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, 2019 ☐ Transition Report Pursuant to Section 13 or 15(d) of the Securities Exchange Act of 1934 For the transition period from _______________ to _______________
Commission File No.	Name of Registrant, State of Incorporation, Address of Principal Executive Offices, and Telephone No.	IRS Employer Identification No.
000-49965	MGE Energy, Inc. (a Wisconsin Corporation) 133 South Blair Street Madison, Wisconsin 53788 (608) 252-7000 | mgeenergy.com	39-2040501
000-1125	Madison Gas and Electric Company (a Wisconsin Corporation) 133 South Blair Street Madison, Wisconsin 53788 (608) 252-7000 | mge.com	39-0444025

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

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

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

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

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

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

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

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

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

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

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, 2019
MGE Energy, Inc.	Common stock, $1.00 par value, 34,668,370 shares outstanding.
Madison Gas and Electric Company	Common stock, $1.00 par value, 17,347,894 shares outstanding (all of which are owned beneficially and of record by MGE Energy, Inc.).

1

Table of Contents

PART I. FINANCIAL INFORMATION3

Filing Format3

Forward-Looking Statements3

Where to Find More Information3

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

Item 1. Financial Statements.6

MGE Energy, Inc.6

Consolidated Statements of Income (unaudited)6

Consolidated Statements of Cash Flows (unaudited)7

Consolidated Balance Sheets (unaudited)8

Consolidated Statements of Common Equity (unaudited)9

Madison Gas and Electric Company10

Consolidated Statements of Income (unaudited)10

Consolidated Statements of Cash Flows (unaudited)11

Consolidated Balance Sheets (unaudited)12

Consolidated Statements of Equity (unaudited)13

MGE Energy, Inc., and Madison Gas and Electric Company14

Notes to Consolidated Financial Statements (unaudited)14

Item 2. Management's Discussion and Analysis of Financial Condition and Results of Operations.37

Item 3. Quantitative and Qualitative Disclosures About Market Risk.53

Item 4. Controls and Procedures.56

PART II. OTHER INFORMATION.57

Item 1. Legal Proceedings.57

Item 2. Unregistered Sales of Equity Securities and Use of Proceeds.57

Item 4. Mine Safety Disclosures.57

Item 6. Exhibits.58

Signatures - MGE Energy, Inc.59

Signatures - Madison Gas and Electric Company60

2

PART I. FINANCIAL INFORMATION.

Filing Format

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

Forward-Looking Statements

This report, and other documents filed by MGE Energy and MGE with the Securities and Exchange Commission (SEC) from time to time, contain forward-looking statements that reflect management's current assumptions and estimates regarding future performance and economic conditions—especially as they relate to economic conditions, future load growth, revenues, expenses, capital expenditures, financial resources, regulatory matters, and the scope and expense associated with future environmental regulation. These forward-looking statements are made pursuant to the provisions of the Private Securities Litigation Reform Act of 1995. Words such as "believe," "expect," "anticipate," "estimate," "could," "should," "intend," "will," and other similar words generally identify forward-looking statements. Both MGE Energy and MGE caution investors that these forward-looking statements are subject to known and unknown risks and uncertainties that may cause actual results to differ materially from those projected, expressed, or implied.

The factors that could cause actual results to differ materially from the forward-looking statements made by a registrant include: (a) those factors discussed in the registrants' 2018 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 17, as updated by Part I, Item 1. Financial Statements – Note 9 in this report, and (b) other factors discussed herein and in other filings made by that registrant with the SEC.

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

Where to Find More Information

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

3

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

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

MGE Energy and Subsidiaries:

CWDCCentral Wisconsin Development Corporation

MAGAELMAGAEL, LLC

MGEMadison Gas and Electric Company

MGE EnergyMGE Energy, Inc.

MGE PowerMGE Power, LLC

MGE Power Elm RoadMGE Power Elm Road, LLC

MGE Power West CampusMGE Power West Campus, LLC

MGE ServicesMGE Services, LLC

MGE State Energy ServicesMGE State Energy Services, LLC

MGE TranscoMGE Transco Investment, LLC

MGEE TranscoMGEE Transco, LLC

North MendotaNorth Mendota Energy & Technology Park, LLC

Other Defined Terms:

ACEAffordable Clean Energy

AFUDCAllowance for Funds Used During Construction

AROAsset Retirement Obligation

ATCAmerican Transmission Company LLC

ATC HoldcoATC Holdco, LLC

BARTBest Available Retrofit Technology

BlountBlount Station

BSERBest System of Emissions Reductions

CAAClean Air Act

CAVRClean Air Visibility Rule

CCRCoal Combustion Residual

codificationFinancial Accounting Standards Board Accounting Standards Codification

ColumbiaColumbia Energy Center

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

CPPClean Power Plan

CSAPRCross-State Air Pollution Rule

DthDekatherms, a quantity measure used in respect of natural gas

EGUsElectric Generating Units

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

Elm Road UnitsElm Road Generating Station

EPAUnited States Environmental Protection Agency

FASBFinancial Accounting Standards Board

FERCFederal Energy Regulatory Commission

Forward WindForward Wind Energy Center

FTRFinancial Transmission Rights

GAAPGenerally Accepted Accounting Principles

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

GHGGreenhouse Gas

heating degree days (HDD)Measure of the extent to which the average daily temperature is below 65 degrees Fahrenheit, which is considered an indicator of possible increased demand for energy to provide heating

IRSInternal Revenue Service

kWhKilowatt-hour, a measure of electric energy produced

4

MISOMidcontinent Independent System Operator (a regional transmission organization)

MWMegawatt, a measure of electric energy generating capacity

MWhMegawatt-hour, a measure of electric energy produced

NAAQSNational Ambient Air Quality Standards

NO_xNitrogen Oxides

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

PPAPurchased Power Agreement

PSCWPublic Service Commission of Wisconsin

RiversideRiverside Energy Center

ROEReturn on Equity

SaratogaSaratoga Wind Farm

SCRSelective Catalytic Reduction

SECSecurities and Exchange Commission

SO₂Sulfur Dioxide

Stock PlanDirect Stock Purchase and Dividend Reinvestment Plan of MGE Energy

Tax ActTax Cuts and Jobs Act

UWUniversity of Wisconsin at Madison

VIEVariable Interest Entity

WCCFWest Campus Cogeneration Facility

WEPCOWisconsin Electric Power Company, a subsidiary of WEC Energy Group, Inc.

working capitalCurrent assets less current liabilities

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

XBRLeXtensible Business Reporting Language

5

Item 1. Financial Statements.

MGE Energy, Inc.

Consolidated Statements of Income (unaudited)

(In thousands, except per share amounts)

		Three Months Ended				Nine Months Ended
		September 30,				September 30,
		2019		2018		2019		2018
Operating Revenues:
Electric revenues	$	120,821	$	119,388	$	315,367	$	313,537
Gas revenues		17,377		18,407		112,547		106,152
Total Operating Revenues		138,198		137,795		427,914		419,689
Operating Expenses:
Fuel for electric generation		15,901		16,793		40,221		43,944
Purchased power		9,126		13,024		31,013		43,036
Cost of gas sold		3,092		4,921		55,220		54,109
Other operations and maintenance		48,070		44,130		143,979		131,976
Depreciation and amortization		18,193		14,259		53,423		41,754
Other general taxes		5,078		4,870		15,026		14,653
Total Operating Expenses		99,460		97,997		338,882		329,472
Operating Income		38,738		39,798		89,032		90,217
Other income, net		5,204		4,330		15,074		13,980
Interest expense, net		(5,831)		(5,025)		(17,227)		(14,547)
Income before income taxes		38,111		39,103		86,879		89,650
Income tax provision		(7,454)		(9,597)		(16,667)		(21,792)
Net Income	$	30,657	$	29,506	$	70,212	$	67,858
Earnings Per Share of Common Stock
(basic and diluted)	$	0.88	$	0.85	$	2.03	$	1.96
Dividends per share of common stock	$	0.353	$	0.338	$	1.028	$	0.983
Weighted Average Shares Outstanding
(basic and diluted)		34,668		34,668		34,668		34,668
The accompanying notes are an integral part of the above unaudited consolidated financial statements.

6

MGE Energy, Inc.

Consolidated Statements of Cash Flows (unaudited)

(In thousands)

		Nine Months Ended
		September 30,
		2019		2018
Operating Activities:
Net income	$	70,212	$	67,858
Items not affecting cash:
Depreciation and amortization		53,423		41,754
Deferred income taxes		4,864		2,352
Provision for doubtful receivables		978		642
Employee benefit plan credit		(2,866)		(1,544)
Equity earnings in ATC		(6,879)		(6,113)
Other items		692		31
Changes in working capital items:
Decrease in current assets		14,307		25,530
Increase (decrease) in current liabilities		(24,088)		6,026
Dividends from ATC		5,526		5,336
Cash contributions to pension and other postretirement plans		(3,707)		(3,967)
Other noncurrent items, net		(760)		527
Cash Provided by Operating Activities		111,702		138,432
Investing Activities:
Capital expenditures		(128,389)		(149,001)
Capital contributions to investments		(5,894)		(4,801)
Other		(248)		368
Cash Used for Investing Activities		(134,531)		(153,434)
Financing Activities:
Cash dividends paid on common stock		(35,622)		(34,062)
Repayments of long-term debt		(3,405)		(23,330)
Issuance of long-term debt		-		100,000
Proceeds from (repayments of) short-term debt		41,500		(4,000)
Other		(1,331)		(659)
Cash Provided by Financing Activities		1,142		37,949
Change in cash, cash equivalents, and restricted cash		(21,687)		22,947
Cash, cash equivalents, and restricted cash at beginning of period		84,929		112,094
Cash, cash equivalents, and restricted cash at end of period	$	63,242	$	135,041
Supplemental disclosures of cash flow information:
Significant noncash investing activities:
Accrued capital expenditures	$	16,819	$	10,991
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		2019		2018
Current Assets:
Cash and cash equivalents	$	61,112	$	83,102
Accounts receivable, less reserves of $2,683 and $2,614, respectively		35,805		43,593
Other accounts receivable, less reserves of $456 and $540 , respectively		7,867		6,262
Unbilled revenues		20,926		28,243
Materials and supplies, at average cost		28,019		24,093
Fuel for electric generation, at average cost		8,339		6,599
Stored natural gas, at average cost		11,402		11,303
Prepaid taxes		11,518		16,215
Regulatory assets - current		10,777		9,477
Assets held for sale		-		3,080
Other current assets		8,631		8,593
Total Current Assets		204,396		240,560
Other long-term receivables		2,343		2,709
Regulatory assets		144,482		145,424
Other deferred assets and other		17,096		12,488
Property, Plant, and Equipment:
Property, plant, and equipment, net		1,524,925		1,369,766
Construction work in progress		88,050		139,671
Total Property, Plant, and Equipment		1,612,975		1,509,437
Investments		85,681		78,000
Total Assets	$	2,066,973	$	1,988,618
LIABILITIES AND CAPITALIZATION
Current Liabilities:
Long-term debt due within one year	$	4,632	$	4,553
Short-term debt		54,500		13,000
Accounts payable		39,139		46,158
Accrued interest and taxes		5,570		7,384
Accrued payroll related items		11,090		13,044
Regulatory liabilities - current		15,606		13,826
Derivative liabilities		10,390		8,550
Other current liabilities		11,124		14,113
Total Current Liabilities		152,051		120,628
Other Credits:
Deferred income taxes		239,433		231,952
Investment tax credit - deferred		786		818
Regulatory liabilities		162,088		165,638
Accrued pension and other postretirement benefits		64,274		67,483
Derivative liabilities		18,600		23,980
Finance lease liabilities		17,657		1,771
Other deferred liabilities and other		70,691		66,361
Total Other Credits		573,529		558,003
Capitalization:
Common shareholders' equity		851,234		816,644
Long-term debt		490,159		493,343
Total Capitalization		1,341,393		1,309,987
Commitments and contingencies (see Footnote 9)
Total Liabilities and Capitalization	$	2,066,973	$	1,988,618
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, 2018
Beginning Balance	34,668	$	34,668	$	316,268	$	443,242	$	-	$	794,178
Net income							29,506				29,506
Common stock dividends declared
($0.338 per share)							(11,701)				(11,701)
Ending balance - September 30, 2018	34,668	$	34,668	$	316,268	$	461,047	$	-	$	811,983
Three Months Ended September 30, 2019
Beginning Balance	34,668	$	34,668	$	316,268	$	481,861	$	-	$	832,797
Net income							30,657				30,657
Common stock dividends declared
($0.353 per share)							(12,220)				(12,220)
Ending balance - September 30, 2019	34,668	$	34,668	$	316,268	$	500,298	$	-	$	851,234
Nine Months Ended September 30, 2018
Beginning Balance	34,668	$	34,668	$	316,268	$	426,874	$	377	$	778,187
Cumulative effect of new accounting principle							377		(377)		-
Beginning balance - adjusted							427,251		-		778,187
Net income							67,858				67,858
Common stock dividends declared
($0.983 per share)							(34,062)				(34,062)
Ending balance - September 30, 2018	34,668	$	34,668	$	316,268	$	461,047	$	-	$	811,983
Nine Months Ended September 30, 2019
Beginning Balance	34,668	$	34,668	$	316,268	$	465,708	$	-	$	816,644
Net income							70,212				70,212
Common stock dividends declared
($1.028 per share)							(35,622)				(35,622)
Ending balance - September 30, 2019	34,668	$	34,668	$	316,268	$	500,298	$	-	$	851,234
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,
		2019		2018		2019		2018
Operating Revenues:
Electric revenues	$	120,821	$	119,388	$	315,367	$	313,537
Gas revenues		17,377		18,407		112,547		106,152
Total Operating Revenues		138,198		137,795		427,914		419,689
Operating Expenses:
Fuel for electric generation		15,901		16,793		40,221		43,944
Purchased power		9,126		13,024		31,013		43,036
Cost of gas sold		3,092		4,921		55,220		54,109
Other operations and maintenance		47,947		43,987		143,282		131,175
Depreciation and amortization		18,193		14,259		53,423		41,754
Other general taxes		5,078		4,870		15,026		14,653
Total Operating Expenses		99,337		97,854		338,185		328,671
Operating Income		38,861		39,941		89,729		91,018
Other income, net		2,672		2,592		7,837		7,402
Interest expense, net		(6,095)		(5,500)		(18,223)		(15,727)
Income before income taxes		35,438		37,033		79,343		82,693
Income tax provision		(6,687)		(9,117)		(14,579)		(19,918)
Net Income	$	28,751	$	27,916	$	64,764	$	62,775
Less: Net Income Attributable to Noncontrolling
Interest, net of tax		(5,614)		(5,629)		(16,725)		(16,940)
Net Income Attributable to MGE	$	23,137	$	22,287	$	48,039	$	45,835
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,
		2019		2018
Operating Activities:
Net income	$	64,764	$	62,775
Items not affecting cash:
Depreciation and amortization		53,423		41,754
Deferred income taxes		3,653		(580)
Provision for doubtful receivables		978		642
Employee benefit plan credit		(2,866)		(1,544)
Other items		1,653		768
Changes in working capital items:
Decrease in current assets		14,236		24,864
Increase (decrease) in current liabilities		(22,234)		9,941
Cash contributions to pension and other postretirement plans		(3,707)		(3,967)
Other noncurrent items, net		(880)		374
Cash Provided by Operating Activities		109,020		135,027
Investing Activities:
Capital expenditures		(128,389)		(149,001)
Other		(477)		(680)
Cash Used for Investing Activities		(128,866)		(149,681)
Financing Activities:
Distributions to parent from noncontrolling interest		(17,000)		(19,000)
Repayments of long-term debt		(3,405)		(23,330)
Issuance of long-term debt		-		100,000
Proceeds from (repayments of) short-term debt		41,500		(4,000)
Other		(1,133)		(659)
Cash Provided by Financing Activities		19,962		53,011
Change in cash, cash equivalents, and restricted cash		116		38,357
Cash, cash equivalents, and restricted cash at beginning of period		6,670		10,093
Cash, cash equivalents, and restricted cash at end of period	$	6,786	$	48,450
Supplemental disclosures of cash flow information:
Significant noncash investing activities:
Accrued capital expenditures	$	16,819	$	10,991
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		2019		2018
Current Assets:
Cash and cash equivalents	$	4,656	$	4,843
Accounts receivable, less reserves of $2,683 and $2,614, respectively		35,805		43,593
Affiliate receivables		540		621
Accounts receivable, less reserves of $456 and $540 , respectively		7,863		6,111
Unbilled revenues		20,926		28,243
Materials and supplies, at average cost		28,019		24,093
Fuel for electric generation, at average cost		8,339		6,599
Stored natural gas, at average cost		11,402		11,303
Prepaid taxes		11,211		15,790
Regulatory assets - current		10,777		9,477
Assets held for sale		-		3,080
Other current assets		8,522		8,541
Total Current Assets		148,060		162,294
Affiliate receivable long-term		2,780		3,177
Regulatory assets		144,482		145,424
Other deferred assets and other		18,178		14,142
Property, Plant, and Equipment:
Property, plant, and equipment, net		1,524,954		1,369,795
Construction work in progress		88,050		139,671
Total Property, Plant, and Equipment		1,613,004		1,509,466
Investments		523		388
Total Assets	$	1,927,027	$	1,834,891
LIABILITIES AND CAPITALIZATION
Current Liabilities:
Long-term debt due within one year	$	4,632	$	4,553
Short-term debt		54,500		13,000
Accounts payable		39,104		46,165
Accrued interest and taxes		7,901		10,319
Accrued payroll related items		11,090		13,044
Regulatory liabilities - current		15,606		13,826
Derivative liabilities		10,390		8,550
Other current liabilities		11,125		11,614
Total Current Liabilities		154,348		121,071
Other Credits:
Deferred income taxes		210,886		204,616
Investment tax credit - deferred		786		818
Regulatory liabilities		162,088		165,638
Accrued pension and other postretirement benefits		64,274		67,483
Derivative liabilities		18,600		23,980
Finance lease liabilities		17,657		1,771
Other deferred liabilities and other		70,655		66,361
Total Other Credits		544,946		530,667
Capitalization:
Common shareholder's equity		596,395		548,356
Noncontrolling interest		141,179		141,454
Total Equity		737,574		689,810
Long-term debt		490,159		493,343
Total Capitalization		1,227,733		1,183,153
Commitments and contingencies (see Footnote 9)
Total Liabilities and Capitalization	$	1,927,027	$	1,834,891
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, 2018
Beginning balance	17,348	$	17,348	$	192,417	$	305,655	$	-	$	138,713	$	654,133
Net income							22,287				5,629		27,916
Distributions to parent from
noncontrolling interest											(5,500)		(5,500)
Ending balance - September 30, 2018	17,348	$	17,348	$	192,417	$	327,942	$	-	$	138,842	$	676,549
Three Months Ended September 30, 2019
Beginning balance	17,348	$	17,348	$	192,417	$	363,493	$	-	$	141,065	$	714,323
Net income							23,137				5,614		28,751
Distributions to parent from
noncontrolling interest											(5,500)		(5,500)
Ending balance - September 30, 2019	17,348	$	17,348	$	192,417	$	386,630	$	-	$	141,179	$	737,574
Nine Months Ended September 30, 2018
Beginning balance	17,348	$	17,348	$	192,417	$	282,135	$	(28)	$	140,902	$	632,774
Cumulative effect of new accounting principle							(28)		28				-
Beginning balance - adjusted							282,107		-				632,774
Net income							45,835				16,940		62,775
Distributions to parent from
noncontrolling interest											(19,000)		(19,000)
Ending balance - September 30, 2018	17,348	$	17,348	$	192,417	$	327,942	$	-	$	138,842	$	676,549
Nine Months Ended September 30, 2019
Beginning balance	17,348	$	17,348	$	192,417	$	338,591	$	-	$	141,454	$	689,810
Net income							48,039				16,725		64,764
Distributions to parent from
noncontrolling interest											(17,000)		(17,000)
Ending balance - September 30, 2019	17,348	$	17,348	$	192,417	$	386,630	$	-	$	141,179	$	737,574
The accompanying notes are an integral part of the above unaudited consolidated financial statements.

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

Notes to Consolidated Financial Statements (unaudited)

September 30, 2019

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 2018 Annual Report on Form 10-K (the 2018 Annual Report on Form 10-K).

The accompanying consolidated financial statements as of September 30, 2019, and for 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 2018 Annual Report on Form 10-K, but does not include all disclosures required by accounting principles generally accepted in the United States of America. These notes should be read in conjunction with the financial statements and the notes on pages 62 through 106 of the 2018 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)		2019		2018		2019		2018
Cash and cash equivalents	$	61,112	$	83,102	$	4,656	$	4,843
Restricted cash		532		634		532		634
Receivable - margin account		1,598		1,193		1,598		1,193
Cash, cash equivalents, and restricted cash	$	63,242	$	84,929	$	6,786	$	6,670

2.

New Accounting Standards - MGE Energy and MGE.

Recently Adopted

Leases.

In February 2016, the FASB issued authoritative guidance within the codification's Leases topic that provides guidance on the classification, recognition, measurement, and disclosure of leases. The new leasing standard establishes that a lease conveys the right to control the use of identified property, plant, or equipment for a period of time in exchange for consideration. Under the new guidance, lessees are required to recognize all leases with terms greater than one year, including operating leases, on the balance sheet by recording a right-of-use asset and lease liability. Prior to the authoritative guidance, only capital leases were recognized on the balance sheet by lessees. The new accounting guidance, as applied by lessors, did not change materially. In January 2018, the FASB issued authoritative guidance which provided an optional

14

practical expedient to grandfather the accounting for existing and expired land easements not accounted for as a lease under the new authoritative guidance. MGE Energy and MGE adopted this practical expedient.

The lease authoritative guidance became effective January 1, 2019. MGE Energy and MGE adopted the standard upon the effective date. In compliance with authorized transition guidance, MGE Energy and MGE began applying the new standard on January 1, 2019, but will continue to present periods prior to that date according to the previous authoritative standard. There was no material impact on the consolidated net income or cash flows. See Footnote 3 for further lease information.

3.

Leases - MGE Energy and MGE.

As part of its regular operations, MGE enters into various contracts related to IT equipment, substations, cell towers, land, wind easements, and other property in use for operations. A contract is or contains a lease if the contract conveys the right to control the use of identified property, plant, or equipment for a period of time in exchange for consideration. Determination as to whether an arrangement is or contains a lease is completed at inception. Leases with an initial term of 12 months or less are not recorded on the consolidated balance sheets; lease expense for these leases are recognized on a straight-line basis over the lease term. Leases with initial terms in excess of 12 months are recorded as operating or financing leases on the consolidated balance sheets.

Operating lease assets and operating lease liabilities are recognized based on the present value of the future minimum lease payments over the lease term at commencement date. For leases that do not provide an implicit rate, a collateralized incremental borrowing rate based on the information available at commencement date, including lease term, is used in determining the present value of future payments. The operating lease asset also includes any lease payments made and excludes lease incentives and initial direct costs incurred. Lease terms may include options to extend or terminate the lease when it is reasonably certain that the option will be exercised. Operating lease expense is recognized on a straight-line basis over the lease term. MGE has regulatory treatment and recognizes regulatory assets or liabilities for timing differences between when net lease costs are recorded and when costs are recognized. As of September 30, 2019, MGE has no significant leases not yet commenced that would create significant future rights and obligations.

The following table shows lease expense for the three and nine months ended September 30, 2019:

(In thousands)		Three Months Ended		Nine Months Ended	Income Statement Location
Finance lease expense:
Amortization of leased assets	$	425	$	1,295	Depreciation and amortization
Interest on lease liabilities		199		597	Interest expense, net
Operating lease expense		32		92	Other operations and maintenance
Total lease expense	$	656	$	1,984

The following table shows the lease assets and liabilities on the consolidated balance sheet as of September 30, 2019:

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(In thousands)			Balance Sheet Location
Lease assets:
Finance lease assets	$	16,275	Property, plant, and equipment, net
Operating lease assets		300	Other deferred assets and other
Total lease assets	$	16,575
Lease liabilities:
Finance lease liabilities - current	$	932	Other current liabilities
Finance lease liabilities - long-term		17,657	Finance lease liabilities
Operating lease liabilities - current		143	Other current liabilities
Operating lease liabilities - long-term		185	Other deferred liabilities and other
Total lease liabilities	$	18,917

The following table shows other financial lease information for the nine months ended September 30, 2019:

(In thousands)
Cash paid for amounts included in the measurement of lease liabilities:
Finance leases - Financing cash flows	$	781
Finance leases - Operating cash flows		597
Operating leases - Operating cash flows		108
Lease assets obtained in exchange for lease liabilities:
Finance leases		12,081
Operating leases		239

The following table shows the weighted average remaining lease terms and discounts as of September 30, 2019:

Weighted-average remaining lease terms (in years):
Finance leases	38
Operating leases	5
Weighted-average discount rates:
Finance leases	4.36	%
Operating leases	3.58	%

The following table shows maturities of lease liabilities as of September 30, 2019:

(In thousands)		Finance		Operating
2019	$	539	$	37
2020		1,644		152
2021		1,428		86
2022		1,309		33
2023		1,228		2
Thereafter		41,317		52
Subtotal		47,465		362
Less: Present value discount		(28,876)		(34)
Lease Liability	$	18,589	$	328

Future minimum rental payments as of December 31, 2018, under agreements classified as operating leases with noncancelable terms in excess of one year are as follows:

(In thousands)		2019		2020		2021		2022		2023		Thereafter
Minimum lease payments	$	1,646	$	1,371	$	1,095	$	989	$	975	$	22,707

4.

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

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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, which, since December 1, 2016, is owned by 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 wholly-owned 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:

		Three Months Ended				Nine Months Ended
		September 30,				September 30,
(In thousands)		2019		2018		2019		2018
Equity earnings from investment in ATC	$	2,364	$	1,672	$	6,879	$	6,113
Dividends from ATC(a)		1,781		1,581		5,526		4,540
Capital contributions to ATC		888		533		2,131		2,308

(a)MGE Transco recorded a $2.3 million dividend receivable from ATC as of December 31, 2017. A cash dividend was received in January of the following year. MGE Transco recorded a $1.6 million dividend receivable from ATC as of September 30, 2018. A cash dividend was received in October 2018.

ATC Holdco was formed in December 2016. In the near term, it is expected that ATC Holdco will be pursuing transmission development opportunities that typically have long development and investment lead times before becoming operational.

In October 2019, MGE Transco made a $0.9 million capital contribution to ATC.

ATC's summarized financial data is as follows:

		Three Months Ended				Nine Months Ended
		September 30,				September 30,
(In thousands)		2019		2018		2019		2018
Operating revenues	$	184,833	$	170,341	$	544,760	$	501,276
Operating expenses		(94,713)		(87,959)		(278,673)		(264,326)
Other income, net		484		439		1,031		2,070
Interest expense, net		(29,165)		(27,754)		(87,121)		(82,411)
Earnings before members' income taxes	$	61,439	$	55,067	$	179,997	$	156,609

MGE receives transmission and other related services from ATC. During the three and nine months ended September 30, 2019, MGE recorded $7.6 million and $22.8 million, respectively, for transmission services received compared to $7.2 million and $21.7 million for the comparable periods in 2018. MGE also provides a variety of operational, maintenance, and project management services for ATC, which is reimbursed by ATC. As of September 30, 2019, and December 31, 2018, MGE had a receivable due from ATC of $1.6 million and $0.1 million, respectively.

5.

Taxes - MGE Energy and MGE.

Effective Tax Rate.

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

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	MGE Energy				MGE
Three Months Ended September 30,	2019		2018		2019		2018
Statutory federal income tax rate	21.0	%	21.0	%	21.0	%	21.0	%
State income taxes, net of federal benefit	6.3		6.3		6.2		6.2
Amortized investment tax credits	(0.1)		(0.1)		(0.1)		(0.1)
Credit for electricity from wind energy(a)	(4.8)		(0.3)		(5.2)		(0.2)
AFUDC equity, net	(0.4)		(0.6)		(0.4)		(0.6)
Amortization of utility excess deferred tax - tax reform(b)	(1.9)		(1.8)		(2.1)		(1.8)
Other, net, individually insignificant	(0.5)		-		(0.5)		0.1
Effective income tax rate	19.6	%	24.5	%	18.9	%	24.6	%
	MGE Energy				MGE
Nine Months Ended September 30,	2019		2018		2019		2018
Statutory federal income tax rate	21.0	%	21.0	%	21.0	%	21.0	%
State income taxes, net of federal benefit	6.3		6.3		6.2		6.2
Amortized investment tax credits	(0.1)		(0.1)		(0.1)		(0.1)
Credit for electricity from wind energy(a)	(5.6)		(0.3)		(6.1)		(0.3)
AFUDC equity, net	(0.3)		(0.8)		(0.3)		(0.8)
Amortization of utility excess deferred tax - tax reform(b)	(2.2)		(1.8)		(2.4)		(2.0)
Other, net, individually insignificant	0.1		-		0.1		0.1
Effective income tax rate	19.2	%	24.3	%	18.4	%	24.1	%

(a)Saratoga Wind Farm became operational in February 2019.

(b)Included are impacts of the Tax Cuts and Jobs Act for the regulated utility for excess deferred taxes recognized using a normalization method of accounting. For the three and nine months ended September 30, 2019, MGE recognized $0.6 million and $1.7 million, respectively, compared to $0.5 million and $1.4 million for the comparable periods in 2018. The amount and timing of the cash impacts will depend on the period over which certain income tax benefits are provided to customers, as determined by the PSCW.

6.

Pension and Other Postretirement Plans - MGE Energy and MGE.

MGE maintains qualified and nonqualified pension plans, health care, and life insurance benefits. Additionally, MGE has defined contribution 401(k) benefit plans.

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. The service cost component of net periodic benefit cost is eligible for capitalization within the consolidated balance sheets. 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.

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		Three Months Ended				Nine Months Ended
		September 30,				September 30,
(In thousands)		2019		2018		2019		2018
Pension Benefits
Components of net periodic benefit cost:
Service cost	$	1,040	$	1,431	$	3,402	$	4,292
Interest cost		3,170		3,215		10,364		9,645
Expected return on assets		(5,054)		(6,560)		(16,523)		(19,680)
Amortization of:
Prior service credit		(26)		(11)		(85)		(33)
Actuarial loss		1,637		1,319		5,351		3,958
Net periodic benefit (credit) cost	$	767	$	(606)	$	2,509	$	(1,818)
Postretirement Benefits
Components of net periodic benefit cost:
Service cost	$	276	$	320	$	829	$	962
Interest cost		721		653		2,164		1,959
Expected return on assets		(677)		(808)		(2,034)		(2,424)
Amortization of:
Transition obligation		1		1		2		2
Prior service credit		(664)		(667)		(1,994)		(2,001)
Actuarial loss		100		122		300		366
Net periodic benefit (credit) cost	$	(243)	$	(379)	$	(733)	$	(1,136)

As a result of lower investment returns in the fourth quarter of 2018, pension and postretirement benefit costs increased in 2019. In August 2019, the PSCW approved MGE's request to defer the difference between estimated pension and other postretirement costs included in the 2019 and 2020 rate settlement and actual expense incurred. MGE expects that the deferred cost for employee benefit plans will be factored into future rate actions starting in 2021. For the three and nine months ended September 30, 2019, MGE has deferred approximately $1.3 million and $4.6 million of pension and other postretirement costs, respectively. The impact of the deferral has not been reflected in the table above.

7.

Equity and Financing Arrangements.

a.Common Stock - MGE Energy.

MGE Energy sells shares of its common stock through its Stock Plan. Those shares may be newly issued shares or shares that MGE Energy has purchased in the open market for resale to participants in the Stock Plan. All sales under the Stock Plan are covered by a shelf registration statement that MGE Energy filed with the SEC. For both the three and nine months ended September 30, 2019 and 2018, MGE Energy did not issue and new shares of common stock under the Stock Plan.

b.Dilutive Shares Calculation - MGE Energy.

MGE Energy does not have any stock option or stock award programs or any dilutive securities.

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

In August 2019, MGE entered into a Note Purchase Agreement for $50 million of new long-term unsecured debt carrying an interest rate of 2.94% per annum over its 10-year life. Funding occurred on November 5, 2019. The proceeds of the debt financing will be used to assist with capital expenditures, maturing short-term debt, and other corporate obligations. The covenants of this debt are substantially consistent with MGE's existing unsecured long-term debt.

8.

Share-Based Compensation - MGE Energy and MGE.

Under MGE Energy's Director Incentive Plan and its Performance Unit Plan, non-employee directors and eligible employees, respectively, may receive performance units that entitle the holder to receive a cash

19

payment equal to the value of a designated number of shares of MGE Energy's common stock, plus dividend equivalent payments thereon, at the end of the performance period set in the award.

In 2019, 5,175 units were granted under the Director Incentive Plan and are subject to a three-year graded vesting schedule, and 17,022 units were granted under the Performance Unit Plan and are subject to a five-year graded vesting schedule. On the grant date, the cost of the director or employee services received in exchange for a performance unit award is measured based on the current market value of MGE Energy common stock. The fair value of the awards is remeasured quarterly, including as of September 30, 2019, as required by applicable accounting standards. Changes in fair value as well as the original grant are recognized as compensation cost. Since this amount is remeasured throughout the vesting period, the compensation cost is subject to variability.

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

During the three and nine months ended September 30, 2019, MGE recorded $0.9 million and $2.8 million, respectively, in compensation expense as a result of awards under the plans compared to $0.3 million and $1.3 million for the comparable periods in 2018. In January 2019, cash payments of $1.5 million were distributed relating to awards that were granted in a prior year under the plans. No forfeitures of units occurred during the three and nine months ended September 30, 2019 and 2018. As of September 30, 2019, $6.2 million of outstanding awards are vested. Of this amount, no cash settlements have occurred as cash payments are only made at the end of the period covered by the awards.

9.

Commitments and Contingencies.

a.Environmental - MGE Energy and MGE.

MGE Energy and MGE are subject to frequently changing local, state, and federal regulations concerning air quality, water quality, land use, threatened and endangered species, hazardous materials handling, and solid waste disposal. These regulations affect the manner in which they conduct their operations, the costs of those operations, as well as capital and operating expenditures. Several of these environmental rules are subject to legal challenges, reconsideration and/or other uncertainties. Regulatory initiatives, proposed rules, and court challenges to adopted rules have the potential to 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 published water effluent limitations guidelines and standards for steam electric power plants, which focus on the reduction of metals and other pollutants in wastewater from new and existing power plants, such as the coal-burning plants at Columbia and the Elm Road Units. The operators of the Columbia and the Elm Road Units have indicated that equipment upgrades may be necessary to comply with the new discharge standards.

•The EPA's cooling water intake rules, which require cooling water intake structures at electric power plants, such as our Blount and Columbia plants, to meet best available technology standards so that mortality from entrainment (drawing aquatic life into a plant's cooling system) and impingement (trapping aquatic life on screens) are reduced. MGE expects that the rule will not have a material effect on its existing plants.

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

In 2015, the EPA finalized the Clean Power Plan (CPP), which directed states to submit plans to reduce GHG emissions from the electric generation sector. The CPP applied the statutory

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requirements for the "best system of emission reduction" (BSER) broadly so as to encompass GHG emission reduction strategies that extend "beyond the fenceline" of existing EGUs and required a shift in the energy generation mix at the grid level.

In July 2019, the EPA published a final rule repealing the CPP and creating the replacement Affordable Clean Energy (ACE) rule to reduce greenhouse gas emissions from existing coal-fired EGUs. The ACE rule applies to EGUs greater than 25 MW. Based upon these criteria, the ACE rule will likely apply to Columbia and the Elm Road Units. EGUs that burn fossil fuels other than coal, such as Blount, WCCF, and smaller natural gas- and diesel-fueled units are not subject to the ACE rule.

In contrast to the CPP, the ACE rule limits BSER to only "inside the fenceline" heat rate improvement technologies or systems that can be applied at an affected coal-fired EGU. Under ACE, states have the primary role in developing standards of performance that result from the application of BSER. The EPA has not provided a standard of performance that it will deem presumptively acceptable in a state plan, but urges states to provide full justification for each component of their plans so that the EPA can evaluate BSER on a unit-by-unit basis. The ACE rule is subject to a legal challenge pending in the United States District Court of the District of Columbia.

States will have three years to develop and submit compliance plans to the EPA. The EPA will have a year to review and approve the plans. The states are given 24 months from the approval date to implement the rule and can extend the compliance schedule for units that meet progress milestones. EGU's compliance with the ACE rule may not be required until 2024 or later. MGE is currently evaluating how this rule may impact operations. Until the State of Wisconsin develops a plan that is accepted by the EPA, MGE will not be able to determine the final impact of the rule. MGE will continue to evaluate the rule and monitor ongoing and potential legal proceedings associated with the CPP and ACE rules.

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

In May 2018, the EPA issued a final rule which designated the northeast portion of Milwaukee County as being in nonattainment with this NAAQS. The Elm Road Units are located in Milwaukee County, outside the designated nonattainment area. In August 2018, several environmental groups, the City of Chicago, and the State of Illinois filed federal lawsuits challenging several of the EPA's attainment designation decisions, including the partial Milwaukee County designation as being too narrow and not sufficiently protective. MGE is monitoring the outcome of this lawsuit and how it may affect our Elm Road Units in Milwaukee County. At this time, MGE expects that the 2015 Ozone NAAQS will not have a material effect on its existing plants based on final designations.

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

MGE has met its CSAPR obligations in 2018 and 2017 through a combination of reduced emissions through pollution control (e.g. SCR installation at Columbia), as well as owned, received, and purchased allowances. CSAPR has been subject to ongoing legal challenges. In September 2019, the U.S. Court of Appeals upheld the legal argument that the EPA cannot provide a partial remedy to the Clean Air Act's "Good Neighbor Provision" which addresses interstate transport of pollutants from upwind states to downwind states. Under the current rule, the EPA was not holding upwind states to the same attainment deadlines as the downwind states that they impacted. The court indicated that this leniency on the upwind states effectively causes downwind states to miss attainment deadlines or over comply to meet deadlines. The court remanded the rule to the EPA without vacating it. No deadline has been set for the EPA to revise the rule. Wisconsin is considered an upwind state under CSAPR and is potentially impacted by rules that the EPA will develop to address this remand.

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MGE will not be able to determine impacts to our operations until rules are promulgated. MGE will continue to monitor developments.

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

•The EPA's Coal Combustion Residuals Rule (CCR), which regulates coal ash from burning coal for the purpose of generating electricity as a solid waste, and defines what ash use activities would be considered generally exempt beneficial reuse of coal ash. The CCR rule also regulates landfills, ash ponds, and other surface impoundments used for coal combustion residuals by regulating their design, location, monitoring, and operation.

Review of the Elm Road Units has indicated that the costs to comply with this rule are not expected to be significant. Columbia's operator has completed a review of their system and has developed a compliance plan. Columbia's operator is also exploring alternative compliance options to meet the rule requirements by the rule's deadline. MGE will continue to monitor the operator's plans for compliance to assess potential impacts on operations.

In July 2018, the EPA published a final rule that included amendments to the CCR (which include the allowance of alternative performance standards for landfills and surface impoundments, revised risk-based groundwater protection standards, and an extension of the deadline by which certain facilities must cease the placement of waste in CCR units). In August 2018, the Court of Appeals for the D.C. Circuit vacated parts of the CCR for not being sufficiently protective of the environment. In August 2019, the EPA introduced a proposed rule that if final would revise some monitoring, corrective action, beneficial reuse, and storage requirements. The revised rule as proposed would not have material impact on MGE. MGE will continue to monitor potential rule modifications to assess potential impacts on operations.

b.Legal Matters - MGE Energy and MGE.

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

c.Purchase Contracts - MGE Energy and MGE.

MGE Energy and MGE have entered into various commodity supply, transportation, and storage contracts to meet their obligations to deliver electricity and natural gas to customers. Management expects to recover these costs in future customer rates. The following table shows future commitments related to purchase contracts as of September 30, 2019:

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(In thousands)		2019		2020		2021		2022		2023		Thereafter
Coal(a)	$	7,293		13,120		5,647		2,313		-		-
Natural gas
Transportation and storage(b)		6,258		21,997		21,728		21,728		21,728		55,460
Supply(c)		8,773		10,600		-		-		-		-
Solar farms(d)		509		310		3,024		726		743		32,474
Other		92		928		929		97		99		1,079
	$	22,925	$	46,955	$	31,328	$	24,864	$	22,570	$	89,013

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

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

(c)These commitments include market-based pricing.

(d)In 2019, MGE entered into commitments related to operations of the Two Creeks and Badger Hollow Solar Farms. See Footnote 14 for further information on the solar farm construction.

d.Capital Purchase Commitments - MGE Energy and MGE.

Various contractual obligations contain minimum future commitments related to capital expenditures for certain construction projects, including the Two Creeks solar project and the Badger Hollow Solar Farm. As of September 30, 2019, the Two Creeks and Badger Hollow future minimum construction commitment is $20.5 million and $53.2 million, respectively.

e.Other Commitments - MGE Energy.

In September 2019, MGE Energy entered into a subscription agreement to invest in a nonpublic venture capital fund. From time to time, the fund makes capital calls to its investors. MGE Energy has committed to contribute $10 million in capital for such capital calls. The timing of these capital calls is dependent on the needs of the funds and is therefore uncertain at this time.

10.

Rate Matters - MGE Energy and MGE.

a.Rate Proceedings.

In December 2018, the PSCW approved the settlement agreement between MGE and intervening parties in the rate case. The settlement decreases electric rates by 2.24%, or $9.2 million, in 2019. MGE will maintain this rate level for 2020, with the exception that MGE will file a 2020 Fuel Cost Plan in 2019 and MGE's electric rates will be adjusted accordingly. The decrease reflects the ongoing tax impacts of the Tax Act. Lower fuel costs and increase in rate base from renewable generation assets are additional items impacting the rate change. The settlement agreement increases gas rates by 1.06%, or $1.7 million, in 2019 and 1.46%, or $2.4 million, in 2020. The gas increase covers infrastructure costs. It also reflects the impacts of the Tax Act. The return on common stock equity for 2019 and 2020 is 9.8% based on a capital structure consisting of 56.6% common equity in 2019 and 56.1% common equity in 2020.

MGE did not file a base rate case for 2018.

b.Fuel Rules.

Fuel rules require the PSCW and Wisconsin utilities to defer electric fuel-related costs that fall outside a symmetrical cost tolerance band around the amount approved for a utility in its annual fuel proceedings. Any over/under recovery of the actual costs is determined in the following year and is then reflected in future billings to electric retail customers. The fuel rules bandwidth is currently set at plus or minus 2%. Under fuel rules, MGE would defer costs, less any excess revenues, if its actual electric fuel costs exceeded 102% of the electric fuel costs allowed in its latest rate order. Excess revenues are defined as revenues in the year in question that provide MGE with a greater return on

23

common equity than authorized by the PSCW in MGE's latest rate order. Conversely, MGE is required to defer the benefit of lower costs if actual electric fuel costs were less than 98% of the electric fuel costs allowed in that order. These costs will be subject to the PSCW's annual review of fuel costs completed in the year following the deferral.

In December 2017, the PSCW approved a surcharge for 2018 electric fuel-related costs. The surcharge increased electric retail revenue in 2018 by $0.5 million, or 0.13%.

In July 2019, the PSCW issued a final decision in the 2018 fuel rules proceedings for MGE to refund $9.5 million of additional fuel savings realized during 2018 plus accrued interest to its retail electric customers in October 2019. There was no change to the refund in the fuel rules proceedings from the amount MGE deferred in the previous year.

As of September 30, 2019, MGE had deferred $0.5 million in 2019 fuel savings. As of December 31, 2018, MGE had deferred $9.5 million of 2018 fuel savings.

c.2018 Tax Reform.

Customer rates approved for 2018 reflected an income tax rate of 35 percent. In January 2018, the PSCW issued an order directing Wisconsin investor-owned utilities to defer the over-collection of income tax expense as a result of the decrease in tax rate to 21 percent.

The PSCW issued an order in May 2018 to return to customers the estimated 2018 over-collection of income tax expense. The decision included a one-time bill credit on customer bills to reflect the estimate of the over-collection for January through June 2018, along with a volumetric bill credit which began in July 2018 and continued through the remainder of 2018 for the estimated remaining annual amount. MGE returned $8.2 million to customers through bill credits as of December 31, 2018.

In August 2019, the PSCW issued a decision on the 2018 tax reform proceedings for MGE to refund the remaining 2018 overcollection of income tax expense to its retail customers as a one-time bill credit. MGE returned $3.2 million in September 2019. There was no change to the refund order from the amount MGE deferred as of December 31, 2018.

11.

Derivative and Hedging Instruments - MGE Energy and MGE.

a.Purpose.

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

b.Notional Amounts.

The gross notional volume of open derivatives is as follows:

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	September 30, 2019		December 31, 2018
Commodity derivative contracts	466,760	MWh	386,440	MWh
Commodity derivative contracts	9,190,000	Dth	5,260,000	Dth
FTRs	4,282	MW	2,252	MW
PPA	1,600	MW	2,050	MW

c.Financial Statement Presentation.

MGE purchases and sells exchange-traded and over-the-counter options, swaps, and future contracts. These arrangements are primarily entered into to help stabilize the price risk associated with gas or power purchases. These transactions are employed by both MGE's gas and electric segments. Additionally, as a result of the firm transmission agreements that MGE holds on electricity transmission paths in the MISO market, MGE holds financial transmission rights (FTRs). An FTR is a financial instrument that entitles the holder to a stream of revenues or charges based on the differences in hourly day-ahead energy prices between two points on the transmission grid. The fair values of these instruments are offset with a corresponding regulatory asset/liability depending on whether they are in a net loss/gain position. Depending on the nature of the instrument, the gain or loss associated with these transactions will be reflected as cost of gas sold, fuel for electric generation, or purchased power expense in the delivery month applicable to the instrument. As of September 30, 2019, the cost basis of exchange traded derivatives and FTRs exceeded their fair value by $0.2 million. As of December 31, 2018, the fair value of exchange traded derivatives and FTRs exceeded their cost basis by $0.7 million.

MGE is a party to a purchased power agreement that provides MGE with firm capacity and energy during a base term from June 1, 2012, through May 31, 2022. The agreement also allows MGE an option to extend the contract after the base term. The agreement is accounted for as a derivative contract and is recognized at its fair value on the consolidated balance sheets. However, the derivative qualifies for regulatory deferral and is recognized with a corresponding regulatory asset or liability depending on whether the fair value is in a loss or gain position. The fair value of the contract as of September 30, 2019, and December 31, 2018, reflects a loss position of $29.0 million and $32.5 million, respectively. The actual cost will be recognized in purchased power expense in the month of purchase.

The following table summarizes the fair value of the derivative instruments on the consolidated balance sheets. All derivative instruments in this table are presented on a gross basis and are calculated prior to the netting of instruments with the same counterparty under a master netting agreement as well as the netting of collateral. For financial statement purposes, instruments are netted with the same counterparty under a master netting agreement as well as the netting of collateral. As of September 30, 2019, and December 31, 2018, the receivable margin account balance of $1.6 million and $1.2 million, respectively, is shown net of any collateral posted against derivative positions.

		Derivative		Derivative
(In thousands)		Assets		Liabilities	Balance Sheet Location
September 30, 2019
Commodity derivative contracts	$	668	$	996	Other current assets(a)
Commodity derivative contracts		81		289	Other deferred charges(a)
FTRs		344		-	Other current assets
PPA		N/A		10,390	Derivative liability (current)
PPA		N/A		18,600	Derivative liability (long-term)
December 31, 2018
Commodity derivative contracts	$	727	$	270	Other current assets
Commodity derivative contracts		74		72	Other deferred charges
FTRs		241		-	Other current assets
PPA		N/A		8,550	Derivative liability (current)
PPA		N/A		23,980	Derivative liability (long-term)

(a)As of September 30, 2019, collateral of $0.7 million was posted against and netted with derivative liability positions on the consolidated balance sheets. No collateral was posted against derivative positions as of December 31, 2018.

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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, 2019
Commodity derivative contracts	$	749	$	(561)	$	-	$	188
FTRs		344		-		-		344
December 31, 2018
Commodity derivative contracts	$	801	$	(342)	$	-	$	459
FTRs		241		-		-		241

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, 2019
Commodity derivative contracts	$	1,285	$	(561)	$	(724)	$	-
PPA		28,990		-		-		28,990
December 31, 2018
Commodity derivative contracts	$	342	$	(342)	$	-	$	-
PPA		32,530		-		-		32,530

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.

		2019				2018
(In thousands)		Current and Long-Term Regulatory Asset		Other Current Assets		Current and Long-Term Regulatory Asset		Other Current Assets
Three Months Ended September 30:
Balance at July 1,	$	33,515	$	878	$	36,924	$	640
Unrealized gain		(4,560)		-		(2,007)		-
Realized (loss) gain reclassified to a deferred account		(411)		411		(316)		316
Realized gain (loss) reclassified to income statement		638		(258)		29		(62)
Balance as of September 30,	$	29,182	$	1,031	$	34,630	$	894
Nine Months Ended September 30:
Balance at January 1,	$	31,830	$	377	$	41,958	$	806
Unrealized gain		(2,256)		-		(5,906)		-
Realized (loss) gain reclassified to a deferred account		(1,402)		1,402		(837)		837
Realized gain (loss) reclassified to income statement		1,010		(748)		(585)		(749)
Balance as of September 30,	$	29,182	$	1,031	$	34,630	$	894

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		Realized Losses (Gains)
		2019				2018
(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	$	471	$	83	$	(145)	$	-
FTRs		(429)		-		(150)		-
PPA		(505)		-		328		-
Nine Months Ended September 30:
Commodity derivative contracts	$	1,038	$	460	$	39	$	637
FTRs		(503)		-		(625)		-
PPA		(1,257)		-		1,283		-

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

The PPA has a provision that may require MGE to post collateral if MGE's debt rating falls below investment grade (i.e., below BBB-). The amount of collateral that it may be required to post varies from $20.0 million to $40.0 million, depending on MGE's nominated capacity amount. As of September 30, 2019, no collateral is required to be, or has been, posted. Certain counterparties extend MGE a credit limit. If MGE exceeds these limits, the counterparties may require collateral to be posted. No counterparties were in a net liability position as of September 30, 2019, and December 31, 2018.

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, 2019, no counterparties have defaulted.

12.

Fair Value of Financial Instruments - MGE Energy and MGE.

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

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

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

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

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

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

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The estimated fair market value offinancial instruments are as follows:

		September 30, 2019				December 31, 2018
(In thousands)		Carrying Amount		Fair Value		Carrying Amount		Fair Value
MGE Energy
Assets:
Cash and cash equivalents	$	61,112	$	61,112	$	83,102	$	83,102
Liabilities:
Short-term debt - commercial paper		54,500		54,500		13,000		13,000
Long-term debt(a)		499,027		578,229		502,431		518,811
MGE
Assets:
Cash and cash equivalents	$	4,656	$	4,656	$	4,843	$	4,843
Liabilities:
Short-term debt - commercial paper		54,500		54,500		13,000		13,000
Long-term debt(a)		499,027		578,229		502,431		518,811

(a) Includes long-term debt due within one year. Excludes debt issuance costs and unamortized discount of $4.2million and $4.5million as of September 30, 2019, and December 31, 2018, respectively.

b.Recurring Fair Value Measurements.

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

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		Fair Value as of September 30, 2019
(In thousands)		Total		Level 1		Level 2		Level 3
MGE Energy
Assets:
Derivatives, net(b)	$	1,093	$	525	$	-	$	568
Exchange-traded investments		1,001		1,001		-		-
Total Assets	$	2,094	$	1,526	$	-	$	568
Liabilities:
Derivatives, net	$	30,275	$	687	$	-	$	29,588
Deferred compensation		3,025		-		3,025		-
Total Liabilities	$	33,300	$	687	$	3,025	$	29,588
MGE
Assets:
Derivatives, net(b)	$	1,093	$	525	$	-	$	568
Exchange-traded investments		178		178		-		-
Total Assets	$	1,271	$	703	$	-	$	568
Liabilities:
Derivatives, net	$	30,275	$	687	$	-	$	29,588
Deferred compensation		3,025		-		3,025		-
Total Liabilities	$	33,300	$	687	$	3,025	$	29,588

		Fair Value as of December 31, 2018
(In thousands)		Total		Level 1		Level 2		Level 3
MGE Energy
Assets:
Derivatives, net	$	1,042	$	296	$	-	$	746
Exchange-traded investments		848		848		-		-
Total Assets	$	1,890	$	1,144	$	-	$	746
Liabilities:
Derivatives, net	$	32,872	$	124	$	-	$	32,748
Deferred compensation		3,078		-		3,078		-
Total Liabilities	$	35,950	$	124	$	3,078	$	32,748
MGE
Assets:
Derivatives, net	$	1,042	$	296	$	-	$	746
Exchange-traded investments		43		43		-		-
Total Assets	$	1,085	$	339	$	-	$	746
Liabilities:
Derivatives, net	$	32,872	$	124	$	-	$	32,748
Deferred compensation		3,078		-		3,078		-
Total Liabilities	$	35,950	$	124	$	3,078	$	32,748

(b) These amounts are shown gross and exclude $0.7 million of collateral that was posted against derivative positions with counterparties as of September 30, 2019.

No transfers were made in or out of Level 1 or Level 2 for the nine months ended September 30, 2019.

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

The deferred compensation plan allows participants to defer certain cash compensation into a notional investment account. These amounts are included within other deferred liabilities in the consolidated balance sheets. The notional investments earn interest based upon the semiannual rate of U.S. Treasury Bills having a 26-week maturity increased by 1% compounded monthly with a minimum annual rate of 7%, compounded monthly. The notional investments are based upon observable market data, however, since the deferred compensation obligations themselves are not exchanged in an active market, they are classified as Level 2.

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

The purchased power agreement (see Footnote 11) was valued using an internally-developed pricing model and therefore is classified as Level 3. The model projects future market energy prices and compares those prices to the projected power costs to be incurred under the contract. Inputs to the model require significant management judgment and estimation. Future energy prices are based on a forward power pricing curve using exchange-traded contracts in the electric futures market. A basis adjustment is applied to the market energy price to reflect the price differential between the market price delivery point and the counterparty delivery point. The historical relationship between the delivery points is reviewed and a discount (below 100%) or premium (above 100%) is derived. This comparison is done for both peak times when demand is high and off-peak times when demand is low. If the basis adjustment is lowered, the fair value measurement will decrease, and if the basis adjustment is increased, the fair value measurement will increase.

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

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

	Model Input
Significant Unobservable Inputs	September 30, 2019		December 31, 2018
Basis adjustment:
On peak	92.2	%	92.1	%
Off peak	92.8	%	92.8	%
Counterparty fuel mix:
Internal generation	40.0% - 60.0	%	50.0% - 75.0	%
Purchased power	60.0% - 40.0	%	50.0% - 25.0	%

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

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		Three Months Ended				Nine Months Ended
		September 30,				September 30,
(In thousands)		2019		2018		2019		2018
Beginning balance	$	(33,337)	$	(37,332)	$	(32,002)	$	(42,026)
Realized and unrealized gains (losses):
Included in regulatory assets		4,317		2,018		2,982		6,711
Included in other comprehensive income		-		-		-		-
Included in earnings		(492)		26		(1,928)		(434)
Included in current assets		4		(25)		(198)		(496)
Purchases		5,205		5,736		16,827		17,602
Sales		-		-		-		-
Issuances		-		-		-		-
Settlements		(4,717)		(5,737)		(14,701)		(16,671)
Transfers in and/or out of Level 3		-		-		-		-
Balance as of September 30,	$	(29,020)	$	(35,314)	$	(29,020)	$	(35,314)
Total gains (losses) included in earnings attributed to
the change in unrealized gains (losses) related to
assets and liabilities held at 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)		2019		2018		2019		2018
Purchased Power Expense	$	(409)	$	26	$	(1,658)	$	(637)
Cost of Gas Sold Expense		(83)		-		(270)		203
Total	$	(492)	$	26	$	(1,928)	$	(434)

(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.

13.

Asset Retirement Obligation - MGE Energy and MGE.

A liability for the fair value of an asset retirement obligation (ARO) is recognized in the period in which it is incurred if it can be reasonably estimated. The offsetting associated asset retirement costs are capitalized as a long-lived asset and depreciated over the asset's useful life.As of September 30, 2019, MGE recorded an obligation of $1.5 million for the fair value of its legal liability for an ARO associated with the Saratoga Wind Farm. MGE has regulatory treatment and recognizes regulatory assets or liabilities for the timing differences between when we recover legal AROs in rates and when those costs would actually be recognized.

14.

Joint Plant Ownership - MGE Energy and MGE.

a. Two Creeks.

In May 2019, MGE acquired a 33% ownership interest in a 150 MW solar generation array in the Town of Two Creeks and the City of Two Rivers in Manitowoc and Kewaunee Counties, Wisconsin. MGE's sole principal asset will be the 33% undivided ownership interest in the solar generation facility, which is being constructed. The estimated share of capital costs for MGE's ownership interest is approximately $65 million (excluding capitalized interest).

As of September 30, 2019, $42.1 million (excluding capitalized interest) related to this project is reflected in "Construction work in progress" on the consolidated balance sheets. The project is anticipated to be completed by the end of 2020.

b. Badger Hollow.

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In July 2019, MGE acquired a 33% ownership interest in a 150 MW solar generation array in southwestern Wisconsin in Iowa County, near the villages of Montfort and Cobb. MGE's sole principal asset will be the 33% undivided ownership interest in the solar generation facility which is being constructed. The estimated share of capital costs for MGE's ownership interest is approximately $65 million (excluding capitalized interest).

As of September 30, 2019, $10.0 million (excluding capitalized interest) related to this project is reflected in "Construction work in progress" on the consolidated balance sheets. The project is anticipated to be completed by the end of 2020.

15.

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		2019		2018		2019		2018
Residential	$	42,442	$	42,371	$	107,772	$	107,847
Commercial		63,466		61,638		165,481		159,264
Industrial		3,760		3,668		10,013		11,193
Other-retail/municipal		9,543		9,431		26,728		26,245
Total retail		119,211		117,108		309,994		304,549
Sales to the market		1,163		1,505		3,914		6,334
Other revenues		233		562		978		1,750
Total electric revenues		120,607		119,175		314,886		312,633
Gas revenues
Residential		11,342		11,916		67,659		64,087
Commercial/Industrial		4,825		5,570		40,833		38,728
Total retail		16,167		17,486		108,492		102,815
Gas transportation		1,126		829		3,756		3,018
Other revenues		84		92		299		319
Total gas revenues		17,377		18,407		112,547		106,152
Non-regulated energy revenues		214		213		481		904
Total Operating Revenue	$	138,198	$	137,795		427,914	$	419,689

Performance Obligations

A performance obligation is a promise in a contract to transfer a distinct good or service to the customer and is the unit of account. A contract's transaction price is allocated to each distinct performance obligation and recognized as revenue when, or as, the performance obligation is satisfied. The majority of MGE Energy's and MGE's contracts have a single performance obligation.

Retail Revenue (Residential, Commercial, Industrial, and Other Retail/Municipal)

Retail revenue of electric and gas utility service represent MGE's core business activities. Tariffs are approved by the PSCW through a rate order and provide MGE's customers with the standard terms and conditions, including pricing terms. The performance obligation to deliver electricity or gas is satisfied over time as the customer simultaneously receives and consumes the commodities provided by MGE. MGE recognizes revenues as the commodity is delivered to customers. Meters are read on a systematic basis throughout the month based on established meter-reading schedules and the customer is subsequently billed for their services. At the end of the month, MGE accrues an estimate for the unbilled amount of commodities delivered to customers. The unbilled revenue estimate is based on daily system demand volumes, weather factors, estimated line losses, estimated customer usage by class, and applicable customer rates.

Utility Cost Recovery Mechanisms

MGE's tariff rates include a provision for fuel cost recovery. The PSCW allows Wisconsin utilities to defer electric fuel-related costs, less excess revenues, that fall outside a symmetrical cost tolerance band. Any over/under recovery of the actual costs in a given year is determined in the following year and is then

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reflected in future billings to electric retail customers. Over-collection of fuel-related costs that are outside the approved range will be recognized as a reduction of revenue. Under-collection of these costs will be recognized in "Purchased power" expense in the consolidated statements of income. The cumulative effects of these deferred amounts will be recorded in "Regulatory assets" or "Regulatory liabilities" on the consolidated balance sheets until they are reflected in future billings to customers. See Footnote 10.b. for further information.

MGE received a PSCW order in January 2018 to defer the over-collection of income tax expense collected in customer rates during 2018 as a result of the Tax Cuts and Jobs Act (the Tax Act) reduction in the income tax rate to 21 percent. See Footnote 10.c. for further information.

MGE has other cost recovery mechanisms. For example, any over-collection of the difference between actual costs incurred and the amount of costs collected from customers is recorded as a reduction of revenue in the period incurred.

Sales to the Market

Sales to the market include energy charges, capacity or demand charges, and ancillary charges represented by wholesale sales of electricity made to third parties who are not ultimate users of the electricity. Most of these sales are spot market transactions on the markets operated by MISO. Each transaction is considered a performance obligation and revenue is recognized in the period in which energy charges, capacity or demand charges, and ancillary services are sold into MISO. MGE reports, on a net basis, transactions on the MISO markets in which it buys and sells power within the same hour to meet electric energy delivery requirements.

Transportation of Gas

MGE has contracts under which MGE provides gas transportation services to customers who have elected to purchase gas from a third party and have the gas delivered via pipelines within MGE's service territory. Revenue is recognized as service is rendered or gas is delivered to customers. Tariffs are approved by the PSCW through a rate order and provide gas transportation customers with the standard terms and conditions, including pricing terms.

16.

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 2018 Annual Report on Form 10-K for additional discussion of each of these segments.

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

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(In thousands) MGE Energy		Electric		Gas		Non-regulated Energy		Transmission Investment		All Others		Consolidation/ Elimination Entries		Consolidated Total
Three Months Ended September 30, 2019
Operating revenues	$	120,607	$	17,377	$	214	$	-	$	-	$	-	$	138,198
Interdepartmental revenues		225		5,679		10,019		-		-		(15,923)		-
Total operating revenues		120,832		23,056		10,233		-		-		(15,923)		138,198
Depreciation and amortization		(13,441)		(2,879)		(1,873)		-		-		-		(18,193)
Other operating expenses		(76,817)		(20,217)		(33)		-		(123)		15,923		(81,267)
Operating income (loss)		30,574		(40)		8,327		-		(123)		-		38,738
Other income, net		1,817		855		-		2,372		160		-		5,204
Interest (expense) income, net		(3,762)		(1,059)		(1,274)		-		264		-		(5,831)
Income (loss) before taxes		28,629		(244)		7,053		2,372		301		-		38,111
Income tax (provision) benefit		(4,948)		183		(1,922)		(646)		(121)		-		(7,454)
Net income (loss)	$	23,681	$	(61)	$	5,131	$	1,726	$	180	$	-	$	30,657
Three Months Ended September 30, 2018
Operating revenues	$	119,175	$	18,407	$	213	$	-	$	-	$	-	$	137,795
Interdepartmental revenues		(20)		4,219		9,912		-		-		(14,111)		-
Total operating revenues		119,155		22,626		10,125		-		-		(14,111)		137,795
Depreciation and amortization		(9,864)		(2,534)		(1,861)		-		-		-		(14,259)
Other operating expenses		(77,847)		(19,824)		(36)		(4)		(138)		14,111		(83,738)
Operating income (loss)		31,444		268		8,228		(4)		(138)		-		39,798
Other income, net		1,763		829		-		1,620		118		-		4,330
Interest (expense) income, net		(3,217)		(963)		(1,320)		-		475		-		(5,025)
Income before taxes		29,990		134		6,908		1,616		455		-		39,103
Income tax (provision) benefit		(7,306)		42		(1,852)		(441)		(40)		-		(9,597)
Net income	$	22,684	$	176	$	5,056	$	1,175	$	415	$	-	$	29,506
Nine Months Ended September 30, 2019
Operating revenues	$	314,886	$	112,547	$	481	$	-	$	-	$	-	$	427,914
Interdepartmental revenues		622		12,571		29,987		-		-		(43,180)		-
Total operating revenues		315,508		125,118		30,468		-		-		(43,180)		427,914
Depreciation and amortization		(39,330)		(8,482)		(5,611)		-		-		-		(53,423)
Other operating expenses		(223,242)		(104,587)		(113)		-		(697)		43,180		(285,459)
Operating income (loss)		52,936		12,049		24,744		-		(697)		-		89,032
Other income, net		5,258		2,579		-		6,808		429		-		15,074
Interest (expense) income, net		(11,253)		(3,132)		(3,838)		-		996		-		(17,227)
Income before taxes		46,941		11,496		20,906		6,808		728		-		86,879
Income tax provision		(6,036)		(2,848)		(5,695)		(1,856)		(232)		-		(16,667)
Net income	$	40,905	$	8,648	$	15,211	$	4,952	$	496	$	-	$	70,212
Nine Months Ended September 30, 2018
Operating revenues	$	312,633	$	106,152	$	904	$	-	$	-	$	-	$	419,689
Interdepartmental revenues		(234)		12,059		29,579		-		-		(41,404)		-
Total operating revenues		312,399		118,211		30,483		-		-		(41,404)		419,689
Depreciation and amortization		(28,817)		(7,374)		(5,563)		-		-		-		(41,754)
Other operating expenses		(228,957)		(99,251)		(113)		(12)		(789)		41,404		(287,718)
Operating income (loss)		54,625		11,586		24,807		(12)		(789)		-		90,217
Other income, net		5,055		2,347		-		5,908		670		-		13,980
Interest (expense) income, net		(9,036)		(2,689)		(4,002)		-		1,180		-		(14,547)
Income before taxes		50,644		11,244		20,805		5,896		1,061		-		89,650
Income tax provision		(11,492)		(2,788)		(5,638)		(1,611)		(263)		-		(21,792)
Net income	$	39,152	$	8,456	$	15,167	$	4,285	$	798	$	-	$	67,858

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

(In thousands) MGE		Electric		Gas		Non-regulated Energy		Consolidation/ Elimination Entries		Consolidated Total
Three Months Ended September 30, 2019
Operating revenues	$	120,607	$	17,377	$	214	$	-	$	138,198
Interdepartmental revenues		225		5,679		10,019		(15,923)		-
Total operating revenues		120,832		23,056		10,233		(15,923)		138,198
Depreciation and amortization		(13,441)		(2,879)		(1,873)		-		(18,193)
Other operating expenses		(76,817)		(20,217)		(33)		15,923		(81,144)
Operating income (loss)		30,574		(40)		8,327		-		38,861
Other income, net		1,817		855		-		-		2,672
Interest expense, net		(3,762)		(1,059)		(1,274)		-		(6,095)
Income (loss) before taxes		28,629		(244)		7,053		-		35,438
Income tax (provision) benefit		(4,948)		183		(1,922)		-		(6,687)
Net income (loss)		23,681		(61)		5,131		-		28,751
Less: Net income attributable to
noncontrolling interest, net of tax		-		-		-		(5,614)		(5,614)
Net income (loss) attributable to MGE	$	23,681	$	(61)	$	5,131	$	(5,614)	$	23,137
Three Months Ended September 30, 2018
Operating revenues	$	119,175	$	18,407	$	213	$	-	$	137,795
Interdepartmental revenues		(20)		4,219		9,912		(14,111)		-
Total operating revenues		119,155		22,626		10,125		(14,111)		137,795
Depreciation and amortization		(9,864)		(2,534)		(1,861)		-		(14,259)
Other operating expenses		(77,847)		(19,824)		(35)		14,111		(83,595)
Operating income		31,444		268		8,229		-		39,941
Other income, net		1,763		829		-		-		2,592
Interest expense, net		(3,217)		(963)		(1,320)		-		(5,500)
Income before taxes		29,990		134		6,909		-		37,033
Income tax provision		(7,306)		42		(1,853)		-		(9,117)
Net income		22,684		176		5,056		-		27,916
Less: Net income attributable to
noncontrolling interest, net of tax		-		-		-		(5,629)		(5,629)
Net income attributable to MGE	$	22,684	$	176	$	5,056	$	(5,629)	$	22,287
Nine Months Ended September 30, 2019
Operating revenues	$	314,886	$	112,547	$	481	$	-	$	427,914
Interdepartmental revenues		622		12,571		29,987		(43,180)		-
Total operating revenues		315,508		125,118		30,468		(43,180)		427,914
Depreciation and amortization		(39,330)		(8,482)		(5,611)		-		(53,423)
Other operating expenses		(223,242)		(104,587)		(113)		43,180		(284,762)
Operating income		52,936		12,049		24,744		-		89,729
Other income, net		5,258		2,579		-		-		7,837
Interest expense, net		(11,253)		(3,132)		(3,838)		-		(18,223)
Income before taxes		46,941		11,496		20,906		-		79,343
Income tax provision		(6,036)		(2,848)		(5,695)		-		(14,579)
Net income		40,905		8,648		15,211		-		64,764
Less: Net income attributable to
noncontrolling interest, net of tax		-		-		-		(16,725)		(16,725)
Net income attributable to MGE	$	40,905	$	8,648	$	15,211	$	(16,725)	$	48,039
Nine Months Ended September 30, 2018
Operating revenues	$	312,633	$	106,152	$	904	$	-	$	419,689
Interdepartmental revenues		(234)		12,059		29,579		(41,404)		-
Total operating revenues		312,399		118,211		30,483		(41,404)		419,689
Depreciation and amortization		(28,817)		(7,374)		(5,563)		-		(41,754)
Other operating expenses		(228,957)		(99,251)		(113)		41,404		(286,917)
Operating income		54,625		11,586		24,807		-		91,018
Other income, net		5,055		2,347		-		-		7,402
Interest expense, net		(9,036)		(2,689)		(4,002)		-		(15,727)
Income before taxes		50,644		11,244		20,805		-		82,693
Income tax provision		(11,492)		(2,788)		(5,638)		-		(19,918)
Net income		39,152		8,456		15,167		-		62,775
Less: Net income attributable to
noncontrolling interest, net of tax		-		-		-		(16,940)		(16,940)
Net income attributable to MGE	$	39,152	$	8,456	$	15,167	$	(16,940)	$	45,835

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The following table shows segment information for assets and capital expenditures:
		Utility				Consolidated
(In thousands) MGE Energy		Electric		Gas		Non-regulated Energy		Transmission Investment		All Others		Consolidation/ Elimination Entries		Total
Assets:
September 30, 2019	$	1,288,752	$	379,160	$	259,542	$	69,829	$	447,307	$	(377,617)	$	2,066,973
December 31, 2018		1,193,083		377,005		265,301		66,366		465,661		(378,798)		1,988,618
Capital Expenditures:
Nine months ended September 30, 2019	$	101,609	$	24,551	$	2,229	$	-	$	-	$	-	$	128,389
Year ended Dec. 31, 2018		176,399		30,497		5,301		-		-		-		212,197

		Utility				Consolidated
(In thousands) MGE		Electric		Gas		Non-regulated Energy		Elimination Entries		Total
Assets:
September 30, 2019	$	1,288,752	$	379,160	$	259,492	$	(377)	$	1,927,027
December 31, 2018		1,193,083		377,005		265,251		(448)		1,834,891
Capital Expenditures:
Nine months ended September 30, 2019	$	101,609	$	24,551	$	2,229	$	-	$	128,389
Year ended Dec. 31, 2018		176,399		30,497		5,301		-		212,197

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

General

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

Regulated electric utility operations, conducted through MGE,

Regulated gas utility operations, conducted through MGE,

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

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

All other, which includes corporate operations and services.

Our principal subsidiary is MGE, which generates and distributes electric energy, distributes natural gas, and represents a majority portion of our assets, liabilities, revenues, and expenses. MGE generates and distributes electricity to approximately 153,000 customers in Dane County, Wisconsin, including the city of Madison, and purchases and distributes natural gas to approximately 161,000 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 meets this challenge by investing in more efficient generation projects, including renewable energy sources. MGE continues to examine and pursue opportunities to reduce the proportion that coal generation represents in its generation mix, including the reduction in its ownership of Columbia and its growing ownership of renewable generation sources. MGE will continue to focus on growing earnings while controlling operating and fuel costs. MGE maintains safe and efficient operations in addition to providing customer value. We believe it is critical to maintain a strong credit standing consistent with financial strength in MGE as well as the parent company in order to accomplish these goals.

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

Weather, and its impact on customer sales,

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

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

Energy commodity prices, including natural gas prices,

Equity price risk pertaining to pension related assets,

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

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

Other factors listed in "Item 1A. Risk Factors" in our 2018 Annual Report on Form 10-K.

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For the three months ended September 30, 2019, MGE Energy's earnings were $30.7 million or $0.88 per share compared to $29.5 million or $0.85 per share for the same period in the prior year. MGE's earnings for the three months ended September 30, 2019, were $23.1 million compared to $22.3 million for the same period in the prior year.

For the nine months ended September 30, 2019, MGE Energy's earnings were $70.2 million or $2.03 per share compared to $67.9 million or $1.96 per share for the same period in the prior year. MGE's earnings for the nine months ended September 30, 2019, were $48.0 million compared to $45.8 million for the same period in the prior year.

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

		Three Months Ended				Nine Months Ended
(In millions)		September 30,				September 30,
Business Segment:		2019		2018		2019		2018
Electric Utility	$	23.7	$	22.6	$	40.9	$	39.1
Gas Utility		-		0.2		8.6		8.5
Nonregulated Energy		5.1		5.1		15.2		15.2
Transmission Investments		1.7		1.2		5.0		4.3
All Other		0.2		0.4		0.5		0.8
Net Income	$	30.7	$	29.5	$	70.2	$	67.9

Our net income during the three and nine months ended September 30, 2019, compared to the same period in the prior year primarily reflects the effects of the following factors:

Electric Utility

An increase in owned generation assets included in rate base contributed to increased earnings for the three and nine months ended September 30, 2019, as a result of the completion of the Saratoga Wind Farm.

During the first nine months of 2019, the following events occurred:

2019/2020 Rate Settlement: In December 2018, the PSCW approved the settlement agreement between MGE and intervening parties in the rate case. The settlement decreases electric rates by 2.24% or $9.2 million in 2019. MGE will maintain this rate level for 2020, with the exception that MGE will file a 2020 Fuel Cost Plan in 2019 and MGE's electric rates will be adjusted accordingly. The decrease reflects the ongoing tax impacts of the Tax Act. Lower fuel costs and increase in rate base from renewable generation assets are additional items impacting the rate change. The settlement agreement increases gas rates by 1.06% or $1.7 million in 2019 and 1.46% or $2.4 million in 2020. The increase covers infrastructure costs. It also reflects the impacts of the Tax Act.

Pension and Other Postretirement Benefit Costs: Costs for pension and other postretirement benefits are affected by actual investment returns on the assets held for those benefits and by the discount rate, which is sensitive to interest rates, used to calculate those benefits. Volatility in interest rates and investment returns could affect the value of the pension and postretirement benefit obligations. These changes may affect benefit costs in future years. As a result of lower investment returns in the fourth quarter of 2018, pension and postretirement benefit costs increased in 2019. In August 2019, the PSCW approved MGE's request to defer the difference between estimated pension and other postretirement costs included in the 2019 and 2020 rate settlement and actual expense incurred. MGE expects that the deferred cost for employee benefit plans will be factored into future rate actions starting in 2021. For the three and nine months ended September 30, 2019, MGE has deferred approximately $1.3 million and $4.6 million of pension and other postretirement costs, respectively.

Saratoga Wind Farm: In December 2017, the PSCW authorized construction of a 66 MW wind farm, consisting of 33 turbines, located near Saratoga, Iowa. Construction of the project was completed in February 2019 for approximately $112 million. MGE received specific approval to recover 100% AFUDC on the project. After tax, MGE has recognized $0.8 million in AFUDC equity related to this project for the nine months ended September 30, 2019.

Columbia: MGE and WPL negotiated an amendment to the existing Columbia joint operating agreement, effective January 1, 2017, under which MGE reduced its obligation to pay certain capital expenditures (other than

38

SCR-related expenditures) at Columbia in exchange for a proportional reduction in MGE's ownership in Columbia. On January 1 of each year from 2017 through 2019 and then on June 1, 2020, the ownership percentage is adjusted through a partial sale based on the amount of capital expenditures foregone. As of December 31, 2018, MGE classified $3.1 million of Columbia assets as held-for-sale on the consolidated balance sheets. In January 2019, MGE reduced its ownership interest in Columbia from 19.4% to 19.1% as a result of the partial sale of plant assets to WPL.

Utility Solar – Two Creeks: In May 2019, MGE acquired a 33% ownership interest in a 150 MW solar generation array in the Town of Two Creeks and the City of Two Rivers in Manitowoc and Kewaunee Counties, Wisconsin. MGE's sole principal asset will be the 33% undivided ownership interest in the solar generation facility, which is being constructed. The estimated share of capital costs for that ownership interest is approximately $65 million (excluding capitalized interest). As of September 30, 2019, $42.1 million (excluding capitalized interest) related to this project is reflected in "Construction work in progress" on the consolidated balance sheets. The project is anticipated to be completed by the end of 2020.

Utility Solar – Badger Hollow: In July 2019, MGE acquired a 33% ownership interest in a 150 MW solar generation array in southwestern Wisconsin in Iowa County, near the villages of Montfort and Cobb. MGE's sole principal asset will be the 33% undivided ownership interest in the solar generation facility which is being constructed. The estimated share of capital costs for that ownership interest is approximately $65 million (excluding capitalized interest). As of September 30, 2019, $10.0 million (excluding capitalized interest) related to this project is reflected in "Construction work in progress" on the consolidated balance sheets. The project is anticipated to be completed by the end of 2020.

2018 Tax Reform: In August 2019, the PSCW issued a decision on the 2018 tax reform proceedings for MGE to refund the remaining 2018 overcollection of income tax expense to its retail customers as a one-time bill credit. MGE returned $3.2 million in September 2019. There was no change to the refund order from the amount MGE deferred as of December 31, 2018.

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

2018 Annual Fuel Proceeding: In July 2019, the PSCW issued a final decision in the 2018 fuel rules proceedings for MGE to refund $9.5 million of additional fuel savings realized during 2018 plus accrued interest to its retail electric customers in October 2019. There was no change to the refund in the fuel rules proceedings from the amount MGE deferred as of December 31, 2018.

Tax Reform: Pursuant to the Tax Act, deferred income tax balances as of December 31, 2017, were remeasured to reflect the decrease in corporate tax rate. Approximately $131 million of regulatory liability was recorded given that changes in income taxes are generally passed through in customer rates for the regulated utility. The amount and timing of the cash impacts will depend on the period over which certain income tax benefits are provided to customers. Approximately $117 million of the regulatory liability is being returned to customers using a normalization method of accounting. The return of the remaining portion will be determined by the PSCW in MGE's next rate case.

ATC Return on Equity: Several parties have filed complaints with the FERC seeking to reduce the ROE used by MISO transmission owners, including ATC. Any change to ATC's ROE could result in lower equity earnings and distributions from ATC in the future. We derived approximately 6.8% and 6.3% of our net income for the nine months ended September 30, 2019 and 2018, respectively, from our investment in ATC. See "Other Matters" below for additional information concerning ATC.

Environmental Initiatives: There are proposed legislative rules and initiatives involving matters related to air emissions, water effluent, hazardous materials, and greenhouse gases, all of which affect generation plant capital expenditures and operating costs as well as future operational planning. At present, it is unclear how the changes in the Presidential and EPA administrations may affect existing, pending or new legislative or rulemaking proposals or regulatory initiatives. Such legislation and rulemaking could significantly affect the costs of owning and operating fossil-fueled generating plants, such as Columbia and the Elm Road Units, from which we derive approximately 43% of our electric generating capacity as of September 30, 2019. 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

39

uncertainty as to the timing and form of the legislation and rules, and the scope and time of the recovery of costs in rates, which may lag the incurrence of those costs.

EPA's Clean Power Plan and Affordable Clean Energy Rule: In 2015, the EPA finalized the Clean Power Plan (CPP), which directed states to submit plans to reduce GHG emissions from the electric generation sector. Implementation of the rule is currently stayed by order to the U.S. Supreme Court. If ultimately upheld, the CPP could have a material effect on MGE's operations. In July 2019, the EPA published a final rule which repeals the CPP and creates the replacement Affordable Clean Energy (ACE) rule to reduce greenhouse gas emissions from existing coal-fired EGUs. The ACE Rule will apply to Columbia and the Elm Road Units. MGE is currently evaluating how this rule may impact operations. Until the State of Wisconsin develops a plan that is accepted by the EPA, MGE will not be able to determine the final impact of the rule. MGE will continue to evaluate the rule and monitor ongoing and potential legal proceedings associated with the CPP and ACE rules.

Columbia: MGE will reduce further its obligation to pay certain capital expenditures (other than SCR-related expenditures) at Columbia in exchange for a proportional reduction in MGE's ownership in Columbia. By June 2020, MGE's ownership in Columbia is forecasted to be approximately 19%, a decrease of 3% from the 22% ownership interest held by MGE on January 1, 2016.

Future Generation - Riverside: In 2016, MGE entered into an agreement with WPL under which MGE may acquire up to 50 MW of capacity in a gas-fired generating plant being constructed by WPL at its Riverside Energy Center in Beloit, Wisconsin, during the five-year period following the in-service date of the plant. The plant is expected to be completed by early 2020. MGE has not yet determined whether it will exercise its option in the Riverside plant. A determination will be made based on a variety of factors in future years.

Future Generation – Utility Solar: In August 2019, MGE and WEPCO filed a joint application with the PSCW for the approval to acquire 150 MW of solar generating capacity for a solar project in Wisconsin, Badger Hollow Solar Farm II. MGE's ownership share of the project is expected to be 50 MW. If approved by the PSCW, construction of the project is expected to begin in 2020. MGE's share of the construction cost is expected to be approximately $65 million.

Debt Issuance: MGE committed to $50 million of long-term unsecured debt in August 2019. Funding occurred on November 5, 2019. The proceeds of the debt financing will be used to assist with additional capital expenditures, such as Two Creeks and Badger Hollow, maturing short-term debt, and other corporate obligations.

The following discussion is based on the business segments as discussed in Footnote 16 of the Notes to Consolidated Financial Statements in this Report.

Results of Operations

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

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

Three Months Ended September 30, 2019 and 2018

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

		Three Months Ended September 30,
(In millions)		2019		2018		$ Change
Electric revenues	$	120.6	$	119.2	$	1.4
Fuel for electric generation		(15.9)		(16.8)		0.9
Purchased power		(9.1)		(13.0)		3.9
Total Electric Margins		95.6		89.4		6.2
Gas revenues		17.4		18.4		(1.0)
Cost of gas sold		(3.1)		(4.9)		1.8
Total Gas Margins		14.3		13.5		0.8
Other operating revenues		0.2		0.2		-
Other operations and maintenance		(48.1)		(44.1)		(4.0)
Depreciation and amortization		(18.2)		(14.3)		(3.9)
Other general taxes		(5.1)		(4.9)		(0.2)
Operating Income	$	38.7	$	39.8	$	(1.1)

Operating income for the three months ended September 30, 2019, compared to the same period in the prior year primarily reflects the effects of the following factors:

A $1.4 million increase in electric revenue driven by the timing of deferred revenue collected in rates.

A $0.9 million decrease in fuel for electric generation driven by lower costs from the wind generation of Saratoga (construction was completed in February 2019).

A $3.9 million decrease in purchased power costs driven by increased internal generation and lower costs in the market.

A $1.0 million decrease in gas revenue driven by a decrease in gas retail sales.

A $1.8 million decrease in cost of gas sold driven by decreased gas sales.

A $4.0 million increase in other operations and maintenance. See consolidated operations and maintenance expenses section below.

A $3.9 million increase in depreciation and amortization expense driven by accelerated depreciation expense for specified electric assets as discussed in the consolidated depreciation expense section below.

Electric sales and revenues

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

		Revenues				Sales (kWh)
(In thousands, except cooling degree days)		Three Months Ended September 30,				Three Months Ended September 30,
		2019		2018	% Change	2019	2018	% Change
Residential	$	42,442	$	42,371	0.2 %	252,786	256,820	(1.6)%
Commercial		63,466		61,638	3.0 %	519,820	520,827	(0.2)%
Industrial		3,760		3,668	2.5 %	45,772	47,381	(3.4)%
Other-retail/municipal		9,543		9,431	1.2 %	99,055	106,953	(7.4)%
Total retail		119,211		117,108	1.8 %	917,433	931,981	(1.6)%
Sales to the market		1,163		1,505	(22.7)%	37,108	33,090	12.1 %
Other revenues		233		562	(58.5)%	-	-	- %
Total	$	120,607	$	119,175	1.2 %	954,541	965,071	(1.1)%
Cooling degree days (normal 486)						535	536	(0.2)%

Electric margin, a non-GAAP measure, increased $6.2 million for the three months ended September 30, 2019, compared to the same period in 2018, due to the following:

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(In millions)
Revenue subject to refund, net	$	4.9
Decreased fuel costs		4.1
Rate changes		(1.4)
Decrease in volume		(0.7)
Other		(0.7)
Total	$	6.2

Revenue subject to refund. For cost recovery mechanisms, any over-collection of the difference between actual costs incurred and the amount of costs collected from customers is recorded as a reduction of revenue in the period incurred.

oTax Act. MGE received a PSCW order in January 2018 to defer the over-collection of income tax expense collected in customer rates as a result of the Tax Act reduction in federal income tax rate to 21 percent. In September 2019, MGE returned $2.2 million to electric customers through bill credits related to the tax credit. The 2019 bill credit was deducted from revenues in previous years and held in a regulatory liability pending the refund to customers. As a result, the refund did not affect reported revenues in the current periods, although it did reduce cash and the corresponding regulatory liability. During the three months ended September 30, 2018, MGE recorded a $1.1 million reduction in retail electric revenues and recorded a corresponding regulatory liability. During the three months ended September 30, 2018, MGE returned $1.8 million to electric customers through bill credits related to the tax credit.

oFuel-related costs. MGE's fuel-related costs subject to refund in 2019 was $0.5 million. MGE's fuel-related costs subject to refund in 2018 was $2.0 million. Under fuel rules, MGE is required to defer electric fuel-related costs that fall outside a 2% cost tolerance band around the amount used in the most recent rate proceeding.

oTransmission. MGE's transmission costs subject to refund decreased revenue $0.1 million in 2019. In 2018, MGE recorded a $0.4 million increase in retail electric revenues.

oOperating Costs. MGE recognized revenue for electric plant operating costs subject to refund from previous years of $0.1 million in 2019. In 2018, MGE recorded a $0.9 million reduction in retail electric revenues primarily related to lower leased generation costs due to the reduction in tax rate.

Fuel costs. Fuel costs decreased during the three months ended September 30, 2019, primarily as a result of the commencement of commercial operations at the Saratoga Wind Farm in February 2019. Electrical generation at Saratoga reduced the need for purchased power and contributed to lower fuel costs in the current quarter.

Rate changes. Rates charged to retail customers during the three months ended September 30, 2019, were $1.4 million lower than those charged during the same period in the prior year.

In December 2018, the PSCW authorized MGE to decrease 2019 rates for electric retail customers by 2.24%.

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:

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		Revenues				Therms Delivered
(In thousands, except HDD and average rate per therm of retail customer)		Three Months Ended September 30,				Three Months Ended September 30,
		2019		2018	% Change	2019	2018	% Change
Residential	$	11,342	$	11,916	(4.8)%	5,707	5,694	0.2 %
Commercial/Industrial		4,825		5,570	(13.4)%	9,195	9,657	(4.8)%
Total retail		16,167		17,486	(7.5)%	14,902	15,351	(2.9)%
Gas transportation		1,126		829	35.8 %	15,514	15,784	(1.7)%
Other revenues		84		92	(8.7)%	-	-	- %
Total	$	17,377	$	18,407	(5.6)%	30,416	31,135	(2.3)%
Heating degree days (normal 154)						57	125	(54.4)%
Average rate per therm of
retail customer	$	1.085	$	1.139	(4.7)%

Gas margin, a non-GAAP measure, increased $0.8 million for the three months ended September 30, 2019, compared to the same period in 2018, due to the following:

(In millions)
Revenue subject to refund, net	$	0.5
Other		0.3
Total	$	0.8

Revenue subject to refund. For cost recovery mechanisms, any over-collection of the difference between actual costs incurred and the amount of costs collected from customers is recorded as a reduction of revenue in the period incurred.

oTax Act. MGE received a PSCW order in January 2018 to defer the over-collection of income tax expense collected in customer rates as a result of the Tax Act reduction in federal income tax rate to 21 percent. In September 2019, MGE returned $1.0 million to gas customers through bill credits related to the tax credit. The 2019 bill credit was deducted from revenues in previous years and held in a regulatory liability pending the refund to customers. As a result, the refund did not affect reported revenues in the current periods, although it did reduce cash and the corresponding regulatory liability. During the three months ended September 30, 2018, MGE recorded a $0.3 million reduction in retail gas revenues and recorded a corresponding regulatory liability. During the three months ended September 30, 2018, MGE returned $0.2 million to electric customers through bill credits related to the tax credit.

Consolidated operations and maintenance expenses

For the three months ended September 30, 2019, operations and maintenance expenses increased $4.0 million, compared to the same period in the prior year. The following contributed to the net change:

(In millions)
Increased administrative and general costs	$	2.8
Increased electric production expenses		0.8
Increased gas distribution expenses		0.3
Increased other costs		0.5
Decreased transmission costs		(0.4)
Total	$	4.0

Increased administrative and general costs are primarily related to increased technology costs associated with the multi-year Enterprise Forward project, which includes a new customer information system.

Consolidated depreciation expense

Electric depreciation expense increased $3.6 million and gas depreciation expense increased $0.3 million for the three months ended September 30, 2019, compared to the same period in the prior year. MGE accelerated depreciation for combustion turbines and Columbia Unit 1 in 2019, as approved in the December 2018 rate

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settlement, increasing electric depreciation expense compared to the prior period. Also approved in the December 2018 rate settlement were new depreciation rates for Columbia, further contributing 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. For both the three months ended September 30, 2019 and 2018, net income at the nonregulated energy operations segment was $5.1 million.

Transmission Investment Operations - MGE Energy

For the three months ended September 30, 2019 and 2018, other income at the transmission investment segment was $2.4 million and $1.6 million, respectively. 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. In the near term, it is expected that ATC Holdco will be pursuing transmission development opportunities that typically have long development and investment lead times before becoming operational. See Footnote 4 of the Notes to Consolidated Financial Statements in this Report and "Other Matters" below for additional information concerning ATC and summarized financial information regarding ATC.

Consolidated Income Taxes - MGE Energy and MGE

In 2019, the effective electric tax rate decreased as a result of a tax credit generated by the Saratoga Wind Farm. See Footnote 5 of the Notes to Consolidated Financial Statements in this Report for the effective tax rate reconciliation.

Noncontrolling Interest, Net of Tax - MGE

The noncontrolling interest, net of tax, reflects the accounting required for MGE Energy's interest in MGE Power Elm Road (the Elm Road Units) and MGE Power West Campus (WCCF). MGE Energy owns 100% of MGE Power Elm Road and MGE Power West Campus; however, due to the contractual agreements for these projects with MGE, the entities are considered VIEs with respect to MGE and their results are consolidated with those of MGE, the primary beneficiary of the VIEs. The following table shows MGE Energy's noncontrolling interest, net of tax, reflected on MGE's consolidated statement of income:

		Three Months Ended
		September 30,
(In millions)		2019		2018
MGE Power Elm Road	$	3.8	$	3.8
MGE Power West Campus		1.8		1.8

Nine Months Ended September 30, 2019 and 2018

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

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		Nine Months Ended September 30,
(In millions)		2019		2018		$ Change
Electric revenues	$	314.9	$	312.6	$	2.3
Fuel for electric generation		(40.2)		(43.9)		3.7
Purchased power		(31.0)		(43.0)		12.0
Total Electric Margins		243.7		225.7		18.0
Gas revenues		112.5		106.2		6.3
Cost of gas sold		(55.2)		(54.1)		(1.1)
Total Gas Margins		57.3		52.1		5.2
Other operating revenues		0.5		0.9		(0.4)
Other operations and maintenance		(144.0)		(132.0)		(12.0)
Depreciation and amortization		(53.4)		(41.8)		(11.6)
Other general taxes		(15.1)		(14.7)		(0.4)
Operating Income	$	89.0	$	90.2	$	(1.2)

Operating income for the nine months ended September 30, 2019, compared to the same period in the prior year primarily reflects the effects of the following factors:

A $2.3 million increase in electric revenue driven by timing of deferred revenue collected in rates.

A $3.7 million decrease in fuel for electric generation driven by lower costs from the wind generation of Saratoga (construction was completed in February 2019).

A $12.0 million decrease in purchased power costs driven by the purchase of the Forward Wind Energy Center in April 2018, which replaced an existing purchased power agreement and increased internal generation.

A $6.3 million increase in gas revenues reflecting higher customer demand resulting from colder weather in the first quarter and an increase in rates to cover infrastructure costs.

A $1.1 million increase in cost of gas sold driven by increased gas sales.

A $12.0 million increase in other operations and maintenance. See consolidated operations and maintenance expenses section below.

An $11.6 million increase in depreciation and amortization expense driven by accelerated depreciation expense for specified electric assets as discussed in the consolidated depreciation expense section below.

Electric sales and revenues

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

		Revenues				Sales (kWh)
(In thousands, except cooling degree days)		Nine Months Ended September 30,				Nine Months Ended September 30,
		2019		2018	% Change	2019	2018	% Change
Residential	$	107,772	$	107,847	(0.1)%	638,590	664,195	(3.9)%
Commercial		165,481		159,264	3.9 %	1,410,360	1,432,222	(1.5)%
Industrial		10,013		11,193	(10.5)%	131,195	136,485	(3.9)%
Other-retail/municipal		26,728		26,245	1.8 %	276,795	294,345	(6.0)%
Total retail		309,994		304,549	1.8 %	2,456,940	2,527,247	(2.8)%
Sales to the market		3,914		6,334	(38.2)%	110,246	151,586	(27.3)%
Other revenues		978		1,750	(44.1)%	-	-	- %
Total	$	314,886	$	312,633	0.7 %	2,567,186	2,678,833	(4.2)%
Cooling degree days (normal 673)						653	783	(16.6)%

Electric margin, a non-GAAP measure, increased $18.0 million for the nine months ended September 30, 2019, compared to the same period in 2018, due to the following:

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(In millions)
Revenue subject to refund, net	$	18.9
Decreased fuel costs		11.6
Rate changes		(6.2)
Decrease in volume		(4.4)
Other		(1.9)
Total	$	18.0

Revenue subject to refund. For cost recovery mechanisms, any over-collection of the difference between actual costs incurred and the amount of costs collected from customers is recorded as a reduction of revenue in the period incurred.

oTax Act. MGE received a PSCW order in January 2018 to defer the over-collection of income tax expense collected in customer rates as a result of the Tax Act reduction in federal income tax rate to 21 percent. In September 2019, MGE returned $2.2 million to electric customers through bill credits related to the tax credit. The 2019 bill credit was deducted from revenues in previous years and held in a regulatory liability pending the refund to customers. As a result, the refund did not affect reported revenues in the current periods, although it did reduce cash and the corresponding regulatory liability. During the nine months ended September 30, 2019 and 2018, MGE recorded a $0.2 million and $3.2 million reduction in retail electric revenues and recorded a corresponding regulatory liability, respectively. During the nine months ended September 30, 2018, MGE returned $4.8 million to electric customers through bill credits related to the tax credit.

oFuel-related costs. MGE's fuel-related costs subject to refund in 2019 and 2018 was $0.5 million and $7.2 million, respectively. Under fuel rules, MGE is required to defer electric fuel-related costs that fall outside a 2% cost tolerance band around the amount used in the most recent rate proceeding.

oTransmission. MGE's transmission costs subject to refund decreased revenue $1.5 million in 2019. In 2018, MGE recorded a $1.8 million reduction in retail electric revenues primarily related to a one-time refund received in June 2018.

oOperating Costs. MGE recognized revenue for electric plant operating costs subject to refund from previous years of $0.9 million in 2019. In 2018, MGE recorded a reduction of $3.2 million in retail electric revenues primarily related to lower leased generation costs due to the reduction in tax rate.

Fuel costs. Fuel costs decreased during the nine months ended September 30, 2019, primarily as a result of a reduction in purchased power. The purchase of the Forward Wind Energy Center in April 2018 replaced an existing purchase power agreement that was previously recorded as purchased power expense in fuel costs. The commencement of commercial operations at the Saratoga Wind Farm in February 2019 further decreased the need for purchased power contributing to the reduction in fuel costs in the current year.

Rate changes. Rates charged to retail customers during the nine months ended September 30, 2019, were $6.2 million lower than those charged during the same period in the prior year.

In December 2018, the PSCW authorized MGE to decrease 2019 rates for electric retail customers by 2.24%.

Volume. During the nine months ended September 30, 2019, there was a 3.9% decrease in residential sales volumes compared to the same period in the prior year driven by less favorable weather conditions.

Other. During the nine months ended September 30, 2019, other items affecting electric operating revenues decreased $1.9 million primarily attributable to adjustments to revenue and a decrease in demand charges. MGE leases electric generating capacity from MGE Power Elm Road. MGE collects in rates the lease payments associated with the electric generating capacity as authorized by the PSCW. Any differential between estimated lease payments collected in rates and actual lease payments paid to MGE Power Elm Road are included in other revenues.

Gas deliveries and revenues

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

		Revenues				Therms Delivered
(In thousands, except HDD and average rate per therm of retail customer)		Nine Months Ended September 30,				Nine Months Ended September 30,
		2019		2018	% Change	2019	2018	% Change
Residential	$	67,659	$	64,087	5.6 %	74,769	70,750	5.7 %
Commercial/Industrial		40,833		38,728	5.4 %	70,255	67,613	3.9 %
Total retail		108,492		102,815	5.5 %	145,024	138,363	4.8 %
Gas transportation		3,756		3,018	24.5 %	54,129	54,259	(0.2)%
Other revenues		299		319	(6.3)%	-	-	- %
Total	$	112,547	$	106,152	6.0 %	199,153	192,622	3.4 %
Heating degree days (normal 4,471)						4,777	4,650	2.7 %
Average rate per therm of
retail customer	$	0.748	$	0.743	0.7 %

Gas margin, a non-GAAP measure, increased $5.2 million for the nine months ended September 30, 2019, compared to the same period in 2018, due to the following:

(In millions)
Revenue subject to refund, net	$	2.4
Increase in volume		1.0
Rate changes		0.9
Other		0.9
Total	$	5.2

Revenue subject to refund. For cost recovery mechanisms, any over-collection of the difference between actual costs incurred and the amount of costs collected from customers is recorded as a reduction of revenue in the period incurred.

oTax Act. MGE received a PSCW order in January 2018 to defer the over-collection of income tax expense collected in customer rates as a result of the Tax Act reduction in federal income tax rate to 21 percent. In September 2019, MGE returned $1.0 million to gas customers through bill credits related to the tax credit. The 2019 bill credit was deducted from revenues in previous years and held in a regulatory liability pending the refund to customers. As a result, the refund did not affect reported revenues in the current periods, although it did reduce cash and the corresponding regulatory liability. During the nine months ended September 30, 2019 and 2018, MGE recorded a $0.1 million and a $1.3 million reduction in retail gas revenues and recorded a corresponding regulatory liability, respectively. During the nine months ended September 30, 2018, MGE returned $1.1 million to gas customers through bill credits related to the tax credit.

Volume. For the nine months ended September 30, 2019, retail gas deliveries increased 4.8% compared to the same period in the prior year primarily related to customer growth and more favorable weather conditions in the current year.

Rate changes. In December 2018, the PSCW authorized MGE to increase 2019 rates for retail gas customers by 1.06%.

Other. During the nine months ended September 30, 2019, other items affecting gas operating revenues increased $0.9 million primarily attributable to an increase in fixed charges as a result of an increase in customers.

Consolidated operations and maintenance expenses

For the nine months ended September 30, 2019, operations and maintenance expenses increased $12.0 million, compared to the same period in the prior year. The following contributed to the net change:

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(In millions)
Increased administrative and general costs	$	6.2
Increased electric production expenses		2.3
Increased gas distribution expenses		1.3
Increased customer accounts costs		1.0
Increased other costs		0.7
Increased transmission costs		0.5
Total	$	12.0

Increased administrative and general costs and customer account costs are primarily related to increased technology costs associated with the multi-year Enterprise Forward project, which includes a new customer information system. In addition, higher administrative and general costs are related to an increase in stock price driving up the costs associated with the performance unit awards. See Footnote 8 of the Notes to Consolidated Financial Statements in this Report for additional information on performance unit awards.

Increased electric production expenses are primarily related to increased operations and maintenance costs at the Elm Road Units and Forward Wind facility.

Increased gas distribution expenses are primarily related to increased costs for maintenance on equipment and locator services.

Consolidated depreciation expense

Electric depreciation expense increased $10.5 million and gas depreciation expense increased $1.1 million for the nine months ended September 30, 2019, compared to the same period in the prior year. MGE accelerated depreciation for combustion turbines and Columbia Unit 1 in 2019, as approved in the December 2018 rate settlement, increasing electric depreciation expense compared to the prior period. Also approved in the December 2018 rate settlement were new depreciation rates for Columbia, further contributing 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. For both the nine months ended September 30, 2019 and 2018, net income at the nonregulated energy operations segment was $15.2 million.

Transmission Investment Operations - MGE Energy

For the nine months ended September 30, 2019 and 2018, other income at the transmission investment segment was $6.8 million and $5.9 million, respectively. 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. In the near term, it is expected that ATC Holdco will be pursuing transmission development opportunities that typically have long development and investment lead times before becoming operational. See Footnote 4 of the Notes to Consolidated Financial Statements in this Report and "Other Matters" below for additional information concerning ATC and summarized financial information regarding ATC.

Consolidated Income Taxes - MGE Energy and MGE

In 2019, the effective electric tax rate decreased as a result of a tax credit generated by the Saratoga Wind Farm. See Footnote 5 of the Notes to Consolidated Financial Statements in this Report for the effective tax rate reconciliation.

Noncontrolling Interest, Net of Tax - MGE

The noncontrolling interest, net of tax, reflects the accounting required for MGE Energy's interest in MGE Power Elm Road (the Elm Road Units) and MGE Power West Campus (WCCF). MGE Energy owns 100% of MGE Power Elm

48

Road and MGE Power West Campus; however, due to the contractual agreements for these projects with MGE, the entities are considered VIEs with respect to MGE and their results are consolidated with those of MGE, the primary beneficiary of the VIEs. The following table shows MGE Energy's noncontrolling interest, net of tax, reflected on MGE's consolidated statement of income:

		Nine Months Ended
		September 30,
(In millions)		2019		2018
MGE Power Elm Road	$	11.3	$	11.6
MGE Power West Campus		5.4		5.3

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, 2019, except as noted below. Further discussion of the contractual obligations and commercial commitments is included in Footnote 17 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 MGE Energy's and MGE's 2018 Annual Report on Form 10-K.

Purchase Contracts - MGE Energy and MGE

See items c. and d. within Footnote 9 of Notes to Consolidated Financial Statements in this Report for a description of commitments as of September 30, 2019, 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 and the solar farm construction and operating contracts.

Other Commitments - MGE Energy

In September 2019, MGE Energy entered a subscription agreement to invest in a nonpublic venture capital fund. From time to time, the fund makes capital calls to its investors. MGE Energy has committed to contribute $10 million in capital for such capital calls. The timing of these infusions is dependent on the needs of the investee and is therefore uncertain at this time.

Long-term Debt - MGE Energy and MGE

MGE committed to $50 million of long-term unsecured debt in August 2019. Funding occurred on November 5, 2019. The proceeds of the debt financing will be used to assist with capital expenditures, maturing short-term debt, and other corporate obligations. See Footnote 7 of the Notes to Consolidated Financial Statements in this Report for further discussion of these debt issuances.

Liquidity and Capital Resources

MGE Energy and MGE have adequate liquidity to fund 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. 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 MGE Energy's and MGE's 2018 Annual Report on Form 10-K for information regarding MGE Energy's and MGE's credit facilities.

Cash Flows

The following summarizes cash flows for MGE Energy and MGE during the nine months ended September 30, 2019 and 2018:

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		MGE Energy				MGE
(In thousands)		2019		2018		2019		2018
Cash provided by (used for):
Operating activities	$	111,702	$	138,432	$	109,020	$	135,027
Investing activities		(134,531)		(153,434)		(128,866)		(149,681)
Financing activities		1,142		37,949		19,962		53,011

Cash Provided by Operating Activities

MGE Energy

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

Cash provided by operating activities for the nine months ended September 30, 2019, was $111.7 million, a decrease of $26.7 million when compared to the same period in the prior year.

MGE Energy's net income increased $2.4 million for the nine months ended September 30, 2019, when compared to the same period in the prior year.

MGE Energy's federal and state taxes paid increased $3.3 million for the nine months ended September 30, 2019, when compared to the same period in the prior year.

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

Working capital accounts (excluding prepaid and accrued taxes) resulted in $17.2 million in cash provided by operating activities for the nine months ended September 30, 2018, primarily due to decreased unbilled revenues and increased other current liabilities.

An increase in hosted software asset expenditures resulted in additional $4.6 million in cash used for operating activities for the nine months ended September 30, 2019, when compared to the prior year. This amount represents a decrease of $0.6 million of cash used when compared to the prior year.

MGE

Cash provided by operating activities for the nine months ended September 30, 2019, was $109.0 million, a decrease of $26.0 million when compared to the same period in the prior year.

Net income increased $2.0 million for the nine months ended September 30, 2019, when compared to the same period in the prior year.

MGE's federal and state taxes paid increased $3.3 million for the nine months ended September 30, 2019, when compared to the same period in the prior year.

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

Working capital accounts (excluding prepaid and accrued taxes) resulted in $19.3 million in cash provided by operating activities for the nine months ended September 30, 2018, primarily due to decreased unbilled revenues

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and increased other current liabilities.

An increase in hosted software asset expenditures resulted in additional $4.6 million in cash used for operating activities for the nine months ended September 30, 2019, when compared to the prior year. This amount represents a decrease of $0.6 million of cash used when compared to the prior year.

Cash Used for Investing Activities

MGE Energy

MGE Energy's cash used for investing activities decreased $18.9 million for the nine months ended September 30, 2019, when compared to the same period in the prior year.

Capital expenditures for the nine months ended September 30, 2019, were $128.4 million. This amount represents a decrease of $20.6 million from the expenditures made in the same period in the prior year. This decrease primarily reflects expenditures on the construction of the Saratoga wind project in the prior year. 2019 capital expenditures include $48.2 million related to the Two Creeks and Badger Hollow solar construction projects. Total cost of the two projects is expected to be approximately $130 million. The projects are anticipated to be completed by the end of 2020.

MGE

MGE's cash used for investing activities decreased $20.8 million for the nine months ended September 30, 2019, when compared to the same period in the prior year.

Capital expenditures for the nine months ended September 30, 2019, were $128.4 million. This amount represents a decrease of $20.6 million from the expenditures made in the same period in the prior year. This decrease primarily reflects expenditures on the construction of the Saratoga wind project in the prior year. 2019 capital expenditures include $48.2 million related to the Two Creeks and Badger Hollow solar construction projects. Total cost of the two projects is expected to be approximately $130 million. The projects are anticipated to be completed by the end of 2020.

Cash Provided by Financing Activities

MGE Energy

Cash provided by MGE Energy's financing activities was $1.1 million for the nine months ended September 30, 2019, compared to $37.9 million of provided by for MGE Energy's financing activities for the same period in the prior year.

For the nine months ended September 30, 2019, dividends paid were $35.6 million compared to $34.1 million in the prior year. This increase was a result of a higher dividend per share ($1.028 vs. $0.983).

During the nine months ended September 30, 2018, MGE issued $100.0 million of senior unsecured notes, which was used to refinance $20.0 million of maturing long-term notes and assist with financing additional capital expenditures. The increase in long-term debt primarily reflects expenditures on the construction of the Saratoga wind project.

For the nine months ended September 30, 2019, net short-term debt borrowings were $41.5 million compared to net short-term debt repayments of $4.0 million for the nine months ended September 30, 2018.

MGE

During the nine months ended September 30, 2019, cash provided by MGE's financing activities was $20.0 million, compared to $53.0 million of cash provided by MGE's financing activities for the same period in the prior year.

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Distributions to parent from noncontrolling interest, which represent distributions from MGE Power Elm Road and MGE Power West Campus to MGE Energy, were $17.0 million for the nine months ended September 30, 2019, compared to $19.0 million in the prior year.

During the nine months ended September 30, 2018, MGE issued $100.0 million of senior unsecured notes, which was used to refinance $20.0 million of maturing long-term notes and assist with financing additional capital expenditures. The increase in long-term debt primarily reflects expenditures on the construction of the Saratoga wind project.

For the nine months ended September 30, 2019, net short-term debt borrowings were $41.5 million compared to net short-term debt repayments of $4.0 million for the nine months ended September 30, 2018.

Capitalization Ratios

MGE Energy's capitalization ratios were as follows:

	MGE Energy
	September 30, 2019	December 31, 2018
Common shareholders' equity	60.8 %	61.5 %
Long-term debt(a)	35.3 %	37.5 %
Short-term debt	3.9 %	1.0 %

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

MGE Energy's and MGE's Capital Requirements

MGE Energy's and MGE's liquidity are primarily affected by their capital expenditure requirements. During the nine months ended September 30, 2019, capital expenditures for MGE Energy and MGE totaled $128.4 million, which included $126.2 million of utility capital expenditures. Included in the utility capital expenditures are costs associated with the Two Creeks and Badger Hollow solar construction projects.

Credit Ratings

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

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

Environmental Matters

The following discussion is limited to updates or developments in environmental matters that occurred during the nine months ended September 30, 2019. Further discussion of environmental matters is included in MGE Energy's and MGE's 2018 Annual Report on Form 10-K and Footnote 9.a. of Notes to Consolidated Financial Statements in this Report.

EPA Affordable Clean Energy (ACE) Rule and Associated Rules Under Section 111(d) of the Clean Air Act (CAA)

In July 2019, the EPA published a final rule which repeals the CPP and creates the replacement Affordable Clean Energy (ACE) rule to reduce greenhouse gas emissions from existing coal-fired EGUs. The ACE rule will apply to Columbia and the Elm Road Units. MGE is currently evaluating how this rule may impact operations. Until the State of Wisconsin develops a plan that is accepted by the EPA, MGE will not be able to determine the final impact of the rule. MGE will continue to evaluate the rule and monitor ongoing and potential legal proceedings associated with the CPP and ACE rules.

U.S. Court of Appeals for the D.C. Circuit’s Remand of CSAPR

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The EPA's final update to its Cross State Air Pollution Rule (CSAPR), which regulates interstate transport of the air pollutants sulfuric oxide (SO₂) and nitrogen oxides (NO_x), has been in place since 2016 and MGE has been complying with the provisions of the rule.

CSAPR has been subject to ongoing legal challenges. In September 2019, the U.S. Court of Appeals D.C. Circuit upheld the challenge to the CSAPR's approach to the Clean Air Act's "Good Neighbor Provision" and remanded the rule to the EPA without vacatur. The court indicated that the EPA's leniency on the upwind states by not holding them to the same deadlines as downwind states effectively causes downwind states to miss attainment deadlines or over comply to meet deadlines. No deadline has been set for the EPA to revise the rule. Wisconsin is considered an upwind state under CSAPR and is potentially impacted by rules that the EPA will develop to address this remand. MGE will continue to monitor developments to determine if our operations will be impacted by any rule revisions.

Other Matters

ATC

In 2013, several parties filed a complaint with the FERC seeking to reduce the base return on equity (ROE) used by MISO transmission owners, including ATC, "due to changes in the capital markets." The complaint alleged that the MISO ROE should not exceed 9.15%, the equity components of hypothetical capital structures should be restricted to 50%, and the relevant incentive ROE adders should be discontinued. At the time, MISO's base ROE was 12.38% and ATC's base ROE was 12.2%. On September 28, 2016, FERC issued an order on the 2013 complaint, for the period November 2013 through February 2015, reducing the base ROE to 10.32%. This base ROE also became effective September 28, 2016, and will apply to future periods until FERC rules in the second complaint described below, at which time the base ROE ordered by FERC in the second complaint will prospectively become the authorized base ROE.

In February 2015, a second complaint was filed for the period February 2015 through May 2015 with the FERC requesting a reduction in the base ROE used by MISO transmission owners, including ATC, to 8.67%, with a refund effective date retroactive to the filing date of the complaint. In June 2016, an administrative law judge issued an initial decision for the second complaint that would reduce the transmission owner's base ROE to 9.7%. The initial decision will be reviewed by FERC. It is anticipated FERC will issue an order on this issue in 2019.

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

We derived approximately 6.8% and 6.3% of our net income for the nine months ended September 30, 2019 and 2018, respectively, from our investment in ATC. Any change to ATC's ROE could result in lower equity earnings and distributions from ATC in the future.

Adoption of Accounting Principles and Recently Issued Accounting Pronouncements

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

Item 3. Quantitative and Qualitative Disclosures About Market Risk.

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

Commodity Price Risk

MGE has commodity price risk exposure with respect to the price of natural gas, electricity, coal, emission credits, and oil. MGE's electric operations burn natural gas in several of its peaking power plants and, in many cases, the cost of purchased power is tied to the cost of natural gas. MGE employs established policies and procedures to

53

reduce the market risks associated with changing commodity prices. MGE's commodity risks are somewhat mitigated by the current ratemaking process in place for recovering electric fuel cost, purchased energy costs, and the cost of natural gas.

MGE's electric fuel costs are subject to fuel rules established by the PSCW. The fuel rules require the PSCW and Wisconsin utilities to defer electric fuel-related costs that fall outside a symmetrical cost tolerance band. Any over/under recovery of the actual costs in a year outside of the symmetrical cost tolerance band is determined in the following year and is then reflected in future billings to electric retail customers. Under the electric fuel rules, MGE is required to defer the benefit of lower costs if the actual electric fuel costs fall outside the lower end of the range and is required to defer costs, less any excess revenues, if the actual electric fuel costs exceed the upper end of the range. Excess revenues are defined as revenues in the year in question that provide MGE with a greater return on common equity than authorized by the PSCW in MGE's latest rate order. The range is defined by the PSCW and has been modified throughout the years based on market conditions and other relevant factors. Currently, MGE is subject to a plus or minus 2% range. MGE assumes the risks and benefits of variances that are within the cost tolerance band. For 2019, fuel and purchased power costs included in MGE's fuel monitoring level rates are $77.3 million. See Footnote 10.b. of the Notes to Consolidated Financial Statements in this Report for additional information.

MGE recovers the cost of natural gas in its gas utility segment through the purchased gas adjustment clause (PGA). Under the PGA, MGE is able to pass through to its gas customers the cost of gas.

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

MGE has financial gas and electric commodity contracts to hedge commodity price risk in the gas and electric utility segments. These contracts are primarily comprised of exchange-traded option and future contracts. MGE also holds financial transmission rights (FTRs), which are used to hedge the risk of increased transmission congestion charges. As of September 30, 2019, the cost basis of these instruments exceeded their fair value by $0.2 million. Under the PGA clause and electric fuel rules, MGE may include the costs and benefits of the aforementioned fuel price risk management tools in the costs of fuel (natural gas or power). Because these costs/benefits are recoverable, the related unrealized loss/gain has been deferred on the consolidated balance sheets as a regulatory asset/liability.

MGE has also entered into a purchased power agreement that provides MGE with firm capacity and energy that began on June 1, 2012, and ends on May 31, 2022 (the "base term"). The agreement also allows MGE an option to extend the contract after the base term. The agreement is considered a derivative contract and is recognized at its fair value on the consolidated balance sheets. However, the derivative qualifies for regulatory deferral and is recognized with a corresponding regulatory asset or liability depending on whether the fair value is in a loss or gain position. The fair value of the contract as of September 30, 2019, reflects a loss position of $29.0 million.

Interest Rate Risk

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

Equity Price Risk - Pension-Related Assets

MGE currently funds its liabilities related to employee benefits through trust funds. These funds, which include investments in debt and equity securities, are managed by various investment managers. Changes in market value of these investments can have an impact on the future expenses related to these liabilities.

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Credit Risk - Counterparty

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

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

Additionally, if a counterparty were to default and MGE were to liquidate all contracts with that entity, MGE's credit loss would include the loss in value of mark-to-market contracts; the amount owed for settled transactions; and additional payments, if any, to settle unrealized losses. As of September 30, 2019, no counterparties have defaulted.

MGE is obligated to provide service to all electric and gas customers within its respective franchised territories. MGE's franchised electric territory includes a 264 square-mile area in Dane County, Wisconsin, and MGE's franchised gas territory includes a service area covering 1,684 square miles in Wisconsin. Based on results for the year ended December 31, 2018, no one customer constituted more than 10% of total operating revenues for MGE Energy and MGE. Credit risk for electric and gas is managed by MGE's credit and collection policies, which are consistent with state regulatory requirements.

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

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Item 4. Controls and Procedures.

During the third quarter of 2019, 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. 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, 2019, 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, 2019, there were no changes in either registrant's internal controls over financial reporting that materially affected, or are reasonably likely to affect materially, that registrant's internal control over financial reporting.

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PART II. OTHER INFORMATION.

Item 1. Legal Proceedings.

MGE Energy and MGE

MGE Energy and its subsidiaries, including MGE, from time to time are involved in various legal proceedings that are handled and defended in the ordinary course of business.

See Footnote 9.a. and 9.b. of Notes to Consolidated Financial Statements in this Report for more information.

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

Issuer Purchases of Equity Securities

Period	Total Number of Shares Purchased		Average Price Paid per Share	Total Number of Shares Purchased as Part of Publicly Announced Plans or Programs(a)	Maximum number (or Approximate Dollar Value) of Shares That May Yet Be Purchased Under the Plans or Programs(a)
July 1-31, 2019	6,556	$	73.42	-	-
August 1-31, 2019	8,676		76.90	-	-
September 1-30, 2019	36,436		75.41	-	-
Total	51,668	$	75.41	-	-

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

Item 4. Mine Safety Disclosures.

Not applicable to MGE Energy and MGE.

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Item 6. Exhibits.

Ex. No.		Exhibit Description
31.1	*	Certifications Pursuant to Rule 13a-14(a) and 15d-14(a) of the Securities Exchange Act of 1934 filed by Jeffrey M. Keebler for MGE Energy, Inc.
31.2	*	Certifications Pursuant to Rule 13a-14(a) and 15d-14(a) of the Securities Exchange Act of 1934 filed by Jeffrey C. Newman 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 Jeffrey C. Newman 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 Jeffrey C. Newman 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 Jeffrey C. Newman 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
*		Filed herewith.
**		Furnished herewith.

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Signatures - MGE Energy, Inc.

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

	MGE ENERGY, INC.
Date: November 6, 2019	/s/ Jeffrey M. Keebler
	Jeffrey M. Keebler Chairman, President and Chief Executive Officer (Duly Authorized Officer)
Date: November 6, 2019	/s/ Jeffrey C. Newman
	Jeffrey C. Newman Executive Vice President, Chief Financial Officer, Secretary and Treasurer (Chief Financial and Accounting Officer)

59

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 COMPANY
Date: November 6, 2019	/s/ Jeffrey M. Keebler
	Jeffrey M. Keebler Chairman, President and Chief Executive Officer (Duly Authorized Officer)
Date: November 6, 2019	/s/ Jeffrey C. Newman
	Jeffrey C. Newman Executive Vice President, Chief Financial Officer, Secretary and Treasurer (Chief Financial and Accounting Officer)

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EX-31

 

EXHIBIT 31.1

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

I, Jeffrey M. Keebler, certify that:

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

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

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

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

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

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

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

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

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

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

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

1

/s/ Jeffrey M. Keebler

Jeffrey M. Keebler

Chairman, President and Chief Executive Officer

Date: November 6, 2019

2

EX-31

 

EXHIBIT 31.2

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

I, Jeffrey C. Newman, certify that:

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

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

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

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

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

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

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

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

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

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

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

1

/s/ Jeffrey C. Newman

Jeffrey C. Newman

Executive Vice President, Chief Financial Officer,

Secretary and Treasurer

Date: November 6, 2019

2

EX-31

 

EXHIBIT 31.3

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

I, Jeffrey M. Keebler, certify that:

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

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

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

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

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

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

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

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

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

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

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

1

/s/ Jeffrey M. Keebler

Jeffrey M. Keebler

Chairman, President and Chief Executive Officer

Date: November 6, 2019

2

EX-31

 

EXHIBIT 31.4

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

I, Jeffrey C. Newman, certify that:

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

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

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

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

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

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

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

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

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

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

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

1

/s/ Jeffrey C. Newman

Jeffrey C. Newman

Executive Vice President, Chief Financial Officer,

Secretary and Treasurer

Date: November 6, 2019

2

EX-32

 

EXHIBIT 32.1

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

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

In connection with the quarterly report on Form 10-Q of MGE Energy, Inc. (the "Company"), for the period ended September 30, 2019, as filed with the Securities and Exchange Commission on the date hereof ("the Report"), I, Jeffrey M. Keebler, Chief Executive Officer of the Company, certify, pursuant to 18 U.S.C. Section 1350, as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002, that:

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

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

/s/ Jeffrey M. Keebler

Jeffrey M. Keebler

Chairman, President and Chief Executive Officer

Date: November 6, 2019

1

EX-32

 

EXHIBIT 32.2

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

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

In connection with the quarterly report on Form 10-Q of MGE Energy, Inc. (the "Company"), for the period ended September 30, 2019, as filed with the Securities and Exchange Commission on the date hereof ("the Report"), I, Jeffrey C. Newman, Chief Financial Officer of the Company, certify, pursuant to 18 U.S.C. Section 1350, as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002, that:

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

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

/s/ Jeffrey C. Newman

Jeffrey C. Newman

Executive Vice President, Chief Financial Officer,

Secretary and Treasurer

Date: November 6, 2019

1

EX-32

 

EXHIBIT 32.3

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

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

In connection with the quarterly report on Form 10-Q of Madison Gas and Electric Company (the "Company"), for the period ended September 30, 2019, as filed with the Securities and Exchange Commission on the date hereof ("the Report"), I, Jeffrey M. Keebler, Chief Executive Officer of the Company, certify, pursuant to 18 U.S.C. Section 1350, as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002, that:

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

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

/s/ Jeffrey M. Keebler

Jeffrey M. Keebler

Chairman, President and Chief Executive Officer

Date: November 6, 2019

1

EX-32

 

EXHIBIT 32.4

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

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

In connection with the quarterly report on Form 10-Q of Madison Gas and Electric Company (the "Company"), for the period ended September 30, 2019, as filed with the Securities and Exchange Commission on the date hereof ("the Report"), I, Jeffrey C. Newman, Chief Financial Officer of the Company, certify, pursuant to 18 U.S.C. Section 1350, as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002, that:

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

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

/s/ Jeffrey C. Newman

Jeffrey C. Newman

Executive Vice President, Chief Financial Officer,

Secretary and Treasurer

Date: November 6, 2019

1

XML

Commitments and Contingencies (Details-1)	Sep. 30, 2019 MW
Minimum [Member]
EPA Greenhouse Gas Reduction Guidelines
Standard of Performance Plan For EGUs Over Threshold	25

XML

Taxes (Details) - USD ($) $ in Millions		3 Months Ended			9 Months Ended
		Sep. 30, 2019		Sep. 30, 2018	Sep. 30, 2019		Sep. 30, 2018
Reconciliation of tax provision to statutory federal income tax rate [Abstract]
Statutory federal income tax rate		21.00%		21.00%	21.00%		21.00%
State income taxes, net of federal benefit		6.30%		6.30%	6.30%		6.30%
Amortized investment tax credits		(0.10%)		(0.10%)	(0.10%)		(0.10%)
Credit for electricity from wind energy		(4.80%)	[1]	(0.30%)	(5.60%)	[1]	(0.30%)
AFUDC equity, net		(0.40%)		(0.60%)	(0.30%)		(0.80%)
Amortization of utility excess deferred tax - tax reform	[2]	(1.90%)		(1.80%)	(2.20%)		(1.80%)
Other, net, individually significant		(0.50%)		0.00%	0.10%		0.00%
Effective income tax rate		19.60%		24.50%	19.20%		24.30%
Excess Deferred Taxes, Tax Cuts And Jobs Act [Member]
Effects Of The Tax Cuts And Jobs Act [Abstract]
Excess deferred tax - Income statement effect		$ 0.6		$ 0.5	$ 1.7		$ 1.4
MGE [Member]
Reconciliation of tax provision to statutory federal income tax rate [Abstract]
Statutory federal income tax rate		21.00%		21.00%	21.00%		21.00%
State income taxes, net of federal benefit		6.20%		6.20%	6.20%		6.20%
Amortized investment tax credits		(0.10%)		(0.10%)	(0.10%)		(0.10%)
Credit for electricity from wind energy		(5.20%)	[1]	(0.20%)	(6.10%)	[1]	(0.30%)
AFUDC equity, net		(0.40%)		(0.60%)	(0.30%)		(0.80%)
Amortization of utility excess deferred tax - tax reform	[2]	(2.10%)		(1.80%)	(2.40%)		(2.00%)
Other, net, individually significant		(0.50%)		0.10%	0.10%		0.10%
Effective income tax rate		18.90%		24.60%	18.40%		24.10%

[1] Saratoga Wind Farm became operational in February 2019.

[2] Included are impacts of the Tax Cuts and Jobs Act for the regulated utility for excess deferred taxes recognized using a normalization method of accounting. For the three and nine months ended September 30, 2019, MGE recognized $0.6 million and $1.7 million, respectively, compared to $0.5 million and $1.4 million for the comparable periods in 2018. The amount and timing of the cash impacts will depend on the period over which certain income tax benefits are provided to customers, as determined by the PSCW.

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Leases (Details-5) $ in Thousands	Sep. 30, 2019 USD ($)
Finance Lease Liabilities Payments Due [Abstract]
2019	$ 539
2020	1,644
2021	1,428
2022	1,309
2023	1,228
Thereafter	41,317
Undiscounted finance lease liability	47,465
Less: Present value discount	(28,876)
Finance lease liability	18,589
Operating Lease Liabilities Payments Due [Abstract]
2019	37
2020	152
2021	86
2022	33
2023	2
Thereafter	52
Undiscounted operating lease liability	362
Less: Present value discount	(34)
Operating lease liability	$ 328

XML

Asset Retirement Obligation (Details) $ in Millions	9 Months Ended
	Sep. 30, 2019 USD ($)
Saratoga Wind Farm [Member]
Asset Retirement Obligations [Roll Forward]
Saratoga Wind Asset Retirement Obligation	$ 1.5

XML

Fair Value of Financial Instruments

9 Months Ended

Sep. 30, 2019

Fair Value Disclosures [Abstract]

Fair Value of Financial Instruments

Fair Value of Financial Instruments - MGE Energy and MGE.

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

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

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

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

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

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

The estimated fair market value offinancial instruments are as follows:

		September 30, 2019				December 31, 2018
(In thousands)		Carrying Amount		Fair Value		Carrying Amount		Fair Value
MGE Energy
Assets:
Cash and cash equivalents	$	61,112	$	61,112	$	83,102	$	83,102
Liabilities:
Short-term debt - commercial paper		54,500		54,500		13,000		13,000
Long-term debt(a)		499,027		578,229		502,431		518,811
MGE
Assets:
Cash and cash equivalents	$	4,656	$	4,656	$	4,843	$	4,843
Liabilities:
Short-term debt - commercial paper		54,500		54,500		13,000		13,000
Long-term debt(a)		499,027		578,229		502,431		518,811

(a) Includes long-term debt due within one year. Excludes debt issuance costs and unamortized discount of $4.2million and $4.5million as of September 30, 2019, and December 31, 2018, respectively.

b.Recurring Fair Value Measurements.

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

		Fair Value as of September 30, 2019
(In thousands)		Total		Level 1		Level 2		Level 3
MGE Energy
Assets:
Derivatives, net(b)	$	1,093	$	525	$	-	$	568
Exchange-traded investments		1,001		1,001		-		-
Total Assets	$	2,094	$	1,526	$	-	$	568
Liabilities:
Derivatives, net	$	30,275	$	687	$	-	$	29,588
Deferred compensation		3,025		-		3,025		-
Total Liabilities	$	33,300	$	687	$	3,025	$	29,588
MGE
Assets:
Derivatives, net(b)	$	1,093	$	525	$	-	$	568
Exchange-traded investments		178		178		-		-
Total Assets	$	1,271	$	703	$	-	$	568
Liabilities:
Derivatives, net	$	30,275	$	687	$	-	$	29,588
Deferred compensation		3,025		-		3,025		-
Total Liabilities	$	33,300	$	687	$	3,025	$	29,588

		Fair Value as of December 31, 2018
(In thousands)		Total		Level 1		Level 2		Level 3
MGE Energy
Assets:
Derivatives, net	$	1,042	$	296	$	-	$	746
Exchange-traded investments		848		848		-		-
Total Assets	$	1,890	$	1,144	$	-	$	746
Liabilities:
Derivatives, net	$	32,872	$	124	$	-	$	32,748
Deferred compensation		3,078		-		3,078		-
Total Liabilities	$	35,950	$	124	$	3,078	$	32,748
MGE
Assets:
Derivatives, net	$	1,042	$	296	$	-	$	746
Exchange-traded investments		43		43		-		-
Total Assets	$	1,085	$	339	$	-	$	746
Liabilities:
Derivatives, net	$	32,872	$	124	$	-	$	32,748
Deferred compensation		3,078		-		3,078		-
Total Liabilities	$	35,950	$	124	$	3,078	$	32,748

(b) These amounts are shown gross and exclude $0.7 million of collateral that was posted against derivative positions with counterparties as of September 30, 2019.

No transfers were made in or out of Level 1 or Level 2 for the nine months ended September 30, 2019.

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

The deferred compensation plan allows participants to defer certain cash compensation into a notional investment account. These amounts are included within other deferred liabilities in the consolidated balance sheets. The notional investments earn interest based upon the semiannual rate of U.S. Treasury Bills having a 26-week maturity increased by 1% compounded monthly with a minimum annual rate of 7%, compounded monthly. The notional investments are based upon observable market data, however, since the deferred compensation obligations themselves are not exchanged in an active market, they are classified as Level 2.

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

The purchased power agreement (see Footnote 11) was valued using an internally-developed pricing model and therefore is classified as Level 3. The model projects future market energy prices and compares those prices to the projected power costs to be incurred under the contract. Inputs to the model require significant management judgment and estimation. Future energy prices are based on a forward power pricing curve using exchange-traded contracts in the electric futures market. A basis adjustment is applied to the market energy price to reflect the price differential between the market price delivery point and the counterparty delivery point. The historical relationship between the delivery points is reviewed and a discount (below 100%) or premium (above 100%) is derived. This comparison is done for both peak times when demand is high and off-peak times when demand is low. If the basis adjustment is lowered, the fair value measurement will decrease, and if the basis adjustment is increased, the fair value measurement will increase.

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

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

	Model Input
Significant Unobservable Inputs	September 30, 2019		December 31, 2018
Basis adjustment:
On peak	92.2	%	92.1	%
Off peak	92.8	%	92.8	%
Counterparty fuel mix:
Internal generation	40.0% - 60.0	%	50.0% - 75.0	%
Purchased power	60.0% - 40.0	%	50.0% - 25.0	%

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)		2019		2018		2019		2018
Beginning balance	$	(33,337)	$	(37,332)	$	(32,002)	$	(42,026)
Realized and unrealized gains (losses):
Included in regulatory assets		4,317		2,018		2,982		6,711
Included in other comprehensive income		-		-		-		-
Included in earnings		(492)		26		(1,928)		(434)
Included in current assets		4		(25)		(198)		(496)
Purchases		5,205		5,736		16,827		17,602
Sales		-		-		-		-
Issuances		-		-		-		-
Settlements		(4,717)		(5,737)		(14,701)		(16,671)
Transfers in and/or out of Level 3		-		-		-		-
Balance as of September 30,	$	(29,020)	$	(35,314)	$	(29,020)	$	(35,314)
Total gains (losses) included in earnings attributed to
the change in unrealized gains (losses) related to
assets and liabilities held at 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)		2019		2018		2019		2018
Purchased Power Expense	$	(409)	$	26	$	(1,658)	$	(637)
Cost of Gas Sold Expense		(83)		-		(270)		203
Total	$	(492)	$	26	$	(1,928)	$	(434)

(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.

XML

Segment Information

9 Months Ended

Sep. 30, 2019

Segment Reporting [Abstract]

Segment Information

Segment Information - MGE Energy and MGE.

MGE Energy operates in the following business segments: electric utility, gas utility, nonregulated energy, transmission investment, and all other. See the 2018 Annual Report on Form 10-K for additional discussion of each of these segments.

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

(In thousands) MGE Energy		Electric		Gas		Non-regulated Energy		Transmission Investment		All Others		Consolidation/ Elimination Entries		Consolidated Total
Three Months Ended September 30, 2019
Operating revenues	$	120,607	$	17,377	$	214	$	-	$	-	$	-	$	138,198
Interdepartmental revenues		225		5,679		10,019		-		-		(15,923)		-
Total operating revenues		120,832		23,056		10,233		-		-		(15,923)		138,198
Depreciation and amortization		(13,441)		(2,879)		(1,873)		-		-		-		(18,193)
Other operating expenses		(76,817)		(20,217)		(33)		-		(123)		15,923		(81,267)
Operating income (loss)		30,574		(40)		8,327		-		(123)		-		38,738
Other income, net		1,817		855		-		2,372		160		-		5,204
Interest (expense) income, net		(3,762)		(1,059)		(1,274)		-		264		-		(5,831)
Income (loss) before taxes		28,629		(244)		7,053		2,372		301		-		38,111
Income tax (provision) benefit		(4,948)		183		(1,922)		(646)		(121)		-		(7,454)
Net income (loss)	$	23,681	$	(61)	$	5,131	$	1,726	$	180	$	-	$	30,657
Three Months Ended September 30, 2018
Operating revenues	$	119,175	$	18,407	$	213	$	-	$	-	$	-	$	137,795
Interdepartmental revenues		(20)		4,219		9,912		-		-		(14,111)		-
Total operating revenues		119,155		22,626		10,125		-		-		(14,111)		137,795
Depreciation and amortization		(9,864)		(2,534)		(1,861)		-		-		-		(14,259)
Other operating expenses		(77,847)		(19,824)		(36)		(4)		(138)		14,111		(83,738)
Operating income (loss)		31,444		268		8,228		(4)		(138)		-		39,798
Other income, net		1,763		829		-		1,620		118		-		4,330
Interest (expense) income, net		(3,217)		(963)		(1,320)		-		475		-		(5,025)
Income before taxes		29,990		134		6,908		1,616		455		-		39,103
Income tax (provision) benefit		(7,306)		42		(1,852)		(441)		(40)		-		(9,597)
Net income	$	22,684	$	176	$	5,056	$	1,175	$	415	$	-	$	29,506
Nine Months Ended September 30, 2019
Operating revenues	$	314,886	$	112,547	$	481	$	-	$	-	$	-	$	427,914
Interdepartmental revenues		622		12,571		29,987		-		-		(43,180)		-
Total operating revenues		315,508		125,118		30,468		-		-		(43,180)		427,914
Depreciation and amortization		(39,330)		(8,482)		(5,611)		-		-		-		(53,423)
Other operating expenses		(223,242)		(104,587)		(113)		-		(697)		43,180		(285,459)
Operating income (loss)		52,936		12,049		24,744		-		(697)		-		89,032
Other income, net		5,258		2,579		-		6,808		429		-		15,074
Interest (expense) income, net		(11,253)		(3,132)		(3,838)		-		996		-		(17,227)
Income before taxes		46,941		11,496		20,906		6,808		728		-		86,879
Income tax provision		(6,036)		(2,848)		(5,695)		(1,856)		(232)		-		(16,667)
Net income	$	40,905	$	8,648	$	15,211	$	4,952	$	496	$	-	$	70,212
Nine Months Ended September 30, 2018
Operating revenues	$	312,633	$	106,152	$	904	$	-	$	-	$	-	$	419,689
Interdepartmental revenues		(234)		12,059		29,579		-		-		(41,404)		-
Total operating revenues		312,399		118,211		30,483		-		-		(41,404)		419,689
Depreciation and amortization		(28,817)		(7,374)		(5,563)		-		-		-		(41,754)
Other operating expenses		(228,957)		(99,251)		(113)		(12)		(789)		41,404		(287,718)
Operating income (loss)		54,625		11,586		24,807		(12)		(789)		-		90,217
Other income, net		5,055		2,347		-		5,908		670		-		13,980
Interest (expense) income, net		(9,036)		(2,689)		(4,002)		-		1,180		-		(14,547)
Income before taxes		50,644		11,244		20,805		5,896		1,061		-		89,650
Income tax provision		(11,492)		(2,788)		(5,638)		(1,611)		(263)		-		(21,792)
Net income	$	39,152	$	8,456	$	15,167	$	4,285	$	798	$	-	$	67,858

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

(In thousands) MGE		Electric		Gas		Non-regulated Energy		Consolidation/ Elimination Entries		Consolidated Total
Three Months Ended September 30, 2019
Operating revenues	$	120,607	$	17,377	$	214	$	-	$	138,198
Interdepartmental revenues		225		5,679		10,019		(15,923)		-
Total operating revenues		120,832		23,056		10,233		(15,923)		138,198
Depreciation and amortization		(13,441)		(2,879)		(1,873)		-		(18,193)
Other operating expenses		(76,817)		(20,217)		(33)		15,923		(81,144)
Operating income (loss)		30,574		(40)		8,327		-		38,861
Other income, net		1,817		855		-		-		2,672
Interest expense, net		(3,762)		(1,059)		(1,274)		-		(6,095)
Income (loss) before taxes		28,629		(244)		7,053		-		35,438
Income tax (provision) benefit		(4,948)		183		(1,922)		-		(6,687)
Net income (loss)		23,681		(61)		5,131		-		28,751
Less: Net income attributable to
noncontrolling interest, net of tax		-		-		-		(5,614)		(5,614)
Net income (loss) attributable to MGE	$	23,681	$	(61)	$	5,131	$	(5,614)	$	23,137
Three Months Ended September 30, 2018
Operating revenues	$	119,175	$	18,407	$	213	$	-	$	137,795
Interdepartmental revenues		(20)		4,219		9,912		(14,111)		-
Total operating revenues		119,155		22,626		10,125		(14,111)		137,795
Depreciation and amortization		(9,864)		(2,534)		(1,861)		-		(14,259)
Other operating expenses		(77,847)		(19,824)		(35)		14,111		(83,595)
Operating income		31,444		268		8,229		-		39,941
Other income, net		1,763		829		-		-		2,592
Interest expense, net		(3,217)		(963)		(1,320)		-		(5,500)
Income before taxes		29,990		134		6,909		-		37,033
Income tax provision		(7,306)		42		(1,853)		-		(9,117)
Net income		22,684		176		5,056		-		27,916
Less: Net income attributable to
noncontrolling interest, net of tax		-		-		-		(5,629)		(5,629)
Net income attributable to MGE	$	22,684	$	176	$	5,056	$	(5,629)	$	22,287
Nine Months Ended September 30, 2019
Operating revenues	$	314,886	$	112,547	$	481	$	-	$	427,914
Interdepartmental revenues		622		12,571		29,987		(43,180)		-
Total operating revenues		315,508		125,118		30,468		(43,180)		427,914
Depreciation and amortization		(39,330)		(8,482)		(5,611)		-		(53,423)
Other operating expenses		(223,242)		(104,587)		(113)		43,180		(284,762)
Operating income		52,936		12,049		24,744		-		89,729
Other income, net		5,258		2,579		-		-		7,837
Interest expense, net		(11,253)		(3,132)		(3,838)		-		(18,223)
Income before taxes		46,941		11,496		20,906		-		79,343
Income tax provision		(6,036)		(2,848)		(5,695)		-		(14,579)
Net income		40,905		8,648		15,211		-		64,764
Less: Net income attributable to
noncontrolling interest, net of tax		-		-		-		(16,725)		(16,725)
Net income attributable to MGE	$	40,905	$	8,648	$	15,211	$	(16,725)	$	48,039
Nine Months Ended September 30, 2018
Operating revenues	$	312,633	$	106,152	$	904	$	-	$	419,689
Interdepartmental revenues		(234)		12,059		29,579		(41,404)		-
Total operating revenues		312,399		118,211		30,483		(41,404)		419,689
Depreciation and amortization		(28,817)		(7,374)		(5,563)		-		(41,754)
Other operating expenses		(228,957)		(99,251)		(113)		41,404		(286,917)
Operating income		54,625		11,586		24,807		-		91,018
Other income, net		5,055		2,347		-		-		7,402
Interest expense, net		(9,036)		(2,689)		(4,002)		-		(15,727)
Income before taxes		50,644		11,244		20,805		-		82,693
Income tax provision		(11,492)		(2,788)		(5,638)		-		(19,918)
Net income		39,152		8,456		15,167		-		62,775
Less: Net income attributable to
noncontrolling interest, net of tax		-		-		-		(16,940)		(16,940)
Net income attributable to MGE	$	39,152	$	8,456	$	15,167	$	(16,940)	$	45,835

The following table shows segment information for assets and capital expenditures:
		Utility				Consolidated
(In thousands) MGE Energy		Electric		Gas		Non-regulated Energy		Transmission Investment		All Others		Consolidation/ Elimination Entries		Total
Assets:
September 30, 2019	$	1,288,752	$	379,160	$	259,542	$	69,829	$	447,307	$	(377,617)	$	2,066,973
December 31, 2018		1,193,083		377,005		265,301		66,366		465,661		(378,798)		1,988,618
Capital Expenditures:
Nine months ended September 30, 2019	$	101,609	$	24,551	$	2,229	$	-	$	-	$	-	$	128,389
Year ended Dec. 31, 2018		176,399		30,497		5,301		-		-		-		212,197

		Utility				Consolidated
(In thousands) MGE		Electric		Gas		Non-regulated Energy		Elimination Entries		Total
Assets:
September 30, 2019	$	1,288,752	$	379,160	$	259,492	$	(377)	$	1,927,027
December 31, 2018		1,193,083		377,005		265,251		(448)		1,834,891
Capital Expenditures:
Nine months ended September 30, 2019	$	101,609	$	24,551	$	2,229	$	-	$	128,389
Year ended Dec. 31, 2018		176,399		30,497		5,301		-		212,197

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Investment in ATC and ATC Holdco (Tables)

9 Months Ended

Sep. 30, 2019

Equity Method Investments and Joint Ventures [Abstract]

Equity Method Investments Financial Data

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

		Three Months Ended				Nine Months Ended
		September 30,				September 30,
(In thousands)		2019		2018		2019		2018
Equity earnings from investment in ATC	$	2,364	$	1,672	$	6,879	$	6,113
Dividends from ATC(a)		1,781		1,581		5,526		4,540
Capital contributions to ATC		888		533		2,131		2,308

(a)MGE Transco recorded a $2.3 million dividend receivable from ATC as of December 31, 2017. A cash dividend was received in January of the following year. MGE Transco recorded a $1.6 million dividend receivable from ATC as of September 30, 2018. A cash dividend was received in October 2018.ATC's summarized financial data is as follows:

		Three Months Ended				Nine Months Ended
		September 30,				September 30,
(In thousands)		2019		2018		2019		2018
Operating revenues	$	184,833	$	170,341	$	544,760	$	501,276
Operating expenses		(94,713)		(87,959)		(278,673)		(264,326)
Other income, net		484		439		1,031		2,070
Interest expense, net		(29,165)		(27,754)		(87,121)		(82,411)
Earnings before members' income taxes	$	61,439	$	55,067	$	179,997	$	156,609

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Investment in ATC and ATC Holdco

9 Months Ended

Sep. 30, 2019

Equity Method Investments and Joint Ventures [Abstract]

Investment in ATC and ATC Holdco

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

ATC owns and operates electric transmission facilities primarily in Wisconsin. MGE received an interest in

ATC when it, like other Wisconsin electric utilities, contributed its electric transmission facilities to ATC as required by Wisconsin law. That interest is presently held by MGE Transco, which, since December 1, 2016, is owned by 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 wholly-owned 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:

		Three Months Ended				Nine Months Ended
		September 30,				September 30,
(In thousands)		2019		2018		2019		2018
Equity earnings from investment in ATC	$	2,364	$	1,672	$	6,879	$	6,113
Dividends from ATC(a)		1,781		1,581		5,526		4,540
Capital contributions to ATC		888		533		2,131		2,308

(a)MGE Transco recorded a $2.3 million dividend receivable from ATC as of December 31, 2017. A cash dividend was received in January of the following year. MGE Transco recorded a $1.6 million dividend receivable from ATC as of September 30, 2018. A cash dividend was received in October 2018.

ATC Holdco was formed in December 2016. In the near term, it is expected that ATC Holdco will be pursuing transmission development opportunities that typically have long development and investment lead times before becoming operational.

In October 2019, MGE Transco made a $0.9 million capital contribution to ATC.

ATC's summarized financial data is as follows:

		Three Months Ended				Nine Months Ended
		September 30,				September 30,
(In thousands)		2019		2018		2019		2018
Operating revenues	$	184,833	$	170,341	$	544,760	$	501,276
Operating expenses		(94,713)		(87,959)		(278,673)		(264,326)
Other income, net		484		439		1,031		2,070
Interest expense, net		(29,165)		(27,754)		(87,121)		(82,411)
Earnings before members' income taxes	$	61,439	$	55,067	$	179,997	$	156,609

MGE receives transmission and other related services from ATC. During the three and nine months ended September 30, 2019, MGE recorded $7.6 million and $22.8 million, respectively, for transmission services received compared to $7.2 million and $21.7 million for the comparable periods in 2018. MGE also provides a variety of operational, maintenance, and project management services for ATC, which is reimbursed by ATC. As of September 30, 2019, and December 31, 2018, MGE had a receivable due from ATC of $1.6 million and $0.1 million, respectively.

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Share-Based Compensation

9 Months Ended

Sep. 30, 2019

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

Share-Based Compensation

Share-Based Compensation - MGE Energy and MGE.

Under MGE Energy's Director Incentive Plan and its Performance Unit Plan, non-employee directors and eligible employees, respectively, may receive performance units that entitle the holder to receive a cash

payment equal to the value of a designated number of shares of MGE Energy's common stock, plus dividend equivalent payments thereon, at the end of the performance period set in the award.

In 2019, 5,175 units were granted under the Director Incentive Plan and are subject to a three-year graded vesting schedule, and 17,022 units were granted under the Performance Unit Plan and are subject to a five-year graded vesting schedule. On the grant date, the cost of the director or employee services received in exchange for a performance unit award is measured based on the current market value of MGE Energy common stock. The fair value of the awards is remeasured quarterly, including as of September 30, 2019, as required by applicable accounting standards. Changes in fair value as well as the original grant are recognized as compensation cost. Since this amount is remeasured throughout the vesting period, the compensation cost is subject to variability.

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

During the three and nine months ended September 30, 2019, MGE recorded $0.9 million and $2.8 million, respectively, in compensation expense as a result of awards under the plans compared to $0.3 million and $1.3 million for the comparable periods in 2018. In January 2019, cash payments of $1.5 million were distributed relating to awards that were granted in a prior year under the plans. No forfeitures of units occurred during the three and nine months ended September 30, 2019 and 2018. As of September 30, 2019, $6.2 million of outstanding awards are vested. Of this amount, no cash settlements have occurred as cash payments are only made at the end of the period covered by the awards.

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Consolidated Statements of Cash Flows (Unaudited) - USD ($)	9 Months Ended
	Sep. 30, 2019	Sep. 30, 2018
Operating Activities:
Net Income	$ 70,212,000	$ 67,858,000
Items not affecting cash:
Depreciation and amortization	53,423,000	41,754,000
Deferred income taxes	4,864,000	2,352,000
Provision for doubtful receivables	978,000	642,000
Employee benefit plan credit	(2,866,000)	(1,544,000)
Equity earnings in ATC	(6,879,000)	(6,113,000)
Other items	692,000	31,000
Changes in working capital items:
Decrease in current assets	14,307,000	25,530,000
Increase (decrease) in current liabilities	(24,088,000)	6,026,000
Dividends from ATC	5,526,000	5,336,000
Cash contributions to pension and other postretirement plans	(3,707,000)	(3,967,000)
Other noncurrent items, net	(760,000)	527,000
Cash Provided by Operating Activities	111,702,000	138,432,000
Investing Activities:
Capital expenditures	(128,389,000)	(149,001,000)
Capital contributions to investments	(5,894,000)	(4,801,000)
Other	(248,000)	368,000
Cash Used for Investing Activities	(134,531,000)	(153,434,000)
Financing Activities:
Cash dividends paid on common stock	(35,622,000)	(34,062,000)
Repayment of long-term debt	(3,405,000)	(23,330,000)
Issuance of long-term debt	0	100,000,000
Proceeds from (repayments of) short-term debt	41,500,000	(4,000,000)
Other	(1,331,000)	(659,000)
Cash Provided by Financing Activities	1,142,000	37,949,000
Change in cash, cash equivalents, and restricted cash	(21,687,000)	22,947,000
Cash, cash equivalents, and restricted cash at beginning of period	84,929,000	112,094,000
Cash, cash equivalents, and restricted cash at end of period	63,242,000	135,041,000
Significant noncash investing activities:
Accrued capital expenditures	16,819,000	10,991,000
MGE [Member]
Operating Activities:
Net Income	64,764,000	62,775,000
Items not affecting cash:
Depreciation and amortization	53,423,000	41,754,000
Deferred income taxes	3,653,000	(580,000)
Provision for doubtful receivables	978,000	642,000
Employee benefit plan credit	(2,866,000)	(1,544,000)
Other items	1,653,000	768,000
Changes in working capital items:
Decrease in current assets	14,236,000	24,864,000
Increase (decrease) in current liabilities	(22,234,000)	9,941,000
Cash contributions to pension and other postretirement plans	(3,707,000)	(3,967,000)
Other noncurrent items, net	(880,000)	374,000
Cash Provided by Operating Activities	109,020,000	135,027,000
Investing Activities:
Capital expenditures	(128,389,000)	(149,001,000)
Other	(477,000)	(680,000)
Cash Used for Investing Activities	(128,866,000)	(149,681,000)
Financing Activities:
Distributions to parent from noncontrolling interest	(17,000,000)	(19,000,000)
Repayment of long-term debt	(3,405,000)	(23,330,000)
Issuance of long-term debt	0	100,000,000
Proceeds from (repayments of) short-term debt	41,500,000	(4,000,000)
Other	(1,133,000)	(659,000)
Cash Provided by Financing Activities	19,962,000	53,011,000
Change in cash, cash equivalents, and restricted cash	116,000	38,357,000
Cash, cash equivalents, and restricted cash at beginning of period	6,670,000	10,093,000
Cash, cash equivalents, and restricted cash at end of period	6,786,000	48,450,000
Significant noncash investing activities:
Accrued capital expenditures	$ 16,819,000	$ 10,991,000

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Leases (Details-3) $ in Thousands	9 Months Ended
	Sep. 30, 2019 USD ($)
Lessee Disclosure [Abstract]
Finance leases - Financing cash flows	$ 781
Finance leases - Operating cash flows	597
Operating leases - operating cash flows	108
Lease assets obtained in exchange for lease liabilities - finance leases	12,081
Lease assets obtained in exchange for lease liabilities - operating leases	$ 239

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Madison Gas and Electric Company Consolidated Statements of Common Equity (Unaudited) - USD ($) shares in Thousands, $ in Thousands	Total	MGE [Member]	Common Stock [Member]	Common Stock [Member] MGE [Member]	Additional Paid-In Capital [Member] MGE [Member]	Retained Earnings [Member]	Retained Earnings [Member] MGE [Member]	Accumulated Other Comprehensive Income/(Loss) [Member]	Accumulated Other Comprehensive Income/(Loss) [Member] MGE [Member]	Noncontrolling Interest [Member] MGE [Member]
Increase (Decrease) In Stockholders' Equity [Roll Forward]
Cumulative effect of new accounting principle	$ 0	$ 0				$ 377	$ (28)	$ (377)	$ 28
Beginning balance, shares at Dec. 31, 2017			34,668	17,348
Beginning balance, value at Dec. 31, 2017		632,774		$ 17,348	$ 192,417		282,135		(28)	$ 140,902
Beginning balance, value - Adjusted at Dec. 31, 2017	778,187	632,774				$ 427,251	282,107	$ 0	0
Increase (Decrease) In Stockholders' Equity [Roll Forward]
Net Income	67,858	62,775					45,835			16,940
Distributions to parent from noncontrolling interest		(19,000)								(19,000)
Ending balance, shares at Sep. 30, 2018			34,668	17,348
Ending balance, value at Sep. 30, 2018		676,549		$ 17,348	192,417		327,942		0	138,842
Beginning balance, shares at Jun. 30, 2018			34,668	17,348
Beginning balance, value at Jun. 30, 2018		654,133		$ 17,348	192,417		305,655		0	138,713
Increase (Decrease) In Stockholders' Equity [Roll Forward]
Net Income	29,506	27,916					22,287			5,629
Distributions to parent from noncontrolling interest		(5,500)								(5,500)
Ending balance, shares at Sep. 30, 2018			34,668	17,348
Ending balance, value at Sep. 30, 2018		676,549		$ 17,348	192,417		327,942		0	138,842
Beginning balance, shares at Dec. 31, 2018			34,668	17,348
Beginning balance, value at Dec. 31, 2018		689,810		$ 17,348	192,417		338,591		0	141,454
Increase (Decrease) In Stockholders' Equity [Roll Forward]
Net Income	70,212	64,764					48,039			16,725
Distributions to parent from noncontrolling interest		(17,000)								(17,000)
Ending balance, shares at Sep. 30, 2019			34,668	17,348
Ending balance, value at Sep. 30, 2019		737,574		$ 17,348	192,417		386,630		0	141,179
Beginning balance, shares at Jun. 30, 2019			34,668	17,348
Beginning balance, value at Jun. 30, 2019		714,323		$ 17,348	192,417		363,493		0	141,065
Increase (Decrease) In Stockholders' Equity [Roll Forward]
Net Income	$ 30,657	28,751					23,137			5,614
Distributions to parent from noncontrolling interest		(5,500)								(5,500)
Ending balance, shares at Sep. 30, 2019			34,668	17,348
Ending balance, value at Sep. 30, 2019		$ 737,574		$ 17,348	$ 192,417		$ 386,630		$ 0	$ 141,179

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Segment Information (Tables)

9 Months Ended

Sep. 30, 2019

Segment Reporting [Abstract]

Segment Information

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

(In thousands) MGE Energy		Electric		Gas		Non-regulated Energy		Transmission Investment		All Others		Consolidation/ Elimination Entries		Consolidated Total
Three Months Ended September 30, 2019
Operating revenues	$	120,607	$	17,377	$	214	$	-	$	-	$	-	$	138,198
Interdepartmental revenues		225		5,679		10,019		-		-		(15,923)		-
Total operating revenues		120,832		23,056		10,233		-		-		(15,923)		138,198
Depreciation and amortization		(13,441)		(2,879)		(1,873)		-		-		-		(18,193)
Other operating expenses		(76,817)		(20,217)		(33)		-		(123)		15,923		(81,267)
Operating income (loss)		30,574		(40)		8,327		-		(123)		-		38,738
Other income, net		1,817		855		-		2,372		160		-		5,204
Interest (expense) income, net		(3,762)		(1,059)		(1,274)		-		264		-		(5,831)
Income (loss) before taxes		28,629		(244)		7,053		2,372		301		-		38,111
Income tax (provision) benefit		(4,948)		183		(1,922)		(646)		(121)		-		(7,454)
Net income (loss)	$	23,681	$	(61)	$	5,131	$	1,726	$	180	$	-	$	30,657
Three Months Ended September 30, 2018
Operating revenues	$	119,175	$	18,407	$	213	$	-	$	-	$	-	$	137,795
Interdepartmental revenues		(20)		4,219		9,912		-		-		(14,111)		-
Total operating revenues		119,155		22,626		10,125		-		-		(14,111)		137,795
Depreciation and amortization		(9,864)		(2,534)		(1,861)		-		-		-		(14,259)
Other operating expenses		(77,847)		(19,824)		(36)		(4)		(138)		14,111		(83,738)
Operating income (loss)		31,444		268		8,228		(4)		(138)		-		39,798
Other income, net		1,763		829		-		1,620		118		-		4,330
Interest (expense) income, net		(3,217)		(963)		(1,320)		-		475		-		(5,025)
Income before taxes		29,990		134		6,908		1,616		455		-		39,103
Income tax (provision) benefit		(7,306)		42		(1,852)		(441)		(40)		-		(9,597)
Net income	$	22,684	$	176	$	5,056	$	1,175	$	415	$	-	$	29,506
Nine Months Ended September 30, 2019
Operating revenues	$	314,886	$	112,547	$	481	$	-	$	-	$	-	$	427,914
Interdepartmental revenues		622		12,571		29,987		-		-		(43,180)		-
Total operating revenues		315,508		125,118		30,468		-		-		(43,180)		427,914
Depreciation and amortization		(39,330)		(8,482)		(5,611)		-		-		-		(53,423)
Other operating expenses		(223,242)		(104,587)		(113)		-		(697)		43,180		(285,459)
Operating income (loss)		52,936		12,049		24,744		-		(697)		-		89,032
Other income, net		5,258		2,579		-		6,808		429		-		15,074
Interest (expense) income, net		(11,253)		(3,132)		(3,838)		-		996		-		(17,227)
Income before taxes		46,941		11,496		20,906		6,808		728		-		86,879
Income tax provision		(6,036)		(2,848)		(5,695)		(1,856)		(232)		-		(16,667)
Net income	$	40,905	$	8,648	$	15,211	$	4,952	$	496	$	-	$	70,212
Nine Months Ended September 30, 2018
Operating revenues	$	312,633	$	106,152	$	904	$	-	$	-	$	-	$	419,689
Interdepartmental revenues		(234)		12,059		29,579		-		-		(41,404)		-
Total operating revenues		312,399		118,211		30,483		-		-		(41,404)		419,689
Depreciation and amortization		(28,817)		(7,374)		(5,563)		-		-		-		(41,754)
Other operating expenses		(228,957)		(99,251)		(113)		(12)		(789)		41,404		(287,718)
Operating income (loss)		54,625		11,586		24,807		(12)		(789)		-		90,217
Other income, net		5,055		2,347		-		5,908		670		-		13,980
Interest (expense) income, net		(9,036)		(2,689)		(4,002)		-		1,180		-		(14,547)
Income before taxes		50,644		11,244		20,805		5,896		1,061		-		89,650
Income tax provision		(11,492)		(2,788)		(5,638)		(1,611)		(263)		-		(21,792)
Net income	$	39,152	$	8,456	$	15,167	$	4,285	$	798	$	-	$	67,858

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

(In thousands) MGE		Electric		Gas		Non-regulated Energy		Consolidation/ Elimination Entries		Consolidated Total
Three Months Ended September 30, 2019
Operating revenues	$	120,607	$	17,377	$	214	$	-	$	138,198
Interdepartmental revenues		225		5,679		10,019		(15,923)		-
Total operating revenues		120,832		23,056		10,233		(15,923)		138,198
Depreciation and amortization		(13,441)		(2,879)		(1,873)		-		(18,193)
Other operating expenses		(76,817)		(20,217)		(33)		15,923		(81,144)
Operating income (loss)		30,574		(40)		8,327		-		38,861
Other income, net		1,817		855		-		-		2,672
Interest expense, net		(3,762)		(1,059)		(1,274)		-		(6,095)
Income (loss) before taxes		28,629		(244)		7,053		-		35,438
Income tax (provision) benefit		(4,948)		183		(1,922)		-		(6,687)
Net income (loss)		23,681		(61)		5,131		-		28,751
Less: Net income attributable to
noncontrolling interest, net of tax		-		-		-		(5,614)		(5,614)
Net income (loss) attributable to MGE	$	23,681	$	(61)	$	5,131	$	(5,614)	$	23,137
Three Months Ended September 30, 2018
Operating revenues	$	119,175	$	18,407	$	213	$	-	$	137,795
Interdepartmental revenues		(20)		4,219		9,912		(14,111)		-
Total operating revenues		119,155		22,626		10,125		(14,111)		137,795
Depreciation and amortization		(9,864)		(2,534)		(1,861)		-		(14,259)
Other operating expenses		(77,847)		(19,824)		(35)		14,111		(83,595)
Operating income		31,444		268		8,229		-		39,941
Other income, net		1,763		829		-		-		2,592
Interest expense, net		(3,217)		(963)		(1,320)		-		(5,500)
Income before taxes		29,990		134		6,909		-		37,033
Income tax provision		(7,306)		42		(1,853)		-		(9,117)
Net income		22,684		176		5,056		-		27,916
Less: Net income attributable to
noncontrolling interest, net of tax		-		-		-		(5,629)		(5,629)
Net income attributable to MGE	$	22,684	$	176	$	5,056	$	(5,629)	$	22,287
Nine Months Ended September 30, 2019
Operating revenues	$	314,886	$	112,547	$	481	$	-	$	427,914
Interdepartmental revenues		622		12,571		29,987		(43,180)		-
Total operating revenues		315,508		125,118		30,468		(43,180)		427,914
Depreciation and amortization		(39,330)		(8,482)		(5,611)		-		(53,423)
Other operating expenses		(223,242)		(104,587)		(113)		43,180		(284,762)
Operating income		52,936		12,049		24,744		-		89,729
Other income, net		5,258		2,579		-		-		7,837
Interest expense, net		(11,253)		(3,132)		(3,838)		-		(18,223)
Income before taxes		46,941		11,496		20,906		-		79,343
Income tax provision		(6,036)		(2,848)		(5,695)		-		(14,579)
Net income		40,905		8,648		15,211		-		64,764
Less: Net income attributable to
noncontrolling interest, net of tax		-		-		-		(16,725)		(16,725)
Net income attributable to MGE	$	40,905	$	8,648	$	15,211	$	(16,725)	$	48,039
Nine Months Ended September 30, 2018
Operating revenues	$	312,633	$	106,152	$	904	$	-	$	419,689
Interdepartmental revenues		(234)		12,059		29,579		(41,404)		-
Total operating revenues		312,399		118,211		30,483		(41,404)		419,689
Depreciation and amortization		(28,817)		(7,374)		(5,563)		-		(41,754)
Other operating expenses		(228,957)		(99,251)		(113)		41,404		(286,917)
Operating income		54,625		11,586		24,807		-		91,018
Other income, net		5,055		2,347		-		-		7,402
Interest expense, net		(9,036)		(2,689)		(4,002)		-		(15,727)
Income before taxes		50,644		11,244		20,805		-		82,693
Income tax provision		(11,492)		(2,788)		(5,638)		-		(19,918)
Net income		39,152		8,456		15,167		-		62,775
Less: Net income attributable to
noncontrolling interest, net of tax		-		-		-		(16,940)		(16,940)
Net income attributable to MGE	$	39,152	$	8,456	$	15,167	$	(16,940)	$	45,835

The following table shows segment information for assets and capital expenditures:
		Utility				Consolidated
(In thousands) MGE Energy		Electric		Gas		Non-regulated Energy		Transmission Investment		All Others		Consolidation/ Elimination Entries		Total
Assets:
September 30, 2019	$	1,288,752	$	379,160	$	259,542	$	69,829	$	447,307	$	(377,617)	$	2,066,973
December 31, 2018		1,193,083		377,005		265,301		66,366		465,661		(378,798)		1,988,618
Capital Expenditures:
Nine months ended September 30, 2019	$	101,609	$	24,551	$	2,229	$	-	$	-	$	-	$	128,389
Year ended Dec. 31, 2018		176,399		30,497		5,301		-		-		-		212,197

		Utility				Consolidated
(In thousands) MGE		Electric		Gas		Non-regulated Energy		Elimination Entries		Total
Assets:
September 30, 2019	$	1,288,752	$	379,160	$	259,492	$	(377)	$	1,927,027
December 31, 2018		1,193,083		377,005		265,251		(448)		1,834,891
Capital Expenditures:
Nine months ended September 30, 2019	$	101,609	$	24,551	$	2,229	$	-	$	128,389
Year ended Dec. 31, 2018		176,399		30,497		5,301		-		212,197

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Commitments and Contingencies (Tables)

9 Months Ended

Sep. 30, 2019

Commitments and Contingencies Disclosure [Abstract]

Purchase Contracts, Fiscal Year Maturity Schedule

The following table shows future commitments related to purchase contracts as of September 30, 2019:

(In thousands)		2019		2020		2021		2022		2023		Thereafter
Coal(a)	$	7,293		13,120		5,647		2,313		-		-
Natural gas
Transportation and storage(b)		6,258		21,997		21,728		21,728		21,728		55,460
Supply(c)		8,773		10,600		-		-		-		-
Solar farms(d)		509		310		3,024		726		743		32,474
Other		92		928		929		97		99		1,079
	$	22,925	$	46,955	$	31,328	$	24,864	$	22,570	$	89,013

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

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

(c)These commitments include market-based pricing.

(d)In 2019, MGE entered into commitments related to operations of the Two Creeks and Badger Hollow Solar Farms. See Footnote 14 for further information on the solar farm construction.

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Commitments and Contingencies (Details-2)	9 Months Ended
	Sep. 30, 2019 USD ($)
Operating expense purchase contracts [Abstract]
Purchase obligation, 2019	$ 22,925,000
Purchase obligation, 2020	46,955,000
Purchase obligation, 2021	31,328,000
Purchase obligation, 2022	24,864,000
Purchase obligation, 2023	22,570,000
Purchase obligation, Thereafter	89,013,000
Coal [Member]
Operating expense purchase contracts [Abstract]
Purchase obligation, 2019	7,293,000	[1]
Purchase obligation, 2020	13,120,000	[1]
Purchase obligation, 2021	5,647,000	[1]
Purchase obligation, 2022	2,313,000	[1]
Purchase obligation, 2023	0	[1]
Purchase obligation, Thereafter	0	[1]
Natural Gas, Transportation and Storage [Member]
Operating expense purchase contracts [Abstract]
Purchase obligation, 2019	6,258,000	[2]
Purchase obligation, 2020	21,997,000	[2]
Purchase obligation, 2021	21,728,000	[2]
Purchase obligation, 2022	21,728,000	[2]
Purchase obligation, 2023	21,728,000	[2]
Purchase obligation, Thereafter	55,460,000	[2]
Natual Gas, Supply [Member]
Operating expense purchase contracts [Abstract]
Purchase obligation, 2019	8,773,000	[3]
Purchase obligation, 2020	10,600,000	[3]
Purchase obligation, 2021	0	[3]
Purchase obligation, 2022	0	[3]
Purchase obligation, 2023	0	[3]
Purchase obligation, Thereafter	0	[3]
Solar farms
Operating expense purchase contracts [Abstract]
Purchase obligation, 2019	509,000	[4]
Purchase obligation, 2020	310,000	[4]
Purchase obligation, 2021	3,024,000	[4]
Purchase obligation, 2022	726,000	[4]
Purchase obligation, 2023	743,000	[4]
Purchase obligation, Thereafter	32,474,000	[4]
Other [Member]
Operating expense purchase contracts [Abstract]
Purchase obligation, 2019	92,000
Purchase obligation, 2020	928,000
Purchase obligation, 2021	929,000
Purchase obligation, 2022	97,000
Purchase obligation, 2023	99,000
Purchase obligation, Thereafter	1,079,000
Two Creeks Construction Commitment [Member]
Long Term Purchase Commitment [Line Items]
Minimum future capital commitments	20,500,000
Badger Hollow Construction Commitment [Member]
Long Term Purchase Commitment [Line Items]
Minimum future capital commitments	53,200,000
MGE Energy [Member] | Venture Capital Funds [Member]
Other Commitments [Line Items]
Other commitment, initial agreed upon commitment total	$ 10,000,000

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

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

[3] These commitments include market-based pricing.

[4] In 2019, MGE entered into commitments related to operations of the Two Creeks and Badger Hollow Solar Farms. See Footnote 14 for further information on the solar farm construction.

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Derivative and Hedging Instruments (Details-3) - USD ($) $ in Thousands	Sep. 30, 2019	Dec. 31, 2018
Offsetting Liabilities [Line Items]
Collateral posted against derivative positions	$ (700)
Commodity Derivative Contracts [Member]
Offsetting Liabilities [Line Items]
Gross amounts	1,285	$ 342
Gross amounts offset in balance sheet	(561)	(342)
Collateral posted against derivative positions	(724)	0
Net amount presented in balance sheet	0	0
Financial Transmission Rights [Member]
Offsetting Liabilities [Line Items]
Collateral posted against derivative positions	0	0
Purchased Power Agreement [Member]
Offsetting Liabilities [Line Items]
Gross amounts	28,990	32,530
Gross amounts offset in balance sheet	0	0
Collateral posted against derivative positions	0	0
Net amount presented in balance sheet	$ 28,990	$ 32,530

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Fair Value of Financial Instruments (Details-2) - USD ($) $ in Thousands	Sep. 30, 2019		Dec. 31, 2018
Liabilities:
Collateral posted against derivative positions	$ 700
Recurring [Member]
Assets:
Derivatives	1,093	[1]	$ 1,042
Total Assets	2,094		1,890
Liabilities:
Derivatives	30,275		32,872
Deferred compensation	3,025		3,078
Total liabilities	33,300		35,950
Recurring [Member] | Exchange Traded [Member]
Assets:
Available-for-sale securities	1,001		848
Recurring [Member] | Level 1 [Member]
Assets:
Derivatives	525	[1]	296
Total Assets	1,526		1,144
Liabilities:
Derivatives	687		124
Deferred compensation	0		0
Total liabilities	687		124
Recurring [Member] | Level 1 [Member] | Exchange Traded [Member]
Assets:
Available-for-sale securities	1,001		848
Recurring [Member] | Level 2 [Member]
Assets:
Derivatives	0	[1]	0
Total Assets	0		0
Liabilities:
Derivatives	0		0
Deferred compensation	3,025		3,078
Total liabilities	3,025		3,078
Recurring [Member] | Level 2 [Member] | Exchange Traded [Member]
Assets:
Available-for-sale securities	0		0
Recurring [Member] | Level 3 [Member]
Assets:
Derivatives	568	[1]	746
Total Assets	568		746
Liabilities:
Derivatives	29,588		32,748
Deferred compensation	0		0
Total liabilities	29,588		32,748
Recurring [Member] | Level 3 [Member] | Exchange Traded [Member]
Assets:
Available-for-sale securities	0		0
MGE [Member]
Liabilities:
Collateral posted against derivative positions	700
MGE [Member] | Recurring [Member]
Assets:
Derivatives	1,093	[1]	1,042
Total Assets	1,271		1,085
Liabilities:
Derivatives	30,275		32,872
Deferred compensation	3,025		3,078
Total liabilities	33,300		35,950
MGE [Member] | Recurring [Member] | Exchange Traded [Member]
Assets:
Available-for-sale securities	178		43
MGE [Member] | Recurring [Member] | Level 1 [Member]
Assets:
Derivatives	525	[1]	296
Total Assets	703		339
Liabilities:
Derivatives	687		124
Deferred compensation	0		0
Total liabilities	687		124
MGE [Member] | Recurring [Member] | Level 1 [Member] | Exchange Traded [Member]
Assets:
Available-for-sale securities	178		43
MGE [Member] | Recurring [Member] | Level 2 [Member]
Assets:
Derivatives	0	[1]	0
Total Assets	0		0
Liabilities:
Derivatives	0		0
Deferred compensation	3,025		3,078
Total liabilities	3,025		3,078
MGE [Member] | Recurring [Member] | Level 2 [Member] | Exchange Traded [Member]
Assets:
Available-for-sale securities	0		0
MGE [Member] | Recurring [Member] | Level 3 [Member]
Assets:
Derivatives	568	[1]	746
Total Assets	568		746
Liabilities:
Derivatives	29,588		32,748
Deferred compensation	0		0
Total liabilities	29,588		32,748
MGE [Member] | Recurring [Member] | Level 3 [Member] | Exchange Traded [Member]
Assets:
Available-for-sale securities	$ 0		$ 0

[1] These amounts are shown gross and exclude $0.7 million of collateral that was posted against derivative positions with counterparties as of September 30, 2019.

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Taxes

9 Months Ended

Sep. 30, 2019

Income Tax Disclosure [Abstract]

Taxes

Taxes - MGE Energy and MGE.

Effective Tax Rate.

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

	MGE Energy				MGE
Three Months Ended September 30,	2019		2018		2019		2018
Statutory federal income tax rate	21.0	%	21.0	%	21.0	%	21.0	%
State income taxes, net of federal benefit	6.3		6.3		6.2		6.2
Amortized investment tax credits	(0.1)		(0.1)		(0.1)		(0.1)
Credit for electricity from wind energy(a)	(4.8)		(0.3)		(5.2)		(0.2)
AFUDC equity, net	(0.4)		(0.6)		(0.4)		(0.6)
Amortization of utility excess deferred tax - tax reform(b)	(1.9)		(1.8)		(2.1)		(1.8)
Other, net, individually insignificant	(0.5)		-		(0.5)		0.1
Effective income tax rate	19.6	%	24.5	%	18.9	%	24.6	%
	MGE Energy				MGE
Nine Months Ended September 30,	2019		2018		2019		2018
Statutory federal income tax rate	21.0	%	21.0	%	21.0	%	21.0	%
State income taxes, net of federal benefit	6.3		6.3		6.2		6.2
Amortized investment tax credits	(0.1)		(0.1)		(0.1)		(0.1)
Credit for electricity from wind energy(a)	(5.6)		(0.3)		(6.1)		(0.3)
AFUDC equity, net	(0.3)		(0.8)		(0.3)		(0.8)
Amortization of utility excess deferred tax - tax reform(b)	(2.2)		(1.8)		(2.4)		(2.0)
Other, net, individually insignificant	0.1		-		0.1		0.1
Effective income tax rate	19.2	%	24.3	%	18.4	%	24.1	%

(a)Saratoga Wind Farm became operational in February 2019.

(b)Included are impacts of the Tax Cuts and Jobs Act for the regulated utility for excess deferred taxes recognized using a normalization method of accounting. For the three and nine months ended September 30, 2019, MGE recognized $0.6 million and $1.7 million, respectively, compared to $0.5 million and $1.4 million for the comparable periods in 2018. The amount and timing of the cash impacts will depend on the period over which certain income tax benefits are provided to customers, as determined by the PSCW.

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Commitments and Contingencies

9 Months Ended

Sep. 30, 2019

Commitments and Contingencies Disclosure [Abstract]

Commitments and Contingencies

Commitments and Contingencies.

a.Environmental - MGE Energy and MGE.

MGE Energy and MGE are subject to frequently changing local, state, and federal regulations concerning air quality, water quality, land use, threatened and endangered species, hazardous materials handling, and solid waste disposal. These regulations affect the manner in which they conduct their operations, the costs of those operations, as well as capital and operating expenditures. Several of these environmental rules are subject to legal challenges, reconsideration and/or other uncertainties. Regulatory initiatives, proposed rules, and court challenges to adopted rules have the potential to 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 published water effluent limitations guidelines and standards for steam electric power plants, which focus on the reduction of metals and other pollutants in wastewater from new and existing power plants, such as the coal-burning plants at Columbia and the Elm Road Units. The operators of the Columbia and the Elm Road Units have indicated that equipment upgrades may be necessary to comply with the new discharge standards.

•The EPA's cooling water intake rules, which require cooling water intake structures at electric power plants, such as our Blount and Columbia plants, to meet best available technology standards so that mortality from entrainment (drawing aquatic life into a plant's cooling system) and impingement (trapping aquatic life on screens) are reduced. MGE expects that the rule will not have a material effect on its existing plants.

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

In 2015, the EPA finalized the Clean Power Plan (CPP), which directed states to submit plans to reduce GHG emissions from the electric generation sector. The CPP applied the statutory

requirements for the "best system of emission reduction" (BSER) broadly so as to encompass GHG emission reduction strategies that extend "beyond the fenceline" of existing EGUs and required a shift in the energy generation mix at the grid level.

In July 2019, the EPA published a final rule repealing the CPP and creating the replacement Affordable Clean Energy (ACE) rule to reduce greenhouse gas emissions from existing coal-fired EGUs. The ACE rule applies to EGUs greater than 25 MW. Based upon these criteria, the ACE rule will likely apply to Columbia and the Elm Road Units. EGUs that burn fossil fuels other than coal, such as Blount, WCCF, and smaller natural gas- and diesel-fueled units are not subject to the ACE rule.

In contrast to the CPP, the ACE rule limits BSER to only "inside the fenceline" heat rate improvement technologies or systems that can be applied at an affected coal-fired EGU. Under ACE, states have the primary role in developing standards of performance that result from the application of BSER. The EPA has not provided a standard of performance that it will deem presumptively acceptable in a state plan, but urges states to provide full justification for each component of their plans so that the EPA can evaluate BSER on a unit-by-unit basis. The ACE rule is subject to a legal challenge pending in the United States District Court of the District of Columbia.

States will have three years to develop and submit compliance plans to the EPA. The EPA will have a year to review and approve the plans. The states are given 24 months from the approval date to implement the rule and can extend the compliance schedule for units that meet progress milestones. EGU's compliance with the ACE rule may not be required until 2024 or later. MGE is currently evaluating how this rule may impact operations. Until the State of Wisconsin develops a plan that is accepted by the EPA, MGE will not be able to determine the final impact of the rule. MGE will continue to evaluate the rule and monitor ongoing and potential legal proceedings associated with the CPP and ACE rules.

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

In May 2018, the EPA issued a final rule which designated the northeast portion of Milwaukee County as being in nonattainment with this NAAQS. The Elm Road Units are located in Milwaukee County, outside the designated nonattainment area. In August 2018, several environmental groups, the City of Chicago, and the State of Illinois filed federal lawsuits challenging several of the EPA's attainment designation decisions, including the partial Milwaukee County designation as being too narrow and not sufficiently protective. MGE is monitoring the outcome of this lawsuit and how it may affect our Elm Road Units in Milwaukee County. At this time, MGE expects that the 2015 Ozone NAAQS will not have a material effect on its existing plants based on final designations.

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

MGE has met its CSAPR obligations in 2018 and 2017 through a combination of reduced emissions through pollution control (e.g. SCR installation at Columbia), as well as owned, received, and purchased allowances. CSAPR has been subject to ongoing legal challenges. In September 2019, the U.S. Court of Appeals upheld the legal argument that the EPA cannot provide a partial remedy to the Clean Air Act's "Good Neighbor Provision" which addresses interstate transport of pollutants from upwind states to downwind states. Under the current rule, the EPA was not holding upwind states to the same attainment deadlines as the downwind states that they impacted. The court indicated that this leniency on the upwind states effectively causes downwind states to miss attainment deadlines or over comply to meet deadlines. The court remanded the rule to the EPA without vacating it. No deadline has been set for the EPA to revise the rule. Wisconsin is considered an upwind state under CSAPR and is potentially impacted by rules that the EPA will develop to address this remand.

MGE will not be able to determine impacts to our operations until rules are promulgated. MGE will continue to monitor developments.

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

•The EPA's Coal Combustion Residuals Rule (CCR), which regulates coal ash from burning coal for the purpose of generating electricity as a solid waste, and defines what ash use activities would be considered generally exempt beneficial reuse of coal ash. The CCR rule also regulates landfills, ash ponds, and other surface impoundments used for coal combustion residuals by regulating their design, location, monitoring, and operation.

Review of the Elm Road Units has indicated that the costs to comply with this rule are not expected to be significant. Columbia's operator has completed a review of their system and has developed a compliance plan. Columbia's operator is also exploring alternative compliance options to meet the rule requirements by the rule's deadline. MGE will continue to monitor the operator's plans for compliance to assess potential impacts on operations.

In July 2018, the EPA published a final rule that included amendments to the CCR (which include the allowance of alternative performance standards for landfills and surface impoundments, revised risk-based groundwater protection standards, and an extension of the deadline by which certain facilities must cease the placement of waste in CCR units). In August 2018, the Court of Appeals for the D.C. Circuit vacated parts of the CCR for not being sufficiently protective of the environment. In August 2019, the EPA introduced a proposed rule that if final would revise some monitoring, corrective action, beneficial reuse, and storage requirements. The revised rule as proposed would not have material impact on MGE. MGE will continue to monitor potential rule modifications to assess potential impacts on operations.

b.Legal Matters - MGE Energy and MGE.

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

c.Purchase Contracts - MGE Energy and MGE.

MGE Energy and MGE have entered into various commodity supply, transportation, and storage contracts to meet their obligations to deliver electricity and natural gas to customers. Management expects to recover these costs in future customer rates. The following table shows future commitments related to purchase contracts as of September 30, 2019:

(In thousands)		2019		2020		2021		2022		2023		Thereafter
Coal(a)	$	7,293		13,120		5,647		2,313		-		-
Natural gas
Transportation and storage(b)		6,258		21,997		21,728		21,728		21,728		55,460
Supply(c)		8,773		10,600		-		-		-		-
Solar farms(d)		509		310		3,024		726		743		32,474
Other		92		928		929		97		99		1,079
	$	22,925	$	46,955	$	31,328	$	24,864	$	22,570	$	89,013

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

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

(c)These commitments include market-based pricing.

(d)In 2019, MGE entered into commitments related to operations of the Two Creeks and Badger Hollow Solar Farms. See Footnote 14 for further information on the solar farm construction.

d.Capital Purchase Commitments - MGE Energy and MGE.

Various contractual obligations contain minimum future commitments related to capital expenditures for certain construction projects, including the Two Creeks solar project and the Badger Hollow Solar Farm. As of September 30, 2019, the Two Creeks and Badger Hollow future minimum construction commitment is $20.5 million and $53.2 million, respectively.

e.Other Commitments - MGE Energy.

In September 2019, MGE Energy entered into a subscription agreement to invest in a nonpublic venture capital fund. From time to time, the fund makes capital calls to its investors. MGE Energy has committed to contribute $10 million in capital for such capital calls. The timing of these capital calls is dependent on the needs of the funds and is therefore uncertain at this time.

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Revenue (Tables)

9 Months Ended

Sep. 30, 2019

Revenue from Contract with Customer [Abstract]

Disaggregation of Revenue

Revenues disaggregated by revenue source were as follows:

		Three Months Ended				Nine Months Ended
(In thousands)		September 30,				September 30,
Electric revenues		2019		2018		2019		2018
Residential	$	42,442	$	42,371	$	107,772	$	107,847
Commercial		63,466		61,638		165,481		159,264
Industrial		3,760		3,668		10,013		11,193
Other-retail/municipal		9,543		9,431		26,728		26,245
Total retail		119,211		117,108		309,994		304,549
Sales to the market		1,163		1,505		3,914		6,334
Other revenues		233		562		978		1,750
Total electric revenues		120,607		119,175		314,886		312,633
Gas revenues
Residential		11,342		11,916		67,659		64,087
Commercial/Industrial		4,825		5,570		40,833		38,728
Total retail		16,167		17,486		108,492		102,815
Gas transportation		1,126		829		3,756		3,018
Other revenues		84		92		299		319
Total gas revenues		17,377		18,407		112,547		106,152
Non-regulated energy revenues		214		213		481		904
Total Operating Revenue	$	138,198	$	137,795		427,914	$	419,689

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Pension and Other Postretirement Plans (Tables)

9 Months Ended

Sep. 30, 2019

Compensation and Retirement Disclosure [Abstract]

Schedule of Net Periodic Benefit Costs

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

		Three Months Ended				Nine Months Ended
		September 30,				September 30,
(In thousands)		2019		2018		2019		2018
Pension Benefits
Components of net periodic benefit cost:
Service cost	$	1,040	$	1,431	$	3,402	$	4,292
Interest cost		3,170		3,215		10,364		9,645
Expected return on assets		(5,054)		(6,560)		(16,523)		(19,680)
Amortization of:
Prior service credit		(26)		(11)		(85)		(33)
Actuarial loss		1,637		1,319		5,351		3,958
Net periodic benefit (credit) cost	$	767	$	(606)	$	2,509	$	(1,818)
Postretirement Benefits
Components of net periodic benefit cost:
Service cost	$	276	$	320	$	829	$	962
Interest cost		721		653		2,164		1,959
Expected return on assets		(677)		(808)		(2,034)		(2,424)
Amortization of:
Transition obligation		1		1		2		2
Prior service credit		(664)		(667)		(1,994)		(2,001)
Actuarial loss		100		122		300		366
Net periodic benefit (credit) cost	$	(243)	$	(379)	$	(733)	$	(1,136)

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Consolidated Statements of Income (Unaudited) - USD ($) shares in Thousands, $ in Thousands	3 Months Ended		9 Months Ended
	Sep. 30, 2019	Sep. 30, 2018	Sep. 30, 2019	Sep. 30, 2018
Operating Revenues:
Electric revenues	$ 120,821	$ 119,388	$ 315,367	$ 313,537
Gas revenue	17,377	18,407	112,547	106,152
Total Operating Revenues	138,198	137,795	427,914	419,689
Operating Expenses:
Fuel for electric generation	15,901	16,793	40,221	43,944
Purchased power	9,126	13,024	31,013	43,036
Cost of gas sold	3,092	4,921	55,220	54,109
Other operations and maintenance	48,070	44,130	143,979	131,976
Depreciation and amortization	18,193	14,259	53,423	41,754
Other general taxes	5,078	4,870	15,026	14,653
Total Operating Expenses	99,460	97,997	338,882	329,472
Operating Income	38,738	39,798	89,032	90,217
Other income, net	5,204	4,330	15,074	13,980
Interest expense, net	(5,831)	(5,025)	(17,227)	(14,547)
Income before income taxes	38,111	39,103	86,879	89,650
Income tax provision	(7,454)	(9,597)	(16,667)	(21,792)
Net Income Including Noncontrolling Interest	30,657	29,506	70,212	67,858
Net Income	$ 30,657	$ 29,506	$ 70,212	$ 67,858
Earnings Per Share of Common Stock (basic and diluted)	$ 0.88	$ 0.85	$ 2.03	$ 1.96
Dividends per share of common stock	$ 0.353	$ 0.338	$ 1.028	$ 0.983
Weighted Average Shares Outstanding (basic and diluted)	34,668	34,668	34,668	34,668
MGE [Member]
Operating Revenues:
Electric revenues	$ 120,821	$ 119,388	$ 315,367	$ 313,537
Gas revenue	17,377	18,407	112,547	106,152
Total Operating Revenues	138,198	137,795	427,914	419,689
Operating Expenses:
Fuel for electric generation	15,901	16,793	40,221	43,944
Purchased power	9,126	13,024	31,013	43,036
Cost of gas sold	3,092	4,921	55,220	54,109
Other operations and maintenance	47,947	43,987	143,282	131,175
Depreciation and amortization	18,193	14,259	53,423	41,754
Other general taxes	5,078	4,870	15,026	14,653
Total Operating Expenses	99,337	97,854	338,185	328,671
Operating Income	38,861	39,941	89,729	91,018
Other income, net	2,672	2,592	7,837	7,402
Interest expense, net	(6,095)	(5,500)	(18,223)	(15,727)
Income before income taxes	35,438	37,033	79,343	82,693
Income tax provision	(6,687)	(9,117)	(14,579)	(19,918)
Net Income Including Noncontrolling Interest	28,751	27,916	64,764	62,775
Less Net Income Attributable to Noncontrolling Interest, net of tax	(5,614)	(5,629)	(16,725)	(16,940)
Net Income	$ 23,137	$ 22,287	$ 48,039	$ 45,835

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Leases (Details-2) - USD ($) $ in Thousands	Sep. 30, 2019	Dec. 31, 2018
Lessee Disclosure [Abstract]
Finance lease assets, net, Property, plant, and equipment, net	$ 16,275
Operating lease assets, Other deferred assets and other	300
Total lease assets	16,575
Finance lease liabilities - current, Other current liabilities	932
Finance lease liabilities - long term, Finance lease liabilities	17,657	$ 1,771
Operating lease liabilities - current, Other current liabilities	143
Operating lease liabilities - long term, Other deferred liabilities and other	185
Total lease liabilities	$ 18,917

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MGE Energy Inc Consolidated Statements of Common Equity (Unaudited) - USD ($) shares in Thousands, $ in Thousands	Total	Common Stock [Member]	Additional Paid-In Capital [Member]	Retained Earnings [Member]	Accumulated Other Comprehensive Income/(Loss) [Member]
Increase (Decrease) In Stockholders' Equity [Roll Forward]
Cumulative effect of new accounting principle	$ 0			$ 377	$ (377)
Beginning balance, shares at Dec. 31, 2017		34,668
Beginning balance, value at Dec. 31, 2017	778,187	$ 34,668	$ 316,268	426,874	377
Beginning balance, value - Adjusted at Dec. 31, 2017	778,187			427,251	0
Increase (Decrease) In Stockholders' Equity [Roll Forward]
Net Income	67,858			67,858
Common stock dividends declared	(34,062)			(34,062)
Ending balance, shares at Sep. 30, 2018		34,668
Ending balance, value at Sep. 30, 2018	811,983	$ 34,668	316,268	461,047	0
Beginning balance, shares at Jun. 30, 2018		34,668
Beginning balance, value at Jun. 30, 2018	794,178	$ 34,668	316,268	443,242	0
Increase (Decrease) In Stockholders' Equity [Roll Forward]
Net Income	29,506			29,506
Common stock dividends declared	(11,701)			(11,701)
Ending balance, shares at Sep. 30, 2018		34,668
Ending balance, value at Sep. 30, 2018	811,983	$ 34,668	316,268	461,047	0
Beginning balance, shares at Dec. 31, 2018		34,668
Beginning balance, value at Dec. 31, 2018	816,644	$ 34,668	316,268	465,708	0
Increase (Decrease) In Stockholders' Equity [Roll Forward]
Net Income	70,212			70,212
Common stock dividends declared	(35,622)			(35,622)
Ending balance, shares at Sep. 30, 2019		34,668
Ending balance, value at Sep. 30, 2019	851,234	$ 34,668	316,268	500,298	0
Beginning balance, shares at Jun. 30, 2019		34,668
Beginning balance, value at Jun. 30, 2019	832,797	$ 34,668	316,268	481,861	0
Increase (Decrease) In Stockholders' Equity [Roll Forward]
Net Income	30,657			30,657
Common stock dividends declared	(12,220)			(12,220)
Ending balance, shares at Sep. 30, 2019		34,668
Ending balance, value at Sep. 30, 2019	$ 851,234	$ 34,668	$ 316,268	$ 500,298	$ 0

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Fair Value of Financial Instruments (Details-3)	9 Months Ended	12 Months Ended
	Sep. 30, 2019	Dec. 31, 2018
Basis adjustment:
Basis adjustment - on peak	92.20%	92.10%
Basis adjustment - off peak	92.80%	92.80%
US Treasury Bill Securities [Member]
Deferred compensation plan [Abstract]
Investment interest calculation, investment maturity period (26 weeks)	182 days
Investment interest calculation, monthly compounding rate	1.00%
Investment interest calculation, minimum annual rate compounded monthly	7.00%
Minimum [Member]
Counterparty fuel mix:
Internal generation	40.00%	50.00%
Purchased power	40.00%	25.00%
Maximum [Member]
Counterparty fuel mix:
Internal generation	60.00%	75.00%
Purchased power	60.00%	50.00%

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Rate Matters (Details) - USD ($)	9 Months Ended	12 Months Ended
	Sep. 30, 2019	Dec. 31, 2020	Dec. 31, 2018	Oct. 31, 2019
Tax Cuts and Jobs Act [Member]
Effects Of The Tax Cuts And Jobs Act [Abstract]
Return of tax credit	$ 3,200,000		$ 8,200,000
PSCW [Member] | MGE [Member]
Rate Proceedings [Abstract]
Authorized return on equity, percentage	9.80%	9.80%
Approved equity capital structure, percentage	56.60%	56.10%
Fuel Rules [Abstract]
Fuel rules, bandwidth	2.00%
Fuel rules, electric fuel deferred costs upper threshold	102.00%
Fuel rules, electric fuel deferred costs lower threshold	98.00%
Deferred fuel rules monitored costs	$ 500,000		9,500,000
Public Utilities Fuel Surcharge Amount			$ 500,000
Public Utilities Fuel Surcharge Percentage			0.13%
PSCW [Member] | MGE [Member] | Fuel Rules Refund, 2018 [Member] | Subsequent Event [Member]
Fuel Rules [Abstract]
Electric fuel credit ($)				$ 9,500,000
Electric Rate Proceeding [Member] | PSCW [Member] | MGE [Member]
Rate Proceedings [Abstract]
Authorized rate increase (decrease), percentage	(2.24%)	0.00%
Authorized rate increase (decrease), amount	$ (9,200,000)
Gas Rate Proceeding [Member] | PSCW [Member] | MGE [Member]
Rate Proceedings [Abstract]
Authorized rate increase (decrease), percentage	1.06%	1.46%
Authorized rate increase (decrease), amount	$ 1,700,000	$ 2,400,000

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Derivative and Hedging Instruments (Details-4) - USD ($) $ in Thousands	3 Months Ended		9 Months Ended
	Sep. 30, 2019	Sep. 30, 2018	Sep. 30, 2019	Sep. 30, 2018
Current and Long-Term Regulatory Asset [Member]
Change In Derivative Fair Value [Roll Forward]
Beginning balance,	$ 33,515	$ 36,924	$ 31,830	$ 41,958
Unrealized loss (gain)	(4,560)	(2,007)	(2,256)	(5,906)
Realized (loss) gain reclassified to a deferred account	(411)	(316)	(1,402)	(837)
Realized gain (loss) reclassified to income statement	638	29	1,010	(585)
Ending balance,	29,182	34,630	29,182	34,630
Other Current Assets [Member]
Change In Derivative Fair Value [Roll Forward]
Beginning balance,	878	640	377	806
Unrealized loss (gain)	0	0	0	0
Realized (loss) gain reclassified to a deferred account	411	316	1,402	837
Realized gain (loss) reclassified to income statement	(258)	(62)	(748)	(749)
Ending balance,	$ 1,031	$ 894	$ 1,031	$ 894

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Investment in ATC and ATC Holdco (Details-2) - USD ($) $ in Thousands	3 Months Ended		9 Months Ended
	Sep. 30, 2019	Sep. 30, 2018	Sep. 30, 2019	Sep. 30, 2018	Dec. 31, 2018
ATC [Member]
Schedule Of Equity Method Investments [Line Items]
Operating revenues	$ 184,833	$ 170,341	$ 544,760	$ 501,276
Operating expenses	(94,713)	(87,959)	(278,673)	(264,326)
Other income, net	484	439	1,031	2,070
Interest expense, net	(29,165)	(27,754)	(87,121)	(82,411)
Earnings before members' income taxes	61,439	55,067	179,997	156,609
ATC [Member]
Related Party Transaction [Line Items]
Related party expenses	7,600	$ 7,200	22,800	$ 21,700
Due from related parties	$ 1,600		$ 1,600		$ 100

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Leases (Details-4)	Sep. 30, 2019
Lessee Disclosure [Abstract]
Weighted average remaining lease term (years) finance leases	38 years
Weighted average remaining lease term (years) operating leases	5 years
Weighted average disocunt rate finance leases	4.36%
Weighted average disocunt rate operating leases	3.58%

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Share Based Compensation (Details) - Performance Units [Member] - USD ($) $ in Millions	1 Months Ended	3 Months Ended		9 Months Ended
	Jan. 31, 2019	Sep. 30, 2019	Sep. 30, 2018	Sep. 30, 2019	Sep. 30, 2018
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Compensation expense		$ 0.9	$ 0.3	$ 2.8	$ 1.3
Cash payments distributed related to awards previously granted and now payable	$ 1.5
Awards forfeited during period, value		$ 0.0	$ 0.0	$ 0.0	$ 0.0
Awards forfeited during period, units		0	0	0	0
Outstanding awards vested during period				$ 6.2
Director Incentive Agreement [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Awards granted during period (in units)				5,175
Award vesting period				3 years
Performance Unit Plan [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Awards granted during period (in units)				17,022
Award vesting period				5 years

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Joint Plant Ownership (Details) - MGE [Member]	Sep. 30, 2019 USD ($) MW
Two Creeks Units [Member]
Jointly Owned Utility Plant Interests [Line Items]
Jointly owned utility plant, ownership interest	33.00%
Jointly owned utility plant, plant capacity (in MW) | MW	150
Projected Solar Farm Project Costs	$ 65,000,000
Public Utilities Property Plant And Equipment Construction Work In Progress	$ 42,100,000
Badger Hollow Units [Member]
Jointly Owned Utility Plant Interests [Line Items]
Jointly owned utility plant, ownership interest	33.00%
Jointly owned utility plant, plant capacity (in MW) | MW	150
Projected Solar Farm Project Costs	$ 65,000,000
Public Utilities Property Plant And Equipment Construction Work In Progress	$ 10,000,000.0

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Taxes (Tables)

9 Months Ended

Sep. 30, 2019

Income Tax Disclosure [Abstract]

Effective Tax Rate Reconciliation

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

	MGE Energy				MGE
Three Months Ended September 30,	2019		2018		2019		2018
Statutory federal income tax rate	21.0	%	21.0	%	21.0	%	21.0	%
State income taxes, net of federal benefit	6.3		6.3		6.2		6.2
Amortized investment tax credits	(0.1)		(0.1)		(0.1)		(0.1)
Credit for electricity from wind energy(a)	(4.8)		(0.3)		(5.2)		(0.2)
AFUDC equity, net	(0.4)		(0.6)		(0.4)		(0.6)
Amortization of utility excess deferred tax - tax reform(b)	(1.9)		(1.8)		(2.1)		(1.8)
Other, net, individually insignificant	(0.5)		-		(0.5)		0.1
Effective income tax rate	19.6	%	24.5	%	18.9	%	24.6	%
	MGE Energy				MGE
Nine Months Ended September 30,	2019		2018		2019		2018
Statutory federal income tax rate	21.0	%	21.0	%	21.0	%	21.0	%
State income taxes, net of federal benefit	6.3		6.3		6.2		6.2
Amortized investment tax credits	(0.1)		(0.1)		(0.1)		(0.1)
Credit for electricity from wind energy(a)	(5.6)		(0.3)		(6.1)		(0.3)
AFUDC equity, net	(0.3)		(0.8)		(0.3)		(0.8)
Amortization of utility excess deferred tax - tax reform(b)	(2.2)		(1.8)		(2.4)		(2.0)
Other, net, individually insignificant	0.1		-		0.1		0.1
Effective income tax rate	19.2	%	24.3	%	18.4	%	24.1	%

(a)Saratoga Wind Farm became operational in February 2019.

(b)Included are impacts of the Tax Cuts and Jobs Act for the regulated utility for excess deferred taxes recognized using a normalization method of accounting. For the three and nine months ended September 30, 2019, MGE recognized $0.6 million and $1.7 million, respectively, compared to $0.5 million and $1.4 million for the comparable periods in 2018. The amount and timing of the cash impacts will depend on the period over which certain income tax benefits are provided to customers, as determined by the PSCW.

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Asset Retirement Obligation

9 Months Ended

Sep. 30, 2019

Asset Retirement Obligation Disclosure [Abstract]

Asset Retirement Obligation

Asset Retirement Obligation - MGE Energy and MGE.

A liability for the fair value of an asset retirement obligation (ARO) is recognized in the period in which it is incurred if it can be reasonably estimated. The offsetting associated asset retirement costs are capitalized as a long-lived asset and depreciated over the asset's useful life.As of September 30, 2019, MGE recorded an obligation of $1.5 million for the fair value of its legal liability for an ARO associated with the Saratoga Wind Farm. MGE has regulatory treatment and recognizes regulatory assets or liabilities for the timing differences between when we recover legal AROs in rates and when those costs would actually be recognized.

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Significant Accounting Policies (Policies)

9 Months Ended

Sep. 30, 2019

Accounting Policies [Abstract]

Variable Interest Entities

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

New Accounting Pronouncements Disclosure

New Accounting Standards - MGE Energy and MGE.

Recently Adopted

Leases.

In February 2016, the FASB issued authoritative guidance within the codification's Leases topic that provides guidance on the classification, recognition, measurement, and disclosure of leases. The new leasing standard establishes that a lease conveys the right to control the use of identified property, plant, or equipment for a period of time in exchange for consideration. Under the new guidance, lessees are required to recognize all leases with terms greater than one year, including operating leases, on the balance sheet by recording a right-of-use asset and lease liability. Prior to the authoritative guidance, only capital leases were recognized on the balance sheet by lessees. The new accounting guidance, as applied by lessors, did not change materially. In January 2018, the FASB issued authoritative guidance which provided an optional

practical expedient to grandfather the accounting for existing and expired land easements not accounted for as a lease under the new authoritative guidance. MGE Energy and MGE adopted this practical expedient.

The lease authoritative guidance became effective January 1, 2019. MGE Energy and MGE adopted the standard upon the effective date. In compliance with authorized transition guidance, MGE Energy and MGE began applying the new standard on January 1, 2019, but will continue to present periods prior to that date according to the previous authoritative standard. There was no material impact on the consolidated net income or cash flows. See Footnote 3 for further lease information.

Leases

As part of its regular operations, MGE enters into various contracts related to IT equipment, substations, cell towers, land, wind easements, and other property in use for operations. A contract is or contains a lease if the contract conveys the right to control the use of identified property, plant, or equipment for a period of time in exchange for consideration. Determination as to whether an arrangement is or contains a lease is completed at inception. Leases with an initial term of 12 months or less are not recorded on the consolidated balance sheets; lease expense for these leases are recognized on a straight-line basis over the lease term. Leases with initial terms in excess of 12 months are recorded as operating or financing leases on the consolidated balance sheets.

Operating lease assets and operating lease liabilities are recognized based on the present value of the future minimum lease payments over the lease term at commencement date. For leases that do not provide an implicit rate, a collateralized incremental borrowing rate based on the information available at commencement date, including lease term, is used in determining the present value of future payments. The operating lease asset also includes any lease payments made and excludes lease incentives and initial direct costs incurred. Lease terms may include options to extend or terminate the lease when it is reasonably certain that the option will be exercised. Operating lease expense is recognized on a straight-line basis over the lease term. MGE has regulatory treatment and recognizes regulatory assets or liabilities for timing differences between when net lease costs are recorded and when costs are recognized. As of September 30, 2019, MGE has no significant leases not yet commenced that would create significant future rights and obligations.

Investments - ATC and ATC Holdco

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

Pension and Other Postretirement Benefit Plan Assets

MGE maintains qualified and nonqualified pension plans, health care, and life insurance benefits. Additionally, MGE has defined contribution 401(k) benefit plans.

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. The service cost component of net periodic benefit cost is eligible for capitalization within the consolidated balance sheets. MGE has regulatory treatment and recognizes regulatory assets or liabilities for timing differences between when net periodic benefit costs are recovered and when costs are recognized.

Common Stock

MGE Energy sells shares of its common stock through its Stock Plan. Those shares may be newly issued shares or shares that MGE Energy has purchased in the open market for resale to participants in the Stock Plan. All sales under the Stock Plan are covered by a shelf registration statement that MGE Energy filed with the SEC.

Share-based Compensation

Under MGE Energy's Director Incentive Plan and its Performance Unit Plan, non-employee directors and eligible employees, respectively, may receive performance units that entitle the holder to receive a cash

payment equal to the value of a designated number of shares of MGE Energy's common stock, plus dividend equivalent payments thereon, at the end of the performance period set in the award.

In 2019, 5,175 units were granted under the Director Incentive Plan and are subject to a three-year graded vesting schedule, and 17,022 units were granted under the Performance Unit Plan and are subject to a five-year graded vesting schedule. On the grant date, the cost of the director or employee services received in exchange for a performance unit award is measured based on the current market value of MGE Energy common stock. The fair value of the awards is remeasured quarterly, including as of September 30, 2019, as required by applicable accounting standards. Changes in fair value as well as the original grant are recognized as compensation cost. Since this amount is remeasured throughout the vesting period, the compensation cost is subject to variability.

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

Wisconsin Fuel Rules

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

Derivative Hedging

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

Derivative Netting

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

Recurring Fair Value Measurements

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

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

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

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

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

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

The deferred compensation plan allows participants to defer certain cash compensation into a notional investment account. These amounts are included within other deferred liabilities in the consolidated balance sheets. The notional investments earn interest based upon the semiannual rate of U.S. Treasury Bills having a 26-week maturity increased by 1% compounded monthly with a minimum annual rate of 7%, compounded monthly. The notional investments are based upon observable market data, however, since the deferred compensation obligations themselves are not exchanged in an active market, they are classified as Level 2.

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

The purchased power agreement (see Footnote 11) was valued using an internally-developed pricing model and therefore is classified as Level 3. The model projects future market energy prices and compares those prices to the projected power costs to be incurred under the contract. Inputs to the model require significant management judgment and estimation. Future energy prices are based on a forward power pricing curve using exchange-traded contracts in the electric futures market. A basis adjustment is applied to the market energy price to reflect the price differential between the market price delivery point and the counterparty delivery point. The historical relationship between the delivery points is reviewed and a discount (below 100%) or premium (above 100%) is derived. This comparison is done for both peak times when demand is high and off-peak times when demand is low. If the basis adjustment is lowered, the fair value measurement will decrease, and if the basis adjustment is increased, the fair value measurement will increase.

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

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

	Model Input
Significant Unobservable Inputs	September 30, 2019		December 31, 2018
Basis adjustment:
On peak	92.2	%	92.1	%
Off peak	92.8	%	92.8	%
Counterparty fuel mix:
Internal generation	40.0% - 60.0	%	50.0% - 75.0	%
Purchased power	60.0% - 40.0	%	50.0% - 25.0	%

Asset Retirement Obligations

A liability for the fair value of an asset retirement obligation (ARO) is recognized in the period in which it is incurred if it can be reasonably estimated. The offsetting associated asset retirement costs are capitalized as a long-lived asset and depreciated over the asset's useful life.

Revenue Recognition

Performance Obligations

A performance obligation is a promise in a contract to transfer a distinct good or service to the customer and is the unit of account. A contract's transaction price is allocated to each distinct performance obligation and recognized as revenue when, or as, the performance obligation is satisfied. The majority of MGE Energy's and MGE's contracts have a single performance obligation.

Retail Revenue (Residential, Commercial, Industrial, and Other Retail/Municipal)

Retail revenue of electric and gas utility service represent MGE's core business activities. Tariffs are approved by the PSCW through a rate order and provide MGE's customers with the standard terms and conditions, including pricing terms. The performance obligation to deliver electricity or gas is satisfied over time as the customer simultaneously receives and consumes the commodities provided by MGE. MGE recognizes revenues as the commodity is delivered to customers. Meters are read on a systematic basis throughout the month based on established meter-reading schedules and the customer is subsequently billed for their services. At the end of the month, MGE accrues an estimate for the unbilled amount of commodities delivered to customers. The unbilled revenue estimate is based on daily system demand volumes, weather factors, estimated line losses, estimated customer usage by class, and applicable customer rates.

Utility Cost Recovery Mechanisms

MGE's tariff rates include a provision for fuel cost recovery. The PSCW allows Wisconsin utilities to defer electric fuel-related costs, less excess revenues, that fall outside a symmetrical cost tolerance band. Any over/under recovery of the actual costs in a given year is determined in the following year and is then

reflected in future billings to electric retail customers. Over-collection of fuel-related costs that are outside the approved range will be recognized as a reduction of revenue. Under-collection of these costs will be recognized in "Purchased power" expense in the consolidated statements of income. The cumulative effects of these deferred amounts will be recorded in "Regulatory assets" or "Regulatory liabilities" on the consolidated balance sheets until they are reflected in future billings to customers. See Footnote 10.b. for further information.

MGE received a PSCW order in January 2018 to defer the over-collection of income tax expense collected in customer rates during 2018 as a result of the Tax Cuts and Jobs Act (the Tax Act) reduction in the income tax rate to 21 percent. See Footnote 10.c. for further information.

MGE has other cost recovery mechanisms. For example, any over-collection of the difference between actual costs incurred and the amount of costs collected from customers is recorded as a reduction of revenue in the period incurred.

Sales to the Market

Sales to the market include energy charges, capacity or demand charges, and ancillary charges represented by wholesale sales of electricity made to third parties who are not ultimate users of the electricity. Most of these sales are spot market transactions on the markets operated by MISO. Each transaction is considered a performance obligation and revenue is recognized in the period in which energy charges, capacity or demand charges, and ancillary services are sold into MISO. MGE reports, on a net basis, transactions on the MISO markets in which it buys and sells power within the same hour to meet electric energy delivery requirements.

Transportation of Gas

MGE has contracts under which MGE provides gas transportation services to customers who have elected to purchase gas from a third party and have the gas delivered via pipelines within MGE's service territory. Revenue is recognized as service is rendered or gas is delivered to customers. Tariffs are approved by the PSCW through a rate order and provide gas transportation customers with the standard terms and conditions, including pricing terms.

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Summary of Significant Accounting Principles (Details-1) - USD ($)	Sep. 30, 2019	Dec. 31, 2018	Sep. 30, 2018	Dec. 31, 2017
Cash Cash Equivalents And Restricted Cash [Line Items]
Cash and cash equivalents	$ 61,112,000	$ 83,102,000
Restricted cash	532,000	634,000
Receivable - margin account	1,598,000	1,193,000
Cash, cash equivalents, and restricted cash	63,242,000	84,929,000	$ 135,041,000	$ 112,094,000
MGE [Member]
Cash Cash Equivalents And Restricted Cash [Line Items]
Cash and cash equivalents	4,656,000	4,843,000
Restricted cash	532,000	634,000
Receivable - margin account	1,598,000	1,193,000
Cash, cash equivalents, and restricted cash	$ 6,786,000	$ 6,670,000	$ 48,450,000	$ 10,093,000

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Consolidated Statements of Common Equity (Unaudited) (Parentheticals) - $ / shares	3 Months Ended		9 Months Ended
	Sep. 30, 2019	Sep. 30, 2018	Sep. 30, 2019	Sep. 30, 2018
Consolidated Statements of Common Equity
Dividends per share of common stock	$ 0.353	$ 0.338	$ 1.028	$ 0.983

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Derivative and Hedging Instruments (Tables)

9 Months Ended

Sep. 30, 2019

Derivative Instruments and Hedging Activities Disclosure [Abstract]

Gross Notional Volume of Open Derivatives

The gross notional volume of open derivatives is as follows:

	September 30, 2019		December 31, 2018
Commodity derivative contracts	466,760	MWh	386,440	MWh
Commodity derivative contracts	9,190,000	Dth	5,260,000	Dth
FTRs	4,282	MW	2,252	MW
PPA	1,600	MW	2,050	MW

Fair Value of Derivative Instruments on the Balance Sheet

The following table summarizes the fair value of the derivative instruments on the consolidated balance sheets. All derivative instruments in this table are presented on a gross basis and are calculated prior to the netting of instruments with the same counterparty under a master netting agreement as well as the netting of collateral. For financial statement purposes, instruments are netted with the same counterparty under a master netting agreement as well as the netting of collateral. As of September 30, 2019, and December 31, 2018, the receivable margin account balance of $1.6 million and $1.2 million, respectively, is shown net of any collateral posted against derivative positions.

		Derivative		Derivative
(In thousands)		Assets		Liabilities	Balance Sheet Location
September 30, 2019
Commodity derivative contracts	$	668	$	996	Other current assets(a)
Commodity derivative contracts		81		289	Other deferred charges(a)
FTRs		344		-	Other current assets
PPA		N/A		10,390	Derivative liability (current)
PPA		N/A		18,600	Derivative liability (long-term)
December 31, 2018
Commodity derivative contracts	$	727	$	270	Other current assets
Commodity derivative contracts		74		72	Other deferred charges
FTRs		241		-	Other current assets
PPA		N/A		8,550	Derivative liability (current)
PPA		N/A		23,980	Derivative liability (long-term)

(a)As of September 30, 2019, collateral of $0.7 million was posted against and netted with derivative liability positions on the consolidated balance sheets. No collateral was posted against derivative positions as of December 31, 2018.

Offsetting Assets

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

Offsetting of Derivative Assets
(In thousands)		Gross Amounts		Gross Amounts Offset in Balance Sheets		Collateral Posted Against Derivative Positions		Net Amount Presented in Balance Sheets
September 30, 2019
Commodity derivative contracts	$	749	$	(561)	$	-	$	188
FTRs		344		-		-		344
December 31, 2018
Commodity derivative contracts	$	801	$	(342)	$	-	$	459
FTRs		241		-		-		241

Offsetting Liabilities

Offsetting of Derivative Liabilities
(In thousands)		Gross Amounts		Gross Amounts Offset in Balance Sheets		Collateral Posted Against Derivative Positions		Net Amount Presented in Balance Sheets
September 30, 2019
Commodity derivative contracts	$	1,285	$	(561)	$	(724)	$	-
PPA		28,990		-		-		28,990
December 31, 2018
Commodity derivative contracts	$	342	$	(342)	$	-	$	-
PPA		32,530		-		-		32,530

Derivative Gains and Losses in Balance Sheet

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

		2019				2018
(In thousands)		Current and Long-Term Regulatory Asset		Other Current Assets		Current and Long-Term Regulatory Asset		Other Current Assets
Three Months Ended September 30:
Balance at July 1,	$	33,515	$	878	$	36,924	$	640
Unrealized gain		(4,560)		-		(2,007)		-
Realized (loss) gain reclassified to a deferred account		(411)		411		(316)		316
Realized gain (loss) reclassified to income statement		638		(258)		29		(62)
Balance as of September 30,	$	29,182	$	1,031	$	34,630	$	894
Nine Months Ended September 30:
Balance at January 1,	$	31,830	$	377	$	41,958	$	806
Unrealized gain		(2,256)		-		(5,906)		-
Realized (loss) gain reclassified to a deferred account		(1,402)		1,402		(837)		837
Realized gain (loss) reclassified to income statement		1,010		(748)		(585)		(749)
Balance as of September 30,	$	29,182	$	1,031	$	34,630	$	894

Derivative Gains and Losses in Income Statement

		Realized Losses (Gains)
		2019				2018
(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	$	471	$	83	$	(145)	$	-
FTRs		(429)		-		(150)		-
PPA		(505)		-		328		-
Nine Months Ended September 30:
Commodity derivative contracts	$	1,038	$	460	$	39	$	637
FTRs		(503)		-		(625)		-
PPA		(1,257)		-		1,283		-

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Consolidated Balance Sheets (Unaudited) - USD ($)	Sep. 30, 2019	Dec. 31, 2018
Current Assets:
Cash and cash equivalents	$ 61,112,000	$ 83,102,000
Accounts receivable, less reserves	35,805,000	43,593,000
Other accounts receivables, less reserves	7,867,000	6,262,000
Unbilled revenues	20,926,000	28,243,000
Materials and supplies, at average cost	28,019,000	24,093,000
Fuel for electric generation, at average cost	8,339,000	6,599,000
Stored natural gas, at average cost	11,402,000	11,303,000
Prepaid taxes	11,518,000	16,215,000
Regulatory assets - current	10,777,000	9,477,000
Assets held for sale	0	3,080,000
Other current assets	8,631,000	8,593,000
Total Current Assets	204,396,000	240,560,000
Other long-term receivables	2,343,000	2,709,000
Regulatory assets	144,482,000	145,424,000
Other deferred assets and other	17,096,000	12,488,000
Property, Plant, and Equipment:
Property, plant, and equipment, net	1,524,925,000	1,369,766,000
Construction work in progress	88,050,000	139,671,000
Total Property, Plant, and Equipment	1,612,975,000	1,509,437,000
Investments	85,681,000	78,000,000
Total Assets	2,066,973,000	1,988,618,000
Current Liabilities:
Long-term debt due within one year	4,632,000	4,553,000
Short-term debt	54,500,000	13,000,000
Accounts payable	39,139,000	46,158,000
Accrued interest and taxes	5,570,000	7,384,000
Accrued payroll related items	11,090,000	13,044,000
Regulatory liabilities - current	15,606,000	13,826,000
Derivative liabilities	10,390,000	8,550,000
Other current liabilities	11,124,000	14,113,000
Total Current Liabilities	152,051,000	120,628,000
Other Credits:
Deferred income taxes	239,433,000	231,952,000
Investment tax credit - deferred	786,000	818,000
Regulatory liabilities	162,088,000	165,638,000
Accrued pension and other postretirement benefits	64,274,000	67,483,000
Derivative liabilities	18,600,000	23,980,000
Finance lease liabilities	17,657,000	1,771,000
Other deferred liabilities and other	70,691,000	66,361,000
Total Other Credits	573,529,000	558,003,000
Capitalization:
Common shareholders equity	851,234,000	816,644,000
Long-term debt	490,159,000	493,343,000
Total Capitalization	1,341,393,000	1,309,987,000
Commitments and contingencies (see Footnote 9)
Total Liabilities and Capitalization	2,066,973,000	1,988,618,000
MGE [Member]
Current Assets:
Cash and cash equivalents	4,656,000	4,843,000
Accounts receivable, less reserves	35,805,000	43,593,000
Affiliate receivables	540,000	621,000
Other accounts receivables, less reserves	7,863,000	6,111,000
Unbilled revenues	20,926,000	28,243,000
Materials and supplies, at average cost	28,019,000	24,093,000
Fuel for electric generation, at average cost	8,339,000	6,599,000
Stored natural gas, at average cost	11,402,000	11,303,000
Prepaid taxes	11,211,000	15,790,000
Regulatory assets - current	10,777,000	9,477,000
Assets held for sale	0	3,080,000
Other current assets	8,522,000	8,541,000
Total Current Assets	148,060,000	162,294,000
Affiliate receivable long-term	2,780,000	3,177,000
Regulatory assets	144,482,000	145,424,000
Other deferred assets and other	18,178,000	14,142,000
Property, Plant, and Equipment:
Property, plant, and equipment, net	1,524,954,000	1,369,795,000
Construction work in progress	88,050,000	139,671,000
Total Property, Plant, and Equipment	1,613,004,000	1,509,466,000
Investments	523,000	388,000
Total Assets	1,927,027,000	1,834,891,000
Current Liabilities:
Long-term debt due within one year	4,632,000	4,553,000
Short-term debt	54,500,000	13,000,000
Accounts payable	39,104,000	46,165,000
Accrued interest and taxes	7,901,000	10,319,000
Accrued payroll related items	11,090,000	13,044,000
Regulatory liabilities - current	15,606,000	13,826,000
Derivative liabilities	10,390,000	8,550,000
Other current liabilities	11,125,000	11,614,000
Total Current Liabilities	154,348,000	121,071,000
Other Credits:
Deferred income taxes	210,886,000	204,616,000
Investment tax credit - deferred	786,000	818,000
Regulatory liabilities	162,088,000	165,638,000
Accrued pension and other postretirement benefits	64,274,000	67,483,000
Derivative liabilities	18,600,000	23,980,000
Finance lease liabilities	17,657,000	1,771,000
Other deferred liabilities and other	70,655,000	66,361,000
Total Other Credits	544,946,000	530,667,000
Capitalization:
Common shareholders equity	596,395,000	548,356,000
Noncontrolling interest	141,179,000	141,454,000
Total Equity	737,574,000	689,810,000
Long-term debt	490,159,000	493,343,000
Total Capitalization	1,227,733,000	1,183,153,000
Commitments and contingencies (see Footnote 9)
Total Liabilities and Capitalization	$ 1,927,027,000	$ 1,834,891,000

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Leases

9 Months Ended

Sep. 30, 2019

Leases [Abstract]

Leases

Leases - MGE Energy and MGE.

As part of its regular operations, MGE enters into various contracts related to IT equipment, substations, cell towers, land, wind easements, and other property in use for operations. A contract is or contains a lease if the contract conveys the right to control the use of identified property, plant, or equipment for a period of time in exchange for consideration. Determination as to whether an arrangement is or contains a lease is completed at inception. Leases with an initial term of 12 months or less are not recorded on the consolidated balance sheets; lease expense for these leases are recognized on a straight-line basis over the lease term. Leases with initial terms in excess of 12 months are recorded as operating or financing leases on the consolidated balance sheets.

Operating lease assets and operating lease liabilities are recognized based on the present value of the future minimum lease payments over the lease term at commencement date. For leases that do not provide an implicit rate, a collateralized incremental borrowing rate based on the information available at commencement date, including lease term, is used in determining the present value of future payments. The operating lease asset also includes any lease payments made and excludes lease incentives and initial direct costs incurred. Lease terms may include options to extend or terminate the lease when it is reasonably certain that the option will be exercised. Operating lease expense is recognized on a straight-line basis over the lease term. MGE has regulatory treatment and recognizes regulatory assets or liabilities for timing differences between when net lease costs are recorded and when costs are recognized. As of September 30, 2019, MGE has no significant leases not yet commenced that would create significant future rights and obligations.

The following table shows lease expense for the three and nine months ended September 30, 2019:

(In thousands)		Three Months Ended		Nine Months Ended	Income Statement Location
Finance lease expense:
Amortization of leased assets	$	425	$	1,295	Depreciation and amortization
Interest on lease liabilities		199		597	Interest expense, net
Operating lease expense		32		92	Other operations and maintenance
Total lease expense	$	656	$	1,984

The following table shows the lease assets and liabilities on the consolidated balance sheet as of September 30, 2019:

(In thousands)			Balance Sheet Location
Lease assets:
Finance lease assets	$	16,275	Property, plant, and equipment, net
Operating lease assets		300	Other deferred assets and other
Total lease assets	$	16,575
Lease liabilities:
Finance lease liabilities - current	$	932	Other current liabilities
Finance lease liabilities - long-term		17,657	Finance lease liabilities
Operating lease liabilities - current		143	Other current liabilities
Operating lease liabilities - long-term		185	Other deferred liabilities and other
Total lease liabilities	$	18,917

The following table shows other financial lease information for the nine months ended September 30, 2019:

(In thousands)
Cash paid for amounts included in the measurement of lease liabilities:
Finance leases - Financing cash flows	$	781
Finance leases - Operating cash flows		597
Operating leases - Operating cash flows		108
Lease assets obtained in exchange for lease liabilities:
Finance leases		12,081
Operating leases		239

The following table shows the weighted average remaining lease terms and discounts as of September 30, 2019:

Weighted-average remaining lease terms (in years):
Finance leases	38
Operating leases	5
Weighted-average discount rates:
Finance leases	4.36	%
Operating leases	3.58	%

The following table shows maturities of lease liabilities as of September 30, 2019:

(In thousands)		Finance		Operating
2019	$	539	$	37
2020		1,644		152
2021		1,428		86
2022		1,309		33
2023		1,228		2
Thereafter		41,317		52
Subtotal		47,465		362
Less: Present value discount		(28,876)		(34)
Lease Liability	$	18,589	$	328

Future minimum rental payments as of December 31, 2018, under agreements classified as operating leases with noncancelable terms in excess of one year are as follows:

(In thousands)		2019		2020		2021		2022		2023		Thereafter
Minimum lease payments	$	1,646	$	1,371	$	1,095	$	989	$	975	$	22,707

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Equity and Financing Arrangements

9 Months Ended

Sep. 30, 2019

Equity and Financing Arrangements Disclosure [Abstract]

Equity and Financing Arrangements

Equity and Financing Arrangements.

a.Common Stock - MGE Energy.

MGE Energy sells shares of its common stock through its Stock Plan. Those shares may be newly issued shares or shares that MGE Energy has purchased in the open market for resale to participants in the Stock Plan. All sales under the Stock Plan are covered by a shelf registration statement that MGE Energy filed with the SEC. For both the three and nine months ended September 30, 2019 and 2018, MGE Energy did not issue and new shares of common stock under the Stock Plan.

b.Dilutive Shares Calculation - MGE Energy.

MGE Energy does not have any stock option or stock award programs or any dilutive securities.

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

In August 2019, MGE entered into a Note Purchase Agreement for $50 million of new long-term unsecured debt carrying an interest rate of 2.94% per annum over its 10-year life. Funding occurred on November 5, 2019. The proceeds of the debt financing will be used to assist with capital expenditures, maturing short-term debt, and other corporate obligations. The covenants of this debt are substantially consistent with MGE's existing unsecured long-term debt.

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Derivative and Hedging Instruments

9 Months Ended

Sep. 30, 2019

Derivative Instruments and Hedging Activities Disclosure [Abstract]

Derivative and Hedging Instruments

Derivative and Hedging Instruments - MGE Energy and MGE.

a.Purpose.

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

b.Notional Amounts.

The gross notional volume of open derivatives is as follows:

	September 30, 2019		December 31, 2018
Commodity derivative contracts	466,760	MWh	386,440	MWh
Commodity derivative contracts	9,190,000	Dth	5,260,000	Dth
FTRs	4,282	MW	2,252	MW
PPA	1,600	MW	2,050	MW

c.Financial Statement Presentation.

MGE purchases and sells exchange-traded and over-the-counter options, swaps, and future contracts. These arrangements are primarily entered into to help stabilize the price risk associated with gas or power purchases. These transactions are employed by both MGE's gas and electric segments. Additionally, as a result of the firm transmission agreements that MGE holds on electricity transmission paths in the MISO market, MGE holds financial transmission rights (FTRs). An FTR is a financial instrument that entitles the holder to a stream of revenues or charges based on the differences in hourly day-ahead energy prices between two points on the transmission grid. The fair values of these instruments are offset with a corresponding regulatory asset/liability depending on whether they are in a net loss/gain position. Depending on the nature of the instrument, the gain or loss associated with these transactions will be reflected as cost of gas sold, fuel for electric generation, or purchased power expense in the delivery month applicable to the instrument. As of September 30, 2019, the cost basis of exchange traded derivatives and FTRs exceeded their fair value by $0.2 million. As of December 31, 2018, the fair value of exchange traded derivatives and FTRs exceeded their cost basis by $0.7 million.

MGE is a party to a purchased power agreement that provides MGE with firm capacity and energy during a base term from June 1, 2012, through May 31, 2022. The agreement also allows MGE an option to extend the contract after the base term. The agreement is accounted for as a derivative contract and is recognized at its fair value on the consolidated balance sheets. However, the derivative qualifies for regulatory deferral and is recognized with a corresponding regulatory asset or liability depending on whether the fair value is in a loss or gain position. The fair value of the contract as of September 30, 2019, and December 31, 2018, reflects a loss position of $29.0 million and $32.5 million, respectively. The actual cost will be recognized in purchased power expense in the month of purchase.

The following table summarizes the fair value of the derivative instruments on the consolidated balance sheets. All derivative instruments in this table are presented on a gross basis and are calculated prior to the netting of instruments with the same counterparty under a master netting agreement as well as the netting of collateral. For financial statement purposes, instruments are netted with the same counterparty under a master netting agreement as well as the netting of collateral. As of September 30, 2019, and December 31, 2018, the receivable margin account balance of $1.6 million and $1.2 million, respectively, is shown net of any collateral posted against derivative positions.

		Derivative		Derivative
(In thousands)		Assets		Liabilities	Balance Sheet Location
September 30, 2019
Commodity derivative contracts	$	668	$	996	Other current assets(a)
Commodity derivative contracts		81		289	Other deferred charges(a)
FTRs		344		-	Other current assets
PPA		N/A		10,390	Derivative liability (current)
PPA		N/A		18,600	Derivative liability (long-term)
December 31, 2018
Commodity derivative contracts	$	727	$	270	Other current assets
Commodity derivative contracts		74		72	Other deferred charges
FTRs		241		-	Other current assets
PPA		N/A		8,550	Derivative liability (current)
PPA		N/A		23,980	Derivative liability (long-term)

(a)As of September 30, 2019, collateral of $0.7 million was posted against and netted with derivative liability positions on the consolidated balance sheets. No collateral was posted against derivative positions as of December 31, 2018.

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, 2019
Commodity derivative contracts	$	749	$	(561)	$	-	$	188
FTRs		344		-		-		344
December 31, 2018
Commodity derivative contracts	$	801	$	(342)	$	-	$	459
FTRs		241		-		-		241

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, 2019
Commodity derivative contracts	$	1,285	$	(561)	$	(724)	$	-
PPA		28,990		-		-		28,990
December 31, 2018
Commodity derivative contracts	$	342	$	(342)	$	-	$	-
PPA		32,530		-		-		32,530

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.

		2019				2018
(In thousands)		Current and Long-Term Regulatory Asset		Other Current Assets		Current and Long-Term Regulatory Asset		Other Current Assets
Three Months Ended September 30:
Balance at July 1,	$	33,515	$	878	$	36,924	$	640
Unrealized gain		(4,560)		-		(2,007)		-
Realized (loss) gain reclassified to a deferred account		(411)		411		(316)		316
Realized gain (loss) reclassified to income statement		638		(258)		29		(62)
Balance as of September 30,	$	29,182	$	1,031	$	34,630	$	894
Nine Months Ended September 30:
Balance at January 1,	$	31,830	$	377	$	41,958	$	806
Unrealized gain		(2,256)		-		(5,906)		-
Realized (loss) gain reclassified to a deferred account		(1,402)		1,402		(837)		837
Realized gain (loss) reclassified to income statement		1,010		(748)		(585)		(749)
Balance as of September 30,	$	29,182	$	1,031	$	34,630	$	894

		Realized Losses (Gains)
		2019				2018
(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	$	471	$	83	$	(145)	$	-
FTRs		(429)		-		(150)		-
PPA		(505)		-		328		-
Nine Months Ended September 30:
Commodity derivative contracts	$	1,038	$	460	$	39	$	637
FTRs		(503)		-		(625)		-
PPA		(1,257)		-		1,283		-

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

The PPA has a provision that may require MGE to post collateral if MGE's debt rating falls below investment grade (i.e., below BBB-). The amount of collateral that it may be required to post varies from $20.0 million to $40.0 million, depending on MGE's nominated capacity amount. As of September 30, 2019, no collateral is required to be, or has been, posted. Certain counterparties extend MGE a credit limit. If MGE exceeds these limits, the counterparties may require collateral to be posted. No counterparties were in a net liability position as of September 30, 2019, and December 31, 2018.

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, 2019, no counterparties have defaulted.

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Derivative and Hedging Instruments (Details-2) - USD ($) $ in Thousands	Sep. 30, 2019	Dec. 31, 2018
Commodity Derivative Contracts [Member]
Offsetting Assets [Line Items]
Gross amounts	$ 749	$ 801
Gross amounts offset in balance sheet	(561)	(342)
Collateral posted against derivative positions	0	0
Net amount presented in balance sheet	188	459
Financial Transmission Rights [Member]
Offsetting Assets [Line Items]
Gross amounts	344	241
Gross amounts offset in balance sheet	0	0
Collateral posted against derivative positions	0	0
Net amount presented in balance sheet	$ 344	$ 241

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Fair Value of Financial Instruments (Details-1) - USD ($) $ in Thousands		Sep. 30, 2019	Dec. 31, 2018
Fair Value Measurement [Domain]
Liabilities:
Unamortized discount and debt issuance costs, net		$ 4,200	$ 4,500
Carrying Amount [Member]
Assets:
Cash and cash equivalents		61,112	83,102
Liabilities:
Short-term debt - commercial paper		54,500	13,000
Long-term debt	[1]	499,027	502,431
Fair Value [Member]
Assets:
Cash and cash equivalents		61,112	83,102
Liabilities:
Short-term debt - commercial paper		54,500	13,000
Long-term debt	[1]	578,229	518,811
MGE [Member] | Fair Value Measurement [Domain]
Liabilities:
Unamortized discount and debt issuance costs, net		4,200	4,500
MGE [Member] | Carrying Amount [Member]
Assets:
Cash and cash equivalents		4,656	4,843
Liabilities:
Short-term debt - commercial paper		54,500	13,000
Long-term debt	[1]	499,027	502,431
MGE [Member] | Fair Value [Member]
Assets:
Cash and cash equivalents		4,656	4,843
Liabilities:
Short-term debt - commercial paper		54,500	13,000
Long-term debt	[1]	$ 578,229	$ 518,811

[1] Includes long-term debt due within one year. Excludes debt issuance costs and unamortized discount of $4.2million and $4.5million as of September 30, 2019, and December 31, 2018, respectively.

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Fair Value of Financial Instruments (Details-5) - USD ($)		3 Months Ended		9 Months Ended
		Sep. 30, 2019	Sep. 30, 2018	Sep. 30, 2019	Sep. 30, 2018
Fair Value Disclosures [Abstract]
Total gains (losses) included in earnings attributed to the change in unrealized gains (losses) related to assets and liabilities	[1]	$ 0	$ 0	$ 0	$ 0
Fair Value, Net Derivative Asset (Liability) Measured on Recurring Basis, Unobservable Input Reconciliation [Line Items]
Included in earnings	[1]	(492,000)	26,000	(1,928,000)	(434,000)
Purchased Power Expense [Member]
Fair Value, Net Derivative Asset (Liability) Measured on Recurring Basis, Unobservable Input Reconciliation [Line Items]
Included in earnings	[1]	(409,000)	26,000	(1,658,000)	(637,000)
Cost Of Gas Sold Expense [Member]
Fair Value, Net Derivative Asset (Liability) Measured on Recurring Basis, Unobservable Input Reconciliation [Line Items]
Included in earnings	[1]	$ (83,000)	$ 0	$ (270,000)	$ 203,000

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

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Segment Information (Details) - USD ($) $ in Thousands	3 Months Ended		9 Months Ended		12 Months Ended
	Sep. 30, 2019	Sep. 30, 2018	Sep. 30, 2019	Sep. 30, 2018	Dec. 31, 2018
Segment Reporting Information [Line Items]
Operating revenues	$ 138,198	$ 137,795	$ 427,914	$ 419,689
Depreciation and amortization	(18,193)	(14,259)	(53,423)	(41,754)
Other operating expenses	(81,267)	(83,738)	(285,459)	(287,718)
Operating income (loss)	38,738	39,798	89,032	90,217
Other income (deductions), net	5,204	4,330	15,074	13,980
Interest (expense) income, net	(5,831)	(5,025)	(17,227)	(14,547)
Income before income taxes	38,111	39,103	86,879	89,650
Income tax (provision) benefit	(7,454)	(9,597)	(16,667)	(21,792)
Net Income Including Noncontrolling Interest	30,657	29,506	70,212	67,858
Net Income	30,657	29,506	70,212	67,858
Segment Reporting Assets And Capital Expenditures [Abstract]
Assets	2,066,973		2,066,973		$ 1,988,618
Capital expenditures			128,389	149,001	212,197
Electric [Member]
Segment Reporting Information [Line Items]
Operating revenues	120,607	119,175	314,886	312,633
Gas [Member]
Segment Reporting Information [Line Items]
Operating revenues	17,377	18,407	112,547	106,152
Non Regulated Energy [Member]
Segment Reporting Information [Line Items]
Operating revenues	214	213	481	904
Transmission Investment [Member]
Segment Reporting Information [Line Items]
Operating revenues	0	0	0	0
All Others [Member]
Segment Reporting Information [Line Items]
Operating revenues	0	0	0	0
Operating Segments [Member]
Segment Reporting Information [Line Items]
Operating revenues	138,198	137,795	427,914	419,689
Operating Segments [Member] | Electric [Member]
Segment Reporting Information [Line Items]
Operating revenues	120,832	119,155	315,508	312,399
Depreciation and amortization	(13,441)	(9,864)	(39,330)	(28,817)
Other operating expenses	(76,817)	(77,847)	(223,242)	(228,957)
Operating income (loss)	30,574	31,444	52,936	54,625
Other income (deductions), net	1,817	1,763	5,258	5,055
Interest (expense) income, net	(3,762)	(3,217)	(11,253)	(9,036)
Income before income taxes	28,629	29,990	46,941	50,644
Income tax (provision) benefit	(4,948)	(7,306)	(6,036)	(11,492)
Net Income	23,681	22,684	40,905	39,152
Segment Reporting Assets And Capital Expenditures [Abstract]
Assets	1,288,752		1,288,752		1,193,083
Capital expenditures			101,609		176,399
Operating Segments [Member] | Gas [Member]
Segment Reporting Information [Line Items]
Operating revenues	23,056	22,626	125,118	118,211
Depreciation and amortization	(2,879)	(2,534)	(8,482)	(7,374)
Other operating expenses	(20,217)	(19,824)	(104,587)	(99,251)
Operating income (loss)	(40)	268	12,049	11,586
Other income (deductions), net	855	829	2,579	2,347
Interest (expense) income, net	(1,059)	(963)	(3,132)	(2,689)
Income before income taxes	(244)	134	11,496	11,244
Income tax (provision) benefit	183	42	(2,848)	(2,788)
Net Income	(61)	176	8,648	8,456
Segment Reporting Assets And Capital Expenditures [Abstract]
Assets	379,160		379,160		377,005
Capital expenditures			24,551		30,497
Operating Segments [Member] | Non Regulated Energy [Member]
Segment Reporting Information [Line Items]
Operating revenues	10,233	10,125	30,468	30,483
Depreciation and amortization	(1,873)	(1,861)	(5,611)	(5,563)
Other operating expenses	(33)	(36)	(113)	(113)
Operating income (loss)	8,327	8,228	24,744	24,807
Other income (deductions), net	0	0	0	0
Interest (expense) income, net	(1,274)	(1,320)	(3,838)	(4,002)
Income before income taxes	7,053	6,908	20,906	20,805
Income tax (provision) benefit	(1,922)	(1,852)	(5,695)	(5,638)
Net Income	5,131	5,056	15,211	15,167
Segment Reporting Assets And Capital Expenditures [Abstract]
Assets	259,542		259,542		265,301
Capital expenditures			2,229		5,301
Operating Segments [Member] | Transmission Investment [Member]
Segment Reporting Information [Line Items]
Operating revenues	0	0	0	0
Depreciation and amortization	0	0	0	0
Other operating expenses	0	(4)	0	(12)
Operating income (loss)	0	(4)	0	(12)
Other income (deductions), net	2,372	1,620	6,808	5,908
Interest (expense) income, net	0	0	0	0
Income before income taxes	2,372	1,616	6,808	5,896
Income tax (provision) benefit	(646)	(441)	(1,856)	(1,611)
Net Income	1,726	1,175	4,952	4,285
Segment Reporting Assets And Capital Expenditures [Abstract]
Assets	69,829		69,829		66,366
Capital expenditures			0		0
Operating Segments [Member] | All Others [Member]
Segment Reporting Information [Line Items]
Operating revenues	0	0	0	0
Depreciation and amortization	0	0	0	0
Other operating expenses	(123)	(138)	(697)	(789)
Operating income (loss)	(123)	(138)	(697)	(789)
Other income (deductions), net	160	118	429	670
Interest (expense) income, net	264	475	996	1,180
Income before income taxes	301	455	728	1,061
Income tax (provision) benefit	(121)	(40)	(232)	(263)
Net Income	180	415	496	798
Segment Reporting Assets And Capital Expenditures [Abstract]
Assets	447,307		447,307		465,661
Capital expenditures			0		0
Consolidation Elimination Entries [Member]
Segment Reporting Information [Line Items]
Operating revenues	(15,923)	(14,111)	(43,180)	(41,404)
Depreciation and amortization	0	0	0	0
Other operating expenses	15,923	14,111	43,180	41,404
Operating income (loss)	0	0	0	0
Other income (deductions), net	0	0	0	0
Interest (expense) income, net	0	0	0	0
Income before income taxes	0	0	0	0
Income tax (provision) benefit	0	0	0	0
Net Income	0	0	0	0
Segment Reporting Assets And Capital Expenditures [Abstract]
Assets	(377,617)		(377,617)		(378,798)
Capital expenditures			0		0
Consolidation Elimination Entries [Member] | Electric [Member]
Segment Reporting Information [Line Items]
Operating revenues	225	(20)	622	(234)
Consolidation Elimination Entries [Member] | Gas [Member]
Segment Reporting Information [Line Items]
Operating revenues	5,679	4,219	12,571	12,059
Consolidation Elimination Entries [Member] | Non Regulated Energy [Member]
Segment Reporting Information [Line Items]
Operating revenues	10,019	9,912	29,987	29,579
Consolidation Elimination Entries [Member] | Transmission Investment [Member]
Segment Reporting Information [Line Items]
Operating revenues	0	0	0	0
Consolidation Elimination Entries [Member] | All Others [Member]
Segment Reporting Information [Line Items]
Operating revenues	0	0	0	0
MGE [Member]
Segment Reporting Information [Line Items]
Operating revenues	138,198	137,795	427,914	419,689
Depreciation and amortization	(18,193)	(14,259)	(53,423)	(41,754)
Other operating expenses	(81,144)	(83,595)	(284,762)	(286,917)
Operating income (loss)	38,861	39,941	89,729	91,018
Other income (deductions), net	2,672	2,592	7,837	7,402
Interest (expense) income, net	(6,095)	(5,500)	(18,223)	(15,727)
Income before income taxes	35,438	37,033	79,343	82,693
Income tax (provision) benefit	(6,687)	(9,117)	(14,579)	(19,918)
Net Income Including Noncontrolling Interest	28,751	27,916	64,764	62,775
Less Net Income Attributable to Noncontrolling Interest, net of tax	(5,614)	(5,629)	(16,725)	(16,940)
Net Income	23,137	22,287	48,039	45,835
Segment Reporting Assets And Capital Expenditures [Abstract]
Assets	1,927,027		1,927,027		1,834,891
Capital expenditures			128,389	149,001	212,197
MGE [Member] | Electric [Member]
Segment Reporting Information [Line Items]
Operating revenues	120,607	119,175	314,886	312,633
MGE [Member] | Gas [Member]
Segment Reporting Information [Line Items]
Operating revenues	17,377	18,407	112,547	106,152
MGE [Member] | Non Regulated Energy [Member]
Segment Reporting Information [Line Items]
Operating revenues	214	213	481	904
MGE [Member] | Operating Segments [Member]
Segment Reporting Information [Line Items]
Operating revenues	138,198	137,795	427,914	419,689
MGE [Member] | Operating Segments [Member] | Electric [Member]
Segment Reporting Information [Line Items]
Operating revenues	120,832	119,155	315,508	312,399
Depreciation and amortization	(13,441)	(9,864)	(39,330)	(28,817)
Other operating expenses	(76,817)	(77,847)	(223,242)	(228,957)
Operating income (loss)	30,574	31,444	52,936	54,625
Other income (deductions), net	1,817	1,763	5,258	5,055
Interest (expense) income, net	(3,762)	(3,217)	(11,253)	(9,036)
Income before income taxes	28,629	29,990	46,941	50,644
Income tax (provision) benefit	(4,948)	(7,306)	(6,036)	(11,492)
Net Income Including Noncontrolling Interest	23,681	22,684	40,905	39,152
Less Net Income Attributable to Noncontrolling Interest, net of tax	0	0	0	0
Net Income	23,681	22,684	40,905	39,152
Segment Reporting Assets And Capital Expenditures [Abstract]
Assets	1,288,752		1,288,752		1,193,083
Capital expenditures			101,609		176,399
MGE [Member] | Operating Segments [Member] | Gas [Member]
Segment Reporting Information [Line Items]
Operating revenues	23,056	22,626	125,118	118,211
Depreciation and amortization	(2,879)	(2,534)	(8,482)	(7,374)
Other operating expenses	(20,217)	(19,824)	(104,587)	(99,251)
Operating income (loss)	(40)	268	12,049	11,586
Other income (deductions), net	855	829	2,579	2,347
Interest (expense) income, net	(1,059)	(963)	(3,132)	(2,689)
Income before income taxes	(244)	134	11,496	11,244
Income tax (provision) benefit	183	42	(2,848)	(2,788)
Net Income Including Noncontrolling Interest	(61)	176	8,648	8,456
Less Net Income Attributable to Noncontrolling Interest, net of tax	0	0	0	0
Net Income	(61)	176	8,648	8,456
Segment Reporting Assets And Capital Expenditures [Abstract]
Assets	379,160		379,160		377,005
Capital expenditures			24,551		30,497
MGE [Member] | Operating Segments [Member] | Non Regulated Energy [Member]
Segment Reporting Information [Line Items]
Operating revenues	10,233	10,125	30,468	30,483
Depreciation and amortization	(1,873)	(1,861)	(5,611)	(5,563)
Other operating expenses	(33)	(35)	(113)	(113)
Operating income (loss)	8,327	8,229	24,744	24,807
Other income (deductions), net	0	0	0	0
Interest (expense) income, net	(1,274)	(1,320)	(3,838)	(4,002)
Income before income taxes	7,053	6,909	20,906	20,805
Income tax (provision) benefit	(1,922)	(1,853)	(5,695)	(5,638)
Net Income Including Noncontrolling Interest	5,131	5,056	15,211	15,167
Less Net Income Attributable to Noncontrolling Interest, net of tax	0	0	0	0
Net Income	5,131	5,056	15,211	15,167
Segment Reporting Assets And Capital Expenditures [Abstract]
Assets	259,492		259,492		265,251
Capital expenditures			2,229		5,301
MGE [Member] | Consolidation Elimination Entries [Member]
Segment Reporting Information [Line Items]
Operating revenues	(15,923)	(14,111)	(43,180)	(41,404)
Depreciation and amortization	0	0	0	0
Other operating expenses	15,923	14,111	43,180	41,404
Operating income (loss)	0	0	0	0
Other income (deductions), net	0	0	0	0
Interest (expense) income, net	0	0	0	0
Income before income taxes	0	0	0	0
Income tax (provision) benefit	0	0	0	0
Net Income Including Noncontrolling Interest	0	0	0	0
Less Net Income Attributable to Noncontrolling Interest, net of tax	(5,614)	(5,629)	(16,725)	(16,940)
Net Income	(5,614)	(5,629)	(16,725)	(16,940)
Segment Reporting Assets And Capital Expenditures [Abstract]
Assets	(377)		(377)		(448)
Capital expenditures			0		$ 0
MGE [Member] | Consolidation Elimination Entries [Member] | Electric [Member]
Segment Reporting Information [Line Items]
Operating revenues	225	(20)	622	(234)
MGE [Member] | Consolidation Elimination Entries [Member] | Gas [Member]
Segment Reporting Information [Line Items]
Operating revenues	5,679	4,219	12,571	12,059
MGE [Member] | Consolidation Elimination Entries [Member] | Non Regulated Energy [Member]
Segment Reporting Information [Line Items]
Operating revenues	$ 10,019	$ 9,912	$ 29,987	$ 29,579

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Pension and Other Postretirement Plans (Details) - USD ($) $ in Thousands	3 Months Ended		9 Months Ended
	Sep. 30, 2019	Sep. 30, 2018	Sep. 30, 2019	Sep. 30, 2018
Defined Benefit Plan Deferred Net Periodic Benefit Cost [Abstract]
Deferred pension and OPRB costs	$ 1,300		$ 4,600
Pension Benefits [Member]
Components of net periodic benefit cost:
Service cost	1,040	$ 1,431	3,402	$ 4,292
Interest cost	3,170	3,215	10,364	9,645
Expected return on assets	(5,054)	(6,560)	(16,523)	(19,680)
Amortization of:
Prior service credit	(26)	(11)	(85)	(33)
Actuarial loss	1,637	1,319	5,351	3,958
Net periodic benefit (credit) cost	767	(606)	2,509	(1,818)
Postretirement Benefits [Member]
Components of net periodic benefit cost:
Service cost	276	320	829	962
Interest cost	721	653	2,164	1,959
Expected return on assets	(677)	(808)	(2,034)	(2,424)
Amortization of:
Transition obligation	1	1	2	2
Prior service credit	(664)	(667)	(1,994)	(2,001)
Actuarial loss	100	122	300	366
Net periodic benefit (credit) cost	$ (243)	$ (379)	$ (733)	$ (1,136)

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Leases (Details-6) $ in Thousands	Dec. 31, 2018 USD ($)
Operating Leases Future Minimum Payments Due [Abstract]
Minimum lease payments, 2019	$ 1,646
Minimum lease payments, 2020	1,371
Minimum lease payments, 2021	1,095
Minimum lease payments, 2022	989
Minimum lease payments, 2023	975
Minimum lease payments, Thereafter	$ 22,707

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Revenue

9 Months Ended

Sep. 30, 2019

Revenue from Contract with Customer [Abstract]

Revenue from Contract with Customer

Revenue - MGE Energy and MGE.

Revenues disaggregated by revenue source were as follows:

		Three Months Ended				Nine Months Ended
(In thousands)		September 30,				September 30,
Electric revenues		2019		2018		2019		2018
Residential	$	42,442	$	42,371	$	107,772	$	107,847
Commercial		63,466		61,638		165,481		159,264
Industrial		3,760		3,668		10,013		11,193
Other-retail/municipal		9,543		9,431		26,728		26,245
Total retail		119,211		117,108		309,994		304,549
Sales to the market		1,163		1,505		3,914		6,334
Other revenues		233		562		978		1,750
Total electric revenues		120,607		119,175		314,886		312,633
Gas revenues
Residential		11,342		11,916		67,659		64,087
Commercial/Industrial		4,825		5,570		40,833		38,728
Total retail		16,167		17,486		108,492		102,815
Gas transportation		1,126		829		3,756		3,018
Other revenues		84		92		299		319
Total gas revenues		17,377		18,407		112,547		106,152
Non-regulated energy revenues		214		213		481		904
Total Operating Revenue	$	138,198	$	137,795		427,914	$	419,689

Performance Obligations

A performance obligation is a promise in a contract to transfer a distinct good or service to the customer and is the unit of account. A contract's transaction price is allocated to each distinct performance obligation and recognized as revenue when, or as, the performance obligation is satisfied. The majority of MGE Energy's and MGE's contracts have a single performance obligation.

Retail Revenue (Residential, Commercial, Industrial, and Other Retail/Municipal)

Retail revenue of electric and gas utility service represent MGE's core business activities. Tariffs are approved by the PSCW through a rate order and provide MGE's customers with the standard terms and conditions, including pricing terms. The performance obligation to deliver electricity or gas is satisfied over time as the customer simultaneously receives and consumes the commodities provided by MGE. MGE recognizes revenues as the commodity is delivered to customers. Meters are read on a systematic basis throughout the month based on established meter-reading schedules and the customer is subsequently billed for their services. At the end of the month, MGE accrues an estimate for the unbilled amount of commodities delivered to customers. The unbilled revenue estimate is based on daily system demand volumes, weather factors, estimated line losses, estimated customer usage by class, and applicable customer rates.

Utility Cost Recovery Mechanisms

MGE's tariff rates include a provision for fuel cost recovery. The PSCW allows Wisconsin utilities to defer electric fuel-related costs, less excess revenues, that fall outside a symmetrical cost tolerance band. Any over/under recovery of the actual costs in a given year is determined in the following year and is then

reflected in future billings to electric retail customers. Over-collection of fuel-related costs that are outside the approved range will be recognized as a reduction of revenue. Under-collection of these costs will be recognized in "Purchased power" expense in the consolidated statements of income. The cumulative effects of these deferred amounts will be recorded in "Regulatory assets" or "Regulatory liabilities" on the consolidated balance sheets until they are reflected in future billings to customers. See Footnote 10.b. for further information.

MGE received a PSCW order in January 2018 to defer the over-collection of income tax expense collected in customer rates during 2018 as a result of the Tax Cuts and Jobs Act (the Tax Act) reduction in the income tax rate to 21 percent. See Footnote 10.c. for further information.

MGE has other cost recovery mechanisms. For example, any over-collection of the difference between actual costs incurred and the amount of costs collected from customers is recorded as a reduction of revenue in the period incurred.

Sales to the Market

Sales to the market include energy charges, capacity or demand charges, and ancillary charges represented by wholesale sales of electricity made to third parties who are not ultimate users of the electricity. Most of these sales are spot market transactions on the markets operated by MISO. Each transaction is considered a performance obligation and revenue is recognized in the period in which energy charges, capacity or demand charges, and ancillary services are sold into MISO. MGE reports, on a net basis, transactions on the MISO markets in which it buys and sells power within the same hour to meet electric energy delivery requirements.

Transportation of Gas

MGE has contracts under which MGE provides gas transportation services to customers who have elected to purchase gas from a third party and have the gas delivered via pipelines within MGE's service territory. Revenue is recognized as service is rendered or gas is delivered to customers. Tariffs are approved by the PSCW through a rate order and provide gas transportation customers with the standard terms and conditions, including pricing terms.

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Leases (Tables)

9 Months Ended

Sep. 30, 2019

Leases [Abstract]

Lease Cost

The following table shows lease expense for the three and nine months ended September 30, 2019:

(In thousands)		Three Months Ended		Nine Months Ended	Income Statement Location
Finance lease expense:
Amortization of leased assets	$	425	$	1,295	Depreciation and amortization
Interest on lease liabilities		199		597	Interest expense, net
Operating lease expense		32		92	Other operations and maintenance
Total lease expense	$	656	$	1,984

Lease Balance Sheet

The following table shows the lease assets and liabilities on the consolidated balance sheet as of September 30, 2019:

(In thousands)			Balance Sheet Location
Lease assets:
Finance lease assets	$	16,275	Property, plant, and equipment, net
Operating lease assets		300	Other deferred assets and other
Total lease assets	$	16,575
Lease liabilities:
Finance lease liabilities - current	$	932	Other current liabilities
Finance lease liabilities - long-term		17,657	Finance lease liabilities
Operating lease liabilities - current		143	Other current liabilities
Operating lease liabilities - long-term		185	Other deferred liabilities and other
Total lease liabilities	$	18,917

Other Financial Information

The following table shows other financial lease information for the nine months ended September 30, 2019:

(In thousands)
Cash paid for amounts included in the measurement of lease liabilities:
Finance leases - Financing cash flows	$	781
Finance leases - Operating cash flows		597
Operating leases - Operating cash flows		108
Lease assets obtained in exchange for lease liabilities:
Finance leases		12,081
Operating leases		239

Weighted Average And Discount Rate

The following table shows the weighted average remaining lease terms and discounts as of September 30, 2019:

Weighted-average remaining lease terms (in years):
Finance leases	38
Operating leases	5
Weighted-average discount rates:
Finance leases	4.36	%
Operating leases	3.58	%

Lessee Operating Lease Liability Maturity

The following table shows maturities of lease liabilities as of September 30, 2019:

(In thousands)		Finance		Operating
2019	$	539	$	37
2020		1,644		152
2021		1,428		86
2022		1,309		33
2023		1,228		2
Thereafter		41,317		52
Subtotal		47,465		362
Less: Present value discount		(28,876)		(34)
Lease Liability	$	18,589	$	328

Lessee Finance Lease Liability Maturity

The following table shows maturities of lease liabilities as of September 30, 2019:

(In thousands)		Finance		Operating
2019	$	539	$	37
2020		1,644		152
2021		1,428		86
2022		1,309		33
2023		1,228		2
Thereafter		41,317		52
Subtotal		47,465		362
Less: Present value discount		(28,876)		(34)
Lease Liability	$	18,589	$	328

Operating Leases, Future Minimum Rental Payments

Future minimum rental payments as of December 31, 2018, under agreements classified as operating leases with noncancelable terms in excess of one year are as follows:

(In thousands)		2019		2020		2021		2022		2023		Thereafter
Minimum lease payments	$	1,646	$	1,371	$	1,095	$	989	$	975	$	22,707

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Fair Value of Financial Instruments (Details-4) - USD ($)		3 Months Ended		9 Months Ended
		Sep. 30, 2019	Sep. 30, 2018	Sep. 30, 2019	Sep. 30, 2018
Fair Value, Net Derivative Asset (Liability) Measured on Recurring Basis, Unobservable Input Reconciliation [Roll Forward]
Beginning balance,		$ (33,337,000)	$ (37,332,000)	$ (32,002,000)	$ (42,026,000)
Realized and unrealized gains (losses):
Included in regulatory assets		4,317,000	2,018,000	2,982,000	6,711,000
Included in other comprehensive income		0	0	0	0
Included in earnings	[1]	(492,000)	26,000	(1,928,000)	(434,000)
Included in current assets		4,000	(25,000)	(198,000)	(496,000)
Purchases		5,205,000	5,736,000	16,827,000	17,602,000
Sales		0	0	0	0
Issuances		0	0	0	0
Settlements		(4,717,000)	(5,737,000)	(14,701,000)	(16,671,000)
Transfers in and/or out of level 3		0	0	0	0
Ending balance,		$ (29,020,000)	$ (35,314,000)	$ (29,020,000)	$ (35,314,000)

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

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Revenue (Details-1) - USD ($) $ in Thousands	3 Months Ended		9 Months Ended
	Sep. 30, 2019	Sep. 30, 2018	Sep. 30, 2019	Sep. 30, 2018
Total Operating Revenue [Member]
Disaggregation of Revenue [Line Items]
Revenues recognized from contracts with customers	$ 138,198	$ 137,795	$ 427,914	$ 419,689
Electric [Member]
Disaggregation of Revenue [Line Items]
Revenues recognized from contracts with customers	120,607	119,175	314,886	312,633
Electric [Member] | Residential [Member]
Disaggregation of Revenue [Line Items]
Revenues recognized from contracts with customers	42,442	42,371	107,772	107,847
Electric [Member] | Commercial [Member]
Disaggregation of Revenue [Line Items]
Revenues recognized from contracts with customers	63,466	61,638	165,481	159,264
Electric [Member] | Industrial [Member]
Disaggregation of Revenue [Line Items]
Revenues recognized from contracts with customers	3,760	3,668	10,013	11,193
Electric [Member] | Other-retail/municipal
Disaggregation of Revenue [Line Items]
Revenues recognized from contracts with customers	9,543	9,431	26,728	26,245
Electric [Member] | Total Retail [Member]
Disaggregation of Revenue [Line Items]
Revenues recognized from contracts with customers	119,211	117,108	309,994	304,549
Electric [Member] | Sales To The Market [Member]
Disaggregation of Revenue [Line Items]
Revenues recognized from contracts with customers	1,163	1,505	3,914	6,334
Electric [Member] | Other Revenues [Member]
Disaggregation of Revenue [Line Items]
Revenues recognized from contracts with customers	233	562	978	1,750
Gas [Member]
Disaggregation of Revenue [Line Items]
Revenues recognized from contracts with customers	17,377	18,407	112,547	106,152
Gas [Member] | Residential [Member]
Disaggregation of Revenue [Line Items]
Revenues recognized from contracts with customers	11,342	11,916	67,659	64,087
Gas [Member] | Commercial/Industrial [Member]
Disaggregation of Revenue [Line Items]
Revenues recognized from contracts with customers	4,825	5,570	40,833	38,728
Gas [Member] | Total Retail [Member]
Disaggregation of Revenue [Line Items]
Revenues recognized from contracts with customers	16,167	17,486	108,492	102,815
Gas [Member] | Gas Transportation [Member]
Disaggregation of Revenue [Line Items]
Revenues recognized from contracts with customers	1,126	829	3,756	3,018
Gas [Member] | Other Revenues [Member]
Disaggregation of Revenue [Line Items]
Revenues recognized from contracts with customers	84	92	299	319
Non Regulated Energy [Member]
Disaggregation of Revenue [Line Items]
Revenues recognized from contracts with customers	$ 214	$ 213	$ 481	$ 904

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Equity and Financing Arrangements (Details) - USD ($)		3 Months Ended		9 Months Ended
	Nov. 05, 2019	Sep. 30, 2019	Sep. 30, 2018	Sep. 30, 2019	Sep. 30, 2018
Common Stock [Abstract]
Common stock issued during period		0	0	0	0
Dilutive Shares Calculation [Abstract]
Dilutive securities				$ 0
Future Debt Issuance, 2.94% due 2029 | Subsequent Event [Member]
Debt Instrument [Line Items]
Face amount	$ 50,000,000
Interest rate	2.94%
Term	10 years

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Investment in ATC and ATC Holdco (Details-1) - USD ($) $ in Thousands		3 Months Ended			9 Months Ended
	Oct. 31, 2019	Sep. 30, 2019	Sep. 30, 2018		Sep. 30, 2019	Sep. 30, 2018		Dec. 31, 2017
Schedule Of Equity Method Investments [Line Items]
Equity earnings from investment in ATC		$ 2,364	$ 1,672		$ 6,879	$ 6,113
Dividends from ATC		1,781	1,581		5,526	5,336
Capital contributions to investments		888	533		5,894	4,801
MGE Transco [Member] | ATC [Member]
Schedule Of Equity Method Investments [Line Items]
Equity earnings from investment in ATC		2,364	1,672		6,879	6,113
Dividends from ATC		1,781	1,581	[1]	5,526	4,540	[1]
Capital contributions to investments		$ 888	533		$ 2,131	2,308
Dividend receivable from ATC			$ 1,600			$ 1,600		$ 2,300
MGE Transco [Member] | ATC [Member] | Subsequent Event [Member]
Schedule Of Equity Method Investments [Line Items]
Capital contributions to investments	$ 900

[1] MGE Transco recorded a $2.3 million dividend receivable from ATC as of December 31, 2017. A cash dividend was received in January of the following year. MGE Transco recorded a $1.6 million dividend receivable from ATC as of September 30, 2018. A cash dividend was received in October 2018.

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Joint Plant Ownership

9 Months Ended

Sep. 30, 2019

Regulated Operations [Abstract]

Joint Plant Ownership

Joint Plant Ownership - MGE Energy and MGE.

a. Two Creeks.

In May 2019, MGE acquired a 33% ownership interest in a 150 MW solar generation array in the Town of Two Creeks and the City of Two Rivers in Manitowoc and Kewaunee Counties, Wisconsin. MGE's sole principal asset will be the 33% undivided ownership interest in the solar generation facility, which is being constructed. The estimated share of capital costs for MGE's ownership interest is approximately $65 million (excluding capitalized interest).

As of September 30, 2019, $42.1 million (excluding capitalized interest) related to this project is reflected in "Construction work in progress" on the consolidated balance sheets. The project is anticipated to be completed by the end of 2020.

b. Badger Hollow.

In July 2019, MGE acquired a 33% ownership interest in a 150 MW solar generation array in southwestern Wisconsin in Iowa County, near the villages of Montfort and Cobb. MGE's sole principal asset will be the 33% undivided ownership interest in the solar generation facility which is being constructed. The estimated share of capital costs for MGE's ownership interest is approximately $65 million (excluding capitalized interest).

As of September 30, 2019, $10.0 million (excluding capitalized interest) related to this project is reflected in "Construction work in progress" on the consolidated balance sheets. The project is anticipated to be completed by the end of 2020.

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Summary of Significant Accounting Principles (Tables)

9 Months Ended

Sep. 30, 2019

Cash, Cash Equivalents, And Restricted Cash [Abstract]

Cash, Cash Equivalents, and Restricted Cash

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

		MGE Energy				MGE
		September 30,		December 31,		September 30,		December 31,
(In thousands)		2019		2018		2019		2018
Cash and cash equivalents	$	61,112	$	83,102	$	4,656	$	4,843
Restricted cash		532		634		532		634
Receivable - margin account		1,598		1,193		1,598		1,193
Cash, cash equivalents, and restricted cash	$	63,242	$	84,929	$	6,786	$	6,670

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Document and Entity Information - shares	9 Months Ended
	Sep. 30, 2019	Oct. 31, 2019
Document And Entity Information [Line Items]
Entity Registrant Name	MGE Energy, Inc.
Entity Central Index Key	0001161728
Document Type	10-Q
Document Period End Date	Sep. 30, 2019
Amendment Flag	false
Trading Symbol	MGEE
Document Fiscal Year Focus	2019
Document Fiscal Period Focus	Q3
Current Fiscal Year End Date	--12-31
Entity Current Reporting Status	Yes
Entity Filer Category	Large Accelerated Filer
Entity Common Stock Shares Outstanding		34,668,370
Entity Emerging Growth Company	false
Entity Small Business	false
Entity Shell Company	false
Security Exchange Name	NASDAQ
Security 12(b) Title	Common Stock, $1 Par Value Per Share
Entity Tax Identification Number	39-2040501
Entity File Number	000-49965
Entity Incorporation State Country Code	WI
Entity Address Address Line 1	133 South Blair Street
EntityAddressCityOrTown	Madison
Entity Address State Or Province	WI
Entity Address Postal Zip Code	53788
City Area Code	608
Local Phone Number	252-7000
Document Transition Report	false
Entity Interactive Data Current	Yes
Document Quarterly Report	true
MGE [Member]
Document And Entity Information [Line Items]
Entity Registrant Name	Madison Gas and Electric Company
Entity Central Index Key	0000061339
Entity Current Reporting Status	Yes
Entity Filer Category	Non-accelerated Filer
Entity Common Stock Shares Outstanding		17,347,894
Entity Emerging Growth Company	false
Entity Small Business	false
Entity Shell Company	false
Entity Tax Identification Number	39-0444025
Entity File Number	000-1125
Entity Incorporation State Country Code	WI
Entity Address Address Line 1	133 South Blair Street
EntityAddressCityOrTown	Madison
Entity Address State Or Province	WI
Entity Address Postal Zip Code	53788
City Area Code	608
Local Phone Number	252-7000
Document Transition Report	false
Entity Interactive Data Current	Yes
Document Quarterly Report	true

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Consolidated Balance Sheets (Unaudited) (Parentheticals) - USD ($) $ in Thousands	Sep. 30, 2019	Dec. 31, 2018
Receivables, Net
Reserve for uncollectible accounts receivable	$ 2,683	$ 2,614
Reserve for uncollectible other accounts receivable	456	540
MGE [Member]
Receivables, Net
Reserve for uncollectible accounts receivable	2,683	2,614
Reserve for uncollectible other accounts receivable	$ 456	$ 540

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Leases (Details-1) - USD ($) $ in Thousands	3 Months Ended	9 Months Ended
	Sep. 30, 2019	Sep. 30, 2019
Lease Cost [Abstract]
Amortization of leased assets, Depreciation and amortization	$ 425	$ 1,295
Interest on lease liabilities, Interest expense, net	199	597
Operating lease expense, Other operations and maintenance	32	92
Total lease expense	$ 656	$ 1,984

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Summary of Significant Accounting Principles

9 Months Ended

Sep. 30, 2019

Organization, Consolidation and Presentation of Financial Statements [Abstract]

Basis of Presentation

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 2018 Annual Report on Form 10-K (the 2018 Annual Report on Form 10-K).

The accompanying consolidated financial statements as of September 30, 2019, and for 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 2018 Annual Report on Form 10-K, but does not include all disclosures required by accounting principles generally accepted in the United States of America. These notes should be read in conjunction with the financial statements and the notes on pages 62 through 106 of the 2018 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)		2019		2018		2019		2018
Cash and cash equivalents	$	61,112	$	83,102	$	4,656	$	4,843
Restricted cash		532		634		532		634
Receivable - margin account		1,598		1,193		1,598		1,193
Cash, cash equivalents, and restricted cash	$	63,242	$	84,929	$	6,786	$	6,670

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Fair Value of Financial Instruments (Tables)

9 Months Ended

Sep. 30, 2019

Fair Value Disclosures [Abstract]

Estimated Fair Market Value of Financial Instruments

The estimated fair market value offinancial instruments are as follows:

		September 30, 2019				December 31, 2018
(In thousands)		Carrying Amount		Fair Value		Carrying Amount		Fair Value
MGE Energy
Assets:
Cash and cash equivalents	$	61,112	$	61,112	$	83,102	$	83,102
Liabilities:
Short-term debt - commercial paper		54,500		54,500		13,000		13,000
Long-term debt(a)		499,027		578,229		502,431		518,811
MGE
Assets:
Cash and cash equivalents	$	4,656	$	4,656	$	4,843	$	4,843
Liabilities:
Short-term debt - commercial paper		54,500		54,500		13,000		13,000
Long-term debt(a)		499,027		578,229		502,431		518,811

(a) Includes long-term debt due within one year. Excludes debt issuance costs and unamortized discount of $4.2million and $4.5million as of September 30, 2019, and December 31, 2018, respectively.

Assets and Liabilities Measured at Fair Value on a Recurring Basis

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

		Fair Value as of September 30, 2019
(In thousands)		Total		Level 1		Level 2		Level 3
MGE Energy
Assets:
Derivatives, net(b)	$	1,093	$	525	$	-	$	568
Exchange-traded investments		1,001		1,001		-		-
Total Assets	$	2,094	$	1,526	$	-	$	568
Liabilities:
Derivatives, net	$	30,275	$	687	$	-	$	29,588
Deferred compensation		3,025		-		3,025		-
Total Liabilities	$	33,300	$	687	$	3,025	$	29,588
MGE
Assets:
Derivatives, net(b)	$	1,093	$	525	$	-	$	568
Exchange-traded investments		178		178		-		-
Total Assets	$	1,271	$	703	$	-	$	568
Liabilities:
Derivatives, net	$	30,275	$	687	$	-	$	29,588
Deferred compensation		3,025		-		3,025		-
Total Liabilities	$	33,300	$	687	$	3,025	$	29,588

		Fair Value as of December 31, 2018
(In thousands)		Total		Level 1		Level 2		Level 3
MGE Energy
Assets:
Derivatives, net	$	1,042	$	296	$	-	$	746
Exchange-traded investments		848		848		-		-
Total Assets	$	1,890	$	1,144	$	-	$	746
Liabilities:
Derivatives, net	$	32,872	$	124	$	-	$	32,748
Deferred compensation		3,078		-		3,078		-
Total Liabilities	$	35,950	$	124	$	3,078	$	32,748
MGE
Assets:
Derivatives, net	$	1,042	$	296	$	-	$	746
Exchange-traded investments		43		43		-		-
Total Assets	$	1,085	$	339	$	-	$	746
Liabilities:
Derivatives, net	$	32,872	$	124	$	-	$	32,748
Deferred compensation		3,078		-		3,078		-
Total Liabilities	$	35,950	$	124	$	3,078	$	32,748

(b) These amounts are shown gross and exclude $0.7 million of collateral that was posted against derivative positions with counterparties as of September 30, 2019.

Significant Unobservable Inputs

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

	Model Input
Significant Unobservable Inputs	September 30, 2019		December 31, 2018
Basis adjustment:
On peak	92.2	%	92.1	%
Off peak	92.8	%	92.8	%
Counterparty fuel mix:
Internal generation	40.0% - 60.0	%	50.0% - 75.0	%
Purchased power	60.0% - 40.0	%	50.0% - 25.0	%

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

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

		Three Months Ended				Nine Months Ended
		September 30,				September 30,
(In thousands)		2019		2018		2019		2018
Beginning balance	$	(33,337)	$	(37,332)	$	(32,002)	$	(42,026)
Realized and unrealized gains (losses):
Included in regulatory assets		4,317		2,018		2,982		6,711
Included in other comprehensive income		-		-		-		-
Included in earnings		(492)		26		(1,928)		(434)
Included in current assets		4		(25)		(198)		(496)
Purchases		5,205		5,736		16,827		17,602
Sales		-		-		-		-
Issuances		-		-		-		-
Settlements		(4,717)		(5,737)		(14,701)		(16,671)
Transfers in and/or out of Level 3		-		-		-		-
Balance as of September 30,	$	(29,020)	$	(35,314)	$	(29,020)	$	(35,314)
Total gains (losses) included in earnings attributed to
the change in unrealized gains (losses) related to
assets and liabilities held at September 30,(c)	$	-	$	-	$	-	$	-

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

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

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

		Three Months Ended				Nine Months Ended
		September 30,				September 30,
(In thousands)		2019		2018		2019		2018
Purchased Power Expense	$	(409)	$	26	$	(1,658)	$	(637)
Cost of Gas Sold Expense		(83)		-		(270)		203
Total	$	(492)	$	26	$	(1,928)	$	(434)

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

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Rate Matters

9 Months Ended

Sep. 30, 2019

Regulated Operations [Abstract]

Rate Matters

Rate Matters - MGE Energy and MGE.

a.Rate Proceedings.

In December 2018, the PSCW approved the settlement agreement between MGE and intervening parties in the rate case. The settlement decreases electric rates by 2.24%, or $9.2 million, in 2019. MGE will maintain this rate level for 2020, with the exception that MGE will file a 2020 Fuel Cost Plan in 2019 and MGE's electric rates will be adjusted accordingly. The decrease reflects the ongoing tax impacts of the Tax Act. Lower fuel costs and increase in rate base from renewable generation assets are additional items impacting the rate change. The settlement agreement increases gas rates by 1.06%, or $1.7 million, in 2019 and 1.46%, or $2.4 million, in 2020. The gas increase covers infrastructure costs. It also reflects the impacts of the Tax Act. The return on common stock equity for 2019 and 2020 is 9.8% based on a capital structure consisting of 56.6% common equity in 2019 and 56.1% common equity in 2020.

MGE did not file a base rate case for 2018.

b.Fuel Rules.

Fuel rules require the PSCW and Wisconsin utilities to defer electric fuel-related costs that fall outside a symmetrical cost tolerance band around the amount approved for a utility in its annual fuel proceedings. Any over/under recovery of the actual costs is determined in the following year and is then reflected in future billings to electric retail customers. The fuel rules bandwidth is currently set at plus or minus 2%. Under fuel rules, MGE would defer costs, less any excess revenues, if its actual electric fuel costs exceeded 102% of the electric fuel costs allowed in its latest rate order. Excess revenues are defined as revenues in the year in question that provide MGE with a greater return on

common equity than authorized by the PSCW in MGE's latest rate order. Conversely, MGE is required to defer the benefit of lower costs if actual electric fuel costs were less than 98% of the electric fuel costs allowed in that order. These costs will be subject to the PSCW's annual review of fuel costs completed in the year following the deferral.

In December 2017, the PSCW approved a surcharge for 2018 electric fuel-related costs. The surcharge increased electric retail revenue in 2018 by $0.5 million, or 0.13%.

In July 2019, the PSCW issued a final decision in the 2018 fuel rules proceedings for MGE to refund $9.5 million of additional fuel savings realized during 2018 plus accrued interest to its retail electric customers in October 2019. There was no change to the refund in the fuel rules proceedings from the amount MGE deferred in the previous year.

As of September 30, 2019, MGE had deferred $0.5 million in 2019 fuel savings. As of December 31, 2018, MGE had deferred $9.5 million of 2018 fuel savings.

c.2018 Tax Reform.

Customer rates approved for 2018 reflected an income tax rate of 35 percent. In January 2018, the PSCW issued an order directing Wisconsin investor-owned utilities to defer the over-collection of income tax expense as a result of the decrease in tax rate to 21 percent.

The PSCW issued an order in May 2018 to return to customers the estimated 2018 over-collection of income tax expense. The decision included a one-time bill credit on customer bills to reflect the estimate of the over-collection for January through June 2018, along with a volumetric bill credit which began in July 2018 and continued through the remainder of 2018 for the estimated remaining annual amount. MGE returned $8.2 million to customers through bill credits as of December 31, 2018.

In August 2019, the PSCW issued a decision on the 2018 tax reform proceedings for MGE to refund the remaining 2018 overcollection of income tax expense to its retail customers as a one-time bill credit. MGE returned $3.2 million in September 2019. There was no change to the refund order from the amount MGE deferred as of December 31, 2018.

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Adoption of Accounting Principles and Recently Issued Accounting Pronouncements

9 Months Ended

Sep. 30, 2019

New Accounting Pronouncements and Changes in Accounting Principles [Abstract]

New Accounting Pronouncements

New Accounting Standards - MGE Energy and MGE.

Recently Adopted

Leases.

In February 2016, the FASB issued authoritative guidance within the codification's Leases topic that provides guidance on the classification, recognition, measurement, and disclosure of leases. The new leasing standard establishes that a lease conveys the right to control the use of identified property, plant, or equipment for a period of time in exchange for consideration. Under the new guidance, lessees are required to recognize all leases with terms greater than one year, including operating leases, on the balance sheet by recording a right-of-use asset and lease liability. Prior to the authoritative guidance, only capital leases were recognized on the balance sheet by lessees. The new accounting guidance, as applied by lessors, did not change materially. In January 2018, the FASB issued authoritative guidance which provided an optional

practical expedient to grandfather the accounting for existing and expired land easements not accounted for as a lease under the new authoritative guidance. MGE Energy and MGE adopted this practical expedient.

The lease authoritative guidance became effective January 1, 2019. MGE Energy and MGE adopted the standard upon the effective date. In compliance with authorized transition guidance, MGE Energy and MGE began applying the new standard on January 1, 2019, but will continue to present periods prior to that date according to the previous authoritative standard. There was no material impact on the consolidated net income or cash flows. See Footnote 3 for further lease information.

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Pension and Other Postretirement Plans

9 Months Ended

Sep. 30, 2019

Compensation and Retirement Disclosure [Abstract]

Pension and Other Postretirement Plans

Pension and Other Postretirement Plans - MGE Energy and MGE.

MGE maintains qualified and nonqualified pension plans, health care, and life insurance benefits. Additionally, MGE has defined contribution 401(k) benefit plans.

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. The service cost component of net periodic benefit cost is eligible for capitalization within the consolidated balance sheets. 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)		2019		2018		2019		2018
Pension Benefits
Components of net periodic benefit cost:
Service cost	$	1,040	$	1,431	$	3,402	$	4,292
Interest cost		3,170		3,215		10,364		9,645
Expected return on assets		(5,054)		(6,560)		(16,523)		(19,680)
Amortization of:
Prior service credit		(26)		(11)		(85)		(33)
Actuarial loss		1,637		1,319		5,351		3,958
Net periodic benefit (credit) cost	$	767	$	(606)	$	2,509	$	(1,818)
Postretirement Benefits
Components of net periodic benefit cost:
Service cost	$	276	$	320	$	829	$	962
Interest cost		721		653		2,164		1,959
Expected return on assets		(677)		(808)		(2,034)		(2,424)
Amortization of:
Transition obligation		1		1		2		2
Prior service credit		(664)		(667)		(1,994)		(2,001)
Actuarial loss		100		122		300		366
Net periodic benefit (credit) cost	$	(243)	$	(379)	$	(733)	$	(1,136)

As a result of lower investment returns in the fourth quarter of 2018, pension and postretirement benefit costs increased in 2019. In August 2019, the PSCW approved MGE's request to defer the difference between estimated pension and other postretirement costs included in the 2019 and 2020 rate settlement and actual expense incurred. MGE expects that the deferred cost for employee benefit plans will be factored into future rate actions starting in 2021. For the three and nine months ended September 30, 2019, MGE has deferred approximately $1.3 million and $4.6 million of pension and other postretirement costs, respectively. The impact of the deferral has not been reflected in the table above.

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Derivative and Hedging Instruments (Details-1)	9 Months Ended		12 Months Ended
	Sep. 30, 2019 USD ($) Dth MWh MW		Dec. 31, 2018 USD ($) Dth MWh MW	Jun. 30, 2019 USD ($)	Sep. 30, 2018 USD ($)	Jun. 30, 2018 USD ($)	Dec. 31, 2017 USD ($)
Derivative fair values [Abstract]
Receivable, margin account balance, net of collateral posted against derivative positions	$ 1,598,000		$ 1,193,000
Collateral posted against derivative positions	700,000
Other Current Assets [Member]
Derivative fair values [Abstract]
Derivative fair value, net	1,031,000		377,000	$ 878,000	$ 894,000	$ 640,000	$ 806,000
Receivable, margin account balance, net of collateral posted against derivative positions	1,600,000		1,200,000
Commodity Contracts And Financial Transimission Rights [Member]
Derivative fair values [Abstract]
Derivative fair value, net	$ (200,000)		$ 700,000
Commodity Derivative Contracts [Member]
Gross Notional Volume of Open Derivatives
Notional amount, energy measure (in MWh) | MWh	466,760		386,440
Notional amount, decatherm measure (in Dth) | Dth	9,190,000		5,260,000
Derivative fair values [Abstract]
Asset Derivatives, fair value, gross basis	$ 749,000		$ 801,000
Liability Derivatives, fair value, gross basis	1,285,000		342,000
Collateral posted against derivative positions	724,000		0
Commodity Derivative Contracts [Member] | Other Current Assets [Member]
Derivative fair values [Abstract]
Asset Derivatives, fair value, gross basis	668,000		727,000
Liability Derivatives, fair value, gross basis	996,000	[1]	270,000
Commodity Derivative Contracts [Member] | Other Deferred Charges [Member]
Derivative fair values [Abstract]
Asset Derivatives, fair value, gross basis	81,000		74,000
Liability Derivatives, fair value, gross basis	289,000	[1]	$ 72,000
Commodity Derivative Contracts [Member] | Cash Flow Hedging [Member]
Derivative fair values [Abstract]
Collateral posted against derivative positions	$ 700,000
Energy Related Commodity Contract [Member] | Cash Flow Hedging [Member]
Derivatives Fair Value [Line Items]
Maximum term of derivative hedging contract	4 years
Financial Transmission Rights [Member]
Gross Notional Volume of Open Derivatives
Notional amount, power measure (in MW) | MW	4,282		2,252
Derivative fair values [Abstract]
Asset Derivatives, fair value, gross basis	$ 344,000		$ 241,000
Collateral posted against derivative positions	0		0
Financial Transmission Rights [Member] | Other Current Assets [Member]
Derivative fair values [Abstract]
Asset Derivatives, fair value, gross basis	344,000		241,000
Liability Derivatives, fair value, gross basis	$ 0		$ 0
PPA [Member]
Gross Notional Volume of Open Derivatives
Notional amount, power measure (in MW) | MW	1,600		2,050
Derivative fair values [Abstract]
Derivative fair value, net	$ (29,000,000.0)		$ (32,500,000)
Liability Derivatives, fair value, gross basis	28,990,000		32,530,000
Collateral posted against derivative positions	0		0
PPA [Member] | Derivative Liability (Current) [Member]
Derivative fair values [Abstract]
Liability Derivatives, fair value, gross basis	10,390,000		8,550,000
PPA [Member] | Derivative Liability (Long-term) [Member]
Derivative fair values [Abstract]
Liability Derivatives, fair value, gross basis	$ 18,600,000		$ 23,980,000

[1] As of September 30, 2019, collateral of $0.7 million was posted against and netted with derivative liability positions on the consolidated balance sheets. No collateral was posted against derivative positions as of December 31, 2018.

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Derivative and Hedging Instruments (Details-5)	3 Months Ended		9 Months Ended
	Sep. 30, 2019 USD ($) counterparty	Sep. 30, 2018 USD ($)	Sep. 30, 2019 USD ($) counterparty	Sep. 30, 2018 USD ($)	Dec. 31, 2018 USD ($)
Counterparties in net liability position or default [Abstract]
Derivative, net liability position of counterparties	$ 0		$ 0		$ 0
Number of counterparties in default | counterparty	0		0
Commodity Derivative Contracts [Member] | Fuel For Electric Generation Purchased Power [Member]
Realized losses (gains) on income statement [Line Items]
Realized losses (gains) on income statement	$ 471,000	$ (145,000)	$ 1,038,000	$ 39,000
Commodity Derivative Contracts [Member] | Cost Of Gas Sold Expense [Member]
Realized losses (gains) on income statement [Line Items]
Realized losses (gains) on income statement	83,000	0	460,000	637,000
Financial Transmission Rights [Member] | Fuel For Electric Generation Purchased Power [Member]
Realized losses (gains) on income statement [Line Items]
Realized losses (gains) on income statement	(429,000)	(150,000)	(503,000)	(625,000)
Financial Transmission Rights [Member] | Cost Of Gas Sold Expense [Member]
Realized losses (gains) on income statement [Line Items]
Realized losses (gains) on income statement	0	0	0	0
Purchased Power Agreement [Member]
Derivative collateral required to be posted for PPA [Abstract]
Minimum collateral that may be required to be posted	20,000,000.0		20,000,000.0
Maximum collateral that may be required to be posted	40,000,000.0		40,000,000.0
Collateral posted	0		0
Purchased Power Agreement [Member] | Fuel For Electric Generation Purchased Power [Member]
Realized losses (gains) on income statement [Line Items]
Realized losses (gains) on income statement	(505,000)	328,000	(1,257,000)	1,283,000
Purchased Power Agreement [Member] | Cost Of Gas Sold Expense [Member]
Realized losses (gains) on income statement [Line Items]
Realized losses (gains) on income statement	$ 0	$ 0	$ 0	$ 0