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MGE ENERGY INC - Quarter Report: 2023 September (Form 10-Q)

10-Q

 

 

United States

SECURITIES AND EXCHANGE COMMISSION

Washington, D.C. 20549

FORM 10-Q

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

For the quarterly period ended:

September 30, 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, 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.).

 

1


 

Table of Contents

PART I. FINANCIAL INFORMATION

3

Filing Format

3

Forward-Looking Statements

3

Where to Find More Information

3

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

4

Item 1. Financial Statements.

6

MGE Energy, Inc.

6

Consolidated Statements of Income (unaudited)

6

Consolidated Statements of Cash Flows (unaudited)

7

Consolidated Balance Sheets (unaudited)

8

Consolidated Statements of Common Equity (unaudited)

9

Madison Gas and Electric Company

10

Consolidated Statements of Income (unaudited)

10

Consolidated Statements of Cash Flows (unaudited)

11

Consolidated Balance Sheets (unaudited)

12

Consolidated Statements of Equity (unaudited)

13

MGE Energy, Inc., and Madison Gas and Electric Company - Notes to Consolidated Financial Statements (unaudited)

14

1. Summary of Significant Accounting Policies.

14

2. New Accounting Standards.

15

3. Investment in ATC and ATC Holdco.

15

4. Taxes.

16

5. Pension and Other Postretirement Plans.

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.

26

12. Joint Plant Construction Project Ownership.

29

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.

50

Item 4. Controls and Procedures.

50

PART II. OTHER INFORMATION.

51

Item 1. Legal Proceedings.

51

Item 1A. Risk Factors.

51

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

51

Item 3. Defaults Upon Senior Securities.

51

Item 4. Mine Safety Disclosures.

51

Item 5. Other Information.

51

Item 6. Exhibits.

52

Signatures - MGE Energy, Inc.

53

Signatures - Madison Gas and Electric Company

54

 

2


 

PART I. FINANCIAL INFORMATION.

 

Filing Format

 

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

 

Forward-Looking Statements

 

This report, and other documents filed by MGE Energy and MGE with the Securities and Exchange Commission (SEC) from time to time, contain forward-looking statements that reflect management's current assumptions and estimates regarding future performance and economic conditions—especially as they relate to economic conditions, future load growth, revenues, expenses, capital expenditures 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' 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.
 

3


 

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

 

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

 

MGE Energy and Subsidiaries:

 

CWDC

Central Wisconsin Development Corporation

MAGAEL

MAGAEL, LLC

MGE

Madison Gas and Electric Company

MGE Energy

MGE Energy, Inc.

MGE Power

MGE Power, LLC

MGE Power Elm Road

MGE Power Elm Road, LLC

MGE Power West Campus

MGE Power West Campus, LLC

MGE Services

MGE Services, LLC

MGE State Energy Services

MGE State Energy Services, LLC

MGE Transco

MGE Transco Investment, LLC

MGEE Transco

MGEE Transco, LLC

North Mendota

North Mendota Energy & Technology Park, LLC

 

Other Defined Terms:

 

2017 Tax Act

Tax Cut and Jobs Act of 2017

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, 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

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

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

4


 

PPA

Purchased Power Agreement

PSCW

Public Service Commission of Wisconsin

ROE

Return on equity

SEC

Securities and Exchange Commission

SO2

Sulfur dioxide

Stock Plan

Direct Stock Purchase and Dividend Reinvestment Plan of MGE Energy

UFLPA

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

5


 

Item 1. Financial Statements.

MGE Energy, Inc.

Consolidated Statements of Income (unaudited)

(In thousands, except per share amounts)

 

 

 

Three Months Ended

 

 

Nine Months Ended

 

 

 

September 30,

 

 

September 30,

 

 

 

2023

 

 

2022

 

 

2023

 

 

2022

 

Operating Revenues:

 

 

 

 

 

 

 

 

 

 

 

 

Electric revenues

 

$

139,104

 

 

$

133,090

 

 

$

378,102

 

 

$

355,381

 

Gas revenues

 

 

21,424

 

 

 

30,310

 

 

 

147,677

 

 

 

169,305

 

Total Operating Revenues

 

 

160,528

 

 

 

163,400

 

 

 

525,779

 

 

 

524,686

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Operating Expenses:

 

 

 

 

 

 

 

 

 

 

 

 

Fuel for electric generation

 

 

19,712

 

 

 

21,045

 

 

 

47,118

 

 

 

48,410

 

Purchased power

 

 

7,021

 

 

 

9,593

 

 

 

28,252

 

 

 

35,757

 

Cost of gas sold

 

 

5,160

 

 

 

14,523

 

 

 

80,296

 

 

 

100,638

 

Other operations and maintenance

 

 

53,997

 

 

 

49,194

 

 

 

156,004

 

 

 

150,714

 

Depreciation and amortization

 

 

25,241

 

 

 

21,447

 

 

 

74,971

 

 

 

63,780

 

Other general taxes

 

 

5,605

 

 

 

5,111

 

 

 

16,922

 

 

 

15,579

 

Total Operating Expenses

 

 

116,736

 

 

 

120,913

 

 

 

403,563

 

 

 

414,878

 

Operating Income

 

 

43,792

 

 

 

42,487

 

 

 

122,216

 

 

 

109,808

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Other income, net

 

 

10,549

 

 

 

6,068

 

 

 

20,841

 

 

 

20,736

 

Interest expense, net

 

 

(7,654

)

 

 

(6,652

)

 

 

(22,901

)

 

 

(19,686

)

Income before income taxes

 

 

46,687

 

 

 

41,903

 

 

 

120,156

 

 

 

110,858

 

Income tax provision

 

 

(8,830

)

 

 

(8,183

)

 

 

(22,540

)

 

 

(20,957

)

Net Income

 

$

37,857

 

 

$

33,720

 

 

$

97,616

 

 

$

89,901

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Earnings Per Share of Common Stock

 

 

 

 

 

 

 

 

 

 

 

 

Basic

 

$

1.05

 

 

$

0.93

 

 

$

2.70

 

 

$

2.49

 

Diluted

 

$

1.05

 

 

$

0.93

 

 

$

2.70

 

 

$

2.49

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Dividends per share of common stock

 

$

0.428

 

 

$

0.408

 

 

$

1.243

 

 

$

1.183

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Weighted Average Shares Outstanding

 

 

 

 

 

 

 

 

 

 

 

 

Basic

 

 

36,163

 

 

 

36,163

 

 

 

36,163

 

 

 

36,163

 

Diluted

 

 

36,189

 

 

 

36,176

 

 

 

36,185

 

 

 

36,174

 

 

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

6


 

MGE Energy, Inc.

Consolidated Statements of Cash Flows (unaudited)

(In thousands)

 

 

 

Nine Months Ended

 

 

 

September 30,

 

 

 

2023

 

 

2022

 

Operating Activities:

 

 

 

 

 

 

Net income

 

$

97,616

 

 

$

89,901

 

Items not affecting cash:

 

 

 

 

 

 

Depreciation and amortization

 

 

74,971

 

 

 

63,780

 

Deferred income taxes

 

 

16,326

 

 

 

18,021

 

Provision for doubtful receivables

 

 

1,323

 

 

 

1,323

 

Employee benefit plan cost (credit)

 

 

(2,976

)

 

 

(6,087

)

Equity earnings in investments

 

 

(7,930

)

 

 

(6,626

)

Other items

 

 

(2,502

)

 

 

(2,821

)

Changes in working capital items:

 

 

 

 

 

 

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

 

 

6,305

 

 

 

5,964

 

Cash contributions to pension and other postretirement plans

 

 

(5,290

)

 

 

(5,095

)

Other noncurrent items, net

 

 

2,519

 

 

 

(2,255

)

Cash Provided by Operating Activities

 

 

194,038

 

 

 

144,282

 

 

 

 

 

 

 

 

Investing Activities:

 

 

 

 

 

 

Capital expenditures

 

 

(150,298

)

 

 

(133,409

)

Capital contributions to investments

 

 

(5,986

)

 

 

(3,938

)

Other

 

 

(206

)

 

 

128

 

Cash Used for Investing Activities

 

 

(156,490

)

 

 

(137,219

)

 

 

 

 

 

 

 

Financing Activities:

 

 

 

 

 

 

Cash dividends paid on common stock

 

 

(44,933

)

 

 

(42,763

)

Repayments of long-term debt

 

 

(53,048

)

 

 

(3,655

)

Issuance of long-term debt

 

 

109,300

 

 

 

 

(Repayments of) proceeds from short-term debt

 

 

(48,500

)

 

 

34,500

 

Other

 

 

(2,128

)

 

 

(745

)

Cash Used for Financing Activities

 

 

(39,309

)

 

 

(12,663

)

 

 

 

 

 

 

 

Change in cash, cash equivalents, and restricted cash

 

 

(1,761

)

 

 

(5,600

)

Cash, cash equivalents, and restricted cash at beginning of period

 

 

17,968

 

 

 

18,835

 

Cash, cash equivalents, and restricted cash at end of period

 

$

16,207

 

 

$

13,235

 

 

 

 

 

 

 

 

Supplemental disclosures of cash flow information:

 

 

 

 

 

 

Significant noncash investing activities:

 

 

 

 

 

 

Accrued capital expenditures

 

$

17,716

 

 

$

11,218

 

 

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

7


 

MGE Energy, Inc.

Consolidated Balance Sheets (unaudited)

(In thousands)

 

 

 

September 30,

 

 

December 31,

 

ASSETS

 

2023

 

 

2022

 

Current Assets:

 

 

 

 

 

 

Cash and cash equivalents

 

$

11,269

 

 

$

11,604

 

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

 

 

24,687

 

 

 

43,086

 

Materials and supplies, at average cost

 

 

35,329

 

 

 

33,465

 

Fuel for electric generation, at average cost

 

 

9,492

 

 

 

7,962

 

Stored natural gas, at average cost

 

 

27,595

 

 

 

32,848

 

Prepaid taxes

 

 

13,856

 

 

 

19,132

 

Regulatory assets - current

 

 

18,308

 

 

 

9,541

 

Other current assets

 

 

14,786

 

 

 

19,017

 

Total Current Assets

 

 

216,411

 

 

 

243,480

 

Regulatory assets

 

 

96,764

 

 

 

103,900

 

Pension benefit asset

 

 

74,087

 

 

 

68,872

 

Other deferred assets and other

 

 

21,485

 

 

 

24,365

 

Property, Plant, and Equipment:

 

 

 

 

 

 

Property, plant, and equipment, net

 

 

1,902,032

 

 

 

1,865,352

 

Construction work in progress

 

 

168,504

 

 

 

105,748

 

Total Property, Plant, and Equipment

 

 

2,070,536

 

 

 

1,971,100

 

Investments

 

 

111,249

 

 

 

105,883

 

Total Assets

 

$

2,590,532

 

 

$

2,517,600

 

 

 

 

 

 

 

 

LIABILITIES AND CAPITALIZATION

 

 

 

 

 

 

Current Liabilities:

 

 

 

 

 

 

Long-term debt due within one year

 

$

5,112

 

 

$

54,314

 

Short-term debt

 

 

22,000

 

 

 

70,500

 

Accounts payable

 

 

53,593

 

 

 

59,334

 

Accrued interest and taxes

 

 

7,368

 

 

 

7,868

 

Accrued payroll related items

 

 

13,155

 

 

 

13,064

 

Regulatory liabilities - current

 

 

13,462

 

 

 

11,925

 

Other current liabilities

 

 

8,148

 

 

 

8,057

 

Total Current Liabilities

 

 

122,838

 

 

 

225,062

 

Other Credits:

 

 

 

 

 

 

Deferred income taxes

 

 

271,453

 

 

 

252,190

 

Investment tax credit - deferred

 

 

47,369

 

 

 

48,735

 

Regulatory liabilities

 

 

155,026

 

 

 

156,988

 

Accrued pension and other postretirement benefits

 

 

54,531

 

 

 

53,607

 

Finance lease liabilities

 

 

17,932

 

 

 

17,108

 

Other deferred liabilities and other

 

 

96,102

 

 

 

96,990

 

Total Other Credits

 

 

642,413

 

 

 

625,618

 

Capitalization:

 

 

 

 

 

 

Common shareholders' equity

 

 

1,135,253

 

 

 

1,081,674

 

Long-term debt

 

 

690,028

 

 

 

585,246

 

Total Capitalization

 

 

1,825,281

 

 

 

1,666,920

 

Commitments and contingencies (see Footnote 8)

 

 

 

 

 

 

Total Liabilities and Capitalization

 

$

2,590,532

 

 

$

2,517,600

 

 

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

8


 

MGE Energy, Inc.

Consolidated Statements of Common Equity (unaudited)

(In thousands, except per share amounts)

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Accumulated

 

 

 

 

 

 

 

 

 

 

 

 

Additional

 

 

 

 

 

Other

 

 

 

 

 

 

Common Stock

 

 

Paid-in

 

 

Retained

 

 

Comprehensive

 

 

 

 

 

 

Shares

 

 

Value

 

 

Capital

 

 

Earnings

 

 

Income/(Loss)

 

 

Total

 

Three Months Ended September 30, 2022

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Beginning Balance

 

 

36,163

 

 

$

36,163

 

 

$

395,338

 

 

$

624,556

 

 

$

 

 

$

1,056,057

 

Net income

 

 

 

 

 

 

 

 

 

 

 

33,720

 

 

 

 

 

 

33,720

 

Common stock dividends declared
   ($
0.408 per share)

 

 

 

 

 

 

 

 

 

 

 

(14,736

)

 

 

 

 

 

(14,736

)

Equity-based compensation plans and other

 

 

 

 

 

 

 

 

159

 

 

 

 

 

 

 

 

 

159

 

Ending Balance - September 30, 2022

 

 

36,163

 

 

$

36,163

 

 

$

395,497

 

 

$

643,540

 

 

$

 

 

$

1,075,200

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Three Months Ended September 30, 2023

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Beginning Balance

 

 

36,163

 

 

$

36,163

 

 

$

396,281

 

 

$

680,140

 

 

$

 

 

$

1,112,584

 

Net income

 

 

 

 

 

 

 

 

 

 

 

37,857

 

 

 

 

 

 

37,857

 

Common stock dividends declared
   ($
0.428 per share)

 

 

 

 

 

 

 

 

 

 

 

(15,460

)

 

 

 

 

 

(15,460

)

Equity-based compensation plans and other

 

 

 

 

 

 

 

 

272

 

 

 

 

 

 

 

 

 

272

 

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

 

Net income

 

 

 

 

 

 

 

 

 

 

 

89,901

 

 

 

 

 

 

89,901

 

Common stock dividends declared
   ($
1.183 per share)

 

 

 

 

 

 

 

 

 

 

 

(42,763

)

 

 

 

 

 

(42,763

)

Equity-based compensation plans and other

 

 

 

 

 

 

 

 

594

 

 

 

 

 

 

 

 

 

594

 

Ending Balance - September 30, 2022

 

 

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.

9


 

Madison Gas and Electric Company

Consolidated Statements of Income (unaudited)

(In thousands)

 

 

 

Three Months Ended

 

 

Nine Months Ended

 

 

 

September 30,

 

 

September 30,

 

 

 

2023

 

 

2022

 

 

2023

 

 

2022

 

Operating Revenues:

 

 

 

 

 

 

 

 

 

 

 

 

Electric revenues

 

$

139,104

 

 

$

133,090

 

 

$

378,102

 

 

$

355,381

 

Gas revenues

 

 

21,424

 

 

 

30,310

 

 

 

147,677

 

 

 

169,305

 

Total Operating Revenues

 

 

160,528

 

 

 

163,400

 

 

 

525,779

 

 

 

524,686

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Operating Expenses:

 

 

 

 

 

 

 

 

 

 

 

 

Fuel for electric generation

 

 

19,712

 

 

 

21,045

 

 

 

47,118

 

 

 

48,410

 

Purchased power

 

 

7,021

 

 

 

9,593

 

 

 

28,252

 

 

 

35,757

 

Cost of gas sold

 

 

5,160

 

 

 

14,523

 

 

 

80,296

 

 

 

100,638

 

Other operations and maintenance

 

 

53,847

 

 

 

48,989

 

 

 

155,251

 

 

 

150,024

 

Depreciation and amortization

 

 

25,241

 

 

 

21,447

 

 

 

74,971

 

 

 

63,780

 

Other general taxes

 

 

5,605

 

 

 

5,106

 

 

 

16,922

 

 

 

15,573

 

Total Operating Expenses

 

 

116,586

 

 

 

120,703

 

 

 

402,810

 

 

 

414,182

 

Operating Income

 

 

43,942

 

 

 

42,697

 

 

 

122,969

 

 

 

110,504

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Other income, net

 

 

7,824

 

 

 

4,430

 

 

 

13,985

 

 

 

12,467

 

Interest expense, net

 

 

(7,721

)

 

 

(6,662

)

 

 

(23,056

)

 

 

(19,709

)

Income before income taxes

 

 

44,045

 

 

 

40,465

 

 

 

113,898

 

 

 

103,262

 

Income tax provision

 

 

(8,093

)

 

 

(7,664

)

 

 

(20,696

)

 

 

(18,781

)

Net Income

 

$

35,952

 

 

$

32,801

 

 

$

93,202

 

 

$

84,481

 

Less: Net Income Attributable to Noncontrolling
  Interest, net of tax

 

 

(5,487

)

 

 

(5,603

)

 

 

(16,382

)

 

 

(15,947

)

Net Income Attributable to MGE

 

$

30,465

 

 

$

27,198

 

 

$

76,820

 

 

$

68,534

 

 

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

10


 

Madison Gas and Electric Company

Consolidated Statements of Cash Flows (unaudited)

(In thousands)

 

 

 

Nine Months Ended

 

 

 

September 30,

 

 

 

2023

 

 

2022

 

Operating Activities:

 

 

 

 

 

 

Net income

 

$

93,202

 

$

84,481

 

Items not affecting cash:

 

 

 

 

 

 

Depreciation and amortization

 

 

74,971

 

 

 

63,780

 

Deferred income taxes

 

 

15,218

 

 

 

17,706

 

Provision for doubtful receivables

 

 

1,323

 

 

 

1,323

 

Employee benefit plan cost (credit)

 

 

(2,976

)

 

 

(6,087

)

Other items

 

 

(2,604

)

 

 

(636

)

Changes in working capital items:

 

 

 

 

 

 

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

 

 

(5,290

)

 

 

(5,095

)

Other noncurrent items, net

 

 

1,840

 

 

 

(2,806

)

Cash Provided by Operating Activities

 

 

190,368

 

 

 

141,786

 

 

 

 

 

 

 

 

Investing Activities:

 

 

 

 

 

 

Capital expenditures

 

 

(150,298

)

 

 

(133,409

)

Other

 

 

(1,338

)

 

 

(680

)

Cash Used for Investing Activities

 

 

(151,636

)

 

 

(134,089

)

 

 

 

 

 

 

 

Financing Activities:

 

 

 

 

 

 

Cash dividends paid to parent by MGE

 

 

(30,000

)

 

 

(21,000

)

Distributions to parent from noncontrolling interest

 

 

(17,250

)

 

 

(17,500

)

Repayments of long-term debt

 

 

(53,048

)

 

 

(3,655

)

Issuance of long-term debt

 

 

109,300

 

 

 

 

(Repayments of) proceeds from short-term debt

 

 

(48,500

)

 

 

34,500

 

Other

 

 

(2,128

)

 

 

(745

)

Cash Used for Financing Activities

 

 

(41,626

)

 

 

(8,400

)

 

 

 

 

 

 

 

Change in cash, cash equivalents, and restricted cash

 

 

(2,894

)

 

 

(703

)

Cash, cash equivalents, and restricted cash at beginning of period

 

 

10,500

 

 

 

7,798

 

Cash, cash equivalents, and restricted cash at end of period

 

$

7,606

 

$

7,095

 

 

 

 

 

 

 

 

Supplemental disclosures of cash flow information:

 

 

 

 

 

 

Significant noncash investing activities:

 

 

 

 

 

 

Accrued capital expenditures

 

$

17,716

 

$

11,218

 

 

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

11


 

Madison Gas and Electric Company

Consolidated Balance Sheets (unaudited)

(In thousands)

 

 

 

September 30,

 

 

December 31,

 

ASSETS

 

2023

 

 

2022

 

Current Assets:

 

 

 

 

 

 

Cash and cash equivalents

 

$

2,668

 

 

$

4,136

 

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

 

 

24,687

 

 

 

43,086

 

Materials and supplies, at average cost

 

 

35,329

 

 

 

33,465

 

Fuel for electric generation, at average cost

 

 

9,492

 

 

 

7,962

 

Stored natural gas, at average cost

 

 

27,595

 

 

 

32,848

 

Prepaid taxes

 

 

14,055

 

 

 

18,467

 

Regulatory assets - current

 

 

18,308

 

 

 

9,541

 

Other current assets

 

 

15,284

 

 

 

19,479

 

Total Current Assets

 

 

208,505

 

 

 

235,807

 

Regulatory assets

 

 

96,764

 

 

 

103,900

 

Pension benefit asset

 

 

74,087

 

 

 

68,872

 

Other deferred assets and other

 

 

21,611

 

 

 

24,817

 

Property, Plant, and Equipment:

 

 

 

 

 

 

Property, plant, and equipment, net

 

 

1,902,060

 

 

 

1,865,380

 

Construction work in progress

 

 

168,504

 

 

 

105,748

 

Total Property, Plant, and Equipment

 

 

2,070,564

 

 

 

1,971,128

 

Investments

 

 

83

 

 

 

115

 

Total Assets

 

$

2,471,614

 

 

$

2,404,639

 

 

 

 

 

 

 

 

LIABILITIES AND CAPITALIZATION

 

 

 

 

 

 

Current Liabilities:

 

 

 

 

 

 

Long-term debt due within one year

 

$

5,112

 

 

$

54,314

 

Short-term debt

 

 

22,000

 

 

 

70,500

 

Accounts payable

 

 

53,578

 

 

 

59,317

 

Accrued interest and taxes

 

 

7,323

 

 

 

7,912

 

Accrued payroll related items

 

 

13,155

 

 

 

13,064

 

Regulatory liabilities - current

 

 

13,462

 

 

 

11,925

 

Other current liabilities

 

 

8,148

 

 

 

6,062

 

Total Current Liabilities

 

 

122,778

 

 

 

223,094

 

Other Credits:

 

 

 

 

 

 

Deferred income taxes

 

 

237,414

 

 

 

219,258

 

Investment tax credit - deferred

 

 

47,369

 

 

 

48,735

 

Regulatory liabilities

 

 

155,026

 

 

 

156,988

 

Accrued pension and other postretirement benefits

 

 

54,531

 

 

 

53,607

 

Finance lease liabilities

 

 

17,932

 

 

 

17,108

 

Other deferred liabilities and other

 

 

98,198

 

 

 

98,217

 

Total Other Credits

 

 

610,470

 

 

 

593,913

 

Capitalization:

 

 

 

 

 

 

Common shareholder's equity

 

 

901,043

 

 

 

854,223

 

Noncontrolling interest

 

 

147,295

 

 

 

148,163

 

Total Equity

 

 

1,048,338

 

 

 

1,002,386

 

Long-term debt

 

 

690,028

 

 

 

585,246

 

Total Capitalization

 

 

1,738,366

 

 

 

1,587,632

 

Commitments and contingencies (see Footnote 8)

 

 

 

 

 

 

Total Liabilities and Capitalization

 

$

2,471,614

 

 

$

2,404,639

 

 

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

12


 

Madison Gas and Electric Company

Consolidated Statements of Equity (unaudited)

(In thousands)

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Accumulated

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Additional

 

 

 

 

 

Other

 

 

Non-

 

 

 

 

 

 

Common Stock

 

 

Paid-in

 

 

Retained

 

 

Comprehensive

 

 

Controlling

 

 

 

 

 

 

Shares

 

 

Value

 

 

Capital

 

 

Earnings

 

 

Income/(Loss)

 

 

Interest

 

 

Total

 

Three Months Ended September 30, 2022

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Beginning balance

 

 

17,348

 

 

$

17,348

 

 

$

252,917

 

 

$

562,878

 

 

$

 

 

$

145,681

 

 

$

978,824

 

Net income

 

 

 

 

 

 

 

 

 

 

 

27,198

 

 

 

 

 

 

5,603

 

 

 

32,801

 

Cash dividends paid to parent by MGE

 

 

 

 

 

 

 

 

 

 

 

(9,000

)

 

 

 

 

 

 

 

 

(9,000

)

Distributions to parent from
   noncontrolling interest

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

(4,250

)

 

 

(4,250

)

Ending Balance - September 30, 2022

 

 

17,348

 

 

$

17,348

 

 

$

252,917

 

 

$

581,076

 

 

$

 

 

$

147,034

 

 

$

998,375

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Three Months Ended September 30, 2023

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Beginning balance

 

 

17,348

 

 

$

17,348

 

 

$

252,917

 

 

$

609,313

 

 

$

 

 

$

148,808

 

 

$

1,028,386

 

Net income

 

 

 

 

 

 

 

 

 

 

 

30,465

 

 

 

 

 

 

5,487

 

 

 

35,952

 

Cash dividends paid to parent by MGE

 

 

 

 

 

 

 

 

 

 

 

(9,000

)

 

 

 

 

 

 

 

 

(9,000

)

Distributions to parent from
   noncontrolling interest

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

(7,000

)

 

 

(7,000

)

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

 

Net income

 

 

 

 

 

 

 

 

 

 

 

68,534

 

 

 

 

 

 

15,947

 

 

 

84,481

 

Cash dividends paid to parent by MGE

 

 

 

 

 

 

 

 

 

 

 

(21,000

)

 

 

 

 

 

 

 

 

(21,000

)

Distributions to parent from
   noncontrolling interest

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

(17,500

)

 

 

(17,500

)

Ending Balance - September 30, 2022

 

 

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.

13


 

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

Notes to Consolidated Financial Statements (unaudited)

September 30, 2023

 

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

 

a.
Basis of Presentation.

 

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

 

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

 

The accompanying consolidated financial statements as of September 30, 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 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 57 through 107 of the 2022 Annual Report on Form 10-K.

 

b.
Cash, Cash Equivalents, and Restricted Cash.

 

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

 

 

 

MGE Energy

 

MGE

 

 

September 30,

 

December 31,

 

September 30,

 

December 31,

(In thousands)

 

2023

 

2022

 

2023

 

2022

Cash and cash equivalents

 

$

11,269

 

$

11,604

 

$

2,668

 

$

4,136

Restricted cash

 

 

645

 

 

867

 

 

645

 

 

867

Receivable - margin account

 

 

4,293

 

 

5,497

 

 

4,293

 

 

5,497

Cash, cash equivalents, and restricted cash

 

$

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.

 

14


 

c.
Property, Plant, and Equipment.

 

Columbia.

 

An asset that will be retired in the near future and substantially in advance of its previously expected retirement date is subject to abandonment accounting. In the second quarter of 2021, the operator of Columbia received approval from MISO to retire Columbia Units 1 and 2. The co-owners intend to retire Unit 1 and Unit 2 by June 2026. Final timing and retirement dates are subject to change depending on operational, regulatory, and other factors. As of September 30, 2023, early retirement of Columbia was probable.

 

The net book value of our ownership share of this generating unit was $133.0 million as of September 30, 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 include retirement dates of 2029 for 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, 2023.

2.
New Accounting Standards - MGE Energy and MGE.

 

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

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

 

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

 

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

 

 

 

Three Months Ended

 

 

Nine Months Ended

 

 

 

September 30,

 

 

September 30,

 

(In thousands)

 

2023

 

 

2022

 

 

2023

 

 

2022

 

Equity earnings from investment in ATC

 

$

2,662

 

 

$

1,473

 

 

$

7,844

 

 

$

6,543

 

Dividends received from ATC

 

 

2,057

 

 

 

2,005

 

 

 

6,305

 

 

 

5,964

 

Capital contributions to ATC

 

 

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 2023, MGE Transco made a $0.7 million capital contribution to ATC.

15


 

ATC's summarized financial data is as follows:

 

 

 

Three Months Ended

 

 

Nine Months Ended

 

 

 

September 30,

 

 

September 30,

 

(In thousands)

 

2023

 

 

2022

 

 

2023

 

 

2022

 

Operating revenues

 

$

206,197

 

 

$

169,779

 

 

$

610,399

 

 

$

552,383

 

Operating expenses

 

 

(102,819

)

 

 

(97,629

)

 

 

(303,412

)

 

 

(288,376

)

Other income, net

 

 

701

 

 

 

272

 

 

 

1,657

 

 

 

1,020

 

Interest expense, net

 

 

(33,555

)

 

 

(34,794

)

 

 

(99,969

)

 

 

(92,293

)

Earnings before members' income taxes

 

$

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, 2023, MGE recorded $8.5 million and $25.4 million, respectively, for transmission service compared to $7.9 million and $23.6 million for comparable periods in 2022. MGE also provides a variety of operational, maintenance, and project management work for ATC, which is reimbursed by ATC. As of September 30, 2023, and December 31, 2022, MGE had a receivable due from ATC of $5.3 million and $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.

4.
Taxes - MGE Energy and MGE.

 

Effective Tax Rate.

 

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

 

 

 

MGE Energy

 

MGE

Three Months Ended September 30,

 

2023

 

2022

 

2023

 

2022

Statutory federal income tax rate

 

 

21.0

 

%

 

 

21.0

 

%

 

 

21.0

 

%

 

 

21.0

 

%

State income taxes, net of federal benefit

 

 

6.2

 

 

 

 

6.2

 

 

 

 

6.2

 

 

 

 

6.2

 

 

Amortized investment tax credits

 

 

(0.6

)

 

 

 

(0.6

)

 

 

 

(0.6

)

 

 

 

(0.7

)

 

Credit for electricity from renewable energy

 

 

(4.9

)

 

 

 

(4.9

)

 

 

 

(5.2

)

 

 

 

(5.2

)

 

AFUDC equity, net

 

 

(0.9

)

 

 

 

(0.4

)

 

 

 

(1.0

)

 

 

 

(0.4

)

 

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

 

 

(1.4

)

 

 

 

(1.7

)

 

 

 

(1.5

)

 

 

 

(1.8

)

 

Other, net, individually insignificant

 

 

(0.5

)

 

 

 

(0.1

)

 

 

 

(0.5

)

 

 

 

(0.2

)

 

Effective income tax rate

 

 

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

 

%

 

(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, 2023 and 2022, MGE recognized $0.9 million and $1.0 million, respectively. For the nine months ended September 30, 2023 and 2022, MGE recognized $2.7 million and $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 months ended September 30, 2023 and 2022, MGE recognized $0.3 million. For both the nine months ended September 30, 2023 and 2022, MGE recognized $1.0 million.

16


 

5.
Pension and Other Postretirement Plans - MGE Energy and MGE.

 

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

 

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

 

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

 

 

 

Three Months Ended

 

 

Nine Months Ended

 

 

 

September 30,

 

 

September 30,

 

(In thousands)

 

2023

 

 

2022

 

 

2023

 

 

2022

 

Pension Benefits

 

 

 

 

 

 

 

 

 

 

 

 

Components of net periodic benefit cost:

 

 

 

 

 

 

 

 

 

 

 

 

Service cost

 

$

723

 

 

$

1,266

 

 

$

2,169

 

 

$

3,798

 

Interest cost

 

 

4,330

 

 

 

2,791

 

 

 

12,989

 

 

 

8,371

 

Expected return on assets

 

 

(6,312

)

 

 

(7,848

)

 

 

(18,936

)

 

 

(23,543

)

Amortization of:

 

 

 

 

 

 

 

 

 

 

 

 

Prior service credit

 

 

 

 

 

(5

)

 

 

 

 

 

(15

)

Actuarial loss

 

 

440

 

 

 

604

 

 

 

1,320

 

 

 

1,812

 

Net periodic benefit (credit) cost

 

$

(819

)

 

$

(3,192

)

 

$

(2,458

)

 

$

(9,577

)

 

 

 

 

 

 

 

 

 

 

 

 

 

Postretirement Benefits

 

 

 

 

 

 

 

 

 

 

 

 

Components of net periodic benefit cost:

 

 

 

 

 

 

 

 

 

 

 

 

Service cost

 

$

195

 

 

$

323

 

 

$

585

 

 

$

970

 

Interest cost

 

 

827

 

 

 

485

 

 

 

2,481

 

 

 

1,455

 

Expected return on assets

 

 

(649

)

 

 

(842

)

 

 

(1,946

)

 

 

(2,524

)

Amortization of:

 

 

 

 

 

 

 

 

 

 

 

 

Transition obligation

 

 

1

 

 

 

1

 

 

 

2

 

 

 

2

 

Prior service credit

 

 

 

 

 

(74

)

 

 

 

 

 

(223

)

Actuarial (gain) loss

 

 

(48

)

 

 

37

 

 

 

(143

)

 

 

109

 

Net periodic benefit (credit) cost

 

$

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 previously deferred. These costs have not been reflected in the table above.

6.
Equity and Financing Arrangements.

 

a.
Common Stock - MGE Energy.

 

Shares of MGE Energy common stock are sold through 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, 2023 and 2022, MGE Energy issued no new shares of common stock under the Stock Plan.

 

17


 

b.
Dilutive Shares Calculation - MGE Energy.

 

As of September 30, 2023, 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.

 

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

 

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 $40 million of new long-term debt (Series A), carrying an interest rate of 5.61% per annum over its 11-year life, and $30 million of new long-term debt (Series B), carrying an interest rate of 5.91% per

annum over its 30-year life. Funding occurred on September 13, 2023, for Series A and funding for Series B is expected to occur on December 1, 2023. The proceeds of the debt financing 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 senior notes.

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

 

During the three and nine months ended September 30, 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 compensation benefit and $0.1 million in compensation expense for the comparable periods in 2022.

 

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

 

In March 2023, MGE issued 11,320 performance units and 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.

8.
Commitments and Contingencies - MGE Energy and MGE.

 

a.
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 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

18


 

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.

 

With the closure of the wet pond system (as described in further detail in the CCR section below), Columbia will be in compliance with ELG requirements.

 

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

 

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 this permit which expires in 2028. The WDNR included a requirement to conduct an impingement study in the latest permit which needs to be completed in the next three years. Once the WDNR determines the impingement requirements at Blount, MGE will be able to determine any compliance costs of meeting Blount's permit requirements.

 

Intakes at Columbia are subject to this rule. The Columbia operator's most recent permit requires that studies of intake structures 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 required in the renewal permit given the owners' plan to retire both units by June of 2026. MGE will continue to work with Columbia's operator to evaluate regulatory requirements in light of the planned retirements. MGE does not expect this rule to have a material effect on Columbia.

 

Greenhouse Gas (GHG) new source performance standards (NSPS) and emission guidelines 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 May 2023, the EPA proposed a rule under section 111 of the Clean Air Act to establish NSPS and emission guidelines to limit GHG emissions from existing fossil fuel-fired EGUs and new, modified, and/or reconstructed fossil fuel-fired power plants. The EPA anticipates promulgating a final rule in

19


 

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 "moderate" nonattainment area. The deadline for moderate classified areas to meet attainment standards is August 2024. At this time, the operator of the Elm Road Units does not expect that the 2015 Ozone NAAQS will have a material effect on 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 PM2.5 ambient air levels in areas that the EPA has determined as being significantly impacted by pollution from upwind states. This is accomplished through a reduction in NOx and SO2 from qualifying fossil-fuel fired power plants and industrial boilers in upwind "contributing" states. NOx and SO2 contribute to fine particulate pollution and NOx contributes to ozone formation in downwind areas. Reductions are generally achieved through a cap-and-trade system. Individual plants can meet their caps through reducing emissions and/or buying allowances on the market.

 

In March 2023, the EPA finalized its Federal Implementation Plan (FIP) to address state obligations under the Clean Air Act "good neighbor" provisions for the 2015 Ozone NAAQS. The final rule impacts 23 states, including Wisconsin. For Wisconsin, the rule includes revisions to the current obligations for fossil-fuel power generation, which includes Blount, Columbia, the Elm Road Units, WCCF, West Riverside, and West Marinette. The final rule became effective partway through the 2023 ozone season in August 2023. Emissions budgets can be met with 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 a further reduction in emissions budgets. Wisconsin would need to submit a State Implementation Plan to meet its obligations or accept the EPA's FIP. MGE is reviewing the final rule. Based on our current evaluation, the 2026 additional emission reductions may impact the Elm Road Units and additional upgrades may be needed to comply, however, we will not know the final impact until evaluations are completed.

 

20


 

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

 

The CCR rule regulates the disposal of solid waste coal ash and defines what ash use activities would be considered generally exempt beneficial reuse of coal ash. The CCR rule also regulates landfills, ash ponds, and other surface impoundments used for coal combustion residuals by regulating their design, location, monitoring, and operation. The CCR rule requires owners or operators of coal-fired power plants to stop transporting CCR and non-CCR wastewater to unlined surface impoundments. In addition, regulated entities must initiate impoundment closure as soon as feasible and in no event later than April 2021, unless the EPA grants an extension. A site-specific extension to initiate closure of the primary ash pond at Columbia by March 31, 2023, was requested, and was met. The EPA has confirmed that Columbia met the 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. The coal combustion residuals system that replaced the unlined surface impoundment was placed in-service in March 2023. MGE's share of the costs of the project is 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.

b.
Legal 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 challenging the fixed customer charge set in MGE's 2022/2023 rate 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.

c.
Purchase 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, 2023:

 

(In thousands)

 

2023

 

 

2024

 

 

2025

 

 

2026

 

 

2027

 

 

Thereafter

 

Coal(a)

 

$

8,511

 

 

$

23,173

 

 

$

14,425

 

 

$

2,581

 

 

$

 

 

$

 

Natural gas(b)

 

 

20,009

 

 

 

41,502

 

 

 

25,517

 

 

 

14,873

 

 

 

2,165

 

 

 

11,995

 

 

$

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

21


 

storage contracts are approved by FERC but may be subject to change. MGE's natural gas supply commitments include market-based pricing.
9.
Rate Matters - MGE Energy and MGE.
a.
Rate Proceedings.

 

 

 

Rate increase

 

Return on Common Equity

 

Common Equity Component of Regulatory Capital Structure

 

Effective Date

Approved 2022/2023 settlement(a)

 

 

 

 

 

 

 

 

Electric

 

8.81%

 

9.8%

 

55.6%

 

1/1/2022

Gas

 

2.15%

 

9.8%

 

55.6%

 

1/1/2022

Gas

 

0.96%

 

9.8%

 

55.6%

 

1/1/2023

Approved limited 2023 reopener(b)

 

 

 

 

 

 

 

 

Electric

 

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 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.
(b)
The electric rate increase was 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 included an increase in fuel costs and the recovery of deferred 2021 fuel costs. The reopener also revised the depreciation schedule for Columbia Unit 2 and shared equipment to 2029 to align with the depreciation schedule for 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 with a final order expected before the end of 2023. MGE cannot predict with any certainty the 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 decisions approving MGE's electric and gas 2022/2023 rate settlement and 2023 electric limited reopener. The PSCW is named as the responding party; MGE is not named as a party. The Petitions challenge the amount of customer fixed charge that does not vary with usage. The requested relief is unclear. The revenue requirement approved by the PSCW in the settlement and limited reopener have not been challenged. The PSCW is expected to vigorously defend its approval of the rate case settlement and limited reopener. MGE has intervened in the proceedings to further defend the PSCW's decision. The Dane County Circuit Court affirmed the PSCW's decision to approve the 2022/2023 rate

22


 

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

b.
Fuel Rules.

 

Fuel rules require Wisconsin utilities to defer electric fuel-related costs that fall outside a symmetrical cost tolerance band around the amount approved for a utility in its annual fuel proceedings. Any over- or under-recovery of the actual costs is determined in the following year and is then reflected in future billings to electric retail customers. The fuel rules bandwidth is set at plus or minus 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 summarizes deferred electric fuel-related costs:

 

 

 

Fuel Costs (in millions)

 

Refund or Recovery Period

2021 deferred fuel costs

 

$3.3(a)

 

January 2023 through December 2023(b)

2022 deferred fuel costs

 

$8.8(a)

 

October 2023 through September 2024(c)

2023 deferred fuel savings

 

($4.3)

 

(d)

 

(a)
There was no change to the recovery 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 2023 fuel costs, expected to be completed in 2024.
10.
Derivative and Hedging Instruments - MGE Energy and MGE.
a.
Purpose.

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

b.
Notional Amounts.

The gross notional volume of open derivatives is as follows:

 

 

 

September 30, 2023

 

December 31, 2022

Commodity derivative contracts

 

 

384,080

 

 

MWh

 

 

353,600

 

 

MWh

Commodity derivative contracts

 

 

7,780,000

 

 

Dth

 

 

8,070,000

 

 

Dth

FTRs

 

 

2,901

 

 

MW

 

 

1,945

 

 

MW

 

c.
Financial Statement Presentation.

 

MGE purchases and sells exchange-traded and over-the-counter options, swaps, and future contracts. These arrangements are primarily entered into to help stabilize the price risk associated with gas or

23


 

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, 2023, and December 31, 2022, the cost basis of exchange traded derivatives and FTRs exceeded their fair value by $2.5 million and $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

 

 

 

(In thousands)

 

Assets

 

 

Liabilities

 

 

Balance Sheet Location

September 30, 2023

 

 

 

 

 

 

 

 

Commodity derivative contracts(a)

 

$

837

 

 

$

3,424

 

 

Other current liabilities

Commodity derivative contracts(a)

 

 

115

 

 

 

413

 

 

Other deferred liabilities and other

FTRs

 

 

337

 

 

 

 

 

Other current assets

 

 

 

 

 

 

 

 

 

December 31, 2022

 

 

 

 

 

 

 

 

Commodity derivative contracts(a)

 

$

2,164

 

 

$

7,687

 

 

Other current liabilities

Commodity derivative contracts(a)

 

 

802

 

 

 

476

 

 

Other deferred liabilities and other

FTRs

 

 

103

 

 

 

 

 

Other current assets

 

(a)
As of September 30, 2023, and December 31, 2022, collateral of $2.9 million and $5.2 million, respectively, was posted against and netted with derivative liability positions on the consolidated balance sheets. The fair value of the derivative liability disclosed in this table has not been reduced for the collateral posted.

 

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

 

Offsetting of Derivative Assets

(In thousands)

 

Gross Amounts

 

 

Gross Amounts Offset in Balance Sheets

 

 

Collateral Posted Against Derivative Positions

 

 

Net Amount Presented in Balance Sheets

 

September 30, 2023

 

 

 

 

 

 

 

 

 

 

 

 

Commodity derivative contracts

 

$

952

 

 

$

(952

)

 

$

 

 

$

 

FTRs

 

 

337

 

 

 

 

 

 

 

 

 

337

 

 

 

 

 

 

 

 

 

 

 

 

 

 

December 31, 2022

 

 

 

 

 

 

 

 

 

 

 

 

Commodity derivative contracts

 

$

2,966

 

 

$

(2,966

)

 

$

 

 

$

 

FTRs

 

 

103

 

 

 

 

 

 

 

 

 

103

 

 

24


 

Offsetting of Derivative Liabilities

(In thousands)

 

Gross Amounts

 

 

Gross Amounts Offset in Balance Sheets

 

 

Collateral Posted Against Derivative Positions

 

 

Net Amount Presented in Balance Sheets

 

September 30, 2023

 

 

 

 

 

 

 

 

 

 

 

 

Commodity derivative contracts

 

$

3,837

 

 

$

(952

)

 

$

(2,885

)

 

$

 

 

 

 

 

 

 

 

 

 

 

 

 

 

December 31, 2022

 

 

 

 

 

 

 

 

 

 

 

 

Commodity derivative contracts

 

$

8,163

 

 

$

(2,966

)

 

$

(5,197

)

 

$

 

 

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.

 

 

 

2023

 

 

2022

 

(In thousands)

 

Current and Long-Term Regulatory Asset (Liability)

 

 

Other Current Assets

 

 

Current and Long-Term Regulatory Asset (Liability)

 

 

Other Current Assets

 

Three Months Ended September 30:

 

 

 

 

 

 

 

 

 

 

 

 

Balance as of July 1,

 

$

5,017

 

 

$

1,074

 

 

$

(8,484

)

 

$

(161

)

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,

 

$

2,548

 

 

$

595

 

 

$

(5,213

)

 

$

633

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Nine Months Ended September 30:

 

 

 

 

 

 

 

 

 

 

 

 

Balance as of January 1,

 

$

5,094

 

 

$

2,747

 

 

$

(617

)

 

$

770

 

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,

 

$

2,548

 

 

$

595

 

 

$

(5,213

)

 

$

633

 

 

 

 

Realized Losses (Gains)

 

 

 

2023

 

 

2022

 

(In thousands)

 

Fuel for Electric Generation/ Purchased Power

 

 

Cost of Gas Sold

 

 

Fuel for Electric Generation/ Purchased Power

 

 

Cost of Gas Sold

 

Three Months Ended September 30:

 

 

 

 

 

 

 

 

 

 

 

 

Commodity derivative contracts

 

$

4,179

 

 

$

 

 

$

(8,698

)

 

$

36

 

FTRs

 

 

(131

)

 

 

 

 

 

212

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Nine Months Ended September 30:

 

 

 

 

 

 

 

 

 

 

 

 

Commodity derivative contracts

 

$

14,566

 

 

$

6,451

 

 

$

(14,343

)

 

$

(800

)

FTRs

 

 

(824

)

 

 

 

 

 

812

 

 

 

 

PPA

 

 

 

 

 

 

 

 

(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, 2023, and December 31, 2022, no counterparties were in a net liability position.

 

25


 

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, 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.

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

 

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

 

 

 

September 30, 2023

 

 

December 31, 2022

 

(In thousands)

 

Carrying Amount

 

 

Fair Value

 

 

Carrying Amount

 

 

Fair Value

 

Long-term debt(a)

 

$

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 $4.7 million and $4.0 million as of September 30, 2023, and December 31, 2022, respectively.

26


 

b.
Recurring Fair Value Measurements.

 

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

 

 

 

Fair Value as of September 30, 2023

 

(In thousands)

 

Total

 

 

Level 1

 

 

Level 2

 

 

Level 3

 

MGE Energy

 

 

 

 

 

 

 

 

 

 

 

 

Assets:

 

 

 

 

 

 

 

 

 

 

 

 

Derivatives, net(b)

 

$

1,289

 

 

$

766

 

 

$

 

 

$

523

 

Exchange-traded investments

 

 

1,771

 

 

 

1,771

 

 

 

 

 

 

 

Total Assets

 

$

3,060

 

 

$

2,537

 

 

$

 

 

$

523

 

Liabilities:

 

 

 

 

 

 

 

 

 

 

 

 

Derivatives, net(b)

 

$

3,837

 

 

$

2,190

 

 

$

 

 

$

1,647

 

Deferred compensation

 

 

5,077

 

 

 

 

 

 

5,077

 

 

 

 

Total Liabilities

 

$

8,914

 

 

$

2,190

 

 

$

5,077

 

 

$

1,647

 

 

 

 

 

 

 

 

 

 

 

 

 

 

MGE

 

 

 

 

 

 

 

 

 

 

 

 

Assets:

 

 

 

 

 

 

 

 

 

 

 

 

Derivatives, net(b)

 

$

1,289

 

 

$

766

 

 

$

 

 

$

523

 

Exchange-traded investments

 

 

83

 

 

 

83

 

 

 

 

 

 

 

Total Assets

 

$

1,372

 

 

$

849

 

 

$

 

 

$

523

 

Liabilities:

 

 

 

 

 

 

 

 

 

 

 

 

Derivatives, net(b)

 

$

3,837

 

 

$

2,190

 

 

$

 

 

$

1,647

 

Deferred compensation

 

 

5,077

 

 

 

 

 

 

5,077

 

 

 

 

Total Liabilities

 

$

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

 

 

(b)
As of September 30, 2023, and December 31, 2022, collateral of $2.9 million and $5.2 million, respectively, was posted against and netted with derivative liability positions on the consolidated balance sheets. The fair value of the derivative liability disclosed in this table has not been reduced for the collateral posted.

 

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 plans allow participants to defer certain cash compensation into notional investment accounts. These amounts are included within "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

27


 

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 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

 

 

September 30,

 

September 30,

(In thousands)

 

2023

 

2022

 

2023

 

2022

Beginning balance

 

$

(2,892)

 

$

8,959

 

$

(866)

 

$

178

Realized and unrealized gains (losses):

 

 

 

 

 

 

 

 

 

 

 

 

Included in regulatory assets

 

 

1,768

 

 

 

 

(258)

 

 

Included in regulatory liability

 

 

 

 

(5,105)

 

 

 

 

3,675

Included in other comprehensive income

 

 

 

 

 

 

 

 

Included in earnings

 

 

(2,016)

 

 

6,609

 

 

(7,590)

 

 

13,607

Included in current assets

 

 

 

 

(73)

 

 

 

 

45

Purchases

 

 

 

 

108

 

 

 

 

11,911

Sales

 

 

 

 

 

 

 

 

Issuances

 

 

 

 

 

 

 

 

Settlements

 

 

2,016

 

 

(6,644)

 

 

7,590

 

 

(25,562)

Balance as of September 30,

 

$

(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,
(c)

 

$

 

$

 

$

 

$

 

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

 

 

 

Three Months Ended

 

Nine Months Ended

 

 

September 30,

 

September 30,

(In thousands)

 

2023

 

2022

 

2023

 

2022

Purchased power expense

 

$

(2,016)

 

$

6,644

 

$

(7,590)

 

$

13,805

Cost of gas sold expense

 

 

 

 

(35)

 

 

 

 

(198)

Total

 

$

(2,016)

 

$

6,609

 

$

(7,590)

 

$

13,607

 

(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.

28


 

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

 

MGE has ownership interests in generation projects with other co-owners, some of which are under construction, 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 Estimated
Costs
(a)

 

Costs incurred as
of September 30, 2023
(a)

 

Date of
Commercial
Operation

Red Barn(b)

 

10%

 

Wind

 

9.16 MW

 

$18 million

 

$16.5 million

 

April 2023

Badger Hollow II(c)

 

33%

 

Solar

 

50 MW

 

$86 million(i)

 

$58.9 million(f)

 

Late 2023 or
early 2024
(g)

Paris(d)

 

10%

 

Solar/Battery

 

20 MW/11 MW

 

$61 million(i)

 

$34.5 million

 

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)
Darien Solar Energy Center is located in Walworth and Rock Counties in southern Wisconsin.
(f)
Includes an allocation of common facilities at Badger Hollow placed in service in November 2021.
(g)
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, cost, and feasibility of the installation of batteries.

 

MGE received specific approval to recover 100% AFUDC on Badger Hollow II, Paris, and Darien. During the three and nine months ended September 30, 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 for the comparable periods in 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

 

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

 

 

29


 

 

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 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

 

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

 

Interdepartmental revenues

 

 

24

 

 

 

12,465

 

 

 

10,405

 

 

 

 

 

 

 

 

 

(22,894

)

 

 

 

Total operating revenues

 

 

132,900

 

 

 

42,775

 

 

 

10,619

 

 

 

 

 

 

 

 

 

(22,894

)

 

 

163,400

 

Equity in earnings of investments

 

 

 

 

 

 

 

 

 

 

 

1,499

 

 

 

 

 

 

 

 

 

1,499

 

Net income (loss)

 

 

27,619

 

 

 

(394

)

 

 

5,576

 

 

 

1,091

 

 

 

(172

)

 

 

 

 

 

33,720

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Nine Months Ended September 30, 2023

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Operating revenues

 

$

377,627

 

 

$

147,677

 

 

$

475

 

 

$

 

 

$

 

 

$

 

 

$

525,779

 

Interdepartmental revenues

 

 

653

 

 

 

12,978

 

 

 

31,143

 

 

 

 

 

 

 

 

 

(44,774

)

 

 

 

Total operating revenues

 

 

378,280

 

 

 

160,655

 

 

 

31,618

 

 

 

 

 

 

 

 

 

(44,774

)

 

 

525,779

 

Equity in earnings of investments

 

 

 

 

 

 

 

 

 

 

 

7,930

 

 

 

 

 

 

 

 

 

7,930

 

Net income (loss)

 

 

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

 

Interdepartmental revenues

 

 

76

 

 

 

26,645

 

 

 

31,073

 

 

 

 

 

 

 

 

 

(57,794

)

 

 

 

Total operating revenues

 

 

354,991

 

 

 

195,950

 

 

 

31,539

 

 

 

 

 

 

 

 

 

(57,794

)

 

 

524,686

 

Equity in earnings of investments

 

 

 

 

 

 

 

 

 

 

 

6,626

 

 

 

 

 

 

 

 

 

6,626

 

Net income

 

 

55,248

 

 

 

12,782

 

 

 

16,451

 

 

 

4,821

 

 

 

599

 

 

 

 

 

 

89,901

 

 

(In thousands)
MGE

 

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

 

Interdepartmental revenues

 

 

24

 

 

 

12,465

 

 

 

10,405

 

 

 

(22,894

)

 

 

 

Total operating revenues

 

 

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

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Nine Months Ended September 30, 2023

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Operating revenues

 

$

377,627

 

 

$

147,677

 

 

$

475

 

 

$

 

 

$

525,779

 

Interdepartmental revenues

 

 

653

 

 

 

12,978

 

 

 

31,143

 

 

 

(44,774

)

 

 

 

Total operating revenues

 

 

378,280

 

 

 

160,655

 

 

 

31,618

 

 

 

(44,774

)

 

 

525,779

 

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

 

Interdepartmental revenues

 

 

76

 

 

 

26,645

 

 

 

31,073

 

 

 

(57,794

)

 

 

 

Total operating revenues

 

 

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

 

 

30


 

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 161,000 customers in Dane County, Wisconsin, including the city of Madison, and purchases and distributes natural gas to approximately 173,000 customers in the Wisconsin counties of Columbia, Crawford, Dane, Iowa, Juneau, Monroe, and Vernon.

 

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

 

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 announcements of the retirement of Columbia (a coal generation plant), the planned change in the Elm Road Units fuel source from coal to natural gas, and its growing ownership of renewable generation sources. MGE will continue to focus on growing earnings while controlling operating and fuel costs. MGE's goal is to provide safe and efficient operations in addition to providing customer value. We believe it is critical to maintain a strong credit rating consistent with financial strength in MGE in order to accomplish these goals.

 

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

 

Weather, and its impact on customer sales,
Economic conditions, including current business activity and employment and their impact on customer demand,
Regulation and regulatory issues, and their impact on the timing and recovery of costs,
Energy commodity prices, including natural gas prices,
Equity price risk pertaining to pension related assets,
Credit market conditions, including interest rates and our debt credit rating,
Environmental laws and regulations, including adopted and pending environmental rule changes, and
Other factors listed in "Item 1A. Risk Factors" in our 2022 Annual Report on Form 10-K.

31


 

 

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

 

During the nine months ended September 30, 2023, MGE Energy's earnings were $97.6 million or $2.70 per share compared to $89.9 million or $2.49 per share during the same period in the prior year. MGE's earnings during the nine months ended September 30, 2023, were $76.8 million compared to $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

(In millions)

September 30,

 

September 30,

Business Segment:

2023

 

2022

 

2023

 

2022

Electric Utility

$

31.1

 

$

27.6

 

$

66.0

 

$

55.2

Gas Utility

 

(0.8)

 

 

(0.4)

 

 

10.5

 

 

12.8

Nonregulated Energy

 

5.6

 

 

5.6

 

 

16.7

 

 

16.5

Transmission Investments

 

2.0

 

 

1.1

 

 

5.8

 

 

4.8

All Other

 

 

 

(0.2)

 

 

(1.4)

 

 

0.6

Net Income

$

37.9

 

$

33.7

 

$

97.6

 

$

89.9

 

Our net income during the three and nine months ended September 30, 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 2023. Timing of depreciation expense and lower fuel costs also contributed to higher earnings in the first nine months of 2023. Depreciation expense is expected to increase after significant capital projects (Badger Hollow II and Paris) are completed. Weather during 2023 has also impacted electric earnings. Warmer than normal weather during the heating season in the first quarter of 2023 lowered electric retail sales reducing earnings and warmer than normal weather in 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 the same period in the prior year. Electric retail sales increased approximately 1% during the third quarter of 2023 compared to the same period in the prior year.

 

Gas Utility

Lower gas retail sales resulting from warmer than normal weather in the first quarter of 2023 contributed to lower gas earnings for the nine months ended September 30, 2023. Gas retail sales decreased approximately 11%. Heating degree days (a measure for determining the impact of weather during the heating season) decreased by approximately 15% in the first nine months of 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 2023:

 

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

32


 

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 and 2023 Electric Limited Rate Case reopener.

 

Utility Solar: Large solar generation projects, some of which are under construction, are 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
as of
September 30, 2023
(a)

 

Date of
Commercial
Operation

Red Barn

 

10%

 

Wind

 

9.16 MW

 

$18 million

 

$16.5 million

 

April 2023

Badger Hollow II

 

33%

 

Solar

 

50 MW

 

$86 million(e)

 

$58.9 million(b)(c)

 

Late 2023 or
early 2024
(d)

Paris

 

10%

 

Solar/Battery

 

20 MW/11 MW

 

$61 million(e)

 

$34.5 million(b)

 

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. After tax, MGE recognized $4.8 million, $1.7 million, and $0.3 million of AFUDC equity through September 30, 2023, on Badger Hollow II, Paris, and 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)
Estimated date of commercial operation.
(e)
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.
(f)
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, cost, and feasibility of the installation of batteries.

 

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 Savings: As of September 30, 2023, MGE has deferred $4.3 million of 2023 fuel savings. These costs will be subject to the PSCW's annual review of 2023 fuel costs, expected to be completed during 2024. See Footnote 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:

 

2022 Annual Fuel Proceeding: MGE under-recovered fuel costs in 2022. As of December 31, 2022, MGE had deferred $8.8 million of 2022 fuel costs. In August 2023, the PSCW issued a final decision in the 2022 fuel rules proceedings for MGE to recover these costs over a 12-month period from October 2023 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.

 

2024/2025 Rate Proceeding: In April 2023, MGE filed with the PSCW a proposed 2024/2025 rate application. MGE has proposed a 3.75% increase for electric rates and a 2.56% increase to gas rates for 2024. The proceeding also proposes a 3.41% increase for electric rates and a 1.66% increase to 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 2024/2025 rate 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 5.7% and 5.1% of our net income during the nine months ended September 30, 2023 and 2022, respectively, from our investment in ATC.

 

33


 

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 target.

 

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

Elm Road Units: MGE, along with the plant co-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. 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 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 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 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 to purchase an additional ownership interest in West Riverside. See the 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: MGE is monitoring import regulations under 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 potential to impact 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 future rate proceedings. See "Other Matters" below for additional information on the solar procurement disruptions.

 

34


 

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, 2023 and 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)

 

 

Three Months Ended September 30,

 

Three Months Ended September 30,

(In thousands, except CDD)

 

2023

 

2022

 

% Change

 

2023

 

2022

 

% Change

Residential

 

$

50,008

 

$

45,154

 

10.7%

 

264,678

 

252,457

 

4.8%

Commercial

 

 

70,795

 

 

65,468

 

8.1%

 

496,161

 

495,135

 

0.2%

Industrial

 

 

3,715

 

 

3,912

 

(5.0)%

 

39,908

 

41,304

 

(3.4)%

Other-retail/municipal

 

 

10,991

 

 

10,010

 

9.8%

 

102,400

 

104,548

 

(2.1)%

Total retail

 

 

135,509

 

 

124,544

 

8.8%

 

903,147

 

893,444

 

1.1%

Sales to the market

 

 

3,305

 

 

7,858

 

(57.9)%

 

72,916

 

48,632

 

49.9%

Other

 

 

77

 

 

474

 

(83.8)%

 

 

 

—%

Total

 

$

138,891

 

$

132,876

 

4.5%

 

976,063

 

942,076

 

3.6%

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Cooling degree days (normal 502)

 

 

 

 

 

 

 

 

 

549

 

507

 

8.3%

 

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

 

(In millions)

 

 

 

Rate changes

 

$

12.3

 

Increase in residential volume

 

 

1.8

 

Sales to the market

 

 

(4.5

)

Revenue subject to refund, net

 

 

(2.9

)

Customer fixed and demand charges

 

 

(0.3

)

Other

 

 

(0.4

)

Total

 

$

6.0

 

 

Rate changes. In December 2022, the PSCW authorized MGE to increase 2023 rates for retail electric customers by approximately 9.01%. Rates charged to retail customers during the three months ended September 30, 2023, were $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, 2023, sales made at lower market prices were partially offset by higher market volumes compared to the same period in the prior year, reflecting an increase in sales. The revenue generated from these sales is included in fuel rules costs. See fuel rules discussion in Footnote 9 of the Notes to Consolidated Financial Statements.

 

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

35


 

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.

 

Electric fuel and purchased power

 

 

Three Months Ended September 30,

(In millions)

2023

 

2022

 

$ Change

Fuel for electric generation

$

19.7

 

$

21.0

 

$

(1.3)

Purchased power

 

7.0

 

 

9.6

 

 

(2.6)

 

The $1.3 million decrease in fuel for electric generation was due to an approximately 18% decrease in the average cost offset by an approximately 15% increase in internal generation. Columbia generation was higher during the three months ended September 30, 2023, compared to the same period in the prior year as a result of market prices.

The $2.6 million decrease in purchased power was due to an approximately 40% decrease in market purchases as a result of higher internal 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 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

(In thousands, except HDD and average

 

Three Months Ended September 30,

 

Three Months Ended September 30,

rate per therm of retail customer)

 

2023

 

2022

 

% Change

 

2023

 

2022

 

% Change

Residential

 

$

13,719

 

$

17,167

 

(20.1)%

 

6,202

 

6,166

 

0.6%

Commercial/Industrial

 

 

6,016

 

 

11,490

 

(47.6)%

 

9,335

 

9,555

 

(2.3)%

Total retail

 

 

19,735

 

 

28,657

 

(31.1)%

 

15,537

 

15,721

 

(1.2)%

Gas transportation

 

 

1,587

 

 

1,588

 

(0.1)%

 

15,014

 

15,183

 

(1.1)%

Other

 

 

102

 

 

65

 

56.9%

 

 

 

—%

Total

 

$

21,424

 

$

30,310

 

(29.3)%

 

30,551

 

30,904

 

(1.1)%

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Heating degree days (normal 138)

 

 

 

 

 

 

 

 

 

70

 

135

 

(48.1)%

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Average rate per therm of retail customer

 

$

1.270

 

$

1.823

 

(30.3)%

 

 

 

 

 

 

 

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

 

(In millions)

 

 

 

Rate changes

 

$

(8.5

)

Decrease in volume

 

 

(0.7

)

Other

 

 

0.3

 

Total

 

$

(8.9

)

 

Rate changes. In December 2021, the PSCW authorized MGE to increase 2023 rates for retail gas customers by approximately 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 decreased driving lower rates during the three months ended September 30, 2023.

36


 

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

 

Cost of gas 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. Average cost per therm decreased approximately 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, 2023, operations and maintenance expenses increased $4.8 million, compared to the same period in the prior year. The following contributed to the net change:

 

(In millions)

 

 

 

Increased administrative and general costs

 

$

4.1

 

Increased electric distribution expenses

 

 

0.6

 

Increased electric production expenses

 

 

0.3

 

Increased other expenses

 

 

0.2

 

Decreased customer accounts costs

 

 

(0.4

)

Total

 

$

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 $3.7 million and gas depreciation expense increased $0.1 million during the three months ended September 30, 2023, compared to the same period in the prior year. As part of the 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.

 

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, 2023 and 2022, net income at the nonregulated energy operations segment was $5.6 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, 2023 and 2022, other income at the transmission investment segment primarily reflects ATC's operations and was $2.7 million and $1.5 million, respectively. 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.

 

Consolidated Income Taxes - MGE Energy and MGE

 

See Footnote 4 of the Notes to Consolidated Financial Statements in this Report for the effective tax rate reconciliation.

 

37


 

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

 

 

 

September 30,

 

(In millions)

 

2023

 

 

2022

 

MGE Power Elm Road

 

$

3.7

 

 

$

3.8

 

MGE Power West Campus

 

 

1.8

 

 

 

1.8

 

 

Results of Operations

 

Nine Months Ended September 30, 2023 and 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)

 

 

 

Nine Months Ended September 30,

 

Nine Months Ended September 30,

(In thousands, except CDD)

 

 

2023

 

 

2022

 

% Change

 

2023

 

2022

 

% Change

Residential

 

$

131,552

 

$

123,183

 

6.8%

 

672,760

 

679,308

 

(1.0)%

Commercial

 

 

193,760

 

 

177,877

 

8.9%

 

1,356,286

 

1,368,060

 

(0.9)%

Industrial

 

 

10,578

 

 

10,535

 

0.4%

 

114,514

 

120,827

 

(5.2)%

Other-retail/municipal

 

 

30,853

 

 

28,215

 

9.3%

 

274,875

 

276,843

 

(0.7)%

Total retail

 

 

366,743

 

 

339,810

 

7.9%

 

2,418,435

 

2,445,038

 

(1.1)%

Sales to the market

 

 

9,617

 

 

13,938

 

(31.0)%

 

126,739

 

121,848

 

4.0%

Other revenues

 

 

1,267

 

 

1,167

 

8.6%

 

 

 

—%

Total

 

$

377,627

 

$

354,915

 

6.4%

 

2,545,174

 

2,566,886

 

(0.8)%

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Cooling degree days (normal 696)

 

 

 

 

 

 

 

 

 

754

 

784

 

(3.8)%

 

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

 

(In millions)

 

 

 

Rate changes

$

 

32.6

 

Other

 

 

0.1

 

Sales to the market

 

 

(4.3

)

Customer fixed and demand charges

 

 

(2.7

)

Net decrease in commercial, industrial and other-retail/municipal volume

 

 

(1.7

)

Decrease in residential volume

 

 

(1.0

)

Revenue subject to refund, net

 

 

(0.3

)

Total

$

 

22.7

 

 

Rate changes. In December 2022, the PSCW authorized MGE to increase 2023 rates for retail electric customers by approximately 9.01%. Rates charged to retail customers during the nine months ended September 30, 2023, were $32.6 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.

 

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

38


 

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, 2023, sales were made at lower market prices and partially offset by increased market volumes compared to the same period in the prior year, reflecting an increase in sales. The revenue generated from these sales is included in fuel rules 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, 2023, residential sales decreased by approximately 1% compared to the same period in 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.

 

Electric fuel and purchased power

 

 

Nine Months Ended September 30,

(In millions)

2023

 

2022

 

$ Change

Fuel for electric generation

$

47.1

 

$

48.4

 

$

(1.3)

Purchased power

 

28.3

 

 

35.8

 

 

(7.5)

 

The $1.3 million decrease in fuel for electric generation was due to an approximately 8% decrease in the average cost offset by an approximately 6% increase in internal generation. West Riverside was purchased in March 2023 contributing to the increase in internal generation during the nine months ended September 30, 2023, compared to the same period in the prior year.

 

The $7.5 million decrease in purchased power was due to an approximately 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.

 

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 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.

 

39


 

Gas deliveries and revenues

 

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

 

 

 

 

Revenues

 

Therms Delivered

(In thousands, except HDD and average

 

 

Nine Months Ended September 30,

 

Nine Months Ended September 30,

rate per therm of retail customer)

 

 

2023

 

 

2022

 

% Change

 

2023

 

2022

 

% Change

Residential

 

$

86,131

 

$

97,498

 

(11.7)%

 

66,948

 

77,091

 

(13.2)%

Commercial/Industrial

 

 

55,726

 

 

66,913

 

(16.7)%

 

66,584

 

73,349

 

(9.2)%

Total retail

 

 

141,857

 

 

164,411

 

(13.7)%

 

133,532

 

150,440

 

(11.2)%

Gas transportation

 

 

5,354

 

 

4,804

 

11.4%

 

53,319

 

58,059

 

(8.2)%

Other revenues

 

 

466

 

 

90

 

n.m.%

 

 

 

—%

Total

 

$

147,677

 

$

169,305

 

(12.8)%

 

186,851

 

208,499

 

(10.4)%

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Heating degree days (normal 4,503)

 

 

 

 

 

 

 

 

 

3,999

 

4,723

 

(15.3)%

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Average rate per therm of retail customer

 

$

1.062

 

$

1.093

 

(2.8)%

 

 

 

 

 

 

 

n.m. not meaningful

 

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

 

(In millions)

 

 

 

Decrease in volume

 

$

(12.4

)

Rate changes

 

 

(10.4

)

Other

 

 

1.2

 

Total

 

$

(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 2023 rates for retail gas customers by approximately 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 decreased driving lower rates during the nine months ended September 30, 2023.

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

 

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

 

Cost of gas sold

 

Cost of gas sold 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

40


 

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, 2023, operations and maintenance expenses increased $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

 

$

4.7

 

Increased electric production expenses

 

 

1.5

 

Increased customer services

 

 

0.6

 

Increased other expenses

 

 

0.3

 

Decreased customer accounts costs

 

 

(1.6

)

Decreased electric distribution expenses

 

 

(0.2

)

Total

 

$

5.3

 

 

Increased 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 lower technology support costs which were higher in 2022 during the stabilization period of the new customer information system that went live in September 2021.

 

Consolidated depreciation expense

 

Electric depreciation expense increased $10.9 million and gas depreciation expense increased $0.3 million during the nine months ended September 30, 2023, compared to the same period in the prior year. As part of the 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.

 

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, 2023 and 2022, net income at the nonregulated energy operations segment was $16.7 million and $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, 2023 and 2022, other income at the transmission investment segment primarily reflects ATC's operations and was $7.9 million and $6.6 million, respectively. 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.

 

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

41


 

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

 

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:

 

 

 

Nine Months Ended

 

 

 

September 30,

 

(In millions)

 

2023

 

 

2022

 

MGE Power Elm Road

 

$

11.0

 

 

$

10.5

 

MGE Power West Campus

 

 

5.4

 

 

 

5.4

 

 

Contractual Obligations and Commercial Commitments - MGE Energy and MGE

 

There were no material changes, other than from the normal course of business, to MGE Energy's and MGE's contractual obligations (representing cash obligations that are considered to be firm commitments) and commercial commitments (representing commitments triggered by future events) during the nine months ended September 30, 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 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, 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 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 $70 million of new long-term debt. See Footnote 6.c. of Notes to Consolidated Financial Statements in this Report for further 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 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 2022 Annual Report on Form 10-K for information regarding MGE Energy's and MGE's credit facilities.

 

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Cash Flows

 

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

 

 

 

MGE Energy

 

MGE

(In thousands)

 

2023

 

2022

 

2023

 

2022

Cash provided by (used for):

 

 

 

 

 

 

 

 

 

 

 

 

Operating activities

 

$

194,038

 

$

144,282

 

$

190,368

 

$

141,786

Investing activities

 

 

(156,490)

 

 

(137,219)

 

 

(151,636)

 

 

(134,089)

Financing activities

 

 

(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, 2023, was $194.0 million, an increase of $49.8 million when compared to the same period in the prior year, driven by:

 

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, 2023, when compared to the prior year, primarily driven by a decrease in the price of natural gas.

 

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

 

An increase of $3.8 million in cash 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, 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, 2023, was $190.4 million, an increase of $48.6 million when compared to the same period in the prior year, driven by:

 

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, 2023, when compared to the prior year, primarily driven by a decrease in the price of natural gas.

 

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

 

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

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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, 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.

 

Capital Requirements and Investing Activities

 

MGE Energy

 

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

 

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

 

Capital contributions in ATC and other investments increased $2.0 million during the nine months ended September 30, 2023, when compared to the same period in the prior year.

 

MGE

 

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

 

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

Capital Expenditures

 

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

 

 

 

Forecasted

 

(In thousands)

 

2023(a)

 

 

2024

 

 

2025

 

 

2026

 

 

2027

 

 

2028

 

Electric

 

$

173,000

 

 

$

177,000

 

 

$

186,000

 

 

$

193,000

 

 

$

222,000

 

 

$

207,000

 

Gas

 

 

33,000

 

 

 

28,000

 

 

 

29,000

 

 

 

32,000

 

 

 

29,000

 

 

 

28,000

 

Utility plant total

 

 

206,000

 

 

 

205,000

 

 

 

215,000

 

 

 

225,000

 

 

 

251,000

 

 

 

235,000

 

Nonregulated

 

 

6,000

 

 

 

9,000

 

 

 

10,000

 

 

 

7,000

 

 

 

6,000

 

 

 

8,000

 

MGE Energy total

 

$

212,000

 

 

$

214,000

 

 

$

225,000

 

 

$

232,000

 

 

$

257,000

 

 

$

243,000

 

 

(a)
Includes actual capital expenditures already incurred in 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

44


 

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

 

The following table provides further detail of MGE Energy's forecasted capital expenditures, separating spending into capital project categories for 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 completed or currently under construction:

 

Project

 

Source

 

Ownership Interest

 

Share of
Generation/
Battery Storage

 

Share of
Estimated
Costs
(b)

 

Date of
Commercial Operation

Red Barn(a)

 

Wind

 

10%

 

9.16MW

 

$18 million(d)

 

April 2023

Badger Hollow II(a)

 

Solar

 

33%

 

50 MW

 

$86 million(c)(d)

 

Late 2023 or early 2024(f)

Paris(a)

 

Solar/Battery

 

10%

 

20 MW/11 MW

 

$61 million(c)(d)

 

2024(f) Solar
2025(f) Battery

Darien(a)

 

Solar

 

10%

 

25 MW

 

$46 million(c)(d)(e)

 

2024(f)

Koshkonong(a)

 

Solar

 

10%

 

30 MW

 

$54 million(c)(e)

 

2026(f)

 

(a)
Approved by the PSCW.
(b)
Excluding AFUDC.
(c)
MGE received PSCW approval to recover 100% AFUDC.
(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)
Estimated date of commercial operation.

 

In 2023, MGE notified the PSCW of increases in projected costs at Badger Hollow II, Paris, and 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. MGE continues to assess the potential impact of these disruptions on current and future solar projects that may result in an increase in costs or delays in construction timelines. See further information on procurement disruptions discussed under "Other Matters" section below.

 

West Riverside: In March 2023, MGE purchased 25 MW of capacity of West Riverside. In 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 increase 25 MW at a purchase price of approximately $25 million. The closing and actual transfer of ownership is expected to occur in June 2024.

 

Electric and Gas Distribution: In 2023 through 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

45


 

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

Cash Used for Financing Activities

 

MGE Energy

 

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

 

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

 

During the nine months ended September 30, 2023, MGE issued $90 million of senior unsecured notes which 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, 2023, net short-term debt repayments were $48.5 million, compared to $34.5 million of borrowings in the same period in the prior year.

 

MGE

 

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

 

During the nine months ended September 30, 2023, cash dividends to parent (MGE Energy) were $30.0 million, compared to $21.0 million 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 $17.3 million during the nine months ended September 30, 2023, compared to $17.5 million in the same period in the prior year.

 

During the nine months ended September 30, 2023, MGE issued $90 million of senior unsecured notes which 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, 2023, net short-term debt repayments were $48.5 million, compared to $34.5 million of borrowings in the same period in the prior year.

 

Capitalization Ratios

 

MGE Energy's capitalization ratios were as follows:

 

 

 

MGE Energy

 

 

September 30, 2023

 

December 31, 2022

Common shareholders' equity

 

61.3%

 

60.4%

Long-term debt(a)

 

37.5%

 

35.7%

Short-term debt

 

1.2%

 

3.9%

 

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

 

46


 

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 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 to increase gas rates 0.96% in 2023 and a potential 2023 electric rate change to be addressed through a limited reopener.

 

In December 2022, the PSCW approved the 2023 electric rate case limited reopener. The reopener provides for a 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 2023 approved settlement agreement and 2023 electric limited 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 (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.

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ATC

 

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

 

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

 

Uyghur Forced Labor Protection Act

 

In June 2021, the U.S. Customs and Border Protection (CBP) issued a Withhold Release Order (WRO) against silica-based products made by Hoshine Silicon Industry Co. Ltd., a company located in China's Xinjiang Uyghur Autonomous Region. As a result of this WRO, CBP is holding many solar panels imported into the United States until importers can prove that the panels do not contain materials originating from this region. The Uyghur Forced Labor Protection Act (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 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

48


 

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 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.

 

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.

49


 

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 2022 Annual Report on Form 10-K.

 

Item 4. Controls and Procedures.

 

During the third quarter of 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, 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, 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.

 

50


 

PART II. OTHER INFORMATION.

 

Item 1. Legal Proceedings.

 

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 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 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.

 

During the three months ended September 30, 2023, no director or officer of MGEE Energy or Madison Gas and Electric adopted or terminated a Rule 10b5-1 trading arrangement or non-Rule 10b5-1 trading arrangement, as defined in Item 408(a) of Regulation S-K.

 

51


 

Item 6. Exhibits.

 

 

 

Ex. No.

 

Exhibit Description

31.1

*

Certifications Pursuant to Rule 13a-14(a) and 15d-14(a) of the Securities Exchange Act of 1934 filed by Jeffrey M. Keebler for MGE Energy, Inc.

 

 

 

31.2

*

Certifications Pursuant to Rule 13a-14(a) and 15d-14(a) of the Securities Exchange Act of 1934 filed by Jared J. Bushek for MGE Energy, Inc.

 

 

 

31.3

*

Certifications Pursuant to Rule 13a-14(a) and 15d-14(a) of the Securities Exchange Act of 1934 filed by Jeffrey M. Keebler for Madison Gas and Electric Company

 

 

 

31.4

*

Certifications Pursuant to Rule 13a-14(a) and 15d-14(a) of the Securities Exchange Act of 1934 filed by Jared J. Bushek for Madison Gas and Electric Company

 

 

 

32.1

**

Certifications Pursuant to Section 1350 of Chapter 63 of Title 18 United States Code (Sarbanes-Oxley Act of 2002) filed by Jeffrey M. Keebler for MGE Energy, Inc.

 

 

 

32.2

**

Certifications Pursuant to Section 1350 of Chapter 63 of Title 18 United States Code (Sarbanes-Oxley Act of 2002) filed by Jared J. Bushek for MGE Energy, Inc.

 

 

 

32.3

**

Certifications Pursuant to Section 1350 of Chapter 63 of Title 18 United States Code (Sarbanes-Oxley Act of 2002) filed by Jeffrey M. Keebler for Madison Gas and Electric Company

 

 

 

32.4

**

Certifications Pursuant to Section 1350 of Chapter 63 of Title 18 United States Code (Sarbanes-Oxley Act of 2002) filed by Jared J. Bushek for Madison Gas and Electric Company

 

 

 

101.INS

 

XBRL Instance

101.SCH

 

XBRL Taxonomy Extension Schema

101.CAL

 

XBRL Taxonomy Extension Calculation

101.DEF

 

XBRL Taxonomy Extension Definition

101.LAB

 

XBRL Taxonomy Extension Labels

101.PRE

 

XBRL Taxonomy Extension Presentation

104.1

 

Included in the cover page, formatted in Inline XBRL

 

 

 

*

 

Filed herewith.

**

 

Furnished herewith.

 

 

52


 

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 2, 2023

/s/ Jeffrey M. Keebler

 

Jeffrey M. Keebler

Chairman, President and Chief Executive Officer

(Duly Authorized Officer)

 

 

 

 

 

 

Date: November 2, 2023

/s/ Jared J. Bushek

 

Jared J. Bushek

Vice President - Chief Financial Officer and Treasurer

(Chief Financial Officer)

 

 

 

 

 

 

Date: November 2, 2023

/s/ Tamara J. Johnson

 

Tamara J. Johnson

Vice President - Chief Accounting Officer and Controller

(Chief Accounting Officer)

 

53


 

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 2, 2023

/s/ Jeffrey M. Keebler

 

Jeffrey M. Keebler

Chairman, President and Chief Executive Officer

(Duly Authorized Officer)

 

 

 

 

 

 

Date: November 2, 2023

/s/ Jared J. Bushek

 

Jared J. Bushek

Vice President - Chief Financial Officer and Treasurer

(Chief Financial Officer)

 

 

 

 

 

 

Date: November 2, 2023

/s/ Tamara J. Johnson

 

Tamara J. Johnson

Vice President - Chief Accounting Officer and Controller

(Chief Accounting Officer)

 

54