, 2023	December 31, 2022
Common shareholders' equity	62.1%	62.2%	61.3%	60.4%
Long-term debt(a)	35.6%	37.5%	37.5%	35.7%
Short-term debt	2.3%	0.3%	1.2%	3.9%

(a)

Includes the current portion of long-term debt.

Credit Ratings

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

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

Environmental Matters

See the discussion of environmental matters included in the ~~2021~~2022 Annual Report on Form 10-K, as updated by Footnote 8.a. of Notes to Consolidated Financial Statements in this Report.

Other Matters

Rate Matters

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

In ~~April~~December 2022, ~~MGE filed with~~ the PSCW approved the 2023 electric rate case limited reopener. The reopener provides for a ~~limited rate reopener proposing a 4.38%~~9.01% increase to electric rates for 2023.

In April 2023, MGE filed a 2024/2025 rate application with a proposed increase of 3.75% for electric rates and a 2.56% increase for gas rates in 2024. The application also proposes a 3.41% increase for electric rates and a 1.66% increase to gas rates for 2025. PSCW approval is pending. A final order is expected before the end of 2023.

Details related to MGE's ~~2022/~~2023 approved settlement agreement and ~~pending~~2023 electric limited ~~reopener:~~reopener, and 2024/2025 proposed rate proceeding are as follows:

(Dollars in thousands)

Authorized Average Rate Base(a)

Authorized Average CWIP(b)

Authorized Return on Common Equity(c)

Common Equity Component of Regulatory Capital Structure

Effective Date
Electric (2022 Test Period)

$
  1,044,362

$
  19,976

9.8%

55.63%

1/1/2022
Gas (2022 Test Period)

$
  299,319

$
  11,410

9.8%

55.63%

1/1/2022
Electric (2023 Test Period)(d)

$
  1,159,155

$
  19,976

9.8%

55.63%

1/1/2023
Gas (2023 Test Period)

$
  312,270

$
  8,228

9.8%

55.63%

1/1/2023


(Dollars in thousands)	Authorized Average Rate Base(a)		Authorized Average CWIP(b)		Authorized Return on Common Equity(c)	Common Equity Component of Regulatory Capital Structure	Effective Date
Electric (2023 Test Period)	$	1,162,516	$	19,976	9.8%	55.63%	1/1/2023
Gas (2023 Test Period)	$	312,270	$	8,228	9.8%	55.63%	1/1/2023
Electric (2024 Test Period)(d)	$	1,202,123	$	13,995	9.8%	56.12%	1/1/2024
Gas (2024 Test Period)(d)	$	338,417	$	3,701	9.8%	56.12%	1/1/2024
Electric (2025 Test Period)(d)	$	1,281,236	$	13,871	9.8%	56.05%	1/1/2025
Gas (2025 Test Period)(d)	$	345,463	$	3,341	9.8%	56.05%	1/1/2025

(a)

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

(b)

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

(c)

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

(d)

Pending approval by the PSCW. A final order is expected before the end of 2023. MGE cannot predict with any certainty the final outcome of the rate proceeding.

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

ATC

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

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

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

Several petitions for review of FERC’s prior orders were filed with the U.S. Court of Appeals for the D.C. Circuit ~~(the "Court")~~(Court) and an oral argument was held in November 2021. In August 2022, the Court ruled that four of the five

arguments made by the complaining parties were unpersuasive. However, the Court agreed that FERC’s decision to reintroduce a risk-premium model into its ROE methodology was arbitrary and capricious. The Court vacated the underlying orders for the First Complaint Period and remanded to FERC for further proceedings. In ~~September~~ 2022, our share of ATC's earnings reflected an estimated possible loss of approximately ~~$0.8~~$0.9 million, inclusive of interest and net of tax, for a possible additional refund for the First Complaint Period and for the period following the Second Complaint Period. Although the Court agreed that FERC was correct to use the base ROE established in the first complaint to adjudicate the second, and that FERC was right to dismiss the second complaint, the second complaint was also remanded for FERC to reopen proceedings. Any reduction in ATC's ROE could result in lower equity earnings and distributions from ATC in the future.

We derived approximately ~~5.1%~~5.7% and ~~5.7%~~5.1% of our net income during the nine months ended September 30, ~~2022~~2023 and ~~2021,~~2022, respectively, from our investment in ATC.

~~Inflation Reduction~~Uyghur Forced Labor Protection Act

In ~~August~~June 2021, the U.S. Customs and Border Protection (CBP) issued a Withhold Release Order (WRO) against silica-based products made by Hoshine Silicon Industry Co. Ltd., a company located in China's Xinjiang Uyghur Autonomous Region. As a result of this WRO, CBP is holding many solar panels imported into the United States until importers can prove that the panels do not contain materials originating from this region. The Uyghur Forced Labor Protection Act (UFLPA), a federal law that became effective on June 21, 2022, further established that all goods mined, produced, or manufactured wholly or in part in Xinjiang or by certain defined entities are prohibited from U.S. importation. Suppliers for MGE's current solar projects were able to provide the CBP sufficient documentation to meet WRO compliance requirements, and MGE expects the same will be true for UFLPA purposes, however we cannot currently predict what, if any, impact the UFLPA will have on the overall supply of solar panels into the United States and the related impact to timing and cost of solar projects included in our capital plan. In the event that such disruptions cause costs to exceed the levels approved for specific projects, we have filed and expect to continue to file a notification with the PSCW and expect to request recovery of any increases in MGE's future rate proceedings.

U.S. Department of Commerce Investigation

In March 2022, the ~~Inflation Reduction Act (IRA) was signed into law. Among other provisions,~~U.S. Department of Commerce (USDOC) announced a solar tariff investigation on solar panels from four Southeast Asian countries. This investigation could result in additional tariffs on solar panels. In June 2022, the IRA: extends current PTC and ITC for renewable technologies (e.g., wind and solar); restores full value of the PTC and ITC for qualifying facilities placed into service after 2021 that satisfy prevailing wage and apprenticeship requirements; createsUSDOC issued a ~~PTC~~24-month exemption from tariffs for solar ~~clean hydrogen~~panel and ~~nuclear; establishes~~module imports from these four

countries. MGE is currently assessing the potential impact of these disruptions on current and future solar projects which may result in an ~~ITC~~increase in costs or delays in construction timelines. In the event that such disruptions cause costs to exceed the levels approved for ~~energy storage, microgrids,~~specific projects, we have filed and ~~interconnection facilities; and allows companies to monetize or sell credits to unrelated parties. In addition, the IRA created a new corporate alternative minimum tax (AMT). MGE Energy does not~~ expect to ~~be subject~~continue to file a notification with the ~~AMT~~PSCW and expect to request recovery of any increases in the near term. Implementation of IRA provisions is subject to the issuance of additional guidance by the U.S. Treasury Department. While the final impact cannot be determined at this time, the IRA is not expected to have a material impact on MGE Energy and MGE for the year ending December 31, 2022.MGE's future rate proceedings.

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.

4849

Item 3. Quantitative and Qualitative Disclosures About Market Risk.

There were no material changes to the market risks disclosed in Item 7A. Quantitative and Qualitative Disclosures About Market Risk in our ~~2021~~2022 Annual Report on Form 10-K~~, except as noted below.~~.

~~Equity Price Risk - Pension-Related Assets~~

MGE currently funds its liabilities related to employee benefits through trust funds. These funds, which include investments in debt and equity securities, are managed by various third-party investment managers. Changes in the market value of these investments can have an impact on the future expenses related to these liabilities. The value of employee benefit plan assets has declined by approximately 23% during the nine months ended September 30, 2022.

Item 4. Controls and Procedures.

During the third quarter of ~~2022,~~2023, 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, ~~2022,~~2023, 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, ~~2022,~~2023, 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.

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.

There were no material changes from the risk factors disclosed in Item 1A. Risk Factors in our ~~2021~~2022 Annual Report on Form 10-K.

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

Under the MGE Energy, Inc. Direct Stock Purchase and Dividend Reinvestment Plan (Stock Plan), common stock shares purchased by plan participants may be either shares issued by MGE Energy or shares purchased on the open market, as determined from time to time by MGE Energy. Shares issued by MGE Energy are covered by an existing registration statement. Shares purchased in the open market are purchased at the direction of the plan participants by MGE Energy's transfer agent's securities broker-dealer for the accounts of those plan participants. Subject to the plan's restrictions, the timing and amount of open market purchases is determined by the plan participants and the broker-dealer. MGE Energy is not involved in the open market purchases. During ~~2022,~~2023, shares purchased under the Stock Plan have been purchased in the open market.

Item 3. Defaults Upon Senior Securities.

None.

Item 4. Mine Safety Disclosures.

Not applicable to MGE Energy and MGE.

Item 5. Other Information.

~~Expected Issuance of Notes~~

During the three months ended September 30, 2023, no director or officer of MGEE Energy or Madison Gas and Electric

~~On November 1, 2022, MGE entered into~~adopted or terminated a ~~private placement Note Purchase Agreement~~Rule 10b5-1 trading arrangement or non-Rule 10b5-1 trading arrangement, as defined in ~~which it committed to issue $25 million~~Item 408(a) of 5.43% senior notes, Series A, due December 1, 2032, $15 million of 5.43% senior notes, Series B, due February 15, 2033, and $35 million of 5.53% senior notes, Series C, due February 15, 2035. Funding will occur on December 1, 2022 for Series A notes and on February 28, 2023 for Series B notes and Series C notes. The proceeds of the notes will be used to assist with capital expenditures and other corporate obligations.Regulation S-K.

The Series A, Series B, and Series C notes are redeemable at any time at MGE's option at a redemption price equal to 100% of the principal amount of the Notes to be redeemed, plus accrued interest to the redemption date and a make-whole premium (not less than zero) equal to the excess, if any, of the discounted present value of the remaining scheduled payments of principal and interest on the notes to be redeemed over the principal amount of the notes to be redeemed, except that no make-whole premium is due on a note that is redeemed during the 90-day period immediately preceding and ending on its maturity date. Following a change in control event, MGE must offer to prepay the notes at a price equal to 100% of the principal amount of the notes, plus accrued interest to the date of prepayment, but without any make-whole premium. The prepayment offer expires if not accepted by a holder of notes within a defined period. A change in control event is deemed to have occurred if MGE does not have an investment grade rating for its senior, unsecured, long-term indebtedness from at least two of Standard & Poor's Rating Services, Moody's Investors Service or any other nationally recognized statistical rating agency, within 90 days after an acquisition of beneficial ownership of 30% or more of the outstanding voting stock of MGE Energy, Inc. by one person, or two or more persons acting in concert.

Events of default under the Note Purchase Agreement include failures to pay principal, make-whole premium or interest on the notes; defaults in the performance of various covenants; cross-defaults to specified other indebtedness; failure to pay specified judgments; and certain bankruptcy-related events; subject to any applicable cure periods. The Note Purchase Agreement requires MGE to maintain a ratio of its consolidated indebtedness to consolidated total capitalization not to exceed a maximum of 65%. Both consolidated indebtedness and consolidated total capitalization are determined in accordance with generally accepted accounting principles, except that amounts included within MGE's indebtedness and capitalization from "variable interest entities" as a result of the application of FASB Interpretation No. 46, Consolidation of Variable Interest Entities – an Interpretation of ARB No. 51, as modified, are excluded.

The Note Purchase Agreement also restricts MGE from issuing "Priority Debt" in an amount exceeding 20% of its consolidated assets. MGE has agreed not to use the capacity to issue Priority Debt to grant a lien to secure its principal credit facility indebtedness without simultaneously providing that the notes be equally and ratably secured with the principal credit facility indebtedness so long as such indebtedness is so secured. Priority Debt is defined as any indebtedness of MGE secured by liens other than specified liens permitted by the Note Purchase Agreement and certain unsecured indebtedness of certain subsidiaries. Principal credit facility indebtedness means the indebtedness under MGE's Amended and Restated Credit Agreements dated as of February 7, 2019, with the lenders party thereto and JPMorgan Chase Bank, N.A., as Administrative Agent, and with the lenders party thereto and US Bank National Association, as Administrative Agent, or, in each case, any replacement credit agreement, including amendments and restatements.

Item 6. Exhibits.



Ex. No.		Exhibit Description
~~4.1~~		Note Purchase Agreement dated November 1, 2022, among MGE and the purchasers named therein, including form of 5.43% Senior Notes, Series A, due December 1, 2032; form of 5.43% Senior Notes, Series B, due February 15, 2033; and form of 5.53% Senior Notes, Series C, due February 15, 2035.

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.

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 ~~3, 2022~~2, 2023	/s/ Jeffrey M. Keebler
	Jeffrey M. Keebler Chairman, President and Chief Executive Officer (Duly Authorized Officer)



Date: November ~~3, 2022~~2, 2023	/s/ Jared J. Bushek
	Jared J. Bushek Vice President - ~~Finance,~~ Chief ~~Information~~Financial Officer and Treasurer (Chief Financial Officer)



Date: November ~~3, 2022~~2, 2023	/s/ Tamara J. Johnson
	Tamara J. Johnson Vice President - Chief Accounting Officer and Controller (Chief Accounting Officer)

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 ~~3, 2022~~2, 2023	/s/ Jeffrey M. Keebler
	Jeffrey M. Keebler Chairman, President and Chief Executive Officer (Duly Authorized Officer)



Date: November ~~3, 2022~~2, 2023	/s/ Jared J. Bushek
	Jared J. Bushek Vice President - ~~Finance,~~ Chief ~~Information~~Financial Officer and Treasurer (Chief Financial Officer)



Date: November ~~3, 2022~~2, 2023	/s/ Tamara J. Johnson
	Tamara J. Johnson Vice President - Chief Accounting Officer and Controller (Chief Accounting Officer)


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

MGE
Assets:
Derivatives, net(c)	$	3,606	$	1,170	$	—	$	2,436
Exchange-traded investments		230		230		—		—
Total Assets	$	3,836	$	1,400	$	—	$	2,436
Liabilities:
Derivatives, net	$	2,989	$	731	$	—	$	2,258
Deferred compensation		3,653		—		3,653		—
Total Liabilities	$	6,642	$	731	$	3,653	$	2,258